The URL can be used to link to this page

Home My WebLink About201-240 Im~~ Project Well History File Cov'~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :;J.t) L - d L¡- 0 Well History File Identifier Organizing (dOI!(~j 0 Two-Sided 1111111111111111111 ~escan Needed 1111111111111111111 OVERSIZED (Scannable) R'lCAN r Color items: ~-,. 0 Grayscale items: DIGITAL DATA 0 Diskettes, No. 0 Maps: Other items scannable by large scanner 0 Other, Noffype 0 0 Poor Quality Originals: 0 Other: OVERSIZED (Non-Scannable) 0 Logs of various kinds NOTES: BY: ~~ 0 Other ~R;-¡_'T DATE:Lf /6/ blpl VV1 P DATE4jqO/f 1111111111111111111 ~R:: YVlP --L X 30 = -:30 + Ilf = TOTAL PAGES I{ If lMR~ DATE:Lj Is/DL(s1 r11P BY: Project Proofing BY: Scanning Preparation Production Scanning ß /1'/ Stage 1 PAGE COUNTFROM SCANNED FILE: * P~GE COUN MATCHES NUMBER IN SCANNING PREPARATION~ /, v, ",'YES BY: IJATE: 7¡;~ 1/S1 Stage 2 IF 0 IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES _NO _NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: 151 (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) 1111111111111111111 ReScanned (imJividual pJ(f'J' [!"./Wd,1/.JflelJtionj ,scaiJning completed) 1111111111111111111 RES CANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Isl General Notes or Comments about this file: Quality Checked (dOIJ('\ 1111111111111111111 12/10tO2Rev3NOTScanned.wpd . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc ,.-..... ,-. AI,ASHA OIL AND GAS CONSERVATI ON COMMISSION Paul K. Berga Drilling Suprintendent Marathon Oil Company PO Box 196168 Anchorage AK 99519 / / TONY KNOWLES, GOVERNOR ~~~~E m¡ ~~~~~~~ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Susan Dionne #2 Marathon Oil Company Permit No: 201-240 Sur. Loc. 110' FSL, 1450' FEL, Sec. 6, TIS, R13W, SM Btmhole Loc. 564' FSL, 2150' FEL, Sec. 32, TIN, R13W, SM Dear Mr. Berga: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the 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. Annular disposal has not been requested as part of the Permit to Drill application for Susan Dionne #2. Please see attached CO Order 465 approving Spacing Exception. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ú .000.f~iJ/ C~echsli Taylot' Chair BY ORDER OF THE COMMISSION DATED this 21st day of February, 2002 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~ . . ~ ~ .. . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501 Re: THE APPLICATION OF Marathon Oil ) Conservation Order No. 465 Company ("Marathon") for an order granting ) an exception to the spacing requirements of ) Susan Dionne #2 20 AAC 25.055(a)(2) to provide for the ) Exploratory Well drilling and testing of the Susan Dionne #2 ) exploratory well to an undefmed gas pool ) February 14,2002 IT APPEARING THAT: 1. ~arathon Oil Company ("Marathon") by letter dated December 13, 2001, and received by the Commission on January 9,2002, requested an exception to thewell spacing provisions of 20 AAC 25.055(a)(2). The exception would allow the proposed Susan Dionne #2 exploratory well to be drilled and test produced at a bottom hole location that is closer than 1,500 feet to a property line where ownership changes. 2. The Commission published notice of opportunity for public hearing in the Anchorage Daily News on January 15,2002, pursuant to 20 AAC 25.540. 3. No protests to the application were received. FINDINGS: 1. The Susan Dionne #2 well will be drilled as a directional hole from a surface location 110 feet from the south line (FSL), 1,450 feet from the east line (PEL) of Section 6, TIS, R13W, Seward Meridian (SM) to a bottomhole location of 564 feet FSL and 2,150 feet FEL of Section 32, TIN, R13W, SM. 2. An exception to the well spacing provisions of 20 AAC 25.055 (a)(2) is necessary for the drilling of this well. CONCLUSION: 1. Granting a spacing exception to allow drilling and testing of the Susan Dionne #2 well promotes efficient development and will not result in waste. 2. Marathon's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(2) for the purpose of drilling and testing the Susan Dionne #2 well is approved. 3. Granting this spacing exception is reasonably necessary to provide Marathon with an opportunity to establish the volume of gas reserves in the general area. . f' ~ ~\ . ¡. NOW, THEREFORE, IT IS ORDERED: Marathon's application for exception to the well spacing provisions of 20 AAC 25.055 (a)(2) for the purpose of drilling and testing the Susan Dionne #2 well is approved. If the well proves capable of hydrocarbon production, regular production will not be permitted until the Commission establishes a drilling unit for the pool and issues an order integrating the interests of owners within the drilling unit, absent voluntary integration by the owners. DONE at Anchorage, Alaska and dated February 14,2002. ...ø"",.c-~~ ø~'~1.j~ 0 It ~ Á~~~;~~}~\Ti7i'~~ Q l ~~ ~~t?~:",""~~,~_~_~.1 ~ '¡ ,"'#'_:""-\""-'--"¡-"-;':"".',~ . .,'" "'. '¡- "'...",,'; J: Jb N C ' ' _.~~.,ø ""w"..""",;""..-..."""'" Cl~ O~l~~' ,t)~~ Cammy Oec1ðli Taylor, ChairQ ~on Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission ~/ ,vi - Þk~'r Julie M. Heusser, Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An afflX.."ted person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by non action of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). Conservation Order No. 465 February 14, 2002 Page 2 of 2 -f , '--- .1~m~E TI} ~~~~~~ OFFICE OF THE GOVERNOR OFFICE OF MANAGEMENT AND BUDGET DIVISION OF GOVERNMENTAL COORDINATION LJ SOUTHCENTRAL REGIONAL OFFICE 550 W. 7TH AVENUE. SUITE 1660 ANCHORAGE. ALASKA 99501 PH: (907) 269-7470/FAX: (oo7) 269-3981 LJ CENTRAL OFFICE P.O. BOX 110030 JUNEAU. ALASKA 99811.0030 PH: (907) 465-3562/FAX: (oo7) 465-3075 February 13,2002 Charles A. Underwood, Jr. Marathon Oil Company P.O. Box 196168 Anchorage, Alaska 99519 SUBJECT: REVIEW NOT REQUIRED Susan Dionne-2 Dear Mr. Underwood: ~ a OJ-dc!a TONY KNOWLES, GOVERNOR . PIPELINE COORDINATOR'S OFFICE 411 WEST 4TH AVENUE. SUITE2C ANCHORAGE. ALASKA 99501-2343 PH: (oo7) 271-4317/FAX: (oo7) 272-3829 The Division of Governmental Coordination (DGC) information regarding the' above referenced project. Based upon the information you provided, your proposed project does not require a state review for consistency with the Alaska Coastal Management Program (ACMP). You are not relieved from obtaining required permits and approvals from state, federal or local agencies, before you begin the proposed work. Nothing in this letter excuses you from compliance with other statutes, ordinances, or regulations that may affect any proposed work. This decision is ONL Y for Ü1e proposed project as described. If there are any changes to the proposed project, including its intended use, prior to or during its siting, construction, or operation, contact this office immediately to determine if further review and approval of the revised project is necessary. Thank you for your cooperation with the ACMP. --.Á ~nc~~Â 1 , dÎ JL-. ~r~ " Kaye Laughliy( Project Review Coordinator Cc: Daniel Bevington, Kenai Peninsula Borough Matt Rader, ADNR (DO&G) Mark Fink, ADF&G Tom Maunder, AOGA Bob Blankenberg, ADEC . 01-A35LH 0 printed on recycled paper ~ ~ January 10,2002 Mr. Steve Davies AOGCC VIA email RE: Marathon Susan Dionne 2 Pemit Application Surface Casing Depth Within Marathon's proposal to drill the above mentioned well, the surface casing setting point of2750'(2,515' TVD) is designed to meet the AOGCC requirements under Title 20 AAC 25.030. During the AOGCC review of the project, a new request under 20 AAC 25.030(c)(3) has been made to quantify the total dissolved solids (TDS) of formation waters in the vicinity of the casing shoe (2,515 ft.). This requirement has been used for injection wells but this is the first time an Application for Permit to Drill review has carried this requirement for a Marathon operated well. The following facts are understood regarding this project: The surface casing will be set into the Tertiary Beluga formation (Figure 1). The drinking water in the area of the project and across the entire Kenai Peninsula is from Holocene glacial sand and gravel (Figure 1) which is higher quality (less than 1000 ppm TDS, Figure 2) than the water from the deeper Tertiary sandstones. The deepest water well in the area (SC, TIS R13W and SB, TIN R13W) is 276 feet in depth (Figure 3), while the deepest water well on the Southern Kenai Peninsula is less than 500' deep (Cook Inlet Areawide 1999 Oil and Gas Lease Sale Final Finding of the Director January 20, 1999, Chapter 5, Page 48.; Figure 4). The Tertiary section is a known hydrocarbon bearing interval that is not compatible with drinking water. The shallowest indication of possible hydrocarbon content is at 1100' MD (Figure 1) in the Susan Dionne 1 well. TDS calculations (EP A approved Rw calculation using the Resistivityl Porosity method for Rw's greater than 1.0 ohmm; Figure 2) for the sandstone intervals around the surface casing shoe range from 1300 ppm to 2700 ppm. Because the TDS is less than 10,000 ppm, these calculations represent an underestimate of TDS due to the effect of reduced influence of Sodium Chloride and the increase of other solids on a percentage basis. A water analysis of this water or one of similar origin and depth is not available to determine the concentration of other components that contribute to TDS. EP A criteria for exemption of an "underground source of drinking water" (40 C.F.R 146.4) can occur and applies in this case if "a freshwater aquifer ... is currently not serving as a source of drinking water and .. . cannot be used in the future as a source of drinking water because ...it is at a depth which makes Marathon Susan Dionne Permit Application Surface Casing Depth Page 1 RECEIVED JAN 1 1 ! ¡ Alaska Oil & Gas Cons. Commission Anchorage ~ ~ recovery of water for drinking water purposes technologically impractical. economically or Given the above information, the surface casing depth proposed for the Susan Dionne 2 project (2750' MD;25l5' TVD) is sufficient to protect any plausible and economic drinking water in the area even though the TDS for the Tertiary sandstone beds around the casing shoe calculate to less than 1300-2700 ppm. Your consideration of this information and approval of the project are greatly appreciated. Please contact me if you have additional questions. Best regards, David L. Brimberry Senior Geologist cc: Eric Ward, Marathon HES Attachment - sd 1- TDS Jec _figures. ppt Marathon Susan Dionne Permit Application Surface Casing Depth Page 2 ~~ /~ ~ ~(Jif ,~v ~ ~ ,,\- , "" ~~~ \J#" f!>'Þ ,jj.rft Q.,: ^?Jt- ()~Q" ~' 'itG :;;.# ~ I"""' .r if :>:.: :>~ :.;;::; =.~) :~~:: - .. - - ~ '- ~ '- ,-- - L. ------- ~- ---- - ------- -r--- - 1 fir-- ~ ~ ~ GC-: ~ ---- - - ---r- ~ -(r-r-- ~ - ~'f'" ----LJ~L:';'J""' ~ -..r-- -..r-- Ÿ-i OC": .. i ~~:OC,.. ~~ . ~ ===== ~~ f I..-.JV- -..r-- ¡m..Š,n ;:;;,. ~ í "..;u ' ..,.-- ~~ ~ ~~,C:r ?== -$,~ ..; ~ ~ ' ~,^ ,';..r-- ~ ~ ---r-- ~.^" ~ j~ ~ ~,~-~"~'J" i ~ .. ---r-- $' -===== .) ~ " ~ . ---r-- ~~"" ----'"' J'~' '~'!" ~ ¡., ~- ---r-- OHW,j 1000.5 vi\' .. ., ~ ~ .' -t ~ :< ) II , , ..- ~ -> - ~ { Ib~ \ ? ~ '/-' ~ j.. { '"\ /" ~ r :» "":- ~ .,Jo , J>} .. " .; ~ ." ~ " I \ #"""""1> t., :t "- ( (J-' .. ~ Ilûlocene (ì lì ~al1as at fi. Un,] :' 'I Gravels , 625 TDS Tertiarv '-- c: \-J er ìiI1g ~~')... "> 't'» "i#~~ ~ "> r...~~~ \~ ,_.(:'¡$~ ,) t-"; tt~ r.§'? ",;60-- "",'1-'-,., ...-\,r¡,' ì;J';¡" ~v ,:-tJÞ ~1? r--.. ~ Figure 2 Marathon Susan Dionne 2 Permit Application Calculated Total Dissolved Solids of Selected Sandstones January 2002 De pth 320 1882 2255 2493 2610 Rw ohmm (Res.! Phi) 9.5 60 F .__?_:!?__@~Q_.E- .- 2.13 9 F 1.59 96 F 2.9 97 F TDS ppm 625 1600 1800 2750 1300 TVD 320 1880 2254 2491 2608 C\~\.. "' 1.\> . .~~ \.). ~~ ~ Ç¡<S\\'" 'J ~ rtJ1.'Po G,. ,. ..f\f?J rß'r- ~.'."" <¡j.v;r ",,-,' ,..:~~,' ~,:~FJ"- i,"V ' '..".:>~ ,»tJ' " , ,,-......., ~ Figure 3 Marathon Susan Dionne 2 Permit Application DNR Registered Water Wells in Area of Project January 2002 TOTAL COMPLETION OWNER SECTION DEPTH DATE T1 S-R 13W 8 50 1976 Mallette 5 200 1980 Wallis 5 127 1984 Wallis 5 127 1984 Tho nto n 7 58 1989 7 58 1989 Jones 7 55 1990 Martin 18 110 1 Jones 5 101 1983 T1 N-R 13W Bouwens 26 66 1981 Bouwens 26 156 1981 Martin 23 80 1982 Marth 33 276 1984 ,~_~~!e 34 94 1985 Blossom 23 54 1987 12 197 1989 Prion 23 33 1991 Tikka 12 75 1979 Tikka 12 97 1985 ? 107 1987 Oskolkoff 23 104 1 34 80 1988 34 146 1983 ~~':L "'\ "ù.~~~ .'\ r<'.~ . '\- '\;'\ , ~.i" \<' - 1;.'Þ' ," ....\fJ .,~~ " (ý"r "'";(;>~ .--:,,~\& ~~\.," "1.t-V \1).'Þ"<' ~ " , . r--.. ~ Figure 4 Marathon Susan Dionne 2 Permit Application Typical Cook Inlet Welbore Diagram from "Cook Inlet Areawide 1999 Oil and Gas Lease Sale, Final Finding of the Director January 20, 1999, Chapter 5, Page 48 January 2002 " Depm m and Ga£ ..'- ProductIOn 0' . ! ! ; ! ¡ i !i i i i i ,~ ,1000 -SO' ("'Æment-: . Steel CaslT\g- i ; ¡ ; r I Cement---.. ¡ ,2(1)0 .2600'~ Steel Casing ~( <\000 DriUmg Mud .._-'-~ -,000 Cement~ ~ Production -Tubing ,5000 -ooco ,7000 ,ðOOO Packer - . ,---- ¡---Oil Perforations - ;-air& - ¡/:-':)j---Gas Cement ~ -.;¡¡¡;;;.--- Stee' ~ Productlon~' Casing '$,000 W.llb«. Nolto See/. ,10"'" ~ Geolog'21<E!Y__- 1':--'1 Conglomerate ~ Coal D Sand [E:[¡ Shale "Ú . Geolog¡c "'t,4,.~",i!fií,¡l,;.,~\~,~e -\:~-:':~~~:~i:~;;;.(:<~ : i ¡II 500'--+- ,0. , . .' .edlme.to ,~,' t 2 Maximum f::'f::ô'::,,'::"":::,,':,'-: 1Þ:1 Water Well Depth "~::'"!",":":~::"",:""!"" &"1 (Southern Peninsular.', ."'~' .~':. '0' :-:~.'.' :o':":.~ .";,'8tedÎaj¡F~~~~",'.';,' O"O"""'7"'~"Ó" -- ..... ....,. '" '" ." , . ."- . ,", . ;.. . ,<~, . P. ' ~, = 2,100' ..~;!:=#'~~~~=.~~:~~=~~ ShaliowestUnderground'o" . b' . '0' . ' t' . ".' , '0' . InjedionDisposalWell '.~':.~::.;'::.~'::~'::,~', on Kenai Peninsula :"..":C'~,:.,:,,~',:.:.,;;:,',:,,:,.:, (~F~~~~:~~:;~:~~~~~ -"'.,~,.".,-=,,~,,~, ,;. . .0. . po, , .~ . , "" . . ~., ø. ~:,:.;ìi~~~':F~~!;'~':~'; g .. .. '" "'," ~ ,0 ',,"';":q':.. ~':.':':.ð::¿::,'7'::."::,.', II 'O"."~"O""~"." Ij Gas Zones) ..,;,:,,'.;.;~,,:"'--:;':';':"',,';';;";""; II: ~ ~77"~-.-o77";;-,-:-:~.-,':;:':-.-;: to '.:":.,~':';'::,~"':":~'::,~', ¡ ='========'=====~== :: "."..q..'..~..,'.A ~ "?,,~..':'..:'...'7,.e':" ¡.. ~~~~~~~~~~~~~~~: "'.ò."',¿.'.',:::"é"".'."";':".~, '0"."-"0"'="'.' ,~ . . , '.' '& . . '," . . '.' . 'l . . : t ~t:~~=~;,=:~?:~~: I ~--~-~--~--~--~- , , , . . Primary Oil :?~~'::.:~:;,~~;":-,:::':: Zones "..o.,>.."',.._..~., ~':,~.~~~.!o~~~..;.':.;. ~~-~-~--~--~--~- :"',-:7<7" ;:.t ';;ffi::{ ,-. 7.7":"' d ' ',~' ,"' "C. , ',,"' , '.' , ~. : '~";"¿"~"'¿>"'~' í , ~ o"~"~""'="',"'e' Q ..,..".....,...., Ij , .,. , . 'Cretaceoas "" . '.' í C :g{5:E:f 1'~1 ~~L. \. ~ .~~~ ~~~ \. (~~~ Cook Inlet Well bore Schemallc ADNR 8196 - ,~ r"\, M Marathon '~"THo: Oil Company ~ , Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 December 5, 2001 Mr. Tom Maunder AOGCC 333 West. 7th Ave. Suite 100 Anchorage, Alaska 99501 Reference: Susan Dionne #2 Dear Mr. Maunder: Enclosed is the Permit to Drill on Susan Dionne #2 with accompanying Drilling Program, maps and drawings. Please contact me if you would like further information. I can be reached at 564-6319 or pkberQa@marathonoiLcom. Sincerely, ~ RECE \\lED DEC \) 5 200\ commiSß\O1\ Oil & Gas cons. Nasl¡.a ~1\C"Qtage Peter K. Berga Drilling Superintendent Enclosure 1a, Type of Work Drill!]] Re-EntryD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4, Location of Well at Su rface 110'FSL, 1450'FEL, Sec. 6, TiS, R13W, S.M. Re-DriliD DeepenD STATE OF ALASKA ~ g\cmn\dr,g\s~J;.4-1Ïtll~cP~xls ~-\SKA OIL AND GAS CONSERVATION C"-,,JMISSION ~?-/ 'Ð ~ tr PERMIT TO DRILL Jþ-" {o:¿. 210 AAC 25.005 1b, Type of well. ExPlorator{~:f~~ StratigraphicTesD serviceD Development Ga{8J Single ZonO 5. Datum Elevation (DF or KB) 10. Field and Pool 153 KB feet Tyonek Development OiD Multiple Zone{]] At top of Productive Interval 4846'FSL, 952'FEL, Sec. 6, TiS, R13W, S.M. 6. Property Designation ADL-359242 ~ ~ /'iltJ ßI> 7. Unit or Property Name 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 8. Well Number Susan Dionne # 2 At Total Depth 564'FSL, 2150'FEL, Sec. 32, T1N, R13W, S,M. 12. Distance to Nearest 13. Distance to Nearest Well Property Line(unit boundary 75 feet 16. To be Completed for Deviated Well: Kickoff Depth 1000 feet Maximum Hole Angle 18. Casing Program Size 9. Approximate Spud Date 02/15/02 14. Number of Acres in Property Amount $200,000 15. Proposed Depth (MD and TVD) 5280 feet 2433 10394' MD/8000' TVD feet 17, Anticipated Pressure (see 20AAC 25.035 (e) (2» 52 0 Maximum Surface 2658 psig at Total Depth (TVD) 8000' Hole Casing Weight Driven 133/8' 68 12-1/4" 95/8" 40 81/2' 7" 23 7" 41/2" 12.6 Specifications Grade Coupling K-55 PE L-80 BTC L-80 BTC L-80 Hydril 521 Setting Depth Top Bottom Length MD TVD MD TVD +/-130' 0' 0' +/-150' +/-150' 2750' 0' 0' 2750' 2515' 8130' 0' 0' 8130' 5900' 2464' 7930' 5730' 10394' 8000' Quantity of Cement (including stage data) 553 sx 635 sx 220 sx ReceiveD DEC 0 5 2001 Alaska Oil & Gas Cons, Commission The Susan Dionne #2 will be directionally drilled to an estimated total depth of 10394' md, 8000'~ an existing pad on the Dionne property.The hole below 7" casing will be drilled with a pilot bit and reaming assembly that will yield a 7" hole. Marathon's drilling rig will be used to drill and complete this well. The following documents are attached: Drilling Program, Area Maps, Location Map, Structure Map, Surface use plan, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing Fee[8J Property PlaŒ: BOP Sketch!]] Drilling Fluid prograrrŒ] Time vs Depth PloD Refraction AnalysiU 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ø ~ Title Drilling ~~:~~~n~:ndent Commission Use Only I Permit Number " ff.... IAPI Number . ~^O. !APproval Date "1 1\ 0, 1. Isee Cover Letter .2.D /- 2- 7' L) 50-- 13'3~ ZD~I..J:::)"(J{) !JU/\ II, For Other Requirements Conditions of Approval Samples Required esJVes DNo Mud Log Required ,~Ves DNo Hydrogen Sulfide Measures DYes ~No Directional Survey Required D(ÍVes DNo Required Work.ing Pressure for BQPF DZM D3M DSM D 10M D1SM Other: 'T.e~t BoeE -leD; ?ol(lS~ fJ.Bç.¿, \,U~ ':JC)~~~",-f...~ ~~~\C~~~<t~~ "J\(j.. ~C)'~.&-Q)\A¡ . fI~lC1a IgneU y -- , ' tarr'my Oechsli by order of . l},).,. . \ j\ J Commissioner the CommiSSion Date f'.. í/I ¡J if' 0 RIG I N A L Sù Jmit in Triplicate Diverter Sketcr[K] Seabed ReporD Drilling Prograrr0 20 MC 25.050 Requirementu Signed p, K. Berga Date 12/5/2001 Approved by Form 10-401 Rev. 12'1-85 ~ . ~ Marathon' Oil Compa Alaska Region Drilling Program Well: Susan Dionne #2 Area: Ninilchik Drilling Contractor: Inlet Drilling Company Geologic Program Target Locations FSL FEL Block Surface 110' 1450' Sec. 6, T1S, R13W Tyonek 1926' 198' Coordinates from North East Wellhead Tyonek T-2 2736' 282' Coordinates from North East Wellhead Tyonek T-3 top 4736' 498' Coordinates from North East Wellhead Target 4750' 500' Coordinates from North East Wellhead Tyonek T-3 pay 5122' 573' Coordinates from North East Wellhead Bottom Hole 5700' 700' Coordinates from North East Wellhead RKB Elevation: RKB to MSL 153' GL to MSL 132' Total Depth: TVD 8000' 10394' Max. Angle MD Abnormal Pressures: None Anticipated Subnormal Pressures: None Anticipated Coring and DST's: None Mud Logging: ~ epared By: Approved By: Date: P.K. Berga 12/5/01 AFE: To be issured Jan 2 Rig: Glacier Drilling Rig No.1 Depth MD TVD Tolerance 21' RKB 21' RKB <;S(~ It ;} "tS()/ ~ 4250' 3425' 5275' 4050' 7870' 5680' 7892' 5700' ,'\ 'ès\~t"\..::.~ 8730' 6450' 10394' 8000' 52.51 Course 7.00 '~ Contractor: Epoch Start Depth: Below Surface Services: Basic with GCA, shale density, temperature in and out, sample collection. 10' samples below Intermediate Logging Program: Contractor: INTEQ for LWD, Schlumberger for Wireline Surface Intermediate Production LWD NA Res/Neu/Den NA Wireline Logs GR/CNL/LDT/AIT/NGT SWC/CMR/RFT/FMI (TLC) GR/CNL/LDT/AIT/DSI/NGT SWC/CMR/RFT/FMI (TLC) Susan Dionne #2 Drilling Program Page 1 of 9 ~ .--...." Drilling progræm Summary Drive Pipe: Surface: Intermediate: Production: / MIRU Glacier Drilling Rig No.1. Drive 13 3/8H O.D., 68#, K-55 casing to +/- 130' BGL, 150' RKB. Install 13 3/8H SO X 13 5/8H 5M starting flange, and 13 5/8H 5M X 21 ~H 2M DSA. NU and function test 21 ~H 2M diverter system. / Drill 12 ~H hole to +/- 2750'MD/2515'TVD per the attached directional program. Run and cement 9 5/8H casing. WOC. Cutoff 9 5/8H and 13 3/8H casing. Install 9 5/8H Slip Lock X 11H 3M X 11H 5M multibowl wellhead. NU 11H 5M X 13 5/8)! 5M spacer spool and 13 5/8H 5M BOPE. Test ~PE and choke manifold to 250/3000 psi., Set wear bushing. Test casing to 1500 psi. Drill ~ float equipment and make 20'- 25' of n~ hole. CBU. Test shoe to leakoff (15 ppg anticipated). Drill 8 ~H hole to 8130'MD/5900' TVD as per the attached directional program. Run logs as per Geologist. Pull wear bushing. Run and cement 7H CaSing~r the attached program. Backout landing joint an. d instal} seal assembly. Test seal assembly to 3000 psi. Test BOPE to 250/~ psi. Test casing " - " to 2700 psi. Install wear bushing. 3Q':'û / Drill float equipment and 20' - 25' of new hole. CBU. }Øst Shoe ~U leakoff (15 ppg anticipated). Drill a 7H dual diameter hole to 10394'MD/8000' TVD using reaming while drilling BHA as per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 4 ~H liner and cement per the attached program. Clean out to top of liner and test lap to 2700 ps~. Clean out / liner and test to 2700 psi. Displace mud with completion fluid. Run tubing and land hanger. Set BPV and N/D BOPE. N/U tree and test. RDMO drilling rig. Casing Progræm API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (psi) (psi) (K lbs) I (MD) 9 5/8H 0' 2750' 40 L-80 BTC 12 1/4H 5750 3090 979 7H 0' 8130' 23 L-80 BTC 81/2H 6340 3830 588 41/2H 7930' 10394' 12.6 L-80 H-521 7H 8430 7500 227 Make sure 9 5/8" and 7" casing float equipment is PDC drillable. All tubulars are new. Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 9 5/8H 40 L-80 2515' 18.8 8.6 2300 2.72 2.46/ 3.32 7H 23 L-80 5900' 17.0 8.6 1748 1. 42 1.17 1. 79 4 1/2H 12.6 L-80 8000' 15.0 8.6 2658 3.11 1. 74 1. 79 Susan Dionne #2 Drilling Program Page 2 of 9 ~, ~ Directional Program Directional Co: Baker Hughes INTEQ KOP: 1000' Direction: 7.0 Gyro Co: Build Rate: 3.0 To: 52.51 deg @ 2515' TVD Drop Rate: 3.0 To: 21. 36 deg @ 6142' TVD Drop Depth: 7353' MOl 5316' TVD Gyro Survey Required: Magnetic Multishots Required: Use MWD surveys below drive pipe General Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. Surface Casing @ 2515' TVD MASP = (FG + SF) * 0.052 * TVDs - (GG * TVDs) MASP = (18.8 + 1.0) * 0.052 * 2515' - (0.115 * 2515') MASP = 2300 psi ~ntermediate @ 5900' TVD MASP = «(PP * .052 * TVDtd) - (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) MASP = (8.6 * 0.052 * 8000) - (0.3 * 0.052 * 9.5 * 8500) - (0.7 * 0.115 * 8000)) MASP = 1748 psi Production @ 8000' TVD MASP = PP * 0.052 * TVDf - (GG * TVDf) MASP = 8.6 * 0.052* 8000' - (0.115 * 8000') MASP = 2658 psi 7 Susan Dionne #2 Drilling Program Page 3 of 9 cementing Program Surface Casing Size: 9 5/8" Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: Production Casing Size: 7" Lead Slurry: Top of Cement: Specifications: Compress Strength: Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: Production Liner Size: 4 1/2" Tail Slurry: Top of Cement: Specifications: Compress Strength: Total Volume: ~ "-, 855 ft3 Sx: 553 sx, cf: 1316 Page 4 of 9 ft3 715 ft3 ft3/sx, Sx: 210 sx, cf: 449 ft3 psi in 24 Density:~ ppg, Yield:~ 2550'MOI 2385' TVD - - Class G + additives Mixed wi fresh water 500 psi in 10 hrs, hrs Contractor: BJ Services 700 .,r Density:~ ppg, Yield:~ ft3/sx, 5275'MOI 4050' TVD - - Class G + additives Mixed wi fresh water Sx: 425 sx, cf: 489 ft3 377 ft3 ft3 Note: Standard policy is to pump a minimum of 50% excess without a caliper log and 25% excess with a caliper log. Setting Depth: 2750' MOl 2515' TVD Annular Volume 0' to 2750' with 12 1/4" gauge hole: ./ Density:~ ppg, Yield:~ ft3/sx, --.9. ' MO I --.9.' TVD Class G + additives Mixed wi fresh water 500 psi in 8 hrs 1316 50% Open Hole Excess, WOC Time: 8 hrs Susan Dionne #2 Drilling Program ft3, Setting Depth: 8130' MOl 5900' TVD Annular Volume 2550' to 8130' with 8 1/2" gauge hole: ./ 1450 psi in psi in hrs 24 12 hrs, 3700 938 ft3, 25% Open Hole Excess, WOC Time: 8 hrs Setting Depth: 10394' MOl 8000' TVD Annular Volume 7930' to 10394' with 7" gauge hole: Density:~ ppg, Yield:~ 7930'MOI 5730' TVD Class G + additives Mixed wi fresh water 500 psi in 8 hrs, ./ ft3/sx, 220 SX, cf: 524 psi in 24 hrs 524 ft3, ~% Open Hole Excess, WOC Time:~ hrs '- . ~, r--.., Diverter and BOP Program The diverter system will consist of a 21 %", 2000 psi annular preventor and a 16" O.D. non- bifurcated vent line. The vent line will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventer with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas separator. Casing Casing Test Size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) Drive Pipe 13 3/8" n/a n/a (1) 21-1/4" 2M Annular w/ HCR Valve Function 1500 (1) 13-5/8" 5M Annular 250/3000 Surface 9 5/8" 2300 13-5/8" 5M Blind ram ..... (9.2 (1) 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 2700 (1) 13-5/8" 5M Annular 250/3000 Intermediate 7" 1748 5M Blind ram ........- (9.8 (1) 13-5/8" 250/3000 ppg (2) 13-5/8" 5M Pipe ram 250/3000 mud) 2700 (1) 13-5/8" 5M Annular 250/3000 Production 4 ¥>" 2658 5M Blind ram ........- (9.8 (1) 13-5/8" 250/3000 Liner (2) 13-5/8" 5M Pipe ram 250/3000 ppg mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up or (3) AOGCC requirements. 9-5/8" Surface Casing at 2515' TVD CTPMASP = 2300 psi CTPBurst = 5750 * 0.7 - ((9.2-8.3) * 0.052 Test to 1500 psi per AOGCC regulations * 2515) = 3907 psi 7" Intermediate at 5900' TVD ,,/ CTPMASP = 1748 psi Test to 2700 psi due to running liner CTPBurst = 6340 * 0.7 - ((9.8-8.3) * 0.052 * 5900) = 3978 psi 4 y~ production Liner at 8000' TVD / CTPMASP = 2658 psi Test to 2700 psi CTPBurst = 8430 * 0.7 - ((9.8-8.3) * 0.052 * 8000) = 5277 psi Susan Dionne #2 Drilling Program Page 5 of 9 "~, Mud Program Contractor: MI Drilling Fluids Interval (MD) Mud Weight From To (ppg) 0' 1000' 9.0 - 9.4 1000' 2750' 9.0 - 9.4 2750' 4250' 9.6 - 10.0 4250' 8130' 9.6 - 10.0 8130' 8730' 9.6 - 10.0 8730' 10394' 9.6 - 10.0 ~ 8 - 10 Mud Type FW Gel FW Gel FLO PRO/KCl (30,000 PPM Cl) FLO PRO/KCl (30,000 PPM Cl) FLO PRO/KCl (30,000 PPM Cl) FLO PRO/KCl (30,000 ppm Cl) below 30,000 ppm. Corrosion inhibitor for torque and drag reduction. <8 Water Loss N/C - 14 8 - 12 10 8 - 10 See attached mud program. Chlorides must stay to be used at all times. Use lubetex as needed Wellhead Program Manufacturer Model Tubing Head Tubing Hanger ABB Vetco Gray MB 150 Split Multibowl System 11" 3M X 11" 5M 11" 5M 9 5/8" Slip Lock X 11" 3M Detailed Drilling Procedure Fo~tion Leakoff Test / Surface and Intermediate casing shoes will be tested to Leak-off. strings, test BOPs and casing to the specified pressure listed in test and record volume required on the drilling report. Prior to drilling out of casing the BOP Program section. Plot Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume shou~d be kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. Susan Dionne #2 Drilling Program Page 6 of 9 ,/"""', r"'. Bit Program The following guidelines are recommended for use on this well. Actual drilling conditions and dull grading should be used to select the proper bit for the next interval. If problems are encountered with 7" reaming while drilling, we will evaluate switch back to 6 1/8" single diameter bits. Interval Bit Size IADC WeB RPM (MD) (in) Bit Model Code (k lbs) 0' - 2,750' 12 1/4" STC FGS+ 117 10130 220 2,750' - 8,130' 8 1/2" To be determined 8,130' - 10,394' 4 3/4" HTC STR444 with M133 8 100-350 7"DOSRWD46.000 Drill String Item 3 '12" HWDP, 3 '12" IF 4", S-135, HT 38 5 'h" HWDP, 4'12" IF Ppf 24.4 15.53 Makeup Torque Max Pull - Premium 12,000-13,200 ft.-lbs. 13,500-19,800 ft.-Ibs. 49.3/53.6 29,000 ft.-Ibs. 248,400 lbs. 403,500 lbs. 543,000 lbs. Hydraulics Program Rig mud pumps available are shown below. Install 5" liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oilwell A 600 PT 4 '12" 8" 3207 1.6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 Oilwell A 600 PT 5 'h" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Rate Standpipe Nozzle Depth Hole Size (gpm) Pressure AV ECD Size (MD) (in) (psi) (fpm) (ppg) (32 Us) Remarks 2500' 12 1/4" 568 2046 105 9.7 18,16,16,12 Motor Drilling 8450' 8 1/2" 459 1474 220 10.1 18,18,20 Motor Drilling 11979' 7" 291 2294 194 11.3 12,12,12,10,10 Motor Drilling Note: 5 '12" liners are recommended for surface hole section and 5" liners are recommended for the intermediate hole section. 4 '12" liners are recommended for the production hole section.. Susan Dionne #2 Drilling Program Page 7 of 9 '- , ,/""', /""""" . OPERATIONAL PROCEDURE 1. MIRV the drilling rig. Drive 13 3/8" conductor. After/completion of drive program. NU 21 ~", 2M diverter system. Install 13 3/8" SO X 13 5/8" 5M sta~ing flange, and 13 5/8" 5M X 21 ~" 2M DSA. NU 21 ~" 2M diverter system. Function test diverter and HCR valve. Record test on IADC book. 2. PV and stand back 4" DP and 5" HWDP. Note: drift pipe while picking up~ PV BHA #1 as per the Directional Driller. Directionally drill 12 ~" hole to 2750' MO/ 2515' TVD per the attached directional program. Backream each stand. Monitor torque and drag to indicate hole cleaning problems. Pump hi-vis sweeps and raise the mud YP as necessary to clean the hole. Start out 9.0 ppg mud weight. Keep weight below 9.4 ppg. with 3. At TD, pump a hi-vis sweep and circuate the hole clean. Short trip to shoe. TIH and circulate the hole clean, raising vis as necessary for hole stability. POOH. Notify AOGCC of up coming cement job 24 hours in advance. 4. Locate casing swage and safety valve. Function safety valve and place function test in IADC book. RV and run 9 5/8" casing as follows: a). (1) jt 9 5/8", 40 ppf, L-80, BTC with float shoe. b). (1) jt 9 5/8", 40 ppf, L-80, BTC with float collar in Box (Bakerlock all connections to top of float collar) c). Fill pipe and circulate thru float equipment. d). Run sufficient 9 5/8", 40 ppf, L-80, BTC to run pipe to TD e). MU circulating head and test lines to 3000 psi. g). Circulate and condition mud. Record on rig floor. 5. Check with Anchorage office on centralizer placement. ./ Cement casing as per the attached cementing program. job will be done. WOC. If no cement is circulated to surface a top 6. ND diverter. Cut off 13 3/8" sliplock starting flange. Rough cut 9 5/8" casing. Slip on 9 5/8" Slip Lock 11", 3M XlI", 5M MultiþG~~t,. head. seal to 2000 psi. NU 11" 5M X 13 5/8" 5M spool. NU an7~Test BOPE. Test Install wear bushing. InstallS" liners in both mud p~ PU 8 ~" bit and BHA # 2 as per the Directional Driller. Pump thru bit and MWD at drilling Record pressure and rate. TIH to float collar. Drill float equipment and 20'-25' of new formation. circulate hole clean. Test shoe to leakoff. Estimated EMW is 18+ PPG. Drill if leakoff is 15 ppg or greater. Displace to FLO PRO mud system before 4250' md. ahead casing. Final cut 9 5/8" Inject sealant and ~st casing to 1500 psi. 7. rate. 8. Drill 8 ~" directional hole to 8130' MO / 5900' TVD. Backream each stand. At TD, short trip to the shoe. Run logs as per Geologist. TIH and circulate the hole clean. POOH. ~trieve wear bushing. Install 7" casing rams in upper rarn. Test door seals to 250/3000 psi. 9. Locate casing swage and safety valve. Function safety valve and place on rig floor. function test in IADC book. RU and run 7" casing as follows: a). (1) jt 7", 23 ppf, L-80, BTC with float shoe. b). (1) jt 7", 23 ppf, L-80, BTC with float collar on top. Bakerlock all connections to top of float collar c). Check floats and circulate thru shoe d). Run sufficient 7", 23 ppf, L-80, BTC e). 7" fluted mandrel hanger w/ 3' BTC pup joint f). 7", 23 ppf, L-80, BTC landing joint g). MU circulating head and test lines. h). Circulate and condition mud. Reciprocate pipe while circulating. Record Check with Anchorage office on centralizer placement. 10. Land hanger and visually verify. Cement 7" casing per the attached program. Do not overdisplace more than ~ of shoe joint volume. Bump plug w/ +500 psi over displacement pressure. Check floats. WOC 11. Back out landing joint, watching hanger to ensure backing out correctly. Drain BOP stack and wash out head. Set 7" packoff and test ~3000 psi. Change out casing rams to 4" drill pipe rams. Test BOPE. Test casing to 2700 psi. Install wear bushing. 12. PU 3 ~" HWDP and additional 4" drill pipe. PU 4 3/4" bit, 7" reaming while drilling sub, and BHA #3 as per Directional Drillers. Pump thru bit, motor, and MWD at drilling rate. Record pressure and rate. TIH to float collar. Susan Dionne #2 Drilling Program Page 8 of 9 ,~ ."""--"", 13 . Drill float equipment and 20'-25' of new formation. Circulate hole clean. Estimated EMW is 16+ PPG. Drill ahead if leakoff is 15 ppg or greater. Test shoe to leakoff. 14. Drill 7" directional hole to 10394' md/8000' tvd as per the directional program. Backrearn each stand. At TD, circulate the hole clean and POOH for logs. Log well as per the Geologist. 15. If decision is made to run production liner switch and Vendors to put the proper AFE number on all of Circulate and condition mud. .et POO. .R.etrieve wear ram. Test door seals to 250/ ps~A- ø\f-Lur", MU plug dropping head on joint of drill pipe and lay in ./' Run 4 ~" production liner as follows: a). (1) jt 4 ~", 12.6 ppf, L-80, H521 with float shoe b). (i) jt 4 ~", 12.6 ppf, L-80, H521 with float collar in Box c). (1) jt 4 ~", 12.6 ppf, L-80, H521 with Baker Type II landing collar in Box d). Sufficient 4 ~", 12.6 ppf, L-80, H521 to bring pipe liner top to 8350' MD e). Baker 7" X 5" Flex Lock liner hanger w/ H521 pup joint f). Baker ZXP Liner top packer w/ 6' extension to completion AFE. Notify all Service personnel their tickets. PU BRA #4. TIH to TD. bushing. Install 4 ~" casing rams in upper 16. V-door. 17. Check with Anchorage office on centralizer placement. 18. Install cementing head. Test lines to 5000 psi. Circulate and condition mud. Reciprocate pipe while circulating. Record up and down weights. Drop ball and pressure up to 1800 psi to set liner hanger. Set 20K down on hanger to confirm setting. Continue to pressure up to 2500 psi and release from hanger. Check release but do not pick up high enough to allow packer setting dogs to clear HR sleeve. Continue to pressure up to 3500 psi and blow ball seat. 19. Cement well as per attached procedure. If full returns during cement job, PU and expose packer setting dogs on running tool. Slowly rotate and slack off to set ZXP packer. Circulate out excess cement and clean up liner top. If returns were lost during cement job, pull three stands of drill pipe and circulate. Do not set ZXP liner packer. Determination will be made as to AOGCC requirements prior to any squeeze work for top of liner. / 20. If ZXP liner hanger is set, TOH. A separate completion procedure will be developed. Susan Dionne #2 Drilling Program Page 9 of 9 ~ ,'"""" POTENTIAL HAZARDS Well: Susan Dionne #2 To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake(driller or relief driller)is responsible for shutting the well in(BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +/-2515'tvd/2750'md to total depth of the well. These sands are expected to be normally pressured and no lost circulation or differential sticking hazards are anticipated. No well interference hazards exist. 400 - 800 - 1200 - 1600 - 2000 - 2400 - ..---.. 2800- +- (l) (l) '+- ......... 3200- -C +- a. (l) 3600- 0 C 4000- 0 :¡:: I.... (l) > 4400- (l) :J I.... 4800- .- I V 5200- 5600 - 6000 - 6400 - 6800 - 7200 - 7600 - 8000 - 0 - a 0.00 o~ -f !:) Ç)':$!:) .~ 'O'Ç)Ç) ~' Ç)Ç) "'\-QO "~'OO 'ò'OÇ) "". ¡;) '\-~':$C 'v:\ ':$!:) '\-Ç)~ ¡;) ":j <;:¡ "J"J. <:P "J~' Ç)Ç) ~~. Ç)Ç) ". ~" ~ (V. ~ ,----, ~ -- MARATHON Oil Company Structure: Nlnllohlk #1 Well: SD#2 Field: Exploration LocatIon: Kenai PenInsula, Alaska WELL PROFILE DATA DLS; 3.00 deg per 100 ft .~þ -s-" ~<Q 0 ~ò ~ "" .... v,"" ,",,'" moo -, ---.- no. ... "" ... ... ... ... ,..... .... ... ... ..,.... ..... ... ..,... ""... ""n ..... ... .,.... ...... ..... ",.,. """ ........ .....- ,...... .... ,- 'II I . - - -.... .... .....- ....... ..... ..... ....., -... ...... OJ"" '....,_m.'. ,.,... ,..., ...... ...... ,.... ""... TANGENT ANGLE 52.51 DEG Tgt 1 - 50#2 - 25 Oct 2001 DLS; 3.00 deg per 100 ft End of Drop/Turn Created by Sutherland For: P. Berga ""Ie plotted' '-Dee-200' Plot Ra~ea I. 5012 Va..lan II. Coo""oole. a'" In 'eet ...'...nea slot 13. M MARATHON Eo.t (foot) -> 0 TO tgt - 5012 - 25 Oct 2001 N ~ l'o. '" "-Í ..... Tot 1 - 5012 - 25 o.t 2001 52.51 51.11 45.17 39.23 36.50 33.28 30.29 27,30 24.32 21.36 TARGET ANGLE 21.36 DEG TNa VerlIcol Depth.... ,of a""'" RKe (Clocl., II). llii. .... INTEQ 0 400 800 TO tgt - 50#2 - 25 Oct 2001 1200 1600 2000 2400 2800 3200 3600 4000 4400 Vertical Section (feet) - > Azimuth 6.01 with reference 0.00 N, 0.00 E from slot #3 4800 5200 N <r: ~ CO to 5600 500 1000 6000 - 5500 - 5000 - 4500 - 4000 ^ - 3500 I Z - 3000 0 ..., .- :r- ..---.. - 2500 - CD CD .- ......... - 2000 -1500 -1000 - 500 - 0 / 6000 r-', ~, MARATHON Oil Company Ninilchik #1 50#2 slot #3 Exploration Kenai Peninsula. Alaska PRO P 0 5 ALL I 5 TIN G by Baker Hughes INTEQ Your ref: 50#2 Version #1 Our ref: prop4941 License: Date printed: 3.Dec-2001 Date created: 25-0ct-2001 Last revised: 25.0ct.2001 Field is centred on n60 48 21.994.wI50 49 18.963 Structure is centred on 214436.499.2236359.987.999.00000.N Slot location is n60 6 46.341.wI51 34 24.084 Slot Grid coordinates are N 2236596.109. E 212982.184 Slot local coordinates are 201.61 N 1459.51 W Projection type: alaska. Zone 4. Spheroid: Clarke. 1866 Reference North is True North r-, ~ MARATHON Oil Company PROPOSAL LISTING Page 1 Ninilchik #1.S0#2 Your ref: S0#2 Version #1 Exploration.Kenai Peninsula. Alaska Last revised: 25.0ct.2001 Measured Inclin. Azimuth True Vert RECTANGULAR Dogleg Vert Depth Degrees Degrees Depth COO R 0 I N ATE S Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 5.89 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 5.89 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 5.89 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 5.89 400.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 5.89 500.00 0.00 N 0.00 E 0.00 0.00 600.00 0.00 5.89 600.00 0.00 N 0.00 E 0.00 0.00 700.00 0.00 5.89 700.00 0.00 N 0.00 E 0.00 0.00 800.00 0.00 5.89 800.00 0.00 N 0.00 E 0.00 0.00 900.00 0.00 5.89 900.00 0.00 N 0.00 E 0.00 0.00 1000.00 0.00 5.89 1000.00 0.00 N 0.00 E 0.00 0.00 1l00.00 3.00 5.89 1099.95 2.60 N 0.27 E 3.00 2.62 1200.00 6.00 5.89 1199.63 10.41 N 1. 07 E 3.00 10.46 1300.00 9.00 5.89 1298.77 23.39 N 2.41 E 3.00 23.51 1400.00 12.00 5.89 1397.08 41. 51 N 4.29 E 3.00 41. 73 1500.00 15.00 5.89 1494.31 64.73 N 6.68 E 3.00 65.08 1600.00 18.00 5.89 1590.18 92.98 N 9.60 E 3.00 93.47 1700.00 21.00 5.89 1684.43 126.18 N 13.03 E 3.00 126.85 1800.00 24.00 5.89 1776.81 164.24 N 16.96 E 3.00 165.12 1900.00 27.00 5.89 1867.06 207.06 N 21.38 E 3.00 208.16 2000.00 30.00 5.89 1954.93 254.52 N 26.27 E 3.00 255.87 2100.00 33.00 5.89 2040.18 306.49 N 31.64 E 3.00 308.12 2200.00 36.00 5.89 2122.59 362.82 N 37.45 E 3.00 364.75 2300.00 39.00 5.89 2201.91 423.37 N 43.71 E 3.00 425.62 2400.00 42.00 5.89 2277.95 487.96 N 50.37 E 3.00 490.56 2500.00 45.00 5.89 2350.47 556.43 N 57.44 E 3.00 559.38 2600.00 48.00 5.89 2419.30 628.57 N 64.89 E 3.00 631. 91 2700.00 51.00 5.89 2484.24 704.20 N 72.70 E 3.00 707.94 2750.42 52.51 5.89 2515.45 743.59 N 76.76 E 3.00 747.54 3000.00 52.51 5.89 2667.34 940.58 N 97.10 E 0.00 945.58 3500.00 52.51 5.89 2971.63 1335.23 N 137.84 E 0.00 1342.32 4000.00 52.51 5.89 3275.93 1729.87 N 178.58 E 0.00 1739.06 4500.00 52.51 5.89 3580.22 2124.52 N 219.32 E 0.00 2135.81 5000.00 52.51 5.89 3884.52 2519.17 N 260.06 E 0.00 2532.55 5500.00 52.51 5.89 4188.81 2913.81 N 300.80 E 0.00 2929.29 6000.00 52.51 5.89 4493.11 3308.46 N 341. 54 E 0.00 3326.03 6500.00 52.51 5.89 4797.40 3703.10 N 382.28 E 0.00 3722.77 7000.00 52.51 5.89 5101. 70 4097.75 N 423.02 E 0.00 4119. 52 7352.86 52.51 5.89 5316.44 4376.26 N 451. 77 E 0.00 4399.51 7400.00 51.11 6.12 5345.59 4413.10 N 455.65 E 3.00 4436.56 7500.00 48.14 6.64 5410.36 4488.80 N 464.11 E 3.00 4512.73 7600.00 45.17 7.22 5479.00 4560.98 N 472.87 E 3.00 4585.43 7700.00 42.20 7.85 5551. 31 4629.44 N 481. 92 E 3.00 4654.46 7800.00 39.23 8.56 5627.10 4694.00 N 491. 21 E 3.00 4719.63 7892.36 36.50 9.30 5700.00 4750.00 N 500.00 E 3.00 4776.24 Tgt 1 - SO#2 0 25 Oct 2001 7900.00 36.27 9.33 5706.15 4754.47 N 500.73 E 3.00 4780.77 8000.00 33.28 9.74 5788.28 4810.72 N 510.17 E 3.00 4837.69 8100.00 30.29 10.22 5873.28 4862.59 N 519.29 E 3.00 4890.24 8200.00 27.30 10.79 5960.90 4909.95 N 528.05 E 3.00 4938.25 8300.00 24.32 11.49 6050.91 4952.67 N 536.45 E 3.00 4981.62 All data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from RKB (Glacier #1) (153.00 Ft above mean sea level). Bottom hole distance is 5742.82 on azimuth 7.00 degrees from wellhead. Total Dogleg for wellpath is 83.91 degrees. Vertical section is from wellhead on azimuth 6.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,~, MARATHON Oil Company Ninilchik #1.S0#2 Exploration.Kenai Peninsula. Alaska Measured Inclin. Azimuth True Vert R E C TAN G U LA R Depth Degrees Degrees Depth COO R 0 I N ATE S 8399.29 21.36 12.37 6142.41 4990.38 N 544.40 E 8500.00 21.36 12.37 6236.20 5026.21 N 552.26 E 9000.00 21.36 12.37 6701.86 5204.09 N 591. 26 E 9500.00 21.36 12.37 7167.51 5381.98 N 630.27 E 10000.00 21.36 12.37 7633.17 5559.86 N 669.27 E 10393.89 21.36 12.37 8000.00 5700.00 N 700.00 E ~ PROPOSAL LISTING Page 2 Your ref: SD#2 Version #1 Last revised: 25.0ct-2001 Dogleg Vert Deg/100ft Sect 3.00 5019.95 0.00 5056.40 0.00 5237.39 0.00 5418.39 0.00 5599.38 0.00 5741.96 TO tgt . SD#2 .25 Oct 2001 All data is in feet unless otherwise stated. Coordinates from slot #3 and TVD from RKB (Glacier #1) (153.00 Ft above mean sea level). Bottom hole distance is 5742.82 on azimuth 7.00 degrees from wellhead. Total Dogleg for wellpath is 83.91 degrees. Vertical section is from wellhead on azimuth 6.01 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ,~ ,-----.., MARATHON Oil Company Ninilchik #1.S0#2 Exploration,Kenai Peninsula, Alaska PROPOSAL LISTING Page 3 Your ref: SO#2 Version #1 Last revised: 25.0ct-2001 MO TVO Rectangular Coords. Comments in wellpath Comment ..-.-...--....-----..---.....--......---..'-"""'-""'""'----"""'-""""'-""""...--.--....... 7892.36 5700.00 10393.89 8000.00 4750.00 N 5700.00 N 500.00 E Tgt 1 - SO#2 - 25 Oct 2001 700.00 E TO tgt . SO#2 . 25 Oct 2001 Targets associated with this wellpath Target name Geographic Location T.V.O. Rectangular Coordinates Revised .....-......-.....-----.-.---...---....-..."---""'---""'-""-""---"""'---"""---.--.......-... Tgt 1 . 50#2 . 25 Oc TO tgt - S0#2 - 250 5700.00 8000.00 4750.00N 5700.00N 500.00E 25-0ct-2001 700.00E 25.0ct.2001 ".......... ,~ MARATHON Oil Company Ninilchik #1 SD#2 slot #3 Exploration Kenai Peninsula. Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref: SD#2 Version #1 Our ref: prop4941 License: Date printed: 3-Dec.2001 Date created: 25-0ct-2001 Last revised: 25.0ct.2001 Field is centred on n60 48 21.994.wI50 49 18.963 Structure is centred on 214436.499.2236359.987.999.00000.N Slot location is n60 6 46.341.wI51 34 24.084 Slot Grid coordinates are N 2236596.109. E 212982.184 Slot local coordinates are 201.61 N 1459.51 W Projection type: alaska. Zone 4. Spheroid: Clarke - 1866 Reference North is True North ,/'--, ~ MARATHON Oil Company PROPOSAL LISTING Page 1 Ninilchik #1,SO#2 Your ref: SO#2 Version #1 Exploration,Kenai Peninsula, Alaska Last revised: 25.0ct.2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R 0 S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 0.00 0.00 0.00 0.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 100.00 0.00 5.89 100.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 200.00 0.00 5.89 200.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 300.00 0.00 5.89 300.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 400.00 0.00 5.89 400.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 500.00 0.00 5.89 500.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 600.00 0.00 5.89 600.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 700.00 0.00 5.89 700.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 800.00 0.00 5.89 800.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 900.00 0.00 5.89 900.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 1000.00 0.00 5.89 1000.00 O.OON O.OOE 0.00 0.00 212982.18 2236596.11 1100.00 3.00 5.89 1099.95 2.60N 0.27E 3.00 2.62 212982.51 2236598.71 1200.00 6.00 5.89 1199.63 10 .41N 1. 07E 3.00 10.46 212983.50 2236606.49 1300.00 9.00 5.89 1298.77 23.39N 2.41E 3.00 23.51 212985.15 2236619.43 1400.00 12.00 5.89 1397.08 41. 51N 4.29E 3.00 41. 73 212987.45 2236637.51 1500.00 15.00 5.89 1494.31 64.73N 6.68E 3.00 65.08 212990.40 2236660.67 1600.00 18.00 5.89 1590.18 92.98N 9.60E 3.00 93.47 212993.98 2236688.84 1700.00 21.00 5.89 1684.43 126.18N 13.03E 3.00 126.85 212998.20 2236721. 95 1800.00 24.00 5.89 1776.81 164.24N 16.96E 3.00 165.12 213003.02 2236759.90 1900.00 27.00 5.89 1867.06 207.06N 21. 38E 3.00 208.16 213008.46 2236802.61 2000.00 30.00 5.89 1954.93 254.52N 26.27E 3.00 255.87 213014.48 2236849.93 2100.00 33.00 5.89 2040.18 306.49N 31.64E 3.00 308.12 213021.07 2236901. 76 2200.00 36.00 5.89 2122.59 362.82N 37.45E 3.00 364.75 213028.22 2236957.94 2300.00 39.00 5.89 2201. 91 423.37N 43.71E 3.00 425.62 213035.91 2237018.32 2400.00 42.00 5.89 2277.95 487.96N 50.37E 3.00 490.56 213044.10 2237082.74 2500.00 45.00 5.89 2350.47 556.43N 57.44E 3.00 559.38 213052.79 2237151.02 2600.00 48.00 5.89 2419.30 628.57N 64.89E 3.00 631.91 213061.94 2237222.96 2700.00 51,00 5.89 2484.24 704.20N 72. 70E 3.00 707.94 213071.54 2237298.39 2750.42 52.51 5.89 2515.45 743.59N 76.76E 3.00 747.54 213076.54 2237337.67 3000.00 52.51 5.89 2667.34 940.58N 97.10E 0.00 945.58 213101.53 2237534.12 3500.00 52.51 5.89 2971.63 1335.23N 137.84E 0.00 1342.32 213151.61 2237927.69 4000.00 52.51 5.89 3275.93 1729.87N 178.58E 0.00 1739.06 213201. 69 2238321.26 4500.00 52.51 5.89 3580.22 2124.52N 219.32E 0.00 2135.81 213251.76 2238714.82 5000.00 52.51 5.89 3884.52 2519.17N 260.06E 0.00 2532.55 213301.84 2239108.39 5500.00 52.51 5.89 4188.81 2913.81N 300.80E 0.00 2929.29 213351.91 2239501. 96 6000.00 52.51 5.89 4493.11 3308.46N 341. 54E 0.00 3326.03 213401. 99 2239895.52 6500.00 52.51 5.89 4797.40 3703.10N 382.28E 0.00 3722.77 213452.07 2240289.09 7000.00 52.51 5.89 5101. 70 4097.75N 423.02E 0.00 4119.52 213502.14 2240682.66 7352.86 52.51 5.89 5316.44 4376.26N 451.77E 0.00 4399.51 213537.48 2240960.41 7400.00 51.11 6.12 5345.59 4413. ION 455.65E 3.00 4436.56 213542.23 2240997.15 7500.00 48.14 6.64 5410.36 4488.80N 464.11E 3.00 4512.73 213552.48 2241072.63 7600.00 45.17 7.22 5479.00 4560.98N 472.87E 3.00 4585.43 213562.96 2241144.58 7700.00 42.20 7.85 5551.31 4629.44N 481.92E 3.00 4654.46 213573.62 2241212.81 7800.00 39.23 8.56 5627.10 4694.00N 491.21E 3.00 4719.63 213584.44 2241277.12 7892.36 36.50 9.30 5700.00 4750.00N 500.00E 3.00 4776.24 213594.55 2241332.90 7900.00 36.27 9.33 5706.15 4754.47N 500.73E 3.00 4780.77 213595.39 2241337.36 8000.00 33.28 9.74 5788.28 4810.72N 510.17E 3.00 4837.69 213606.16 2241393.36 8100.00 30.29 10.22 5873.28 4862.59N 519.29E 3.00 4890.24 213616.50 2241445.00 8200.00 27.30 10.79 5960.90 4909.95N 528.05E 3.00 4938.25 213626.39 2241492.14 8300.00 24.32 11.49 6050.91 4952.67N 536.45E 3.00 4981.62 213635.79 2241534.65 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from RKB (Glacier #1) (153.00 Ft above mean sea level). Bottom hole distance is 5742.82 on azimuth 7.00 degrees from wellhead. Total Dogleg for wellpath is 83.91 degrees. Vertical section is from wellhead on azimuth 6.01 degrees. Grid is alaska. Zone 4. Grid coordinates in FEET and computed using the Clarke. 1866 spheroid r----. ~ Presented by Baker Hughes INTEQ MARATHON Oil Company PROPOSAL LISTING Page 2 Ninilchik #1.SD#2 Your ref: SQ#2 Version #1 Exploration,Kenai Peninsula. Alaska Last revised: 25.0ct.2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 8399.29 21.36 12.37 6142.41 4990.38N 544.40E 3.00 5019.95 213644.63 2241572.15 8500.00 21. 36 12.37 6236.20 5026.21N 552.26E 0.00 5056.40 213653.33 2241607.79 9000.00 21.36 12.37 6701. 86 5204.09N 591. 26E 0.00 5237.39 213696.54 2241784.70 9500.00 21.36 12.37 7167.51 5381.98N 630.27E 0.00 5418.39 213739.75 2241961.61 10000.00 21.36 12.37 7633.17 5559.86N 669.27E 0.00 5599.38 213782.96 2242138.52 10393.89 21.36 12.37 8000.00 5700.00N 700.00E 0.00 5741.96 213816.99 2242277.89 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #3 and TVD from RKB (Glacier #1) (153.00 Ft above mean sea level). Bottom hole distance is 5742.82 on azimuth 7.00 degrees from wellhead. Total Dogleg for wellpath is 83.91 degrees. Vertical section is from wellhead on azimuth 6.01 degrees. Grid is alaska. Zone 4. Grid coordinates in FEET and computed using the Clarke. 1866 spheroid ~, ~ Presented by Baker Hughes INTEQ MARATHON Oil Company Ninilchik #1.S0#2 Exploration.Kenai Peninsula. Alaska PROPOSAL LISTING Page 3 Your ref: SD#2 Version #1 Last revised: 25.0ct.2001 MO TVO Rectangular Coords. Comments in wellpath Comment ..-...---..--...........---..---...-.-..---...---.....----'-"---""---'-'---""--"".-.--.--.....,-.--- 7892.36 5700.00 10393.89 8000.00 4750.00N 5700.00N 500.00E Tgt 1 . SD#2 - 25 Oct 2001 700.00E TO tgt - SO#2 - 25 Oct 2001 Targets associated with this wellpath Target name Geographic Location T.V.O. Rectangular Coordinates Revised ",---,--",,---,'--"--""-""'--'-"-""-""'-'---",-'-----"".---"---""-'-""..--....-----.... Tgt 1 . SO#2 - 25 Oc TO tgt - SD#2 - 250 5700.00 8000.00 4750.00N 5700.00N 500.00E 25.0ct-2001 700.00E 25-0ct.2001 ,r--, /~ MARATHON Oil Company M Created by Sutherland For: P. Berea Oote plotted: 4-Qec-2oo1 Plo' .ef...nce r. 5012 ""...ron 1'. Structure: Nlnllchlk #1 Well: SD#2 Coordlno'.. 0.. In feet "'e..nee .10' ~ MARATHON T"", Verlfc:ol )opth. ore re'...ene. RK8 (Goeie, II). .. Field: Exploration Location: Kenol Peninsula. Alaska .... INTEQ <- West (feet) 4000 3600 3200 2800 2400 2000 1600 1200 800 400 0 400 800 1200 1600 2000 2400 6800 6800 6400 - - 6400 6000 - - 6000 SO#2 5600 - 8000 7900 - 5600 7600 7300 7000 5200 - 6700 - 5200 6400 6100 5900 4800 - 5700 - 4800 5600 5500 5400 4400 - 5300 - 4400 5200 5100 4000 - 5000 - 4000 4900 4800 ^ 3600 - 4700 - 3600 ^ I 4600 I 4500 ----- 4400 Z +- 3200 - - 3200 Q) 4300 0 Q) ., - 4200 -i- '-" ::r 2800 - 4100 - 2800 ..r::. ----- +- 4000 ..... L 3900 CD 0 CD Z 3800 - 2400 -i- 2400 - '-" 3700 3600 2000 - 3500 - 2000 3400 3300 p:,(;) 3200 -1600 1600 - SD#1 "'~ \)<:> 3100 ",þ¡ ~!P 3000 ",C5 (;)<:> ro"ì çp 2900 1200 - rJ' d;> 2800 -1200 ror¡; ~(;) roO ~p 2700 ",'t' S:p 2600 800 - ",'P ~ - 800 þ.C5 ¡;:¡ 2500 ~ C5 2400 ~r¡; ¡;:¡(;) ",C5 2300 400 - 2200 - 400 2000 1800 1600 0 - 100 - 0 400 - - 400 800 800 4000 3600 3200 2800 2400 2000 1600 1200 800 400 a 400 800 1200 1600 2000 2400 <- West (feet) ~, /"""'... - Created by Sutherland For: P. Berga ea.. plol""', 4-Dec:-2001 MARATHON Oil Company Plo' ""..nco t. 5012 V.";on 11. structure: Nlnllchlk (11 Well: SD(l2 M MARATHON COD'dlno". 0'" In foe' ..f...no. .Iot "'- TN. V.rtlcoI Deplh. 0'" ,"f.,.n.. RKB (Glo.ie, 11). ..8 .... INTEQ Field: ExploratIon Location: KenaI Peninsula, Alaska 300 TRUE NORTH ~ c::::J 350 0 10 340 330 280 20 30 320 40 310 50 60 290 70 280 80 270 90 260 100 250 11 0 240 120 230 130 220 140 210 150 200 160 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 13 1/8" SM Manually I Operated Valves ) ~~ :, []@ill[]@illrn ŒIID I~:)/ 113 5/8" SM Cross . /""- Flow Nipple I 1135/8" SM Annular I Preventer 113 5/8" SM Double Ram Preventer Ie ----. e 135/8" SM Single Ram Preventer e .---.. Marathon Oil Well SD-2 BOP Stack . . ') 1 I) ~ I I < IPipe Ram I IBlind Ram I I Flow Line I I ~ ~ --'""""'"\. 3 1/8" SM Hydraulically Operated Valve < 1 /1 JI' I Cho ke I m[lI@[J][]@ill t ..... 1 1 < Pipe Ram I > I 1 '\ < I J í ~ 131/8" SM Manually I Operated Valve ~ /"'"',. Marathon Oil Well SD-2 Choke Manifold ITO Gas Buster I ITO Blooey Line I I Bleed off Line to I Shakers ç::::::;¡ ~[]I@[[1l 1,_,1 ~ X [IJ@Iill]@[Q [IJ@[III]@1L '\ I ~ I I t 13" 5M Valves I ç::::::;¡ mITØmO I ç::::::;¡ t::::::J ~ - 29/16" 10M Swaco Hydraulically Operated Choke ~ I From BOP Stack I 13 1/8" 5M Manually Adjustable Choke /", Marathon Oil Well SD-2 Diverter ~ I Flow line 1203/4" 3M Diverter 1-+ ") / I I I" I /' I Diverter Spool Þ ./ I 1,\ " I I í 116" Automatic Hydraulic Valve I I \:~~ø~ 116" Diverter Line I e'CI" - t 14'-r .\ I I 1 I L____---- I ! I I I I f I I I t "",--"", l,~\ flDEGASSER) I' I , , I ""-- I . II ~-----~ ~-----~ r ! ~-_.J II ! ! 1 f I r--' Q ¡ I r! 1\ r . I t I .. I (I I - i " , D! r -; I Œ "I 1 ~ ,I. ~ III I c I I I I' t 1 i riM II I l ¥ ,. I I' U I , or: ., 18 , j Q . I II I L____..J L-----.JI I r---------ì I ,.....,... I 8 "',,' "'\ 1 I I L.. I J ..... I. I r-----' I I i I CENTRIFUGEI I UNIT I I 4* X in- I I I I I I I I I I DlI4P I t -, I 1 '.... '" I I I 1..-'-'--_..1 I KOOKY 3' X 12* '- 75 HP 6 X 5 , U' ~ L 751-P 6)c~ 11. ;Ht ...... " , ... 18JI&i .. 4. ~ . 8 . . '8 '- ..-.c: ( till 1IIIIit .. GLACIER DRILLING RIG #1 MUD PITS AND PUMP ROOM LAYOUT ~- .75 HP , '6 X :5 i II" t : _.ì Jlll!1111 41.. I .. . . \ ,~" I ¡ _AD ~ !l . .w-r ()-y. I 5\1 9L . , ,,-600 PT . 75 W ~ 6 )( ~ ' 11. ' . < - ~- t . ". I . . " .. 8- ~ l.::. I . -----¡ ~ '41: :~ '~. 'X: i f 5\1 9l - A-6tJD PT R~ ~¡ ~ i ~ -[iJ I . f ì . ~..,~ . r -- -II ...' PIU. PIT -14'-V I I I I I I I I I I I I I ) I I I I I I I Z3"-o" ~ " i~:'1 ~,.> ~ ~ ~ SURFACE USE PLAN FOR SUSAN DIONNE #2 WELL Surface Location: SW 1/4 of SE 1/4, Sec. 6, T1S, R13W, S.M. 1. Existing Roads The Sterling Highway will be used for access to the SD #2 well and is shown on the attached map. Ninilchik, Alaska is the nearest town to the site. 2. Access Roads to be Constructed or Reconstructed No new roads are required. 3. Location of Existing Wells The SD #1 (formerly called the Union Ninilchik #1 or the McCoy well) is the only existing well on the pad. The other nearest well is the Mobil Ninilchik well which is approximately 15000 feet away. 4. Location of Existing and/or Proposed Facilities No facilities are proposed at this time. 5. Location of Water Supply An existing water well will be used to make and maintain the drilling mud. 6. Construction Materials No materials are required. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 in the Kenai Gas Field for disposal into Well KU 11-17, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). N :\DRLG\W ELLS\SD#2\SU RFUS E.doc ..:- .~. ~ Surface Use Plan Susan Dionne #2 Well Page 2 b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the water well on the pad. S & R will collect and transport sanitary wastes to their ADEC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Reclamation of the pad, if required by the landowner, will occur after abandonment of all wells. 10. Surface Ownership Paul Dionne is the surface owner of the land at the Susan Dionne #2 well. 11. Operator's Representative and Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and N:\D RLG\W ELLS\SD#2\SU RFU SE.doc r'-'. ~. Surface Use Plan Susan Dionne #2 Well Page 3 subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: December 5, ~2001 Name & Title: ~¡f" - - , arath~~mpany P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 564-6319 Drilling Superintendent N:\D RLG\W ELLS\SD#2\SU RFUSE.doc ) R14W R13W MCG1 -9- Marathon Susan Dionne 2 PTD 10,394' MD T 1 S \. ') ~o\.J ;1l}o I§ , " ~~..JJ0 S_____~~A. ~l~. ~~ î~ \~ ~3 ^~ o I 3 I MILES STUCTURE TYONEK T2SCAN'\\ED AUG 1 6 2005 CI = 500' )~ '() I ~;" 'if (} MARATHON OIL COMPANY ALASKA REGION Marathon Susan Dionne 2 Location COOK INLET, ALASKA November 2001 o:freehand\ninilchik\ninL dionne2_loc.fh9 /~ Marathon Oil Company ~roject: Susan Dionne No.2 -----,-,--- "-,-"~---, --,-------, ---- i --,-- ,--- -"--!T' -J I BASE LINE I , T------- -----r--..L <I; <I; ~ lL! ~ 3 4 " , +- .. í. 2 15 / ,;1. ",pl"> \ ~ 11,', ""c \.Nin¡lètfi~'ì- " landint S,,¡~,', I l ',,> /t-_J 7 /: -s,,/\ - - - b~~¿~-'~_~ik //- I I (I I lâJ I 2¿OX 18 I (- I I \,"bo;\: ' !, V : I'" R 14 W ~5' R 13 W 12 665: 0 34 W t I I ISE!OOVIA ~--51 ! 4()' . ,"".,;;;-o,moo,o" 'unv" .m~N, V'.O'N"-"" 582000m, E. 60' 151°3a ---,---~ KENAI (A-5) QUADRANGLE -- ALASKA-KENAI PENINSULA BOROUGH I 1:63 360 SERIES (TOPOGRAPHIC) r-4 ~ J >--< >--< 3000 0 '=L-'='__~ '----' 1 .5 SCALE 1:63360 , 3 -'==='-'=~'-~----'---'=r-- 4 'HL£S 3000 >----< 6000 ~ 9DCO >----< 12000 >----< 15000 18000 21000 FEET >-----< >----< 5 KILOMETERS -, ~~~HH' CHECK 1 STANDARD LETTER DEVELOPMENT L>(. DEVELOPMENT REDRILL EXPLORATION ~ INJECTION WELL INJECTION WELL RED RILL ~ .~\ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ..:5U.s4-~::;;;¡;~d;l1ne- "¡/2- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new wellbore segment of existing well ------.J Permit No, API No. ' ' Production should continue to be reported as a function of the original API number stated above. ' (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) In accordance with 20 AAC 25.005(1), all 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). ANNULAR n-¿ML ~~gs, Annular disposal has not been requested. . . ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . L.J YES ANNULAR DISPOSAL THIS WELL Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS L.J YES + Enclosed is the approved application for permit to drill the above referenced well. The permit is approved ,subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Comnany Name) will assume the liability of any protest to the spacing exception that may occur. ->~~." " ~;L-I ,f... -: ¿d~A éX <'~~ . qflkíJ. ~ Templates are located m drive\jody\templates ~ .r-",\ 7 III 0 0 ~ 5 5 '7 III I: I. 25 2000571: 0 1.1110785 b 11111 Marathon Oil Company P.O. Box 196168 ANCHORAGE ALASKA 99519-6168 _1~~'II]tl!l:::l~lIJI'jl:!=-: ('~~I:\ =- :ll]:t II ~ [~""I ;£, '11."" NON-REPORTING 100% REPORTABLE OR INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT NON.EMPLOYEE COMP, PRIZES, AWARDS, OR DAMAGES OPERATOR CITY STATE ------- - - -- .]~-\I!I:W.I[I]~ Filing fee for Pprmit to drill Susan Dionne /12 ".' .-.... .._,~ "..' -- .._,-_.-~-...... - '...--.-""'", . ...,- ,..-'.. ...-u -~_.. ......,,--..___,...m,-, ""."""""'-"----~~_.'~"-'~~'..----~,'--'- .0... .., ......_",-_..-..-.'0'---..-.. -" ."-----'" '-,-'-'-~'-'--~"~-'---'-'---'-'" ..... - _._--_.~.._. .__..... -,~-- _...-..".~~~~_u....._------' .... , ,.,.,-., ... .. .'_.__'n..............~---_.,-~----""-"--,,,, , .. _.._-------~._._.- -------..-....,- ' -~.~_._- ., --._---,,-,~~,_.'---~..__..~ 3U5C<,j~ WELL PERMIT CHECKLIST COMPANY ~,~.tf .f~WELL NAMi:Ð/~/1/1¿#2PROGRAM: exp /dev - redrll- serv - wellbore seg _ann. disposal para req- ! FIELD & POOL ..J A INIT CLASS g;,XpC ( G,.c?S) GEOL AREA B2CJ UNIT# P\J/J- ON/OFF SHORE D/î ~" ADMINISTRA nON 1. Pennit fee attached. . . . . . . . . .. " ...... " . , , 2 Lease numberappropn'ate'* ¿Dd ~"~IID""¿¡OI , ' #' ..:S<..V~ /C:>CZ4"¡'cr-r-.., ~d %{f .?»"~dl(c./[I;'¿"/~lhvc.J ~r¡7>L. 3~2"'2.' . . . .~ . . . . . . . . . . . . . . f,:D. .A.t- /}Dc.... 3gt:j1/g"ð. .d,t (/ C> / '7-) 3.Umquewellnameandnumber.................. Y , 4.Welllocatedinadefinedpool................... @ '~l' '7 '/ ,é' . 5. Well located proper d~stance from drilling unit boundary.~~. V@ ~~ ~T'~l h<7 . f::::;'t.c.~n~ f:-~\U (n:::-¿ ;, ~p o.-r ¡,~u<!....f ~ 6. Well located proper distance from other wells.. . . . . . . . . ~ ~...-'cL.( aA:::Jd '77'[::" ho ~ I/~.. 4;) r-f"- u.... r ~ S"b6 of' ---f?rt!fP2 r!J . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N /the..- tc.:>£.~YY" C>LV~~i<.'i> ?""-rc..e...YIf~, A é../<.c.-~.,' -'('.e..i'- - 8. If deviated, is wellbóre platincluded.. . . . . . . . . . . . . . 20 nÂ c ;z.S .65"Ç e:t sd:b-c::L<:- A<{ ~x.<!.~:t:~ ~ ~u (-ì€.d ~ . 9. Operatoron/yaffectedparty...... .,.. .. .... .. . ~," " ,)~-<\~~/ :C'-'5ied ...fe-X..¡-It.À! Æ,,~, .aJ.,~" /-z;.'Ic,¿,O/: -l1-"/~' ,<Se..rl J2.1"<!.~~' 10. Operator has appropriate bond in force. . . . . . . . . . . . . G~ to' þ",d R.d./~. J!& I: 69.óz.: ,~.ec~~ ~~c-~ ¿")lL.~~éh...-i) , 11. Pennit can be issued without conservation order. . . . . . . . -xŒ) 7¿f 1¿'1.s~, /-/5.oz..' ffi/r¿.¿. ¿t /~~ I'r.JJ¡'~c.....£. " 12. Pennit can.be issued without administrative approval.. . . . . é:f) ~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . Yß . . ~,+- CJISO"T\lC) . ~ 14. Conductor stnng proVIded. . . . . . . . .. . . . . . . . . . N 5 l.,\. l'-'"'" " . /? 15. Surfacecasingprotect~allknownUSDWs. . . . . . . . . . . N ,:z.'I'¡'DI.'~'& ,~~, ' ~II--w, <2.5'-"i~ ~~' /ì-t;.:2A4f'lJ/";,,¡;', "","Vfd./:Jo.....k..ry, 16. CMT vol adequate to arculate on conductor & surf csg. . . . . N / ell- ðZ.' , ~.:f tÁA'¡:'~ ~. . U4.,tyf7.t:!.-'" 14D?-o-. /ð'f) 17. CMTvoladequatetotie-inlongstringtosurfcsg....... . N /z.~.&>z.:., t'rf1":4-fCL--~~../"-Y~ Dt /~~~.ø-{'--<-ZS7s:/7"Vb íc.>7/r ' 18. CMTwilicoverallknownproductivehorizons. . . . . '. . . . . N ~~ c¿/f?l"'Ifl-rl: ~-r ¡;¿re.-~£~~ ~r""/..,(., 19. Casing designs adequate for C~ T, B & pennafrost. . . . . . . N ". ' , ' ~d!;~ /:u.Þ/J <::- ~ þ.-- .s /1";~ ù.- c./k.-~ ~. ~ 20. Adequatetankageorreservepit................. NGIer.c--t,I?",.- h:J' 'ttJ No, 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N (.I/A. . 22. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N filA. ' 23. If diverter required, does it meet regulations. . . . . . . . . . ~N 24. Drilling fluid program schematic & equip list adequate. . . . . " N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N G P R t=i ", , JA +.. t . APPRA. .I?ATE ,26. BOPE press rating appropriate; test to -:s 000 psig. ~ N JAI4ñ p ::: Z. '58 f <:,.1. l"I-etAt C-SL¡' 'f< ~ 1- tco f (-'to.. y../.6".l:t..illrl'Z- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N in 28. Work will occur without operation shutdbwn. . . . . . . . . . . ~ RtPJ)Y{ ~ 29. Is presence of H~ gas probable.. . . . . . . . . . . . . . . . Y Q;V , ~' , GEOLOGY 30. Pennit can be issued w/o hydrogen sulfide measures. . . .. Y 'N ,.¡. r?<-i. d. . ¡. I í) 31. Data presented on potential overpressure zones. . . . . . . . V"?^"" l:~5(J¡-L.. ff"Æ. J~ ~~ ' . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . y. UU( tu-al( k ~I:.. ~ (J~ J,.fI- no/- ~./).h<..- VI.oV APPR DATE , 33, Sea bed condffion suNO\' (If oIf.shore). , . . . , , . . . , ., Nfl f-u>Æ ~ _1/ $--, ,ý ~ "'.~~ ;/;:;;:<.o<4~...t "- 75b . n>d,b '1: b. ¿I. .~ ~-z- 34. Contact name/phone for weekly progress reports [exploratory onlYJéJ) N f2rL/...e..~.... /:k- ,5t-, If-to.'?íC¡ /,.)ð"" ANNULAR DISPOSAL35. With proper cementing records, this plan . ¿J . (A) will contain waste in a suitable receiving zone; . . . . . . . Y N . J I I ' ( d' APPR DATE (B) will not contaminate freshwater; or cause drilling waste. " Y N IV I!J ~tfA.."t.vv¡/ CU ~ ~ Ç. Cv f yo f'J,:) ~ . to surface; .. (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: ~Þ8 ~"...' WM 8~s 0</2/ Ic"C" ~ TË~.:I"}I ¥~ JMH (:h\,V\\-' ;2../;M102-- AP~ DATE þÞ l/r ðf..-- ENGINEERING Com m e ntsll nstructi ons: c:\msoffice\wordian\diana\checklist (rev. 11101/100) c 0 Z 0 -t :E ::tJ J -t m Z -t J: - en )- ::tJ m > )