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Home My WebLink About202-227 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc 3 a tRp). ~--t\ l- DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill Well Name/No. NATCHIQ 1 Operator PIONEER NATURAL RESOURCES US 2022270 MD 7500 _/ TVD 6740 r Completion Date 3/31/2003 ~ Completion Status P&A Current Status P&A ---- -~----- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey No "------.--- ------------- DATA INFORMATION Types Electric or Other Logs Run: LWD:GRlRes/CNUFDC. E-Line: GRlRNUFDC/Sonic/NGT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~$",-L /7 ~~~ ~ API No. 50-703-20438-00-00 UIC N (data taken from Logs Portion of Master Well Data Maint) Received Comments A Mud Log is required to be submitted. This record automatically created from Permit to Drill Module on: 12/4/2002. Interval OH I Start Stop CH Log Log Run Scale Media No r----- ct C Las {2027 Directional Survey C Las 2027 LIS Verification ! Rpt Report: Final Well R Log Mud Log Col Log See Notes Col Log I nd uction/Resistivity 25 Blu o 7500 Open 6/17/2003 o 7500 Open 6/17/2003 Open 6/17/2003 Open 6/17/2003 390 7500 390 7500 Open 6/17/2003 7499 Open 6/17/2003 334 Log Neutron 25 Blu 334 7499 Open 6/17/2003 Log Density Blu 25 334 7499 Open 6/17/2003 -' 4 reports on disk. Located in Well History File Located in Well History File w/Final Well Report. Custom View Log, located in Well History File w/Final Well Report. Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray,Caliper -~ DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022270 Well Name/No. NATCHIQ 1 Operator PIONEER NATURAL RESOURCES US API No. 50-703-20438-00-00 MD 7500 TVD 6740 Completion Date 3/31/2003 Completion Status P&A Current Status P&A UIC N ~--------------- Log Caliper log 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Log I nd uction/Resistivity 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper -," Log Neutron 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Log Density 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Log Caliper log 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper Log Sonic 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper -~ Log Sonic 25 Blu 334 7499 Open 6/17/2003 Multiple Propagation Resistivity, Caliper Corrected Neutron, Optimized Density Gamma Ray, Caliper ED C Pds 12084 See Notes 25 3390 5320 Open 5/27/2003 Triple Combo - Platform Express Log See Notes 25 cor 3390 5320 Open 5/27/2003 Triple Combo - Platform Express ED C Pds 12084 Sonic 25 3400 7491 Open 5/27/2003 BHC Sonic / NGT Log Log Sonic 25 Col 3400 7491 Open 5/27/2003 BHC Sonic / NGT Log ED C Pds 12084 Density 25 3390 5320 Open 5/27/2003 Density/Porosity Log - Platform Express DATA SUBMITTAL COMPLIANCE REPORT 4/1/2005 Permit to Drill 2022270 Well Name/No. NATCHIQ 1 MD 7500 NO 6740 ----------~~ Log Density 12084 Induction/Resistivity ED C Pds Completion Date 3/31/2003 Log I nd uction/Resistivity Well Cores/Samples Information: Name ,-~-'-------- I i i_~____ Cuttings ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ~ / ~~ "'- Analysis Y / N Received? ----- ~----- -- ~-- Comments: ---~--- Compliance Reviewed By: ~ Interval Start Stop 420 7500 Operator PIONEER NATURAL RESOURCES US API No. 50-703-20438-00-00 Completion Status P&A Current Status P&A UIC N 25 Col 3390 5320 Open 5/27/2003 Density/Porosity Log - Platform Express 25 3390 5320 Open 5/27/2003 Resistivity Log - Platform Express 25 Col 3390 5320 Open 5/27/2003 Resistivity Log - Platform Express Sent Sample Set ~r ~N' ~r ~ omments ~ ~ores and/or Samples are required to be , ___ submitted. This record automatically created from Permit to Drill Module on: 12/4/2002. _/ Received Daily History Received? ØN LY'N Formation Tops Date: ~ M; ~ 'Þ '-' ) PIONEER NATURAL RESOURCES CANADA INC. II . ....... DATATRAN8MITTAL DATE: June 10, 2003 TO: Alaska Oil & Gas Conservation Commission 333 W. - 7th Ave., Suite 100 Anchorage, AK 95501 Attention: Lisa M. Weepie FROM: Kevin Schmidt ENCLOSED IS THE FalLING INFORMATION: <ð - ;9'9-r- é)OCT Natchiq #1 50-703-20438 ~s: (2 copies) Multiple Propagation Resistivity Caliper Corrected Neutron -;. / Optimized Density Gamma Ray, Caliper Log 90~ ;--¡;x:ro 13 (1 copy) ~ Well Report (1 copy) Oooqaruk #1 50-703-20437 ()O'J. - dd(P ~s: (1 copy) ...... _ ~ ~ Multiple Propagation Resistivity Gamma Ray RWD Log ?{.VØ~g.R (1 copy) ¿.Rínal Well Report (1 copy) Ivik #1 50-703-20436 - ¿). Od - é)()5 ~: (1 copy) Multiple Propagation Resistivity Caliper Corrected Neutron ~ Optimized Density Gamma Ray, Caliper Log ~ ;:::Cj).-R(1 copy) ~inal Well Report (1 copy) SENT BY: Melony Larsen, Phone: (403) 231-3222 Administrative Assistant, Enqineerinq ') ~~:~ I[::,~ C·~ i= 'V 1::, () ~ -.;, ~."e'." ..' !:..,.,~ ...., JUN 1 7' ¿OO~) ,',1. ::.~...:,\: 'I:; 'f, !".:~~~;: ,"',,;¡,. :·'~'··-¡n",¡')ÞÁ.n~ r\.,~'1-.;.h(:"': v:. \._ __.\,J ...)v. .L. V~I' H..."\nVíi~ I~JKhofl!'S~ 2~)()() 2~;!j·!) A\!INlIL SW, CAU;AIÚ. /\I.IJi:lHA 171' :lCìG . I1lJSINLS~; (·¡CUI ;':!I:J]()() . lAX (~()3) 2m·D'HJl , One copy of tillS transmittal IS kept on file for our reference. Schlumberger Des i-Reservoir, Data and Consulting Services 3940 Arctic Blvd., Suite 300 Anchorage, Alaska 99503-5711 Job No: Add'! Tapes: '" Well Name: ¡/lL'10 ......) r , . {/C' ,..4:: I . yvell Name: _ r."'\ c.:J..LD \ / (.y ....., U A (.'- -') h ¿í} ~ r.rJU' "Services. _.._ J (_.if) f()f.j Æ¿· £,1'\ (j" Ie x .- (~: s;~f!J -6) ~~vV ~. ~, Ou - " . ..(~i)c S~/t'\.611 c.l~,l,lJt.~/L 1-.0.-1/ (J,-<;~ /)n)r6l~.c/n~'c s. U L :;;.! / ,¡:-- IYI / 7'" ~ c.. i.) (/ Schlumberger Courier: Company: Location: Attention: Well Name: Services: ~,i::'tt:. No. of Bo'es: No. of Boxes: Job No: Add'! Tapes: Well Name: Services: No. of Boxes: Job No: Add' Tapes: 'I) Jchlumberger i\l~ 2793 Î I .,,-"\, ,.....'......: '", I fr. "," , ", l-, t ý /(/' C¡.¡... Ir)r LJ.;::~,,' Date: .If I ('-.. (\, , 1 \:..~' , '-" . J "J - ~"~/¢' .. r ,...;~.... I' ì ":¡ ""'. I ~)~3--..3 l . /' I 0·0 t':' . \,-..)ú ,-k //,.:0 I ' /' ¡ I ", l j.. . l-I t'srl lUE2..· III (Z' ti l i ----'-11/1 /: II ¡4-':1' ,';1;¿ ;2o-tJ3 ,......-; ,/ (' / '-../ /l)' 4-1"(" ,Á I 0' ,;f I Well Nam e: _ ð),. 41- -::r I'" 1\ n Y' Q-U 0 I.' ~il)L~ ;~~_.I¿/ I··.~c:· v-- ¡¿·r."..<" <:.J.. J .'/. ' Services: .6ìOvU- --'- I't:-) C,r U1 I. '-- ,.,,~ .' -'" ru vi ~11 / U . / /( I ) /t: ¿o II-' 6 n ß /-1 (, _.:t~} l~" ;c ~t:"l,tJ/X.¡t)t.· 0,.þUVì )' {:.-b "';" ~ ." ~.' ',i. . /' No. of Boxes: , l ~'"",.;: -'I ' Q c~.., ) :;I.. (I:) f Job No: Add' Tapes: ,j" ". ..::: Ii-¡"" t:- /! '~ ,4 /; () 1.1 (;; No. of Boxes: ""'\ '--:2. /1 çj...., );¿ I~? , Job No: Add'! Tapes: ,.--- Well Name: Services: RECEIVED No. of Boxes: t, I Job No: Add' Tapes: MAY 27 2006 Alaðkð Oil & Gas Cons. Commi8eion Anå10rage ~I'~,..,p---.~.""'."-" '" ""'\"\ £__,.,._~"._. ,1/ «:~:~~;>~/ .~'~. ---1- í" ,. Received By: ~. Date Delivered: \ \., \ ) ) i ~~!Æ:E ~ } !Æ~!Æ~~~!Æ FRANK H. MURKOWSK', GOVERNOR o AIfASKA. OIL AND GAS CONSERVAnONCO~SSION 333 w. rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 8,2003 Kenneth H. Sheffield, Jr. President Pioneer Natural Resources Alaska, Inc. 310 K Street, Suite 200 Anchorage, AK 99501 Re: Natchiq #1 Permit to Drill 202-227 BOPE Configuration Dear Mr. Sheffield: Pioneer Natural Resources Alaska, Inc., (Pioneer) recently completed drilling of the Natchiq # 1 exploration well on the North Slope of Alaska. Drilling commenced March 17, 2003, with the Nordic 3 drill rig and the well was plugged by April 4, 2003. The AOGCC inspected your operations and specifically witnessed the testing of blowout prevention equipment on March 22, 2003. The AOGCC inspector that witnessed testing of the Nordic 3 blowout preventer (BOP) stack noted that the stack arrangement was not consistent with the normal arrangement that is maintained in AOGCC files as required on 20 MC 25.035(b)(1). Pioneer did not provide any notification of the change, and was requested to provide notice of the alternate arrangement to this office. We understand the alternate BOP stack arrangement was caused by an incompatibility between the 13-5/8" wellhead (pre-installed) and the 11"Nordic 3 BOP stack. We further understand that the Nordic 3 rig was not planned for use at N atchiq# 1 when the wellhead was pre-installed. You are reminded that changes· to BOP stack and associated equipment should be provided to the AOGCC when encountered. This will ensure consistency of our well records with the actual drilling activities and will assist our inspection staff with accurate information as they perform their duties. Please contact Jim Regg at 793-1236 should you have any questions. Sincerely, ~e~L~ Commissioner ') ) BUSINESS DEVELOPMENT J. Patrick Foley Alaska Land & Negotiations Consultant (907) 264-6750 . (907) 830-0999 mobile PIONEER NATURAL RESOURCES ALASKA, INC. April 23, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-33539 HAND DELIVERED Subject: N atchiq # 1 Well Reports and Information Permit No. 202-227 Harrison Bay, North Slope, Alaska Dear Commissioners, Pioneer Natural Resources Alaska, Inc. has completed operations on the Natchiq #1 well. The well was plugged and abandoned on March 31,2003. The following forms, reports and information are enclosed with this transmittal: 1. Well Completion Report Form 10-407 2. Wellbore diagram showing Final Status 3. Survey Listing 4. Final Well / Event Summary 5. Operations Summary Report (Drilling) 6. As-Built Drawing The information transmitted herewith is CONFIDENTIAL. We respectfully request that this material be maintained as CONFIDENTIAL in accordance with the provisions of 20 AAC 25.537(d) and the current practices of the Commission. Additional geologic data and logs required by 20 AAC 25.071 will be delivered under separate transmittal in the near future. Best regards, Æf~;< Cc: Mr. Dave Braddock - Pioneer Natural Resources USA, Inc. Mr. Rusty Cooper - Pioneer Natural Resources Alaska, Inc. Mr. Ed Kerr - Armstrong Alaska, Inc. RECEIVED APR 23 2003 Ala!i(e Oii & Gas Cons. Cornmiseton Anchorage 310 "K" STREET, SUITE 200, ANCHORAGE, ALASKA 99501 . . FAX (907) 264-6743 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D Suspended D 2. Name of Operator Pioneer Natural Resourses Alaska Abandoned 0 Service D 7. Permit Number 202-227 I 3. Address 310 K Street, Suite 200, Anchorage, AK 99501 4. Location of well at surface ft~+t:(:JJ/,!YL1 800' FSL & 900' FWL of Sec 16 T13N R8E UM ; i..:,',,~(:.':~; :V'f ¡ At Top Producing Interval!..Q:...j2~6i At Total Depth 7500' MD 6739.8' TVD ¡ ._~B.':::..t 1274' FSL & 1199' FEL of Sec 17 T13N R8E1,."..m,o,,,,,.r",,',,,'_toIw." 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKS 52.5 feet ADL AD 0389951 12. Date Spudded 13. DateT.D. R~ched ,.1.1> 14. DateComp., Susp. Or Aband. March 17, 2003 Marc~003 p March 31, 2003 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 7500' MD / 6739.8' TVD 20' below the mud line YES 0 No D 22. Type Electric or Other Logs Run LWD: GR/Res/CNL/FDC. E-Line: GR/Res/CNL/FDC/Sonic/NGT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 68 K-55 Surface 130' N/A Drive Pipe 50' 7-518" 29.7 L-80 Surface 3526' 9-7/8" 542 sx ASL & 227 sx G 58' Top Job: 100 sx ASL Cmt Down-squeezed through port collar. 8. API Number 50-703-20438 9. Unit or Lease Name Natchiq 10. Well Number 1 11. Field and Pool Exploration 15. Water Depth, if offshore 16. No. of Completions 7.5 feet MSL 0 20. Depth where SSSV set 21. Thickness of Permafrost N/A feet MD N/A 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE TUBING RECORD DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. Date First Production PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for OIL-BBL Test Period> Calculated OIL-BBL 24-Hour Rate> GAS-MC F WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED To Be Sent Under Separate Cover APR 23 2003 Alaska orl & Gas Cons. Commileton Anchorage GC ØlJDMS b,;-· . CONTI"D ..~ REVERSE. SIDE APR :1 \1 2003 u.:dG~NAl Submit in duplicate Form 10-407 Rev. 7-1-80 ) 30. ) 29. GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME Top / Middle Brookian Top / HRZ Base / HRZ Top / Torok Top / Kuparuk Top / Nuiqsit 4404' 6295' 6430' 5735' 6613' 7035" 4343' 5737' 5844' 5312' 5991' 6341' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, Final well diagram, logs 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed Title for Ken Sheffield, Pres Date Patrick Foley o INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ') ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska SURVEY LISTING Page 1 Well bore: Natchiq #1 Wellpath: MWD <0-7500'> Date Printed: 10-Apr-2003 "¡. BAKER MUGMES INTEQ Well bore _~.!1l~L_.._.____.......__..__........._._____.__._....__._.__________.________.____ Created _._______.._..____________.____.__._______.___. Last Revised ~!º-IJ&.~_t____... __.. n __ __ _ ___... H_. _n.. _____ __ ._ _ . t~::.Mª..r=-~9__Q_~.__._ ____ __ __.._._.__.___________._...__..J__Q::ð-ºr:-_~_º03_____. _._--_.._---~-_._~-_.._,,- n._ _,.,._~..,__.._'...._._ _'.____.._ _,_ ....___ _ ________.__.._...."...._._ Well Name .Nª!9_t!t9..t!1. _ .--... ...,.._---,,---_.. -.---........ __..____________._._____ Govern ment I D .--..-------.-__._.___..__._____________.______.._~?_ª!J~.evised 12-Mar-2003 .'-._...._,.. "...,,__"...._____.___.....,._,__".._"'....."" _._...._...____,.. ·"m"_'_...,.____....___.___ __.._, ... ."~_.,~._...,__.__.,.. _ ___._....." _"'.. ._.." _....___.__..._. ."'_._.._....._"'_.,,____..__,__~_____~______,.___,____._ _.._.. _n___..__._n.'.'.____ ___. .___,..",_._,.."._.,..._.~___._._.,__~~_..___,___~____.____. __~, .____~.~__.____._.___,._._ --.------~_.__._--------_. --.-.....---.----,---.- ---,,--..-.,-------.- Slot --._---,--_.~--...--~-~._._.., -., .--.._~_._-".~_. -_._--~-- _._-,---~_. -_._-- _._--_.-,----~------_._-~-- ------·---------___0_..- .Nª.ill.EË___.._..__ .. .___.___.__Qdº..~ºr1bjQg____º!.1(L~ª~D_9_._____ _~at[!!:!º~_..._______._.___________.__ _~Q.o.gJtl:!~:tEË__________..__.__ _NQ_r:!b.....___.._.___.__~_ªªL___.__.__._..___ §Jºt1!1 ..__...._. .-__.___________9_Q4_~§ª.§~~~_Q_º__4ªI94J~~.1º.9_ N70 28 32.3219 -- -..-.---..---,-..."'''.--.--..- ----,--_._- W150 63.4223 800.18N .._ª_ªI~~tt=.:._ ____. _._ - --_..,-_.__._--_..---~...._---,-_._---------_._---,.--------.-..-.-.-.------ -..--.-_.._....._...,....______~..______._...__....___....________o___._____u_______.__~.___ _._------_._---~ Installation ---...-..-------------..-.----.--...------. ----.-----.---..---,.--.---- ~ª_r:D~__ _______ . Nachiq#1 .. - --- -,---..-----..-,-.....--.-.- '-'- .... ..~ªª_º!lg_.______.________._._NºB.bln9_____________..__...__._~-ºQL(;L§y_ªtem_~_ª.r:D..~.....___._____ .______.____________Nºrt..tL~Jj9.Q!!1~.D_L_ 486743.2698 6022786.7880 AK-4 on NORTH AMERICAN DATUM True t ª_gLº_ª!~.r:D. _. __. ________u...______._ ____..,_~._._."._.....____._,... _-'_._0'-"__' _"_'''_''_.___ .._._.". ,..__.______._~.... __...._____...__ .---.-...----.. -'---".--, -,-,.---...-- - "..-- '''--...-..-- -.-.-.--.---- ..--__ -_.._____"~_,___.._____ _.._.__..,,____. __.o__..·_·"·__~·___.....·.._o.___ Field Name Beaufort Sea Exploration Easting____ .Nºrt.hLl}g______________..___~.9_ºrº_.§y.ªlEË.rrLriªm~_________._u_________________J~º_rtlJ._ðHg..rlr:n.EË.!JL. 481458.3800 6028077.2700 AK-4 on NORTH AMERICAN DATUM True ..____.__________u_.__ ____..1927__º_ª~~m__.______._____..._ ---.------ _..,----.,- Created By For SKIP COYNER by Tom Jones . -_._-~._..-..-.__..._--_._- -- --.-.--.-.-----...-.-.-,-.- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.65 degrees Bottom hole distance is 2151.66 Feet on azimuth 282.73 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) ) SURVEY LISTING Page 2 Well bore: Natchiq #1 Wellpath: MWD <0-7500'> Date Printed: 10-Apr-2003 '&i. BAKER HUGHES INTEQ ~?:~II;~'~!" ............ '!\.'. '.................. :.................... '.':" "<1 #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska -----_.~,._,_._.._-_.._--_.__._--._-._,-_.".".~--,-_.'-..--..----.-.-------.-..- --'-'- ____w__..,,·.._____n________.____.._..__,_______._.''''''_._._____.-.____.___h._________.."_ Comments ________________.___.__..."..~_..~_._.,___".._._"'______"'__"'_" - ...._.__."_ ____ "._., n___.___._ "_"__..___ _.._..._~.._._. _._._'._ ....___.,.__... _._.__,.".. ____. .".~_.....,_,.,., _.,,__ "_._..___.. ,."'._ .'_____"_. ,,__,,_ __...__..__...____._. __'. - '._. ___..."._.._._. ,____'._.~, ___ 0" ,_~_,.,..,.__.. _.__ _,.,,_...._.____.._ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.65 degrees Bottom hole distance is 2151.66 Feet on azimuth 282.73 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) ') #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska SURVEY LISTING Page 3 Wellbore: Natchiq #1 Well path: MWD <0-7500'> Date Printed: 10-Apr-2003 r'¡. BAKER HUGHES INTEQ Well path Report MD[ft] Inc[deg] Dir[deg] TVD[ft] North[ft] East[ft] Dogleg Vertical ______._.___________.______. ___._________.______.____._____.___ ~/ 100ft] Section [ft] __ __º~ºQ____. _ ____QJ:tQ. . __.__~QQ____Q~_ºº______JLºº~___________º~ººs.____. __!1_00___________º~.9_Q_ . 2Z?:~Iº____d 0.97 ._.J3~J}t_ }~Z?:]§___ .__LZ~§_L§~.~.____ _u___º~~_º_.__________::1~_8jt ___________549.50 0.79 135.99 549.45 _________ 4.87S 4.39E 0.07 -5:~1.._ . . . ___ª_?§J~º________º_}-ª.______.__ . ____1?3. ~4_.m ._ __..____ª~_§_:~__ _..__.__ .______L.?:9S__ ____________._.·L~Q_~_.____._____.__.__º~_º_º_ _____._____ __._.:ª.~_ª-?_ .. . ... _ _JJ9_;3~_§'º_. __ _ ___. _ _ .__ º_·L~_m__ ._... _ _._J_?.1.~~_ª_ _____.___11º-ª: 56__..___...____.__ª:.~ª_§______ __u__lº_:§_~~_.._u__ .____.___._9_=9..1.... .._..__.______:1lA,!L . :t~ª!;)-,-~§ . _ __ _Q_·_Z~t _ _..JltZ·~L_._ __1ª~~ªª___. _n __JJJ-ª§______.t4:_Q~~_ _.Qj)§___ ___=_19_1.Z__ tE?-ª.t?º_ _H_ 0.79 .. 1J?:nL_ ___Jp-ªLJQ___. ____1?J~§.ª__ .__. _JZ~l§~____ ____ __.._º·_ººu____.______--=?:Q~?:~_ .__________J§F 0 .52 ______________J_:t4.___._____________J~ºJ_º___ ______ ___J_iE9._·_ªª___. ___ ._.. ._. _Jþ..: 12S__ __..____.____~.L~~~__ _._....... __ __. ._.....__Q~J4_____.____.___.___~±&I_ . ___.____~~ª?:ºª_.. __ _. .u__ ____.__ ___1.:.14._ __. .______.____1l~_=_~ª-_._____n_m?~61~~ª__._ _om. ____.Jª~~?_§______.______m 26.70 E.__ _______º=º_?_____ __m__ _ -30..:~J;L 2554.64 1.32 119.12 2554.32 21.64S 32.08E 0.07 -36.28 .". "..__._.~.__.'_"".,. ~_.._,. ___ ___.__"._ __._0.' ...__..._.,_..., ~__,______,___.u_.,,__.__,_.,____ ?ª_4_§:ºº 1.58 119.82 _:?ª44_:_9P___ _?:§.:.?§'~L..___ª.ªA:I~ ____JLº~L_____::~~:.~4_ ~1~_5.77.__J-,-4~Lu _____J41:g§__ ___...___;H~_~.:..?p _n._n_ __._~0.2º~L_ ___4_,Lªjg____._n __ ._. m__º1.Q___ _ ______::9-ºJ_.ª_. .. . ..n~~~'§~-ªQ. ____~.~_~º___ . __ __JI§.~_.~_Z __._9.4.~_E?J1___. ...__.~ª_:I~_ª___________4LJ_ª_I;__ __________.__º:4~.__.._m.__..:_§:t_ª4._ _ _ .__~§_44.J§L __ .. __?~§.~ _. ... .. J-ªQJ.P_____ . ___~.§.4~.:..~__ _.__ _ _.A.~:§§§. _n _._n __ _~Z~.?J}É_ ..____._ _____._Q_:~_4__________.::..5J?_::?:?_ _________~ª_4J.§~.____________~· 30____ __ ____.?29 .:.HL ___~ª_~!1§§ 47. Q;3S ..__._.________.J§.J.~~m_____._______.__?_:§.ª__._... _ ___:.§§_:QI 3738.87 8. 75 __~_ª?ß§ ;l'7~7.49_ 49.68S 35.60E 6.67 -46.32 _ _~ª~§.&r. .. _J]~.? _ _~Z_tº§._ _____ ___;3_~_~1_~.ª_Q__ ... 49}_~§___________ 16.89E _._____.___.___ 4.96 -28.16 _~ªª~_~~:tn_ _JJLª_9_.~?~-,Jtl __.__~~~J~.:?:§_4Z:~.~§_. ....-ªAI.'lÝ___ .... n___'!::?:?___.. __u=~:~§ _1Q_~ª~ª?____ _____.?L~JL_ . .. _ __:?ª:bp_? ._..___1QJJL?JL m_._ 4Q_~!?'§.___ .______.~__~.t~W___________._m_.._.1:..ª__L______._______28.:.4ª_ 4.t4A~_1f:t 25.51. ..~ªª_·_~I _____.__1tQ4.:§In__:?~L§§§_______?§._·§.ª'!Y_________ __-:Lªº_ ... .ßªA.~__ 4??:;3.3?_. 29.59 _4JH3.~§_ ._____41~_2._Jª Jf5:J§§_ ... u.J.1.~_ª.i'lÝ___ _ _ _ 4:t~______J.1L~7 _.___.4~21_~64 m_____.___________ 33.64 __________ 288.05 4275.90__________Q-'-94~___m_ 167.86W 4.12 163.34 _ . h . __4:t14·§ª_ __;lZ.~_3._ª_ .... _u___?:ª4_:~_Q__.___.__'~:_~~t5~__ _ __J!?J3_QN__ _ ._____~l~~Z~W____n._ .______4_:ººmm__ _.. _:?11-=~.EL __ ~§JtgL .__. _____4º~?:ª. _____gª4:.~_º_ n______.._44..~º·8º___ ._.__ªQ&ª_~___..._gz-ªAJ_YY..___n__.__._~__=~~__n__ __~.IZ:-ª_~__ ____.4_º-ºª~§ª _.n _.__:tt~ ._____2._ª-ª-:??:.______ . _.1§Q9..:º_ª__ ___4..º:..Q~tt_. m_ª40.14~___ __. ___ttº-____ __ __ 3..4_1.:_4.Q_ 47.º_4.27 41.55 284.35 __457~_AZ__ __6_t_Q-ª~_ ___4QJ.::46V'L._ 0.90 ._4.Q4.:.9_ª. ___________4Z99J~L___.____.__4~:_ª1______ _._~ª§.:.t~L_.._.______4ª4g_~l_L u_ _.___.IZ~ºJti_ ._____ 4ª-~J§'W__n_ ___~~.§º__. _ _____ 4-ª--ª:_ª-6_ 4ªª?..:~t2__ _ _. __4_~:ªº_______n__~86~_º-L _____._~?1~~?: n'_ .__un_95.69N _______ 528.93W____JJ...ª_.____m_.f5~6·§.Z_n _4Q~H?:..ªJL _ ____4J.:~§___ _ n ___~~t§_:1?_________~?87.46 _____·L13.56N 592.96W 1.62 __.___-ª-º_~QL 5094.90 42.93 . ~ª-4~-ª--ª__ _4ªª--ºJ)ª._ J ~_º-:4ª-_~º-§º-·_4ZY'! ___ 1·_ª-ºn . itª-_ª--I1 5190.03 47.06 283.75 4927.34 146.92N 721.67W 4.39 735.96 . . 5~ª§A4 46.12 ng_ª~:Z_~ 4.9jt2..:ªº n _163.421'!_ ..I-ªª--ªªW . -9-=ª-ª'r--- _ ___-ª05~?7_ {~~ci:~~ : iHcii i~{~~~-, ~~~::~ ~ ~~~i~, --~~::~6~ I ~:~; f- ~H6 5771.26 T _ --u-42~48T- - -~284~07l-u 5338.26 I . U 249~5ªÑ-!-- u-1-119.47Wr-- 1.06 ! 1146~I51 6061.97 I 40.70 283.17' 5555.68' 295.04N: 1307~ÓOW 1 0.65 1339.71 º~~4·23 u, _ _~.z:4~__. u _ ~~i§§~ _º~?:..º§._ _ª~)?.f2N_._ ___14-ª§:~_ºW~ J.Jl.._ _ l..§~_ª-=ª§_j 6643.72 35.34 282.21 601.5.5_ª ~ 36_9.89]'J _ 1 §§1.:.~_ª'^'~ 0.74 16~§þ3 : All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.65 degrees Bottom hole distance is 2151.66 Feet on azimuth 282.73 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) ) SURVEY LISTING Page 4 Wellbore: Natchiq #1 Wellpath: MWD <0-7500'> Date Printed: 10-Apr-2003 r4i. BAKER HUGHES INTEQ #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska ---_._.~...~-- Well path Report MD[ft] Inc[deg] 6935.32 _ ,,_ _ ~__'..,,_,_____n'__.'____.__ 7227.08 , __~_.,_,____,..._.'_..._n 7416.84 --"'-~'-"''''-''---'---''''-''- 7500.00 _ _0 _ '___""'_,,~.k,____'____""_" Dogleg Vertical [deg/100ft] Section[ft] _ _ _ ___]_:3-"ª-~L_.__ ___~ªª-..§~ J3..~§!t~9 __ _._._~º§J?lNmm__. 1 ªt~~~\lYm _.m._ ..m_____Q.:Z~____m__m1ª§Q·.º_~. 31.12 283.62 6503.06 443.29N 1966.60W 0.77 2015.66 ... - __ - ,.. - ___,~____,__. __._'. __ ___ , . - __ ..._ - __"_.._"."__,___ ._.,__._..,. ._, __,.,_____._"____..._____. _,,__ __.'_' ___ __.__._"_____________,_.__ - - ___._._.____"___..____._.._.... - . _.. ,,_____._n____._.. ___., '. .___.__,._..__ ..__.___._____.__"'__.._.__._._ 29.39 _____._______ 282.86 6666.~Jt_ _________46~.J-º!i___.___ 2059.6~Y'L._____.__..__.___º-~_~_______._______~J11.27 . ____..m_.~ª·.~º_. __.__. ...... .._...___~82 ~~º_______..___-º?]_ªu~ªº__ __._______....4 7 4:J.J.N__u___~_~8. 7 8'IY.________ _____u__.__L~L ____._._~.tºJ:~_ª_ Dir[deg] TVD[ft] North[ft] East[ft] All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.65 degrees Bottom hole distance is 2151.66 Feet on azimuth 282.73 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska SURVEY LISTING Page 5 Wellbore: Natchiq #1 Wellpath: MWD <0-7500'> Date Printed: 10-Apr-2003 r&i. BAKER HUGHES INTEQ Comments J~~tºlf!L..,___._ JV D [ft] ____.__ North [ft ]..___,__,~ª_~JlftL._._._..__.9_C?-':D_rr.I? nt.__..________._ .____._.____.______.. ______.._,_,__.____._____ 79-ºº_·ºº___..._º]~~~ªº._._._._4Z~JJ_N .... ....~Q~ª~.~.ªW .ErºJ~ç!ª_º.-º~ª_-:_NQ_§!JR.'{gy___._........._ .,._... ____.___ _____ _____.~...__.w....~.. .._.._..,.___._ ._.....__.'''._w "..- -...-.--.--,.--..----.-..------...-....-.-.---.-.. Hole Sections Diameter Start Start Start Start End End End Start Well bore 1LoL_. ., ..._ M.Qlf!l..._____IY-º_lf!l ___ .~º_dhlf!L.___ East[ft].___,_ M Q1ftL.__,____.IYQlftl__...__t'Jº_r!blftl___ J~'ªª!IJ!L____.______m_.._______ .~ZIª _....._ ___º~Qº_________º.ºº_ º~Qº~...º~Qº_E.. __~§4~~Qº___:3_!:?~.~~4_ ..... 4:3}9§_ _..__47~~7g_Nj~lçhlg._~~L_ _-ª_~/4..____~_§4_~:.ºQ.___._~_§~_ª~?_4___.._._4.:3_]__6JL.___47.27E__I§Q.º=-ºQ._..____6739.80 474.11 N 2098.78W Natchiq #1 " - .._~__. - _,.__________."__..._,, _. _""""_ ____ ___.~___,_ _______._.___ ,.,._.__._.__..._..._._ _..,_ .._.______._..._.__..,_ ___'..u"_. __,'___..._._~.__~ __.____._"'._.__. ___~.__ .~_._____.__... .._._..____._ ______~____.___. _____",__________ _~_.. _.__,_.__._.._.__..__~.__________ _._____,_.___.________. -._._.._,______._,_. ___~.__,_.._._.~_..._... .___.._____ _Çª_ªI.rtQ_ª_.____....__..__..___.__________.__._.._._._ ._..._.___.__.___.___ _.._. _____.____.._____________________.....______._____.___-----_____________ Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore .__Mºlf1L___.._. . IYQIftL_... ..... ~gdblf!l.___.I;ª§1IftL.___MºlftL,._.__JYÇHf!L__.__.Nºr:1tJlf!]__mgªê!L1:tL___.__..._..______.______.__.___________. 0.00 0.00 O.OON O.OOE 152.00 152.00 0.54S 0.47E Natchiq #1 13 3/8in Conductor . ._.__._"._.,,___.~,_.___ ____ - ___'_ _..______.________.___._.______.__".___.__m___.__·_ 7 5/8in 0.00 0.00 çasin.g - ._-_._.._._-----------"--~------- --.-------- ..---.-----.--.. ,---_.._~----~.------------ O.OON O.OOE 3529.00 3528.26 42.89S 47.28E Natchiq #1 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.65 degrees Bottom hole distance is 2151.66 Feet on azimuth 282.73 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated L-SO 130' ) Cut & pulled 13-3/8" casing 20' below the mud line. Cut & pulled 7-5/8" casing 28' below the mud line. 13-3/S" 6S# Balanced Cement Plug #5: 93' - 285' 23' below mud line to 220' the below mud line. (10 bbl) of Arcticset Cement Pressure tested plug to 875 psi. Tagged at 93'. 7-5/S" 29.7# L-SO Balanced Cement PluQ #4: 3090' - 4350' 266 sx (55 bbl) of "G". Pressure tested #4 to 875 psi. Tagged at 3090': witnessed by J Spaulding Cement Plug #3: 4350' - 5400' 266 sx (55 bbl) of "G". Cement PluQ #2: -5400' - 6450' 266 sx (55 bbl) of "G". Bottom Founded PluQ #1: 6450' - 7500' 266 sx (55 bbl) of "G" cement. ) Natchiq #1 Final Status -¡il'¡¡¡~)¡¡~~~':¡¡¡¡!~¡!¡ -II ~~~~~~~?:~:~::::~~~: ~:~~::~~::~\~:~ ~:~~?:::: ~~::~ Wž~~ 172' TVD 10 ppg Mud TOC / .......... 3090' M D ~:t.:t.::s 3526' MD [íll~tfliill:.j 4350' M D !illlllll!11111 I '. I ..........,..#3....:..........'.. ..:~:~: ~::':'::'::..".. -,....". :,.::p: :.: ~ %:..% .:" :.: ~ I . .1 i;;;:;:"::"~:':':"~:':'i~J · . ... . 3526' TVD 5400' MD I . .1 " " i;~:}~:~:} +~Ú~}m~~rn ~~i 6450' MD ......................................... i~~;J;:m~~~:~nn~mm:~m; _:::::::?:\::: #2 :\?\\\::... ........... ................ I:::::::::: ::: ~: :::::: ::::~ ::: ~ :;~: ::: :; ~: ~: ~:~ ~:~:~: :~ ;: ~:; :;) ......................................".. '......................................... -: ::::. '::. '::. '::.": ::: ::::.": ::::. ';:. ': ::: ::::. li:::;::~ ::: ::::::: ::::i ::: :::~::;~::i:; :i:::;:~::i:~ ::: ::: ~i .......................................... · ,':. ',.:. '::. ',':' '::."; ::,,' ::: ::::. '::. ': ::::. ': :":':.. ......................................... 1-"::--:':-::-'-:":':'::":':'::·'::-'-:-'::·'::·'::.': :::::~ ~::~ ~::::::/:::;:;: ~:::<::::::\<:~~::: ::::J ........................."................ · ': .:<.:.:. :.: .:. :.: .:-:.::.::.: :..:.:::.:::. (. :.:-:. ~': ~.:.: -; :.:-:.. f:::::::;:\?: #1 ::::::::X:~\:{I '....'....... .......,....... I- ; :::~::~ ::: ::: ::: ;: ~~ ~: ~~ ::: ::: ::: ~ ~ :::~:~::~ :::;: :; :~ ::::~ ~: ::1:- ........".......,....-................... :.:.:.:.:.::. :.: .:.:.: ~:~.:.:.: .:. :.: .:.:.:.:.:.: .:.:.:.:.~.: .~:.: :.:.:.:.:. ......................................... .~.::. ~'::: ::: :::.: .::. ~':. '::.':.: '::.': ;:::, .:::.. ,......................................... I,:·,::·,::·,:::::·,::·,::·,:,::::·,::·,::·:,:·':·,'::. ;::::::~:\:::::::;:\?::::;:~:::::::;::::::::::;~::::::J ................,........................ .;.;..;.;....~.~..;.;;.;....~..~..~..~ 6740' TVD 7500' MD ) ) ,.¡f'~~ ï~~' ,.!, ~~~\~..'" . .,,\.~ " . .' '¡;¡'i , " <PIONEER . "~Q·'~~"·~~~{!s';~,~~~:~{·~~¡;;"í;,::~f, . " , ., .,' .' " , " . " '. .... .:' ':.PI()N~E.~:NATUFtÄLiRÊ~OLJ~PES:: ..... . :.:'pperêl~iO~S:$utnrn~ry'Rèp.ort '. . .. .Pa.g~1 of 3 Legal Well Name: NA TCHIQ #1 Common Well Name: NA TCHIQ #1 Spud Date: 3/17/2003 Event Name: ORIG DRilLING Start: 3/9/2003 End: 4/3/2003 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2003 Group: Rig Name: NORDIC Rig Number: 3 Sub '. . ·····Dàte From .~ To Hours ··Code Pha~e " QesÇriþtion of9p~ration$. . Codè 3/13/2003 06:00 - 06:00 24.00 002 MIRU MOVING INTO LOCATION ALONG LAST THREE MILES OF ROAD, BROKE THROUGH SEVERAL TIMES, CURRENTLY AT 0.9 MILES IN (ICE ENGINEERS INDICATE THAT WE ARE AT THE END OF THE BAD PORTION OF THE ROAD) WILL BEGIN REPAIRING ROAD BEHIND THE RIG TODAY 3/14/2003 06:00 - 06:00 24.00 002 MIRU Move Rig down Ice road to Natchlq Island. Rig Is 1.1 mile from location. Setting matting boards In front of rig to move over ice road. 3/1512003 06:00 - 06:00 24.00 002 MIRU Move rig down Ice road to Natchiq Island, lay rig mats on road. 3/16/2003 06:00 - 06:00 24.00 003 MIRU Rig up, Nipple up dlVerter, Repairing Ice road (approx 75% complete) 3/17/2003 06:00 - 06:00 24.00 003 PROD1 RIG UP, TAKE ON MUD, PREPARE FOR SPUD, P/U DRilL PIPE & BHA 3/18/2003 06:00 - 12:00 6.00 002 CSGSUR PICKED UP DP, ETC. TOOK ON SPUD MUD FROM IVIK#1. LOADED CASING IN PIPE SHED. PREPARED TO SPUD. 12:00 - 15:30 3.50 006 CSGSUR SPUD NATCHIQ #1 AT 12:00 NOON ON 3/17/03. DRilLED TO 334' WHILE PIU BHA COMPONENTS. 15:30 - 16:30 1.00 210 CSGSUR TEST & ORIENT MWDILWD TOOLS. 16:30 - 19:30 3.00 006 CSGSUR RE-CONFIGURE BHA, P/U 6" DC's, ETC. 19:30 - 06:00 10.50 006 CSGSUR DRILLED 9-7/8" SURFACE HOLE TO 1225'. OART: DRLG AT 100-125 FT/HR, MW III 9.6 PPG. 3/1912003 06:00 - 08:00 2.00 006 CSGSUR DRILLING 97/ff' SURFACE HOLE 08:00 - 08:30 0.50 016 CSGSUR SERVICE TOP DRIVE 08:30 - 13:30 5.00 006 CSGSUR DRILLING 9 7/8" HOLE 13:30 - 14:00 0.50 210 CSGSUR RE~lOG INTERVAL 1545-1578 14:00 - 23:30 9.50 006 CSGSUR DRILLING 9 7/8" HOLE 23:30 - 00:00 0.50 016 CSGSUR SERVICE TOP DRIVE 00:00 - 06:00 6.00 006 CSGSUR DRILLING 9 7/8" HOLE 3/20/2003 06:00 - 19:30 13.50 006 CSGSUR DRILLED 9-7/8" SURFACE HOLE TO CASING POINT AT 3549'. HAULING DRILLING WASTE & CUTTINGS WITH "SUPER SUCKERS" FOR DISPOSAL TO DS-4IN PRUDHOE BAY. MW = 9.7 PPG. 19:30 - 20:30 1.00 010 CSGSUR CIRCULATED BOTTOMS UP & CONDITIONED THE HOLE. 20:30 - 06:00 9.50 013 CSGSUR BACKREAMED OUT OF THE HOLE TO THE BHA. THE HOLE WAS TIGHT. RECOVERED LARGE AMOUNTS OF CLAY, ETC. WHILE BACKREAMING. 3/21/2003 06:00 ~ 15:00 9.00 013 CSGSUR WIPER TRIP: PUMPED OUT (BACKREAMED) OUT OF THE HOLE. MUCH TIGHT HOLE & MANY CUTTINGS, ETC. RIH & RE-REAMED TIGHT SPOTS. 15:00 - 16:30 1.50 010 CSGSUR CIRCULATED & CONDITIONED THE HOLE FOR CASING. 16:30 - 22:30 6.00 012 CSGSUR POOH TO RUN SURFACE CASING. 22:30 - 06:00 7.50 028 CSGSUR RUN GBR CASING TOOLS. PJSM. RAN 7-518" SURFACE CASING. 3J22J2003 06:00 - 09:00 3.00 028 503 CSGSUR WASHED 7-518" CASING TO BOTTOM: SHOE AT 3526' MDrrvD. HOLE WAS PACKING OFF & VERY STICKY. PARTIAL RETURNS. 09:00 - 12:00 3.00 010 CSGSUR CIRCULATED & CONDITIONED THE HOLE FOR CEMENTING. PUMPED A CARBIBE AROUND FOR A FLUID CALIPER: ESTIMATED AVERAGE HOLE SIZE = 10.25". 12:00 -17:00 5.00 026 CSGSUR RIU DOWELL. TESTED LINES. PUMPED 50 BBL OF CHEMICAL WASH FOLLOWED BY 50 BBL OF "MUD PUSH". MIXED AND PUMPED 413 BBL (542 SX) OF ARCTICSET LITE CEMENT (10.7 PPG & 4.28 CF/SX) FOLLOWED BY 47 BBL (227 SX) OF CLASS "G" CEMENT (15.8 PPG & 1.16 CF/SX). DISPLACED WITH 155 BBL OF MUD. PLUG BUMPED. FLOATS HELD. HAD PARTIAL RETURNS (EST 40%) FOR THE FIRST 385 BBL OF LEAD PUMPED THEN LOST COMPLETE RETURNS. FINISHED Printed: 4110/2003 11:29:19 AM ) ) - , Æ,'~"'~ ¡)~~J. ' 1:.1 r~~ :;1: - --PIONEElt · , ~':,'~'~ :~~,ÿ.:·;í. ';,I~'{~',~.~:,~~"~~::;~ t, , , ", . , " '. ," . , . ,,',,' '. ," ",.. '. PIQNEERNATURÅL :RESOURCES - .·Q~e~()n$Su·IÎlrÌ1~~~~P()~ ... ... page 2()f3 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NATCHIQ #1 NA TCHIQ #1 ORIG DRILLING NORDIC CALISTA NORDIC Start: 3/9/2003 Rig Release: 3/30/2003 Rig Number: 3 Spud Date: 3/17/2003 End: 4/3/2003 Group: Sub--- Qatè_ From-To tlours -,COdeCo(ie _ Phase> ,", ' , . - -DesçriptionorOperation~ i-: 3/22/2003 12:00 -17:00 5.00 026 CSGSUR PUMPING THE JOB WITH NO RETURNS. ESTIMATE TOC AT +1- 1500' FROM SURFACE. RID DOWELL NOTIFIED AOGCC FIELD INSPECTOR & "ON CALL" ENGINEER. 17:00 - 19:00 2.00 031 CSGSUR WASHED OUT WELLHEAD & BOP's. UD LANDING JOINT. SET CASING PACKOFF & TESTED SAME. 19:00 - 20:30 1.50 031 CSGSUR OPENED PORT COLLAR AT +/- 90' RKB. ESTABLISHED INJECTION RATE FOR "DOWN SQUEEZE" TOP JOB. CLOSED PORT COLLAR. 20:30 - 00:30 4.00 004 CSGSUR NID DIVERTER LINE & NlU BLIND FLANGE. N/U BOPE. 00:30 - 03:00 2.50 025 CSGSUR RlU DOWELL. OPENED PORT COLLAR. "DOWN SQUEEZED" 13-318" X 7-518" ANNULUS WITH 75 BBL OF ARCTICSET LITE CEMENT AT 1.5 BPM & 78 PSI. OPENED CASING HEAD VALVE AND CIRCULATED THE ANNULUS CLEAN ABOVE PORT COLLAR. FREEZE PROTECT THE ANNULUS WITH CACL2 WATER. CLOSED & TESTED PORT COLLAR. RID DOWELL. UD COMBO TOOL. 03:00 - 06:00 3.00 004 CSGSUR CONTINUED N/U BOPE, PREPARING FOR BOP TEST. 312312003 06:00 - 08:30 2.50 004 CSGSUR NU BOPE. 08:30 - 18:30 10.00 021 CSGSUR TEST BOPE TO 4000 PSI AS PER PROGRAM: WITNESSED BY JOHN CRISP. 18:30 - 03:30 9.00 011 CSGSUR PIU BHA & DRILL PIPE. 03:30 - 04:30 1.00 022 CSGSUR CIRCULATED ABOVE THE FLOAT COLLAR & TESTED CASING TO 4000 PSI. 04:30 - 06:00 1.50 031 CSGSUR DRILLED SHOE TRACK 3/2412003 06:00 - 06:30 0.50 031 CSGSUR DRILLED OUT THE FLOAT SHOE & CLEANED OUT THE RAT HOLE TO 3549'. 06:30 - 07:00 0.50 006 CSGSUR DRILLED 10' OF NEW HOLE. 07:00 - 07:30 0.50 010 CSGSUR CIRCULATED THE HOLE CLEAN & POOH INTO THE SHOE. 07:30 - 08:30 1.00 022 PROD1 RAN FIT TO 14 PPG EMW. RIH TO BOTTOM. 08:30 - 23:00 14.50 006 PROD1 DRILLED TO 4439' TO BURY THE BHA & AVOID MAGNETIC INTERFERENCE. 23:00 - 00:00 1.00 010 PROD1 CIRCULATED BOTTOM UP 00:00 - 06:00 6.00 007 PROD1 BACK REAM 4404-4307, POOH, ORIENTED THE BHA AND BUILT ANGLE BY SLIDING AS PROGRAMMED. DOWNLOAD CNUFDC TOOL, RIH 3/25/2003 06:00 - 07:30 1.50 011 PROD1 TESTED MWD. RIH WITH PDC BIT AND BHA TO DRILL THE TANGENT SECTION. REDUCED THE AKO SETTING TO 0.8 DEGREES TO DRILL THE TANGENT. 07:30 - 10:30 3.00 011 PROD1 P/U ADDITIONAL DRILL PIPE. 10:30 - 11 :00 0.50 009 PROD1 PRECAUTIONARY WASHED TO BOTTOM. 11 :00 - 06:00 19.00 006 PROD1 DRILLED TANGENT SECTION WITH PDC BIT & BAKER PDM - SLIDING TO CORRECT AS NEEDED. 3/2612003 06:00 - 16:30 10.50 006 PROD1 DRILLED TANGENT SECTION - SLIDING AS NEEDED FOR CORRECTIONS. 16:30 -17:30 1.00 010 PROD1 CIRCULATED & CONDITIONED HOLE. 17:30 - 20:00 2.50 013 PROD1 MADE A 2O-STAND WIPER TRIP: OK 20:00 - 06:00 10.00 006 PROD1 DRILLED TANGENT SECTION - SLIDING AS NEEDED FOR CORRECTIONS. 312712003 06:00 -17:30 11.50 006 PROD1 DRILLED 6-314· HOLE TO TD AT 7500' MD 17:30 - 19:00 1.50 010 PROD1 CIRCULATED & CONDITIONED THE HOLE. 19:00 - 21 :30 2.50 013 PROD1 MADE A WIPER TRIP TO 6300': OK PrintBd: 4/1ar2003 11:29:19 AM ) ) ~IO~E~~~I\T\J~!-Rk$qURÇE$ ..PlQe3 of3 -·9per.tiQns."~~m:mf1ry-·_fi~_PP~ .-- legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From ~ To· -- Hours .COd~~~e.'p~a~e- 3/Zl12OO3 3/28/2003 3/2912003 3130/2003 3/31/2003 4/1/2003 4/2/2003 NA TCHIQ #1 NATCHIQ#1 ORIG DRilLING NORDIC CALISTA NORDIC Spud Date: 3/17/2003 End: 4/3/2003 Group: Start: 3/9/2003 Rig Release: 3/30/2003 Rig Number: 3 :- :-Desçription of Operations _ - 21 :30 - 23:30 2.00 010 PROD1 CIRCULATED & CONDITIONED THE HOLE. SPOT 100 BBL PILL. 23:30 - 05:30 6.00 012 PROD1 POOH FOR LOGS. LID BHA& DOWN LOADED LWD DATA. 05:30 - 06:00 0.50 210 PROD1 RIU SCHLUMBERGER. 06:00 - 12:00 6.00 003 ABAND RIG UP SLB 12:00 - 17:00 5.00 019 ABAND FAST TRIPLE COMBO FROM 3390 TO 5800 17:00 - 23:00 6.00 019 ABAND NGT/SONIC 23:00 - 01 :30 2.50 012 ABAND LID HEAVY WALL AND FILL COLLARS 01 :30 - 04:00 2.50 012 ABAND PIU 3--1/2" TUBING 04:00 - 06:00 2.00 011 ABAND RIH W/1000' TUBING STINGER ON 3-112" DRILL PIPE 06:00 - 12:30 6.50 016 ABAND SERVICE RIG , 12:30 - 17:00 4.50 026 ABAND PUMPED P & A PLUGS FROM 7500 TO 3090' ,/ 17:00 - 23:30 6.50 003 ABAND LAY DOWN DRILL PIPE C.I.P. @ 1630 23:30 - 01 :00 1.50 026 ABAND CIRC & TAG CEMENT @ 3090 FOR AOGCC /' 01 :00 - 06:00 5.00 012 ABAND LAID DOWN DRILL PIPE 06:00 - 08:00 2.00 026 ABAND PUMPED 10 BBL 15.8 ARCTIC SET T.O.C. @ 84' 08:00 - 12:00 4.00 027 ABAND W.O.C. 12:00 - 14:00 2.00 026 ABAND TAG CEMENT @ 93'. CHAIN OFF CELLAR BOX 14:00 - 14:30 0.50 021 ABAND TEST TÇ>P PLUG W/875 PSI FOR 30 MIN ,./ 14:30 - 16:30 2.00 219 ABAND CUT 7-5IW' CASING @ 88'. PULL WEAR RING, L.D. HANGER AND STUB 16:30 - 18:00 1.50 002 ABAND CHANGE OVER TO FRESH WATER AND WASH CASING AND BOPs 18:00 - 19:30 1.50 002 ABAND L.D. TOOLS AND CLEAN FLOOR 19:30 - 05:00 9.50 004 ABAND N.D. AND REMOVE BOP 05:00 - 06:00 1.00 004 ABAND REMOVE WELL HEAD 06:00 - 12:30 6.50 030 ABAND CaNT. TO NID BOP'S. CUT 13-3/8 CSG @ 80'. 12:30 - 15:00 2.50 030 ABAND LID CUTOFF 15:00 - 20:00 5.00 030 ABAND CLEAN MUD PITS 20:00 - 06:00 10.00 030 ABAND RELEASED RIG. PREP FOR RIG MOVE 06:00 - 06:00 24.00 002 ABAND CLEAN UP AND RIG MOVE 06:00 - 06:00 24.00 002 ABAND DROVE NORDIC 3 OFF THE ICE. USED DOUBLE MATS ON THE EAST-WEST NATCHIQ ROAD WITH NO BREAK THROUGHS. DROVE THE BEACH ROAD TO STP WIO MATS. THE RIG IS ON THE SPINE ROAD AT REPORT TIME. CLEAN LOCATION. HAUL OFF DIRTY ICE. Prinl8d: 411012003 11:28:19 AM ') REV DA TE BY CK APP DESCRIPTION NOTES: 1. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. GEOGRAPHIC COORDINATES ARE NAD 27. 3. ALL DISTANCES ARE TRUE. 4. BASIS OF LOCATION IS DRILL SITE 3R MONUMENTS, SET BY LHD & ASSOCIATES. 12 5. ELEVA TJONS ARE DERIVED FROM LEICA HI-PRECIS!ON GPS UNITS & ARE DEPENDENT ON GRAVIMETRIC GEOID MODELING. DATUM IS B.P.M.S.L. 6. DATE OF SURVEY; 3/8/03, F.B. L03-9, PC. 23. NA TCHIQ 1 LOCA TED WITHIN PROTRACTED SEC. 16, T 13 N, & R 8 E UMIAT MERIDIAN. 800' F.S.L., 900' F.W.L. LAT = 70'28'32.322" N LONG = 15Ø-06'03.422" W Y = 6,023,585.29 X ::: 487,641.91 ICE PAD ELEV.= 22.2' -0-0coguruk 1 36 W W :tI 32 ,.... CD I æ:æ: I , I I /'" 6 ......../0IVIK #1 9 I 0 11. 12 7 /,~ ~a THIS arE ~/,/, 0 DE:~INE 17 / " " >/,/'" 1:'>'!ft 20 21 Harrison Ba.y fí/:o0/ n_ ,Ó'// oS-J& P (ì \1 ~s-~ " " ", )l.~ ~ "" $OK: ~0"CJ "~ " I"~ 3~ 3~, /¡p:; ~~D~ .~ "\\ ~" \f)2 ~ '\ 0 U T 1 3N ~ ~ a ' T12N \f OS-31 " ~Q u.J l.d ð ~ C'~e; QADS 3H ~! ~ F 1 ,\ ~t ~ I 'f-" ~ .1 . ,\ ..--{) t ~ r 9000 QJ\ ~~ OS-JA '\ ~ 25 13 2~ ....., \ , 25\ \ \ \ ( ~ 400' I - - --- Rig--Pad - - - I I I I I : Natchiq 1 I 900' 1 I .. I.p- I · I~_ I I I I I <> I L-_._______.J ¡..... (J n 17116 20 21 w Pioneer Natural Resources Alaska, Inc. CADD FILE NO. LK601D512 3/10/03 I DRAWING NO: ) REV DA TE BY CK APP 30 29 ~~ThE tis Is?B ..~ "t 2 DESCRIPTION 2S 29 27 33 3<4 30 36 WW 31 CD(J\ æ:æ: 32 T14N l13N IB VICINITY MAP SCALE: 1" = 2 MILES ~"''''''''''''''' ~.....\,: OF A / II.., .. ~"\ \:.... ............ t.... L'/ C\ .. .,< í' .., ..~ì.~%. ... (" _" .......... .....:ä . ~./ ,+ ~......"" . ~ ~ ~ ~ (..~l.~..~.?~...~...:~SY ~~....... :....... ~....... if to': íQ ~ ....7": Q:: iI ~ ~.~ BRIAN G. MANGOLD .: f? 1':& ~ '. .' kI . .,.."" V',A ..... LS-8626 .,' ~ . ..... ~ '. ." .' ~. ~ -P~ ....~ _If) -O.~.·" C? ¿r .. 0 þ ........... ~\). '.... ;.rOF"[SSIONf>.\... \-~... ..",................... N 4Þ;: SCALE: 1" = 200' SURVEYOR'S CERTIFICA TE I HEREBY CERTIFY THA T I AM PROPERL Y REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STA T£ OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA T ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 7Ø, 2003. NSK NA TCHIO 1 WELL CONDUCTOR ASBUILT LOCATION 6.Ø1-d512 SHEET:, I REV: OF 1 0 Re: Pioneer eyes slice of Slope . . ) ) ~~~~ *'1 à:)d-Jð~ Subject: Re: Pioneer eyes slice of Slope Date: Fri, 11 Apr 200309:28:38 -0700 From: Park.Chae@epamail.epa.gov To: Godsey.Cindi@epamail.epa.gov CC: Tom_Maunder@Admin.State.AK.US Cindi, I spoke with Tom Maunder at the AOGCC about this company (Pioneer Natural Resources Co.) According to Tom, the drilling occurred without any discharge. All potential discharges were collected and disposed of in a nearby class 2 injection well. Without a discharge, NPDES would not apply, which explains why they are not covered by an NPDES permit. I want to let you know Cindi that I appreciate you taking the time to bring things like to my attention. Cindi Godsey/R10/USEPA/ To: Chae Park/R10/USEPA/US@EPA US@EPA cc: Sent by: Subject: Pioneer eyes slice of Slope Anchorage Daily News <adn@nandomedia.c om> 04/07/2003 01 :56 PM Please respond to Cindi Godsey The following adn.com article was sent by: Cindi Godsey (godsey.cindi@epa.gov) And Cindi Godsey had this to say: Chae, I saw this story and thought that these guys didn't have permit coverage under the Arctic GP and I am not sure how they could have drilled 3 wells from an ice island without discharging so thought you might want to look into it. Any comments on the North Slope GP?? --------------------------------------------------------------- Pioneer eyes slice of Slope Oil: Though exploration yields modest results, Dallas company plans another test. 1 of 2 4/11/20038:38 AM ,Re: Pio~,eer eyes slice of Slope ) ) By WESLEY LOY, Anchorage Daily News Published: April 1,2003 A Dallas-based oil company on Monday announced mixed results from its first round of exploratory drilling on the North Slope. Pioneer Natural Resources Co. said all three wells it drilled in shallow water northwest of the Kuparuk oil field struck sandstone filled with oil but the sands were "too thin to be considered commercial." Pioneer added, however, that it found Jurassic rocks, which are deeper and older, and one well flowed at a sustained rate of 1,300 barrels of oil per day. The well will undergo a pressure buildup test to determine whether the find is worth developing, the company said. You can read the full story online at: http://www.adn.com/business/story/2872950p-2909203c.htm I --------------------------------------------------------------- This article is protected by copyright and should not be printed or distributed for anything except personal use. For information on reprinting this article or placing it on your Web site, please contact the Daily News marketing department at (907) 257-4429 or marketing@adn.com. 2 of 2 4/11/20038:38 AM BUSINESS DEVELOPMENT J. Patrick Foley Alaska Land & Negotiations Consultant (907) 264-6750 . (907) 830-0999 mobile PIONEER NATURAL RESOURCES ALASKA, INC. March 28, 2003 Mr. Randy Ruedrich, Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501-33539 HAND DELIVERED Subject: Natchiq #1 Permit No. 202-227 API No. 50-703-20438 Form 10-403 Application for Sundry Approvals Harrison Bay, North Slope, Alaska Dear Mr. Ruedrich, Attached are duplicate original copies of form. 10-403 Application for Sundry Approvals relative to the abandonment of the Natchiq #1 Well. We intend to commence plugging operation immediately upon receipt of your approval. We ask that you review and approve this activity at your early possible convenIence. Should you have questions on the matter please call Skip Coyner at (907) 743-0921. Skip may be reached today on his cell phone (907) 748-3689. Please call me as soon as the form. is approved and I will rush over to pick it up. Thank you for your quick help! Best regards, Æf:~~ F:'::~'~"-: (~:i ~:~~ ~ \i':'_~ 0 !- r........ '" ....;,.. (- Cc: Ken Sheffield - Pioneer Natural Resources Alaska, Inc. Rusty Cooper - Pioneer Natural Resources Alaska, Inc /~~~~i~3 C>:ri .;~ \~~.':-~; 1_"":C,'''~'~. '.~,~·::~~;"Ù¡·I,~'3~on ./~': "'~>·.ft~'.~~f:~ O~:G'NAi. 310 "K" STREET, SUITE 200, ANCHORAGE, ALASKA 99501 . . FAX (907) 264-6743 ) ) W6¡\-. ')/2;~( WOs OfJJ :J) 2J>'/CJ _-:::> ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon X Suspend _ Alter casing _ Repair well _ Change approved program _ Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: 2. Name of Operator Pioneer Natural Resourses Alaska Development _ Exploratory _X Stratigraphic _ Service Re-enter suspended well _ Time extension Stimulate Variance Perforate 6. Datum elevation (DF or KB feet) RKB 52 feet 7. Unit or Property name Natchiq / Other 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 800' FSL & 900' FWL of See 16 T13N R8E UM At top of productive interval None At effective depth At total depth 1272' FSL & 1199' FEL of See 17 T13N R8E UM 12. Present well condition summary Total depth: 7500' MD 6740' TVD 8. Well number 1 9. Permit number / approval number , Nov-02 202-227./ 10. API number 50-703-20438 11. Field / Pool Exploration Casing Length Size Cemented Measured Depth True vertical Depth Conductor 100' 13-3/8" Drive Pipe 130' 130' Surface 3496' 7-5/8" 542 sx (413 bbl) ArcticSet Lite 3526' 3526' 227 sx (47 bbl) Class "G" Top Job 1 00 sx (75 bbl) ArcticSet Lite AI~&:~a CH '~;':~:~;I;;;';;mon 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketbn:;",..::~~_~:' Refer to attached morning drilling report for LOT test, surface cement details and casing detail sheets, schematic _ 14. Estimated date for commencing operation 15. Status of well classification as: March 28, 2003 16. If proposal was verbally approved Oil Gas Suspended _ Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ ¡:;... KH.r enneth H, Sheffield, Jr_ Questions: call Skip Coyneer at 748-3689 Title: President Date ~'~:J FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness \/ Plug integrity'x BOP Test _ Location clearance ð. Mechanical Integrity Test _ Subsequent form re~ired 10- 4D7 I Approval no. :10;-; _I í) :- -....y--. :) . ~.., .) Form 10-403 Rev 06/15/88 . L--S ~ Commissioner RBDMS BFl OR G NA_ Date :ý¿ &/05 Approved by order of the Commission .-...,t',";'ì SUBMIT IN TRIPLICATE ) NATURAL RESOURCES Weekly Operations Report N atchiq # 1 Permit No.: 202-227 April 4, 2003 · De-mobilized Nordic #3 back to Kuparuk. Rig move down the ice road went without incident (no break through's). · Scraped the ice pad and disposed of all dirty ice. Back - filled the cellar with clean ice. · Closed the road. · Final report. No accidents or injuries. Skip Coyner NTS/Pioneer ) .., Weekly Operations Report Natchiq #1 Permit No.: 202-227 NA.TURAL RæOU~~::ES March 21, 2003 · MI & RU Nordic 3 on Natchiq #1 including camps, solids control van, satellite phone, etc. · RU diverter "T", diverter line, etc. · Function tested diverter system: witnessed by Chuck Sheve. · Spud Natchiq #1 at noon on March 17,2003. · Drilled 9-7/8" hole to 3549'. · Made a wiper trip to the BHA. RIH, circ & cond, POOH to run casing. · RJU & ran 7-5/8" casing. Washed 80' to bottom: tight hole. · Ran "carbide fluid caliper" for cement volume estimate. · RJU Dowell to cement surface casing. No accidents or injuries. Skip Coyner NTS/Pioneer ) Cut & pull 7-5/8" & 13-3/8" casings 5' - 10' below the mud line. Recover the cellar. Clean location. 13-3/8" 68# Balanced Cement Plug #5: 85' - 285' 22' below mud line to 222' bekow mud line. (10 bbl) of Arcticset I. Casing Volume + 10%. Pressure test #5 per AOGCC regulations. ~/ 7 -5/8" 29.7# Balanced Cement PluQ #4: 3300' - 4350' 266 sx (55 bbl) of "G". Volume is caliper (7") + 10%. Pressure test #4 per AOGCC regulations. Tag test #4 per AOGCC regulations. ,..- Cement Plug #3: 4350' - 5400' 266 sx (55 bbl) of "G". Volume is caliper (7") + 10%. No tag required per J Spaulding AOGCC Cement PluQ #2: 5400' - 6450' 266 sx (55 bbl) of "G". Volume is caliper (7") + 10%. No tag required per J Spaulding AOGCC Bottom Founded PluQ #1: 6450' - 7500' 266 sx (55 bbl) of "G" cement. Volume is caliper (7") + 10%. No tag required per J Spaulding AOGCC L-80 130' L-80 ) Natchiq #1 Plug & Abandon 1!11¡~;¡I¡I¡lill .......'" Ii 172' TVD 10 ppg Mud ~~s~s~: .......-.,; 11 ~~-:.:.~, ~~~~~~: Toe !:.':::::.: ~~m~,.:...~.~~.ro.R.:..:: ~~~~~{ 3526' MD ..._.......................................' ~~Jlilflì immm~~mmmm~t ì~~iill.~¡lli~¡mr.~ ¡1!11¡~;I¡rÎ~ · ~~~ ~...: .:"." .: .... :/::.. -: 0":.\". ..... .":::...... .... ...: .":: O"A-:. l~mm~m~mm~mm1 · ~.::.:. %~. ~:~.%.: %.::.:~.::~. ::;.;: -:::..::..: ~.:.: ~ (L~n~~1~~~~Y1~;{~ · :: .~ ~ :. :. .:.:: .~ ;::. :: :. ~ .:. :::.::.~ ::~:.": :~': :~ I~~~mmum~~m~m~~ ...... :OM:.: 0;,\".....·:.·::.-::.-:.°,·::..·::........:":.:·::0":. 1~~~~~W?~~~~:~~~mm~1 ···········#2··············· .:~:g:g~::: ~: ~:g:::::::g:g. I ~~:~m ~~~::~~~~~~~~~ ~~~~~~~~ · .:. :.: .:. :.: .: ~: .:. :: .:. :.:.: :.:.:. :.: .:. :.: .:. :.:.:. :: ~. :.: -: :.: -:.. !~~i~~mm~mmmf.i: I?KTnmnmm~:~~J · -; :: .:- :.: .:. :: -:. :.: .:. ~. .:. :: .:. :: .::: .:. ;: ~. ~: .:. ~: .:- :.: .;. (>%~ #1 nnUi imm¡¡!.mmmmm~ .;: .:.:-: .:.;::. :.::.:-: .:. ~ .:.:: .:. :-:.:. :.::. ::.:. ::.:.;: :.:.:. I~:~m~\m~mr{:~~:~{~g, 6740' TVD I··.··¡.¡;.¡.¡··.¡;·~··.;.··~··.··~ 3526' TVD 4350' MD ,) \ vt1 e,._~Þ ¡f ~ 1 \ 1'1IA"",t- . \ \ r)~/' ,!}Þ" i 5400' MD ) 6450' MD 7500' MD Pioneer Natural Resourses Alaska, Natchiq#1 ) ') Subject: Pioneer Natural Resourses Alaska, Natchiq#1 Date: Fri, 14 Mar 2003 14:29:09 -0800 (PST) From: V Coyner <v_ccoyner@yahoo.com> To: tom_maunder@admin.state.ak.us CC: skip_coyner@natchiq.com I appreciate your patients with me on this. Please correct my error on the am mended 401 submitted yesterday for the captioned well. The correction will make the bottom hole location on the 401 agree with Baker-Inteq's BHL: TVD: 7050 ft Location: 1444' FSL & 1752' FEL of Sec 17 T13N R8E UM Again, my appologies. Skip Coyner NTS/Pioneer 622-0030 748-3689 Do you Yahoo!? Yahoo! Web Hosting - establish your business online http://webhosting.yahoo.com 1 of 1 3/14/2003 1 :33 PM I, ) \, ~1r~T~ :,} fÆ -~fÆ~~~fÆ A..,A.SIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Kenneth H. Sheffield, Jr. President Pioneer Natural Resources Alaska, Inc. 310 "K" Street Ste 200 Anchorage Alaska 99501 Re: Natchiq # 1 Pioneer Natural Resources Alaska, Inc. Permit No: 202-227 (rev) Surface Location: 800' FSL & 900' FWL, Sec. 16, TI3N, R8N, UM Bottomhole Location: 1444' FSL & 1752' FEL, Sec. 17, T13N, R8N, UM Dear Mr. Sheffield: Enclosed is the approved revised application for permit to drill the above referenced exploration well. Since the bottomhole location was changed more than 500' laterally, a new approval was necessary. 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. 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. 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 to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED thisJ1.ãay of March, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ) ) PIONEER NATURAL RESOURCES ALASKA, INC_ Randy Ruedrich Chairman Alaska Oil and Gas Conservation Commission 333 W. ih Avenue, Suite 100 Anchorage, Alaska 99501 /' RE'CEi ED MAR ~!3 .3 OJi&Gæ', 'I@Iß March 13, 2003 Re: Exploration Drilling Permit Natchiq #1, Revised BHL Dear Mr. Ruedrich Attached is our application for a revised bottom hole location for the previously permitted Natchiq #1. Included are a revised 401, directional plan, casing program and plat. Should you or staff have any questions please contact Skip Coyner, Natchiq Technical Services at 907-339-6250. Sincerely, S~G~~ flft> Stuart W. Gustafson. Regulatory Affairs Pioneer Natural Resources Alaska, Inc Attachments: Natchiq #1 Application Package 310 "K" STREET, SUITE 200; ANCHORAGE, ALASKA 99501 FAX (907) 264-6743 ") STATE OF ALASKA ') ALA.,r(A OIL AND GAS CONSERVATION COMMISShJN PERMIT TO DRILL 20 MC 25.005 Drill 0 Redrill D o D 1 b. Type of well. Exploratory 0 Stratigraphic Test 0 Service D Development Gas D Single Zone D 5. Datum elevation (DF or KB) 52.5 feet 1 a. Type of work: Ammended 2. Name of Operator Pioneer Natural Resourèes Alaska Inc. 3. Address 310 "K"str., Ste 200, Anchorage, AK 99501 4. Location of well at surface 800' FSL & 900' FWL of Sec 16 T13N R8E UM Attop of productive interval 1230' FSL & 870 FEL of Sec 17 T13N R8E UM 6100' TVD Attotaldepth \4~'-\ ç:..~\... \"5~t:.G'- l.ii!r1,3/1«-1, ~L &p4'"FEL of See 17 T13N R8E UM 7050' TVD 12. Distance to ~earest property line I 13. Distance to nearest well 800 feet 3M-27 BHL, >11000 feet 16. To be completed for deviated wells Kickoff depth: 3620' MD 18. Casing program size Maximum hole angle Hole Casing Weight 13-3/8" 72 9-718" 7-5/8" 29.7 6-3/4" 5-1/2" 17 3-1/2" 9.2 Specifications Grade Coupling L-80 PE - L-80 BTG-Mod K-55 FJ L-80 BTG-Mod Length 80 3500 900 3250 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Effective Depth: measured true vertical feet feet Casing Conductor Surface Production Length Size Cemented Perforation depth: measured true vertical 6. Property Designation AD 0389952 I 7. Unit or property Name Natchiq 8. Well number 1 l8-?JV( ~1\,~ Development Oil D Multiple Zone D 10. Field and Pool Exploration 11. Type Bond (see 20 AAC 25.0251) Statewide Number 103655283 9. Approximate spud date Amount March 15, 2003 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 1280 8088 I MD /7050' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3000 psig At 6100' TVD 3615 psig (Kup G) Setting Depth 44° Top MD 32 o 3350 4350 Bottom TVD 112 3500 4300 ;¡JJfj(]' ~ ~<š6 ')C\'ÇC) k~( :, Plugs (measured) Quantity of Cement (include stage data) Drive Pipe 433 sx AreticSet LiteL & 202 sx G 113 sx of Premium + 8% Gel & 558 sx of class G Expanding cmt True Vertical depth RECEIVED ~1AR 13 2003 Oil &GæGons.o.Rsion ~ Commission Use Only I Approval date Mud log required Directional survey required D 10M;D 12/3/2002 D ~Yes TVD 32 o 3350 4300 MD 112 3500 4350 20. Attachments Filing fee D Property Plat D BOP Sketch D Diverter Sketch D Drilling program 0 Drilling fluid program DTime vs depth plot LRefraction analysis DSeabed report 020 MC 25.050 requirements 0 21. I hereby certify that the foregoing is true and cor~ect to the best of my knowledge Questions call S. Coyner 339-6269 S;gned ..G? ~ ~~...e- F.,r Title: forKenSheflield, Pres Date 11:J, t ~ patriC~--,l ~ r' VOj I API number 202-227 50- 703-20438 Conditions of approval Samples required ~ Yes D No Hydrogen sulfide measures D Yes ~ No Required working pressure for BOPE D2M; D 3M; ~ 5M; Other: ~~\ \S()\'-\<,-S-\- Approved by J\Þ--j ~~ Permit Number Form 10-401 Rev. 12/1/85 · Junk (measured) Measured depth Commissioner by order of the commission fee cover letter for other requirements Yes U No D No Date ¿?Y/¡Y&J Submit in triplicate ) DESCRIPTION ) REV DAlE BY CK APP REV DATE BY Cr- APP 29 28 27 26 25 30 32 COOGARUK #1 -0 33 34 35 36 31 NOTES: 1. COORDINATES SHOWN ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. GEOGRAPHIC COORDINATES ARE NAD 27. 3. ALL DISTANCES ARE TRUE. NA TCHIQ No. 1 BOTTOM HOLE LOCATION LOCATED WITHIN PROTRACTED SEC. 17, T 13 N, & R 8 E, UMIAT MERIDIAN. 870' F.E.L, 1230' F.S.L. LA T = 70°28'36.55" LONG = 150°06'55.50" Y = 6,024,018.7 X = 485,872.Ø ~ ( 870' -. N (> ÌSI I") N w DESCRIPTION 29 ~ 28 Thetis Is. 3~ 3 2 32 33 T14N T13N 3 2 ~ '>;r -S>O 1 0 "2 .<1/ Q¿.... 6 0- IVIK #' 12 10 11 NATCHIQ #1 15 14 13 18 17 16 15 14 BHL-0 -0 SL 22 o THIS" SITË ,,, 21 22 23 27 26 25 30 29 28 ~ AJAJ ~ ~~ \ ""CO "" I"'ll"'l 31 32 ~() ~<&\ ~ ~~ C' ôr13N ~ ( \ ~ . J ~Q T1¿; ~ <f:.t ~ c \) ~ ~¢>I: . ~ 3Hi-sl \)~ 1 C'~4'<t" 11 Q ~ , D ? a % V 900qó U~~~\ " n ð" <;1 _C'. ] ^' Q VICINITY MAP SCALE: 1" = 2 MILES ~ ~ 900' NATCHIQ No.1 SURFACE LOCATION LOCATED WITHIN PROTRACTED SEC. 16, T 13 N, & R 8 E, UMIAT MERIDIAN. 9ØØ' F. W.L, 8ØØ' F.S.L. LA T = 7ø028'32.32" LONG = 15øoØ6'Ø3.42" Y = 6,Ø23,585.3 x = 487,641.9 ADL Ø389951 ) ~ "" (> (> ÌSI !S! ex) 1~6 20121 I w ^v Pioneer Natural Resources Alasks, Inc. CADD FILE NO. LK601D514 3/13/03 DRAWING NO: NATCHIQ #1 EXPLORATORY WELL PERMIT EXHIBIT NSK 6.Ø1-d514 SHEET: 1 OF 1 REV: ø 00coguruk 1 1. COORDINATES SHOWN ARE ALASKA STATE 36 WW:fl 32 PLANE, ZONE 4, NAD 27. b2~ / 2. GEOGRAPHIC COORDINATES ARE NAD 27. / 1 ","'" 6 S 3. ALL DISTANCES ARE TRUE. ......../0IVIK #1 4. BASIS OF LOCATION IS DRILL SITE 3R ,. MONUMENTS, SET BY LHD & ASSOCIATES. 12 5. ELEVATIONS ARE DERIVED FROM LEICA HI-PRECISION GPS UNITS & ARE DEPENDENT ON GRAVIMETRIC GEOID MODELING. DATUM IS B.P.M.S.l. 6. DATE OF SURVEY; 3/8/03. F.B. LØ3-9, PG. 23. 9 10 II 12 7 I'JL. ~8 _ THIS arc' ~"'~ 0 OE:~INE I ' ". / - $-30 .s 17 6 " ... ,>7, " t:. '~ Harrison Bay ~o-t;"" ßY1 I' \f- c.-r... ". DS-Ju; f: S n ~/ \.p DSJN ¿,;7i ~ _'26 25 L J" 2f) ~ ~ ()~ ~ \'IESI SAK 16~ \J ~ "' 3~~ I....~ ~~c~ .~~, 36\\_. ~ 31 W2 ~ " () U T13N '\ ~ II a ' T 12N \ ~ D5-3\ ., ~a ww \ ~ G ~Q D ~ I ~~'ì 6 5 Q \OS-3J ~<9/ \ ~ \ ' F C'~4"; DS Jt.I r ~ \ ~~ ~. ~ " Qt:;. \ì\~. · 9o°~u~~~ ~~ VICINITY MAP SCALE: 1" = 2 MILES SURVEYOR'S C£RTIFICA TE I HEREBY CERTIFY THA T J AM PROPERL Y REGISTERED AND LlCENSED TO PRACTICE LAND SURVEYING IN THE STA TE OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA T ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MARCH 12. 2ØØ3. REV DATE BY CK 1 3/11/Ø3 MRT NOTES: APP _DESCRIPTION )tion Offset Distance ~5 30 Edit 13 24 NA TCHIQ1 LOCATED WITHIN PROTRACTED SEC. 16, T 13 N, & R 8 E. UMIAT MERIDIAN. 8ØØ' F.S.L., 9Ø0' F. W.L. LA T = 70'28'32.322" N LONG = 150'06'03.422" W Y = 6,023,585.29 X = 487,641.91 ICE PAD ELEV.= 22.2' ~6 "Ill :s ð. ~ ' \r" ( 400' ! - - - Rig Pod - - - "I I I I 1 : Natchiq 1 ¡ Py' I 90Ø' ) ß I.p.- I A I~ I I I I ¿ I L_________~ ~ CS1 ro 17 ¡ 16 20 21 'Ii Pioneer Natural Resources Alaska, Inc. CADD FILE NO. LK6Øl D512 I DRAWING NO: 3/10/03 APP DESCRIPTION '1 <?5 30 29 35 36 WW 31 32 0)0" æœ: 2 6 REV- -- DATE BY CK 29 ~~ThEtiS Is~Ð ) , 27 33 34 T14N T13N 3 B 30 29 28 ~~"''''''... ......c OF A¿ -., .+ 'r:\ v ".......... .L1~'. .. ^ .... '..;1,:.. '" r ~" ..' ........ ; - .J..... ~..... ~ ." ~ . ~ É..·:l...···~~?~..·~ . j, .Æ..::.:;.........~...... .~......... ,.. " .~ '''r' -~_ ~ ~ '::.. BRIAN G. MANGOLD l E. 1';A.~' '/.". 1';A. \$loA .... LS-8626 .... a:~ . ....... ~ "". ? .' >0' ... "'. -?<') ··..~~Z....o ;:...... c.;; ~ +. () þ ........... ~\). ,_.. ~OF'E'SSIONÞ.\.. \..~.... ......"'........-: NA TCHIQ 1 WELL CONDUCTOR ASBUJL T LOCATION I SHEET: 1 NSK 6.Ø1-d512 N + SCALE: 1"' = 200' 'REV: OF 1 1 ) ) :) ON ==~ NA,TU RA.L RESOU RCES Revised Exploratory Drilling Program Well Name: Rig Days: AFE NO.: Natchiq #1 15 TBD Classification: API No.: AOGCC Permit: Exploration 50-703-20438 202-227 Drill and Complete (Test & Abandon off Rig) Estimated Spud: March 15, 2003 Prepared By: S. Coyner EXPLORA TION OBJECTIVES FOR WELL: 1. Drill the well through the Kuparuk "C" as directed. 2. Run the completion as directed. MORT. 3. Peñorate and test the well. 4. After testing, plug back as required using E-Line, etc. 5. Properly plug and abandon - without the rig. 6. Cut off all casing strings below the mud line. HSE OBJECTIVES FOR WELL: 1. No Lost time Accidents. 2. No Spills. 3. No environmental damage 1 Natchiq #1 Drilling Program ") I Well Name: ) Natchiq #1 Drilling and Completion Plan Summary I Type of Well: Directional Suñace Location: Target Location at 6100' TVD: I Drill, Case, Complete, Test and Abandon North 6,023,585' East 487,642' 800 ft FSL & 900 ft FWL of Section 16, T13N, R8E UM North 6,023,907' East 486,325' 1230 ft FSL & 870 ft FWL of Section 17, T13N, R8E UM Bottom Hole Location at North 6,024,234' East 484,991' 7050' TVD: 1557 ft FSL & 2204 ft FWL of Section 17, T13N, R8E UM I AFE Number: I TSD I Estimated Spud Date: 13/15/2003 I MD: 18,088' I Objectives: I TVD: 17,050' I I Drilling Rig: I Nordic 3 I Estimated Rig days: 115 I Pad Elev: I ± 22' I RKB: 152' Kuparuk "C" Formation at 6100' TVD Telephone Contacts: Name: Skip Coyner Rusty Cooper Nordic 3 Nordic Brooks Camp Guard Shack Kuparuk Kuparuk Kuparuk Global Medical AOGCC AOGCC Position: Drilling Supt. Oper Mgr. Pioneer otc Nabors Ofc Geology otc Anchorage General Ice Road Security CPF-3 Medical Evac-Assit North Slope T Maunder Natchiq #1 Drilling Program Home No.: 622-0030 276-6000 743-0501 743-0504 743-0506 561-7458 943-5066 943-5049 659-7300 659-7401 659-7230 (206)781-8770 659-3607 (pgr) 279-1433 Anchorage Office No.: 339-6269 264-6752 Pgr No.: Cell No.: 748-3689 519-1214* * (403) Home No.: 208-3809* 2 ) ) Casina & Tubina Proaram: (see attached wellbore diagrams) Size & Type Top Bottom Length Hole Size Drift 13-3/8", 68#, J-55, PElS GL 172' 120' nla 12.259" 7-5/8",29.7#, L-80, STC-Mod Surf 3500' 3500' 9.875" 6.750" 5-1/2", 17#, L-80, Hydril 511 3350' 4350' 1000' 6.750" 4.767" 3-1/2",9.2#, L-80, 1ST-Mod 4350' 8080' 37300' 6.750" 2.867" 3-1/2",9.2#, L-80, 1ST-Mod Surf 4350' 4320' nla 2.867" Mud Proaram: The mud program for this well is designed to inhibit the clays, to minimize drilling waste and to minimize formation damage. We will spud with a KCI based-polymer mud and we will drill the entire well with that system. As such, we will minimize clay hydration and swelling which in turn minimizes drilling waste, MST, viscosity and ECD. Mud weight and fluid loss control will be maintained as needed to provide primary well control and minimize invasion. Run the solids control equipment at maximum efficiency and save the "end of well" volume to be used for spud mud on the second well. Suñace Hole: Properties (9-7/8" Hole to 7-518" Casing Point at 3500' TMD/TVD) Mud Density Viscosity yp PV 10 Sec KCI API FL Properties (ppg) (sec/qt) Gel % (cc's/30 min) Initial 9.5 80 -120 35 - 45 13 - 21 10 -15 10-12 <15 Final 9.5-9.8 50 - 80 15 - 30 15 - 23 10 -15 10-15 6-8 Production Hole: Properties (6-3/4" Hole B/SC to 8088' MD (7050' TVD) Mud Density H YP PV 10 Sec KCI Properties (ppg) P Gel 0/0 Initial 9.6 9.0-9.5 10-15 6-12 2-5 10-12 Final 9.9-10.2 9.0-9.5 15-25 15-25 2-6 10-15 APIFL (cc's/30 min) 6-10 <6 Bit Proaram: Interval Size Type Footage Hours ROP RPM WOB Surf - 3,500' 9-7/8" MXC-1 3500' 20 175 200/300 5-30 3500' - 7050' 6-3/4 PDC 4588' 46 100 200/300 5-15 3 Natchiq #1 Drilling Program Surveys & LWD: Directional Program: While Drilling: LOQQi nQ ProQram: Surface Hole: LWD: Open Hole: E-Line: Production LWD: Hole: Open Hole: E-Line (OH) E-Line: (CH) ) ) 9-7/8" Hole: MWD Surveys every 300' / 300' to 3500' MD 6-3/4" Hole: MWD Surveys every 100' / 3500' to 8088' MD MWD / GR/ RES Mud Logging: 30' samples below permafrost (700') Pull GR/Sonic to surface when logging the 6-3/4" hole) MWD / GR / CNL / FDC / RES Mud Logging: as above + 10' samples in target zones GR/PEX/AIT/CMR/Caliper, FMI-DSI, MDT's, SWC's SCMT in the Liner (bond & correlation), Perforating. Formation Markers: Formation Tops MD TVD (measured from drill floor) Mud Line 59' 59' Water = 7.0', Ice Freeboard = 22', DF = 30' Permafrost Zone 700' 700' May not exist Sagavanirtok 750' 750' Possible gas hydrates: 800' to 1550' Ugnu 1850' 1850' West Sak 2580' 2580' Colville Mudstones 3400' 3400' Middle Brookian 4400' 4360' Possible Hydrocarbons, 9.6 ppg EMW Torok 5565' 5225' Possible Hydrocarbons, 9.6 ppg EMW T/HRZ 6635' 6000' Kalubik 6705' 6050' T/Kuparuk 6843' 6100' Kuparuk "C" 6843' 6100' Hydrocarbon Bearing, 9.8 ppg EMW Kuparuk "A" 6871' 6170' Hydrocarbon Bearing, 9.8 ppg EMW T/Miluveach Sh. 6940' 6220' Nuiqsut Sand 7625 6715' Possible Hydrocarbons, 9.8 ppg EMW Kingak Sh. 7665 6765' PTD 8088 7050' Natchiq #1 Drilling Program 4 Casing Shoe Integrity Testing: Test Point: Depth: ± 3520' Surface Casing Shoe (20' below the shoe) Test Type: LOT Expected EMW ~ 13.7 ppg (based on offset data) 1. After NU & testing BOPE, RIH. Test the 7-5/8" casing to 4000 psi. Record the volume of mud required to pressure up to 1000 psi, 2000 psi, 3000 psi and 4000 psi. 2. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in/out. Pull up into the casing shoe. 3. Perform a Leak Off Test: · Shut the well in. RU cement pump. · Record the fluid volume in the cement unit's tanks. · The estimated Leak Off surface pressure with 9.5 ppg mud is = 608 psi. · As a guide, use the data from the casing test to determine the approximate volume of mud required to reach 608 psi on the LOT. · Bring the pump on line at 0.1 - 0.2 bpm & keep the rate constant. · Record the pressure for every tenth of a bbl pumped. · Continue pumping until the pressure breaks over plus 1 bbl. · Plot the data to determine the Leak off pressure at the shoe as EMW. , . Repeat the test if needed. Cementina Proaram: Surface Casina: Hole Size: Casing Size: Basis for Calculations: I Volumes: Production Liner: Hole Size: Liner Size: Basis for Calculations: I Volumes: 9-7/8" 7-5/8" Lead: Based on 3000' of annular fill + 250% excess (excess to be determined by a carbide fluid caliper) Tail: Based on 500' of annular fill + 100°,10 excess + 80' shoe track volume. Lead ArcticSet Lite III, 4.28 cf/sk, 10.7 ppg Tail Class UG" + CaCI2 1.16 cf/sk, 15.8 ppg 6-3/4" 5-1/2" x 3-1/2" Lead: Based on 1900' of annulus, 150' of over lap, 100' above TOL. Open Hole excess is 25% unless a caliper log is run: use caliper + 15%. Tail: Based on 2600' of annular fill + 25% excess + 90' shoe track volume. Lead Class UG" + 8% Gel 1.99 cf/sk, 13.0 ppg Tail Class UG" + expanding 1.20 cf/sk, 15.8 ppg Natchiq #1 Drilling Program 5 ) ') Well Control: Surface hole will be drilled with a diverter. The production hole will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer capable of handling maximum potential surface pressures. The maximum anticipated BHP assumes communication with KRU 3M-27 which is supported by an injector 3M-20. This scenario is unlikely as the Natchiq #1 well should be fault separated from 3M-20 and 3M-27. · Maximum anticipated BHP: 11.3 ppg EMW at 6150' = 3315 psi, Kuparuk "C" · Maximum surface pressure: 3615 psi - a full column of gas @ 0.10 psi/ft = 3000 psi · Planned BOP test pressure: 4000 psi per AOGCC Permit · Test the BOPE when N/U, changing rams, etc. · Test BOPE every 7 days as per AOGCC regulations. · Notify the AOGCC field inspector 24 hours prior to testing BOPE: 659-3607. Disposal: · Cuttings Handling: Cuttings generated from drilling operations will be hauled via "Super Sucker" to Prudhoe Bay OS-4 for underground injection subject to Ballot 262. · Use Waste Manifests signed by a "Red Book" certified personnel only. · Use cuttings bins as needed to catch and hold excess drilling waste. · We do not plan to have open pits on the ice. Solids Control: · Before spud, ensure that all solids control equipment is functioning properly. · The initial flow rate will be ± 550 gpm. "Screen up" to maximize the efficiency of the ALS shakers (100 mesh). Put finer mesh screens on as conditions allow. · Run the shaker discharge through Baroid's solids control van using both Centrifuges. · Watch for holes in the screens & change them when they occur. · If the screens plug/blind, stop and circulate while cleaning the screens. · Watch for plugged cones & correct the problems as they occur. ~ H2S has not been seen/reported on any of the offset wells: Kalubik #1, Kalubik #2, Kalubic #3, E. Harrison Bay #1 & Thetis Island #1. Minor amounts of H2S have been recorded at KRU, 3M-27. This H2S is probably the result of seawater injection into 3M-20. The Natchiq #1 well is mapped as being fault separated from the wells on 3M pad and therefore H2S migration is unlikely. As a precaution, however, H2S monitors will be used at all times and 30-minute air packs will be available. 6 Natchiq #1 Drilling Program ) ) DRILLING AND COMPLETION PROCEDURE Pre-RiQ Work: 1. The 13-3/8" (non-insulated) conductor was driven to ± 172' OF. 2. NU the multi-bowl casing head on the 13-3/8" conductor. 3. Spot and fill the reserve fuel tank - with spill containment. 4. Spot and fill the reserve water tank at the rig. 5. Stockpile mud, cement casing, tubing and other materials on/near location. 6. Ensure communications are up and running: phones and radios. 7. Ensure all training requirements have been met. 8. Notify ACS and AOGCC 24 hours prior to spud and prior to BOP test. DrillinQ Hazards: 1. The shallow hazard survey indicates the presents of no discernable hazards. In addition, none of the offset wells reported any hazardous conditions while drilling near surface. 2. Gas generated from drilling through "hydrates" is expected to be minimal. Again, offset wells reported only minor volumes of gas while drilling the surface hole. The reduced hole size planned for this well with minimize the volume of gas generated while drilling. 3. Gumbo and other reactive formations constitute potential hazards from surface to TD. The planned use of inhibitive drilling fluid should minimize this problem, however, caution should be used at all times because swabbing and packing off could occur at any depth. It is recommended to "pump out" of the hole if swelling clays cause undue trouble. 4. No HzS is expected in this well, however, HzS monitors will be used at all times and the crews should be made ware of this potential hazard. 5. Abnormal pressure is possible if the Kuparuk "C" is hydraulically connected to 3M-27. If so, the maximum expected mud weight is 11.8 ppg, however, it is believed that Natchiq #1 is fault separated from 3M-27. Keep adequate supplies of barite on location to weight up if needed. Drill only 3-5 ft of Kuparuk "C" and flow check the well. 6. BOP tests "kick drill" will be conducted in accordance with AOGCC regulations. 7. Lost circulation represents a potential hazard in this area. An adequate supply of LCM will be stockpiled on location for use if needed. The drilling fluid will be maintained to minimize ECD, surge and swab pressures. Lost circulation is considered a low potential hazard even though the offset well (Kalubik #1) lost returns while cementing 13-3/8" casing at 2758 ft. StandinQ Orders: 1. All personnel must sign in at the camp. Only authorized personnel are allowed beyond STP. 2. All travelers must notify the camp boss of their arrival and departure. All travelers must check in at the guard shack (near STP) when traveling on or leaving the ice. 3. A planning meeting will be held prior to all major phases of the operation: surface hole, surface casing, production hole, logging, running the liner, running the completion. 4. A, daily operations meeting will be held to plan out the day's work and a liP/an of the Dav" will be distributed to rig and service personnel involved in the operation. 5. All tools and equipment to be verified, strapped and callipered before they are needed. 6. A full opening safety valve (with correct threads) will be kept on the drill floor in the open position at all times and the hex-wrench will be readily available. 7. Pit drills/kick drills will be conducted one with each crew in each hole section. 8. Slow pump rates will be taken each tour while drilling and after drilling 1000' of new hole and after any significant changes in the mud properties. 9. The toolpusher and company man will witness the first ten (10) stands off bottom for all trips. Use the trip tank. Keep a detailed trip sheet. Keep the hole full. 7 Natchiq #1 Drilling Program ) ) Natchia #1 Ria Operations: 1. MIRU Nordic #3, 36-man camp with berms and Herculite as required for secondary spill containment. 2. Take on water and (used) spud mud from Baroid's mixing plant or directly from the previous well. Make sure all solids control equipment is operating: including good 100-mesh shaker screens, etc. R/U Baroid's solids control van. Set the cutting bins, etc. Have two (or more) Super Suckers trucks available for waste hauling. 3. NU a DSA and diverter spool on the wellhead. NU the 11" BOP stack above the diverter spool. The 11" annular will be used as a diverter and it should be tied in with the diverter valve in "fail safe" mode. RU the diverter lines and knife valves as per AOGCC regulations. Function test the diverter system. 4. Make up the 9-7/8" bit and BHA with MWD/GRlRES and a performance (straight-hole) motor. Mix or off-load spud mud and ensure that ample supplies of fuel, water and materials are on location. 5. Load the 7-5/8" surface casing in the pipe shed to warm up. Tally and drift the 7-5/8" casing while drilling. Install centralizers, etc (if possible) while the casing is on the rack. Set the long wear bushing in the multi-bowl wellhead to protect the seal areas. Notify AOGCC 24 Hrs prior to spud & Diverter Function Test 6. Commence drilling the 9-7/8" surface hole. While drilling the surface hole, stop and circulate the hole clean at 1500' and at 2500' (or as needed). Try not to out drill the solids control equipment - control drill if necessary. Record MWD surveys every 300 ft. Drill the surface hole to .± 3500'. The 7-5/8" casing is run with a mandrel hanger so drill the hole to fit the casing including 1 0-20' of rat hole. 7. While circulating at casing point, drop a carbide and use the stroke counter to help estimate the average hole size. Use experience gained at Ivik #1. 8. At casing point, circulate the hole clean. Rotate the drill string at ~ 120 rpm to help clean the hole. Make a 20 stand wiper trip. Circulate bottoms up again. LD the 6-1/2" (and bigger) BHA components if necessary. Stand back the 4-3/4" DC's for use later with the port collar. If the hole is "tight", pump out of the hole using the top drive to prevent swabbing. 9. Make up the port collar "Combo Tool" on a stand of 4-3/4" drill collars and stand it back. Retrieve the wear bushing. 10. RU casing tools & "fill up tool". Run and cement the 7-5/8", 29.7# surface casing (see table below). A port collar will be run in the casing string .± 60 ft below the mandrel hanger (.± 35' below the mud line). Use PDC drill-able float equipment. Run (4) Spiragliders: 1 ea on joints 1, 3 & 5 and the 4th Spiraglider near the 13-3/8" shoe. Run 10 bow-spring centralizers spaced out evenly below the permafrost. Wash to bottom and land the casing hanger. Note: 10-20 ft of rat hole is acceptable. Pick up .± 1 ft before circulating and cementing. 8 Natchiq #1 Drilling Program ) 7 -5/8" Casing - Running Order Length 35.00' 1.50' 4.00' 40.00' 10.00' 2.50' 3320.0' 2.50' 82.00' 2.50' Description (1) 7-5/8" Landing Joint (1) Fluted Casing Hanger (1) 7-5/8" Double Pin Sub (1) 7-5/8" Casing Joint (1) 7-5/8" Casing Pup (1 ) 7 -518" TAM Port Collar (83) 7-5/8" Casing Joints (1) 7-5/8" Float Collar (2) 7-5/8" Casing Joints (1) 7-5/8" Float Shoe Top BTC box Acme LH box BTC pin BTC box BTC box BTC box BTC box BTC box BTC box BTC box ') Bottom Max OD Drift ID Acme LH pin 8.500" 6.750" BTC box 11.00" 6.750" BTC pin 7.625" 6.750" BTC pin 8.500" 6.750" BTC pin 8.500" 6.750" BTC pin 8.750" 6.750" BTC pin 8.500" 6.750" BTC pin 8.500" 6.750" BTC pin 8.500" 6.750" nla 8.500" 6.750" 11. Circulate at least one full casing volume and adjust the rheology of the mud as needed. Pump a carbide lag. Again, use the stroke counter to confirm the hole size and adjust the cement volume accordingly to minimize waste. Cement as per the attached program. Displace with drilling mud. Bump the plug with 1000 psi over final pump pressure. Record cement returns. 12. N/D the cement head. Back out the landing joint and lay down same. Set the 7-5/8" casing pack off and test same. RIH with the "TAM" combo tool on 3 stands of 4-3/4" DC's (2 std below & 1 std above) and open the port collar. Circulate the 13-3/8" x 7-5/8" annulus clean from the port collar to surface using water or brine. Spot freeze protect fluid (CaCb brine & methanol) in the 13-3/8" x 7-5/8" annulus. Close and test the port collar. L/D the "combo tool". L/D BHA components as/if necessary. 13. Drain and wash out the BOP stack and wellhead. ND the diverter lines and blank off the side outlet on the diverter spool. Re-configure the hydraulic lines on the annular. Use a test plug and test the BOPE to 250 psi and 4000 psi on chart. Retrieve the test plug and test the casing/port collar to 3500 psi. Circulate the mud through the SCE to remove LGS's. Notify AOGCC 24 Hrs prior to testing BOPE 14. Set the short wear bushing in the multi-bowl wellhead. MU 6-3/4" drilling assembly with MWD/GRlRES/CNL/FDC, and a bent-housing motor. PU more 3-1/2" drill: "single in the hole". RIH to the float collar. Test the 7-5/8" casing to 4000 psi. 15. Drill out the shoe track and 20' of new formation. Circulate the hole clean. Pull up into the shoe and perform a Leak Off Test. The expected LOT should be 13.7 ppg. a. Shut the well in. RU cement pump. b. Record the fluid volume in the cement unit's tanks. c. The estimated Leak Off surface pressure with 9.7 ppg mud is = 728 psi. d. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach 728 psi on the LOT. e. Bring the pump on line at 0.1 - 0.2 bpm & keep the rate constant. f. Record the pressure for every tenth of a bbl pumped. g. Continue pumping until the pressure breaks over plus 1 bbl. h. Plot the data to determine the Leak off pressure at the shoe as EMW. 16. Drill ± 120 ft of "Rat Hole" below casing to eliminate magnetic interference. Orient the bent- housing motor and build angle at 4°/100' as per the directional plan. Once the planned angle of 43.71 ° is built, circulate while rotating at ~ 100 RPM to clean the hole. Make a wiper trip to the shoe if necessary. (see attached directional plan) Natchiq #1 Drilling Program 9 ) ) 17. Continue drilling the 6-3/4" hole to the top of the Kuparuk "C" at ± 6774' MD (6100' TVD) while maintaining angle and azimuth. Drill with 10 ppg solids-free KCI mud. Drill with maximum rotary speed to enhance hole cleaning. 18. Drill into the Kuparuk "C" 3-5 ft and check for flow. We could be 1.3 ppg under-balanced so be ready to mix barite as required. If not, continue drilling with 10 ppg mud as before. Circulate bottoms up while rotating the drill pipe at ~ 100 rpm to aid hole cleaning. 19. At ± 8088' MD (7050' TVD), circulate and condition hole for logs, etc. Make a 20-stand wiper trip and circulate bottoms up. Spot a clean, Hi-Vis pill on bottom. 20. R/U SchlumbergerE-Line, with riser and packoff. Log the hole as directed by Geology. Run the SWC's last. Make a wiper trip between E-Line runs only if needed. While logging, load the liner in the pipe shed to warm it up. Talley and drift the liner. R/D Schlumberger. 21. RIH with a mill-tooth bit and BHA. Ream any tight spots. Circulate bottoms up at least twice. Spot a clean, Hi-Vis pill on bottom. POOH. R/U casing/tubing tools. 22. P/U the 3-1/2" portion of the tapered liner and circulate the liner volume. P/U and rack back ± 900' of extra 3-1/2" tubing. P/U the 80-40 CSR, crossovers and,the 5-1/2", "511" portion of the tapered liner and the crossover to BTC box up. Hang the liner in the slips. 23. R/U a false floor and run the extra 3-112" tubing into the 5-1/2" liner as an inner string with the 3-1/2" liner wiper plug on bottom. Carefully sting the liner wiper plug through the CSR and into the 3-1/2" tubing below. Make up the HMC liner hanger, ZXP PKR and setting tools. Circulate the liner volume. RIH with the liner on drill pipe with the CSR at ± 4320' MD The liner hanger setting depth ~ 150' above the 7-5/8" shoe: ± 3350'. Combination Liner - Running Order: Lenp"th Description Top Bottom Max OD Drift ID (1) Baker's Running Tools 3-1/2" IF n/a 2.000" 10.0' (1) ZXP Liner-Top Packer n/a BTC pin 6.550" 4.767" 8.0' (1) 7-5/8" X 5-1/2" Liner Hanger BTC box BTC pin 6.500" 4.767" 4.0' (1) 5-1/2" Crossover BTC box 511 pin 6.050" 4.767" 960.0' (24) 5-1/2" Liner Joints (R-3) 511 box 511 pin 5.500" 4.767" 4.0' (1) 5-1/2" X 5" Double Box X-O 5.5" 511 box 5" BTC box 5.500" 4.767" 18.0' (1) Casing Seal Receptacle: 5" 00 BTC pin BTC pin 5.000" 4.000" 4.0' (1) 5" X 3-1/2" Crossover 5" BTC box 3.5" IBT pin 5.500" 2.867" 2700.0' (90) 3-1/2" Liner Joints IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" Pup Joint [cross over] IBT box EVE box 4.500" 2.867" 1.0' (1) 3-1/2" "X" nipple EVE pin EVE pin 4.500" 2.813" 6.0' (1) 3-1/2" Pup Joint [cross over] EVE box IBT pin 4.500" 2.867" 900.0' (30) 3-1/2" Liner Joints IBT box IBT pin 4.250" 2.867" 1.0' (1) 3-1/2" Landing Collar IBT box IBT pin 4.250" 2.867" 30.0' (2) 3-1/2" Liner Joint IBT box IBT pin 4.250" 2.867" 1.0' (1) 3-1/2" Float Collar IBT box IBT pin 4.250" 2.867" 60.0' (2) 3-1/2" Liner Joints IBT box IBT pin 4.250" 2.867" 1.0' (1) 3-1/2" Float Shoe IBT box n/a 4.250" 2.867" 24. Circulate and condition the mud prior to cementing the liner. Correct the cement volume: caliper + 15% excess in open hole. Adjust the rheology as needed prior to cementing. 25. RU Dowell. Mix and pump the liner cement job as programmed. Drop the drill pipe dart and displace with 9.8 ppg brine. Displace at no more than 3 bpm. Reciprocate the liner while 10 Natchiq #1 Drilling Program ') ) cementing. Note the final displacement pressure (differential). Bump the plug and set the "HMC" liner hanger. Then set the "ZXP' PKR using the "Pusher Toof'. Check the floats to see if they are holding. 26. Pressure up the drill string to .± 500 psi and dis-engage from the liner slowly. Circulate the casing and upper portion of the liner (5-1/2") clean at.± 5 bpm (20 minutes for bottoms up) and note cement returns if any. Shut down the pump and check for flow. Test the "ZXP' to 500 psi> the 7-5/8" LOT (ie: EMW + 3.2 ppg). 27. Displace the casing and 5-1/2" portion of the liner with 9.8 ppg brine. Shut down for 30 minutes and check for flow. LID the drill pipe used to run the liner along with the liner setting tools but rack back the tubing (inner string) in the derrick. 28. RU §Iick .bine Unit. Run a 2.75" gage ring on sinker bars to PBTD to verify that the lower liner section was displaced properly. POOH. RD SLU. Load the 3-1/2" tubing in the pipe shed to warm it up. Tally and drift the tubing in preparation to complete the well. RIH with DP from the derrick. LID all remaining drill pipe and BHA components. 29. RU and run the 3-1/2" completion (using the tubing already in the derrick), CSR seal nipple, "X" nipple, sliding sleeve, GLM (wI RP shear valve) and SSSV (see attached diagram). Tag the CSR and space out the tubing such that the seal nipple is "floating". Completion Tubin2 - Runnin2 Order Len2;th Description Top Bottom Max OD Drift ID 31.0' (1) 3-1/2" Landing Joint IBT box IBT pin 4.250" 2.867" 1.0' (1) 3-1/2" Tubing Hanger IBT box IBT pin 11.00" 2.867" 6.0' (1) 3-1/2" Pup Joint IBT box IBT pin 3.500" 2.867" 30.0' (1) 3-1/2" Tubing Joint (R-2) IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" Pup Joint IBT box IBT pin 4.250" 2.867" 4.0' (1) 3-1/2" SSSV (Wellstar) IBT box IBT pin 5.200" 2.813" 10.0' (1) 3-1/2" Pup Joint IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" X 1" GLM (wi RP) IBT box IBT pin 5.390" 2.867" 6.0' (1) 3-1/2" Pup Joint IBT box IBT pin 4.250" 2.867" 3500.0' (115) 3-1/2" Tubing Joints IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" Pup Joint IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" Sliding Sleeve (Baker) IBT box IBT pin 4.280" 2.750" 6.0' (1) 3-1/2" Pup Joint IBT box IBT pin 4.250" 2.867" 700.0' (23) 3-1/2" Tubing Joints IBT box IBT pin 4.250" 2.867" 6.0' (1) 3-1/2" Pup Joint [cross over] IBT box EVE box 4.500" 2.867" 1.0' (1) 3-1/2" "X" Dipple EVE pin EVE pin 4.500" 2.813" 6.0' (1) 3-1/2" Pup Joint [cross over] EVE box IBT pin 4.500" 2.867" 17.0' (1) 4" Seal Nipple (Baker) IBT box n/a 4.000" 2.867" Notes: The sliding sleeve must be 100 ft deeper than the 7-5/8" shoe. The GLM & SSSV should be below the mud line with the GLM just above the 7-5/8" port collar. That way there is no risk of opening the port collar by running the GLM through it. 30. N/U 'X" control line and test same to 5000 psi. The SSSV will be controlled with a hand pump while NID, N/U and testing the well. 31. Displace the tubing with 44 bbl of diesel. String into the CSR, land the tubing hanger and RILDS. The resulting hydrostatic head at the Kuparuk "c" (6100 ft TVD) is estimated to be about 2460 psi when perforating. 11 Natchiq #1 Drilling Program ') ') 32. Test the tubing to 3500 psi for 30 minutes on chart. Bleed off the tubing to ± 2000 psi and hold that pressure while testing the IA to 4000 psi for 30 minutes on chart. Bleed off the IA first. Then bleed off the tubing: we do not want to rupture the "RP" shear valve. 33. Test the SSSV control lines to 5000 psi. R/U SLU. Close and test the SSSV. Note: Barriers to flow are 1) un-perforated, cemented liner wi ZXP PKR and 2) SSSV. 34. Wash out the BOP's and LO the landing joint. NO the BOP's and diverter spool. NU and test the upper tree assembly to 4000 psi with diesel. Leave the tree and wellhead valves freeze protected with diesel. Secure the well. 35. RO and MORT. Completion and well test program to follow. Prepared by: hn~.. sV;¡¡:ynr¡l' NTS / Pioneer NRA 12 Natchiq #1 Drilling Program ;::: -400 0 0 '<t II 0 E tJ iii 400 ro tJ f/J 800 1200 1600 2000 2400 - - ~ 2800' :t:.. .r:: ë. 3200 CD C ¡; 3600 CJ :e CD 4000 > CD ~ r... ~ 4400 . V 4800 5200 5600 6000 6400 6800 7200 L 7600 Pio.leèr Nåtural Resources Location:' Nor~hSI~pe;~I~Ska(lm~~rted) .··Fleld:· . Beaufort Sea Exploration .' Installation: Naèhiq#1' Slot: . Slot #1 . Well: Natc:hiq#1 Scale 1 em = 250 ft East (feet) -> -3000 -2750 -2500 -2250 -2000 -1750 '-1500 -1250 -1000 -750 -500 -250 0 TD LOCATION: 1443' FSL, 1751' FEL SEC. 17, T13N, R8E Est. TD - 43.71 Inc, 8088.49 Md, 7050.00 TVD ~ t 1>- I RKB Elevation: 52.5' Permafrost Zone - 0.00 Inc, 700.00 Md, 700.00 TVD, 0.00 VS : Sagavanirotok - 0.00 Inc, 750.00 Md, 750.00 TVD, 0.00 VS ) r&iill BAKER HUGHES JNTEQ KOP - 0.00 Inc, 3620.00 Md, 3620.00 TVD OTarget - 43.71 Inc, 6774.27 Md, 6100.00 TVD Natchiq #1 SURFACE LOCATION: 800' FSL, 900' FWL TARGET LOCATION, SEe 16, T13N, R8E 1230' FSL, 869' FEL SEC. 17, T13N, R8E WELL PROFILE DATA Point M D Inc Dir TVD North East· deg/100ft V. Sect Tie on 0.00 0.00 0.00 0.00 0.00 0.00 KOP 3620.00 0.00 283.65 3620.00 0.00 End of Build 4712.71 43.71 283.65 4609.77 93.71 -385.75 Target Natchiq #1 6774.27 43.71 283.65 6100.00 430.00 -1770.00 T.D. & End of Hold 8088.49 43.71 283.65 7050.00 644.38 -2652.44 ~ 7 5/8" Casing 8.00 16.00 DLS: 4.00 deg/100ft Middle Brookian - 31.11 Inc, 4397.64 Md, 4360.00 TVD, 205.95 VS 40.00 End of Curve . 43.71Ine, 4712.71 Md, 4609.77 TVD, 396.97 VS Torok - 43.71 Inc, 5563,81 Md, 5225,00 TVD, 985,07 VS Top HRZ . 43.71 Inc, 6635.93 Md, 6000.00 TVD, 1725.89 VS Target - 43.71Inc, 6774.27 Md, 6100.00 TVD, 1821.48 VS Top Kuparuk e , Kuparuk A TI Miluve.ch Sh. 0.00 0.00 0.00 0.00 0.00 4.00 396.97 0.00 1821.48 '0.00 2729.59 o 1000 750 ^ . 500 Z 0 ;¡ 250 .a: -... CD CD ~ 0 ~ -250 iõ ª II \) g: ;::þ PropoeellD: 438905 THIS PLOT HAS BEEN PRODUCED FOR Plon.er N.tur.1 Re.ourc.. BY a.kDr Hughe.INTEQ IN ACCORDANCE WITH: DRilliNG MANUAL QUALITY STANDARD PREPARED BY VERIFIED BY AVTHORISED BY DATE 03-13-03 DATE DATE 03-13-03 Nuiqsut Sand - 43.71 Inc, 7625.05 Md, 6715.00 TVD, 2409.36 VS Kingak Sh. . 43.711nc, 7694.22 Md, 6765.00 TVD, 2457.16 VS ~ Est. TD - 43.71 Inc, 8088.49 Md, 7050.00 TVD, 2729.59 VS -400 0 400 800 1200 1600 2000 2400 2800 Scale 1 em = 400 ft Vertical Section (feet) -> Azimuth 283.66 with reference 0.00 N, 0.00 E from Slot #1 ) ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska{lmported) ) PROPOSAL LISTING Page 1 ,&.. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 Wellbore -~~......---._~~----- .----------. -- -------.----.- ----._------ -- --_._------------_..._~-_._-~---_._-- ---------------"---........... Nª-.me _~atchig #1 Version #2 Created 12-Mar-2003 Last Revised 14-Mar-2003 --------- .__.._._~---_._- ~----_._-~_...._~_._.__.----..._~-~-_._.. ____~__~____._._'~__~~........_..."'.__h___._ Wêll Bame Natchiq #1 Government ,10 LastRevised 12-Mar-2003 ----~-,-~_._._~- --"-~-~ ._----,--...__..__.__.._-_._-,---...__.,,--~---------,-...-....-------.---- _._____w___ I Slot Name Slot #1 .__._'_"__h~___________ ---------- .-.--_._'-_._----_...,.~..~_.__._,..-,......._..-..--..~._....--- Grid Northætg.__ Grid EastinQ 6023585.2900 487641.9100 ----...-------...---..--.-.-- Latitude Longitude !,:!ort.h. East N70 28 32.3219 W150 63.4223_9·00N____ 03E --..-----------.-------- --,--_._,._-----~, \. "'~,' ~ r'-'-- '.. . -..----..-:--'.-.--...--..-.-....-..-.-..'---...-....-.-.--.,........-..--:-. Ilnstall$tion . . .. Name Eastin9......__..__.___.._ Northing Coord System Name ___ North Alignment Nachiq#1 487641.9100 6023585.2900 AK-4 on NORTH AMERICAN DATUM True 1927 datum ------.-.----.--- ----.~~,_."-_. ..~~._.~-_._,,------_._-_._- 1------· .---.--.-------- ------.--.----. .-.- .---.-.---.....-... ---.---.- .------------ --...-----.--.---.---..--- 'Field .N.ªI!I~._ ._____.,.~ª_ª!!!:!.9......_._____..._._._ Beaufort Sea Exploration 481458.3800 _._...._._._~_..,_,.___. ·'.n....__~__.·__'. . ,_ _ "'__"__.__r _____ --.-.-.-----......-..---. - Northing _,______,Ç.c..<?ord 'SysternName _____.________..______._..._J~ºrt.b Allgnrrt~nt'._ 6028077.2700 AK-4 on NORTH AMERICAN DATUM True 1927 datum -_.._--_.~- --------- ---_....------._-- _._._----~-_. -,-~~.------------,~.-._-----.__._,-'-------.-----,.---.~-_.-_.~-- -----.~-.~-_..--- ._----_..-_..._-_._...~.-._~.__._-_._~.._--_..._,_. Created By Revised For Tom Maunder --_."~--- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) ~ Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees ~ W(.\ \ \t~<:..u Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ') #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska{lmported) ) PROPOSAL LISTING Page 2 r'.. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 I· .' ".' ..' ., ' . -:-.-..-.-'-.-..--...--....--'.....--..---......-... IComments ......_..._.--_.__._._--.....-.........-._~~_..,.._.-.......~-~--_._-....... ~-~~=c-7 -~---------~- ~-_._~----_..~-_._~_.- Report referenced to Surface Location: 0,0 Surface Coordinates: 800' FSL, 900' FWL, Sec, 16, T13N, R8E, UM All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) ') PROPOSAL LISTING Page 3 '41. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Well path: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 _Wellpath~_tGriºlJ~ep()rt .._ MD[ft] Inc[deg] Dir[deg] TVD[ft] North[ft] ---..-.--.East[fti----'-D~g¡;g-·-·-··--Ve-rtT~~T--1-Ea$ting --·--·---Ñorthi·~g----·---- ~~-\-~ ~\\~~ [degI100ft] Section[f t] __ 0.00 0.00 _____Q..9_º-__ 0.00 O.OON _______-º-=-QQF__.__.____._ 0.00 0.00 487641.91 6023585.29 100.00 0.00 0.00 100.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 200.00 O.OO___.___QJlQ_ 200.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 ____.~º_Q_~9lL__ .___~º_Q.______n.____º_.g_º____._._._ª_º.9·0Q___.____ O.OON _._.__.__~9_ºÉ___ 0.00 0.00 487641.91 6023585.29 400.00 0.00 0.00 400.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 500.00 0.00 0.00 500.00 O.OON __Q:9-º£.._. 0.00 0.00 487641.91 6023585.29 600.00 º_~.9_Q________0.0_º______600.00 O.OON O.OOE 0.00 0.00 487641.91 ____.____._El023585.29 700.00 0.00 0.00 700.00 O.OON 0.00ê..__.___ 0.00 0.00 487641.91 6023585.29 800.00 0.00 0.00 800.00 O.OON O.OOE 0.00 0.00 487641.9j_____._ 6023585.29 900.00 0.00 0.00 900.00 O.OON ____.D.OOE 0.00 0.00 487641.91 6023585.29 --1.Q.9J100 ...9.00__._._ 0.00 1000.00 O.OON. _.º-'-º_Q£____.__.__ 0.00 0.00 487641.91 6023585.29 _:!.~OO.OJL___ 0.00 0.00 1100.00 O.OON _.__O.OOE 0.00 0.00 487641.91 6023585.29 1200.00 0.09__.._.______.9~.º-Q___. 1200.00____~Qº~_____..______!hº9E______. 0.00 ____.__..9..:..90 487641.91 6023585.29 __1ª_º.9..:..9-º-_.____.Q~º-_______._9.00_._ 1300.00 O.OON _______.º.~Q9E ___. 0.00 0.00 487641.91-________ 6023585.29 1400.00 0.00 0.00 1400.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 1500.00 0.00 0.00 1500.00 O.OON O.OOE O.:Qº-___.-º-=-ºº__._ 487641.91 6023585.29 1600.00 Q~_.______º~Qº____1§.OO.OO O.OON .9...:..9-º-ê._.___ 0.00 0.00 487641.91 6023585.29 1700.00 0.00 0.00 1700.00 O.OON __._______._Q:.9_º~_____________º_:ºº__._._____Q.:.ºº__.____...__1?1.º-1.1.§).1.___.______ 6023585.29 _..:Lªºº-~ºQ.______.___º.:.º-º-_ _....____..9.:.ºº__._Jª-ºº. 00 O. 9_ºJ~L _u___._.º_~ºÉ______._____º:_ºº________..!LQº_________4_ªIª1.UL_.________~_º23585 .29 1900.00_____-º~00____..___º.:.Q_9__._'L~ºº.:º_º_.._._____º_~ºº-N__..__n__._º.:º_Q.ê__.________.____O.OO 0.00 487641.91 6023585.29 2000.00 O.QQ________O.OO 2000.00 O.OON O.OOE __._________9.00_____ 0.00 487641.91 6023585.29 _.~_1QQ.:.9-º-___ 0.00 0.00 ~1Qº.00 .. O.OON O.OOE 0.00 0.00 487641.91 6023585.29 __ 2200:.9_º-___ 0.00 _____-º.~.Qº 2200.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 2300.00 _.__º_.OO___.._____Q~P 2300.00 O.OON O.OOE _________0.00 ______ 0.00_._.___ 487641.91 6023585.29 2400.00 0.09__._.______...9.00 2400.00 O.OON OJtOE________ 0.00 0.00 487641.91 6023585.29 2500.00 0.00 0.00 2500.00 O.OON O.OOE 0.00 _____-º-_&Q_ 487641.91 6023585.29 2600.00 0.00 0.00 2600.00 O.OON __~º9E ____ 0.00 0.00 487641.91 6023585.29 2700.00 0.00 _-ºßO_ 2700..:00 ___j).OO~L_____ O.OOE 0.00 0.00 487641.91 6023585.29 2800.00 0.00 _____..0.00 .___~~OO.OO O.OON ____.__9.00E 0.00 0.00 487641.:.~L______ 6023585.29 2900.00 0.00 0.00 2900.00 __-º.:.OON O.OOE 0.00 0.00 487641.91 6023585.29 -ªº-Q9.00 ___ 0.00 0.0-º--ªºº.9.:00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 3100.00 0.00 0.00 3100.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 _ª~Q~Qº-h______º-=-OO _____ __._º:Qº.____~OO.OO _-º_]_Q~__h___hº.:_º9.É_____JLQº________º.:00 ___ 48764.1.:.91__._______E?023585.29 3300.00 0.00 0.00. 3300.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 I ;~~~~~~ M UU ..~~~~ T==~~~~ I· -~~~--=~ ~~===-%.~:--=-==~~~~=-=~:~=--~:;: ~ :~~=u-I~1!~:}~f t~§Qº~Q-º-_r~~=_~~Qº- r_~-:9 ~ºQI:=~_~oO .00 .___~_ºJiº!;iJ=~ -~_~Q~º-OE_~:~:::.=:_=~:9~j==__ 0.00______._ 487641 .ª.1~l____-ª-Q~~.§.ã~29l c::,~~~'''~~ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Dogleg Vertical Easting [deg/100ft] Section[f __._..__.____ _._._ .__. t] 3620.00 0.00 283.65 3620.00 O.OON O.OOE 0.00 0.00 487641.91 6023585.29 3720.00 4.00 283.65 3719.92 0.82N 3.39W 4.00 3.49 487638.52 6023586.12 3820.00 ...______JtQ.9___._283.65 3819.35 3.29N __J~..:.§5W ______4.0º-______J 3.94 487628.37 6023588.60 3920.00..._J2.Q.9 283.65 3917.81 7.39N 30.42W 4.00 31.30 487611.51 6023592.73 4020.00_____.___16.:.9.Q____....?_83.65 4014.82 13.10N 53.92W 4.00 .___Þ~:1ª-, 487588.02 ._§023598.48 4120.00 20.00 283.65 4109.91 20.39N 83.94W 4.00 86.38 487558.01 6023605.82 4220.00 m_____~~_º_º_._._.l?3.6JL_ 4202.6.1___________?J!:.?.ª~_____120.34W 4.00 123.84 487521.63 6023614.72 4320.00 _.__.._.?ª_:ºº____.?ª~.:.-~Q____ 4292.4 7 _____..__.-ªª_:.§.ª.~.__. 162.93W ____4.:.º-º___J§I.:§.?_ 487479.07 6023625.14 4420.00 _._.__._~_~.:ºº__.____.lª-;h§§'_ 4379.05 51.3ª~.______~j 1.50W 4.00 217.66 487430.51 6023637.02 _~52Q:.ºQ___.______~§_:ºº______~83..65 4461.94_____ª_~L~ª~ 265.83W 4.00 ____~Z~?_ª_ 487376.21 6023~5Q:ªJ__ 4620.00 40.00 283.65 4540.73 79.11 N 325.64W 4.00 335.12 487316.43 6023664.93 4712.71 _..__...1~?J___.._._~_ª_~.65_ 4609.77 93.71 N 385.75W 4.00 396.97 487256.36 _____j~º.?367.~_:ºª-_.. __1~tº0.OQ_.____._4~..lL.___lª_~~~~_.._ 4672.87 107.95N 444.36W 0.00 457.28 487197.78 602ª_~t~.:ª1_ _.:J900.:Qº-.____.~~.~.?J__.___.l_~_~.6§..__.174.§J.§.____.1?.1.26N 511.50W ___..__._._º-=º_Q...____§~6.38 487130.67 6023710.39 5000.00 43.71 283.65 4817.44 140.58N 578.65W...._______.._º-=-ºº-_.___~_ª-§..48 487063.55___ 6023726.81 ....§.19_Q:º-º_.._.______41~.z.L__.__?-ª~:§.§ 4889.Jl_____._..156JlliJi_.___ 64.§.:.~~'- 0.00 664.58 486996.44 6023743.23 _.91QO.QQ____ ._.4~_:LL__~_ª~.:...E?.§ 4962.01 173.20N 712.94W 0.00 733.68 486929.33 602R59.~__ __.Qª-º_Q.:.-QQ__ _.._.4~.}J._.._. 283.65 __§.Q_ª!:~-º_______1ª~L§_1 ~__ 780.09W _________._Q:.ºº.._.__ªº.?.:?JL..____._._ 486862.22 6023776.08 ~4.9-º_:º.º___..... .1~]1_ __.. ..lª~_J~§_._ 51 06 .59 __._._..?.9_~A~?_~_ ____-ª4 7 .23W O. og__.__J!Zl:ªª__. 486795 .11__ ____._.___..f?_º.?_ªI~..?:§Q_ 5500.00 .___..1ª.:I1___ 283.65 5178.87 222.14N 914.38W 0.OQ_.__._JHQ:97 ._.__ 4867~':'-~ª-._.._n.__-ªº~38-º-ª_:~___ 5600.00 _.A:.ª:?J__ 283.65 5251.16 238:1ê..ti.._..J}81.52W 0.00 1010.07 486660.88 6023825.34 5700.00 __.._._.4l:1.L 283.65 5323-1:.§___...~p4.76N 1048.67W 0.00 J.Q?§!.:1? 486593.77 6023841.77 5800.00 __n_ 43_11_._ 283.65 5395.73 271.07N 1115.:.ª2W __ O.OO__JJiª.:.?I_ 486526.66 6023858.19 5900.0Q__.__n__.4l:ZL_n_.l83_:.~_§__ 5468.02 287.39N 1182.96W 0.00 _l~Z.:~J_ 486459.55 6023874.61 6000.00__...._1~]_L__ 283.65 5540.31 ___~03]0~ 1250.11W 0.00 1286.47 486392.44 6023891.03 6100.0Q___..____.4.~.l_L_ 283.65 5612.59 .___~_?ºJ?1..~ 1317.25W 0.00 1355.§L_____ 486325.32 6023907.45 6200.00 43.71 283.65 5684.88 336.32N 1384.40W 0.00 1424.67 486258.21 6023923.88 -,-~ ._.,_.__.~._--_.._-_._-,- .-- 6300.00______4_ª.:Z1 283.65 5757.17 352.63N 1451.55W 0.00 _11-ªª-=-IZ.___._ 486191.10 6023940:ªº- 6400.0Q_..____4~_.?:L_ 283.65 5829.45 368.95_~_1§18.69W .Q:..QQ.-1§..~.?ß6 _ 486123.99 __~023956.?g__ 6500.00 43.71 283.65 5901.74 385.26N 1585.84W 0.00 1631.96 486056.88 6023973.14 ----- -'.-.._------------ --- 6600.00 43.71 283.65 5974.02 1.º1=_§?li.. 1652.98W 0.00 1701.06 485989.76 6023989.57 6700.00 43.71 283.65 6046.31 417.88N 1720.13W 0.00 1770.16 485922.65 6024005.99 ___·_._n.._···____·_·____ ... ~ --- --.----..-.--.---- ------ - (.:~~~:~~ ,-u:~:i~-, -}¿~:~Š_~-----:~¡~%6~-.. ~~~~:~~~------ ~:~~ - ~~~~:~~ ---.-- :~~~~~:~1 --------~-~~~~:1i- _._______.."[ ._.... ... ..._ .. >._ _..____._.____.___~___.___.__ _.__.______.___ ______ m____.___ ........_.___ __......._______ .. _. _...___. ___._.._____ ~~~~:~~! :~:i~! -i~~::}---~~-~~~~-·- m¡~%-~}~---~:~~:~~~ --- ~:~gn-}~~i~~-!--·- :~~~~~~-....---~-~~~:~~~:~~ I __i1 00~~º__r·_--4~-.71:;-_..?~~_:§.§___~_~ª§.4~_J-~_-.1ª3~lªti.l 1988.71 YJ________ ~~~ººI.?º4.~:§~I~~~_ 485654.21 60240'7-1-lia-J ') #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) !W~H.Q..ª..th __< G rirJJ__R~ort MD[ft] Inc[deg] Dir[deg] TVD[ft] ........--.~-..._--,_.'_._----_.- North[ft] East[ft] -) PROPOSAL LISTING Page 4 ,&¡. BAKER Well bore: Natchiq #1 Version #2 HUGHES Well path: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 -,--------~-----~----~.,_.....- ---.........---....---.-- Northing All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ~ ~~~SC)::- \J~t~ 'Ç:~\...- \ ~ "'" C) - c; 0 a";:-. <¡;-;'ì, 0 \=-E L -=;fL~ \ '\ ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) ') PROPOSAL LISTING Page 5 '4ií. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Well path : Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 I Well path _(~_[iqlJ_~~porj_~~.___.._~____.,___c_c:__'___-r_ MD[ft] Inc[deg] Dir[deg] TVD[ft] North[ft] East[ft] Dogleg [deg/100ft] ---~.~---- ~..---_.,--_.~. 7200.00 43.71 283.65 6407.74 -------------~ 7300.00 43.71 283.65 6480.03 7400.00 43.71 283.65 6552.32 7500.00 43.71 283.65 6624.60 ---".---...------- ..--....--..-..------. .--.-- ------,,_._--- 7600.00 _.___1ªLL__1.ª~_.~ª§____®_~.89 7700.00 43.71 283.65 6769.18 7800.00 43.71 283.65 6841.46 ---..-------..- 7900 .00 _._____1ª:IL_.__.1_ªª.~º§____6913. 7 5 8000. 00 _.__.1~.:X.1.___'?_~~~º_§'.__._§ªª-ª.:.Q~__._ 8088.49 43.71 283.65 J-º~O.OO Vertical Section[f t] 499.45N 2055.86W 0.00 2115.66 ----------- 515.76N 2123.00W 0.00 2184.75 532.07N 2190.15W 0.00 2253.85 -'--~------'-' 548.38N 2257.30W 0.00 2322.95 564.70N 2324.44W 0.00 2392.05 581.01N 2391.59W 0.00 2461.15 597.32N 2458.73W 0.00 2530.25 .-._._-~.,~-.,.__._- 613.63N 2525.88W 0.00 2599.35 -.---.-..---,-....-,.---..-.---- 629.94N 2593.03\~L____._ 0.00 2668.45 644.38N 2652.44W 0.00 2729.59 --.--,..------ ~q\J\.. ~Q\\ "'~.~~ Easting Northing 485587.09 6024088.10 485519.98 6024104.52 ___.___..1?5452.81.___._____.___ 6024120.94 485385.76 6024137.36 485318.65 6024153.79 485251.53 6024170.21 ._______~851ª.1:42__________._.§.91~ 186.63 485117.31 6024203.05 485050.20 6024219.47 484990.81 6024234.01 \ . \ \. (' '-6c::t:.J ~S '- '\~ \=\).J \- ~, '0 d-~ 5') -----./.... ..- . '-""\ -p '. ~~~ , ~ f:)ì:J \ ~()() <6c)()-\~\-\~ ~... \l\~~ ~\- d:OS'ð4 00 ~ \ ~ S;) ~'- All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) ) PROPOSAL LISTING Page 6 ,&¡¡. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Well path: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 Comments ---.---'.-~-.-. _._--~._..'-,_.._......_.--- .".- ----- --_. .-- -------.- ---.---------- ----,----- - --..-.---------------.-.- ._- .-------. - -----.-----..--. ----".--- _1\1.ºIftl TVD[ft] _____._~grthm] East[ft]_ Comment _________________.___..___.____.._______ 700.00 700.00 O.OON O.OOE Permafrost Zone _---.750.00 750..ºº___.-._____._QJJON___ O.OOE Sagavanirotok 1850.00 1850.00 O.OON O.OOE U9!!Y___.________________.._ 2580.00 2580.00 ___CbQ.QtL_____ O.OOE West Sak 3400.00 3400.00 O.OON O.OOE Colville Mudstones ------.-.--.--....-....-. .-----.--,.--.". 3620.00 3620.00 O.OON O.OOE KOP -~-"...,'------,._-,-_...._,---"------..-.__.,--_.__.,,.'..__.-_._-,---,-,. ...-,-.--,,--------..--- 4397.64 436Q:..QQ____________:J8.§..2N__.__ 200.13W Middle BrookiaD_..____.__.________ 4712.71 4609.77 93.71N 385.75W End of Curve ~------_._---_.-._,._._.-.,_. --~,---_.._-----,- 5563.81 5225..:..ºº_______.?_32 .55 N 957 .23W Torok .__._._._._.__._____._____...._______________._.________._.________ 6635.93 6000..Q.Q_______._._4QZ.A3N 1677.11W TopHRZ _____________..__m__.______.._____ 6774.27 61 OQ~ºº__.____..____4_ªº_~_ºº~.. 1770.00W Lé!!:.g~_.____.__ .____________...___._.___ 6843.44 6150.00 441.28N 1816.44W 19P Kuparuk C I ~_~_~.~__.___.________ 6940.28 ___º1.~Q_:_9_Q______._..__._.~.57.º.mi_ 1881.47W Kuparuk ð___________ 7009.45 6270.00 468.36N 1927.91W TI Miluveach Sh. ---..-. ~.__._---.----_._-..... ..-".-..--..------.----.---.----- 7625. 05 __-ªzt~J>-º-_. ..______§§.ª_:Z~__ ___..?~1j_~?J>W N u i~~_L~ª_Q.çI__________.____._.__________.__________._ ___._]6~4.2?____._g~Z,§_§.:º_º_._. ..____§§-º_. 0 7lL___ 2387.71 W Kingak S h. ____________._____.___m______._________._________________________________ ___J~088.49 ____LQ_5..9JJ_Q___.._. __.pA:4.38N 2652.44W Est. TD .____.._.______._.____ ~___"__M__.'__..__.___,_ -------- -.------.--------- --.-..---.-- _~~__,·_,·._...________._._w_,__ -.--.---,.-- ------------ ...----.------ .-..--.-..--..-.,-.- --.'..._-._'.'-...,----,.,. .', _...-.~._..._---~._,-_._----- . ..._.__._-,---._-----'--,-----_._-_.__._--_._.._-~-'_.-."--.-.--..'-------...--.,..------.---.-------..,.- Diameter liD1_._ Hole Sections ------ ------- Start Start Start Start End J~tºrnL____.__.._ _IY--ºlf!l______~i:>rthmL_._· East[ ft] MD[ft] 97/8 0.00 0.00 O.OON O.OOE 3500.00 End TVD[ft] 3500.00 End Start North[ft] East[ft] O.OON O.OOE Natchiq #1 Version #2 ___.."._._..__M______.____...________ 7050.00 644.38N 2652.44 Natchiq #1 Version W#2 ~________.__.________..__M_.__.._____________ Well bore ____.M.M_..____V__·____.__·_______·M_.__..____..,._ ..__.__._.,.__.~..__,.,____ 6 3/4 3500.00 3500.00 O.OON O.OOE 8088.49 --~-.----,--.._--------_._.__.._.~_.._._,--_._....- .--".-".--'".....-.-----".--..----.---..-..----.----.- -.----,.----..---- --.....-.-----,-.-- Casi~~$ Name Top Top Top Top Shoe Shoe Shoe Shoe Wellbore _.________M-ºlftlu..___u.1YmftL______ North[ft] East[ft] _ M Dlf!l_.____ TVD[ft] ___~Qdb1f!L.__.gª~ 7 5/8in 0.00 0.00 O.OON O.OOE 3500.00 3500.00 O.OON O.OOE Natchiq #1 Version Casing_________ ____..__.._....______._ ________________ #2 4 1/2in 0.00 I', 0.00 O.OON O.OOE 8088.49 7050.00 644.38N 2652.44 Natchiq #1 Version _CaªLlJ.g____.__.._ _. _ __.... __ ___________.______________._______ _________.__ ____ ___.._ ___________......... _____.__..____. _ .. ___.. __._. ____ W #2 __________u____ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.DON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Targets Name Natchiq #1 ) #1 Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) .~"'~_""'____~"_W·······_~·_____·______________~~_'~__'H_._'__'_~_'..~___..~_ ) PROPOSAL LISTING Page 7 '&1. BAKER Well bore: Natchiq #1 Version #2 HUGHES Well path: Natchiq #1 Version #2 INTEQ Date Printed: 14-Mar-2003 ---'--..........._~---~-_.~-~.~.._-- North[f!L__ê.~Jlf!]____~D[ft] Latitude ___~ongitude Easting_______~-ºr!:tling 430.00N 1770.00 6100.00 N70 2115.548 W1505$.471 485872.81 6024018.18 W ____~_,___._,_._w.__ --.--.---.--- Last Revised 14-Mar-2003 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Datum #1 52.5ft above Mean Sea Level) Vertical Section is from O.OON O.OOE on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated #'. ') Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmporte~) PROPOSAL ~ )TING Page 1 r4i. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 13-Mar-2003 Version #2 28 32.3219 63.4223 Name_ - Beaufort Sea Exploration Bill Michaelson for Skip Coyner All data is in Feet unless otherwise stated Coordinates are from Installation MD's are from Rig and TVD's are from Rig ( Nordic III 52.5ft above Mean Sea Level) . VerÌìcal Section is from ~OO.18N 897.31E. on azimuth 283.66 degrees ~ <:::'~~~'õ"c...(J\~r Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated #. ') Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported} PROPOSAL\))TING Page 2 r'.. BAKER Wellbore: Natchiq #1 ,Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 13-Mar-2003 ¡Comments- - All data is in Feet unless otherwise stated Coordinates are from Installation MO's are from Rig and TYO's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from 800.18N 897.31 E on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated #') Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) PROPOSAL.¡, -)TING Page 3 r&l. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 13-Mar-2003 0.00 0.00 0.00 0.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 100.00 0.00 0.00 100.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 200.00 0.00 0.00 200.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 300.00 0.00 0.00 300.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 400.00 0.00 0.00 400.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 500.00 0.00 0.00 500.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 600.00 0.00 0.00 600.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 700.00 0.00 0.00 700.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 800.00 0.00 0.00 800.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 900.00 0.00 0.00 900.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1000.00 0.00 0.00 1000.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1100.00 0.00 0.00 1100.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1200.00 0.00 0.00 1200.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1300.00 0.00 0.00 1300.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1400.00 0.00 0.00 1400.00 800.18N 897.31 E 0..00 0.00 487641.91 6023585.29 1500.00 0.00 0.00 1500.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1600.00 0.00 0.00 1600.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1700.00 0.00 0.00 1700.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1800.00 0.00 0.00 1800.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 1900.00 0.00 0.00 1900.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2000,00 0.00 0.00 2000.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2100.00 0.00 0.00 2100.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2200.00 0.00 0.00 2200.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2300.00 0.00 0.00 2300.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2400.00 0.00 0.00 2400.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2500.00 0.00 0.00 2500.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2600.00 0.00 0.00 2600.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2700.00 0.00 0.00 2700.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2800.00 0.00 0.00 2800.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 2900.00 0.00 0.00 2900.00 800.18N 897.31 E 0.00 -0.00 487641.91 6023585.29 3000.00 0.00 0.00 3000.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3100.00 0.00 0.00 3100.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3200.00 0.00 0.00 3200.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3300.00 0.00 0.00 3300.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3400.00 0.00 0.00 3400.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3500.00 0.00 0.00 3500.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3600.00 0.00 0.00 3600.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 ~~~\ ~\f<: All data is in Feet unless otherwise stated Coordinates are from Installation MO's are from Rig and TVO's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from 800.18N 897.31E on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated "It ) Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported) PROPOSAL .~TING Page 4 ,&.. BAKER Wellbore: Natchiq #1 Version #2 HUGHES Well path: Natchiq #1 Version #2 INTEQ Date Printed: 13-Mar-2003- 3620.00 0.00 283.65 3620.00 800.18N 897.31 E 0.00 0.00 487641.91 6023585.29 3720.00 4.00 283.65 3719.92 801.01 N 893.92E 4.00 3.49 487638.52 6023586.12 3820.00 8.00 283.65 3819.35 803.47N 883.76E 4.00 13.94 487628.37 6023588.60 3920.00 12:00 283.65 3917.81 807.57N 866.89E 4.00 31.30 487611.51 6023592.73 4020.00 16.00 283.65 4014.82 813.28N 843.39E 4.00 55.49 487588.02 6023598.48 4120:00 20.00 283.65 4109.91 820.57N 813.36E 4.00 86.38 487558.01 6023605.82 4220.00 24.00 283.65 4202.61 829.40N 776.97E 4.00 123.84 487521.63 6023614.72 4320.00 28.00 283.65 4292.47 839.74N 734.38E 4.00 167.67 487479.07 6023625.14 4420.00 32.00 283.65 4379.05 851.54N 685.80E 4.00 217.66 487430.51 6023637.02 4520.00 36.00 283.65 4461.94 864.73N 631.47E 4.00 273.56 487376.21 6023650.31 4620.00 40.00 283.65 4540.73 879.26N 571.65E 4.00 335.12 487316.43 6023664.93 4712.71 43.71 283.65 4609.77 893.85N 511.55E 4.00 396.97 487256.36 6023679.63 4800.00 43.71 283.65 4672.87 908.08N 452.94E 0.00 457.28 487197.78 6023693.97 4900.00 43.71 283.65 4745.15 924.38N 385.79E 0.00 526.38 487130.67 6023710.39 5000.00 43.71 283.65 4817.44 940.69N 318.64E 0.00 595.48 487063.55 6023726.81 5100.00 43.71 283.65 4889.73 956.99N 251.49E 0.00 664.58 486996.44 6023743.23 5200.00 43.71 283.65 4962.01 973.30N 184.35E 0.00 733.68 486929.33 6023759.66 5300.00 43.71 283.65 5034.30 989.60N 117.20E 0.00 802.78 486862.22 6023776.08 5400.00 43.71 283.65 5106.59 1005.91 N 50.05E 0.00 871.88 486795.11 6023792.50 5500.00 43.71 283.65 5178.87 1022.21 N 17.10W 0.00 940.97 486727.99 6023808.92 5600.00 43.71 283.65 5251 . 16 1038.51 N 84.25W 0.00 1010.07 486660.88 6023825.34 5700.00 43.71 283.65 5323.45 1054.82N 151.39W 0.00 1079.17 486593.77 6023841.77 5800.00 43.71 283.65 5395.73" 1071.12N 218.54W 0.00 1148.27 486526.66 6023858.19 5900.00 43.71 283.65 5468.02 1087.43N 285.69W 0.00 1217.37 486459.55 6023874.61 6000.00 43.71 283.65 5540.31 1103.73N 352.84W 0.00 1286.47 486392.44 6023891.03 6100.00 43.71 283.65 5612.59 1120.04N 419.98W 0.00 1355.57 486325.32 6023907.45 6200.00 43.71 283.65 5684.88 1136.34N 487.13W 0.00 1424.67 486258.21 6023923.88 6300.00 43.71 283.65 5757.17 1152.64N 554.28W 0.00 1493.77 486191.10 6023940.30 6400.00 43.71 283.65 5829.45 1168.95N 621.43W 0.00 1562.86 486123.99 6023956.72 6500.00 43.71 283.65 5901.74 1185.25N 688.58W 0.00 1631.96 486056.88 6023973.14 6600.00 43.71 283.65 5974.02 1201.56N 755.72W 0.00 1701.06 485989.76 6023989.57 6700.00 43.71 283.65 6046.31 1217.86N 822.87W 0.00 1770.16 485922.65 6024005.99 6774.27 43.71 283.65 6100.00 1229.97N 872.74W 0.00 1821.48 485872.81 6024018.18 6800.00 43.71 283.65 6118.60 1234.16N 890.02W 0.00 1839.26 485855.54 6024022.41 6900.00 43.71 283.65 6190.88 1250.47N 957.17W 0.00 1908.36 485788.43 6024038.83 7000.00 43.71 283.65 6263.17 1266.77N 1024.32W 0.00 1977.46 485721 .32 6024055.25 7100.00 43.71 283.65 6335.46 1283.08N 1091.46W 0.00 2046.56 485654.21 6024071.68 All data is in Feet unless otherwise stated Coordinates are from Installation MO's are from Rig and 1YO's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from 800.18N 897.31 E on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated #. ) Nachiq#1, Beaufort Sea Exploration,North Slope, Alaska(lmported} PROPOSAL ~')TING Page 5 r'l. BAKER Well bore: Natchiq #1 Version #2 HUGHES Wellpath: Natchiq #1 Version #2 INTEQ Date Printed: 13-Mar-2003 7200.00 43.71 283.65 6407.74 1299.38N 1158.61W 0.00 2115.66 485587.09 6024088.10 7300.00 43.71 283.65 6480.03 1315.68N 1225.76W 0.00 2184.75 485519.98 6024104.52 7400.00 43.71 283.65 6552.32 1331.99N 1292.91 W 0.00 2253.85 485452.87 6024120.94 7500.00 43.71 283.65 6624.60 1348.29N 1360.05W 0.00 2322.95 485385.76 6024137.36 7600.00 43.71 283.65 6696.89 1364.60N 1427.20W 0.00 2392.05 485318.65 6024153.79 7700.00 43.71 283.65 6769.18 1380.90N 1494.35W 0.00 2461.15 485251.53 6024170.21 7800.00 43.71 283.65 6841 .46 1397.21 N 1561.50W 0.00 2530.25 485184.42 6024186.63 7900.00 43.71 283.65 6913.75 1413.51N 1628.65W 0.00 2599.35 485117.31 6024203.05 8000.00 43.71 283.65 6986.03 1429.81 N 1695.79W 0.00 2668.45 485050.20 6024219.47 8088.49 43.71 283.65 7050.00 1444.24N 1755.21W 0.00 2729.59 484990.81 6024234.01 ..Ç~"" c..~~\- t\o~-\~ ~<è'--\~a\, \~ All data is in Feet unless otherwise stated Coordinates are from Installation MO's are from Rig and TVO's are from Rig ( Nordic III 52.5ft above Mean Sea Level) Vertical Section is from 800.18N 897.31 E on azimuth 283.66 degrees Bottom hole distance is 2729.59 Feet on azimuth 283.65 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ') ) Pioneer Natural Resources Alaska Inc. 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----------------------------------------- ~---------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ~---------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- ~---------------------------------------- ----------------------------------------- ----------------------------------------- ----------------------------------------- -----------------------------------------. 13-3/8" Drive Pipe 3500 ' 7050' TVD I"^Ó-"" :-;:: !~~¡~'$~ :~f~~~ ~f~_-.:.!~:< ~ ) ------ ) N atchiq #1 Surface Casing & Production Hole 1¡I~i {~;~~:{...- 9-7/8" Hole '<'~:':'] :~i~ffZj 7-5/8",29.7#, L-80, BTC-M ~'~:~z·~~z,~ . {,;:~~ý~ PI· = 6,890 PSI ·"'>'''1 ~;;::;:.:.:_'.'.; P = 4 790 Psi ~ c , ~ 6-3/4"Hole 8088' MD ') IIÎ ;11 m~i~: mm: Iii II!I II m:;§:;: 3500' I'::.:.!:,i~...."..::..·,....~...i:i,.:..:......!:....:..:~'...........;,.. ¡I!~ X:. :~~~:::f~ ~J ....!.:.',.,..:.!,'.·.....i,.:....·:¡.!:...:JI.: ~~:~tii ',. l~iÍ?, :;:;:~;ii :,~:}~~ ' . I" ", ....~......:..·:,..¡:..:i.):,.:!.·..,..:,¡:..·.¡.!~.·.·.!1......... 4350' ~¡¡IL J.~f;¡; ~%~:~m~~:j '" :.~,:~~,:..~,:.~:~,::.f5.:',,~.:.'~.:: ~,;..:.;,i.:~.~.!.~.'.;:.~.:.,j. . ".! :;::.11 -'. . :~~:~~~::?~~ ~(..\...:....,¡.!:..":.~,..;.¡.',~..... ~~mi~~~; .. " " .:~~:~~~~~~) I ..... :::.{.:.<>,.~:....;:...;". ~::,·::,r.·,.:.,:..::.':¡:..::,:::.:::,:.,.:'..: 1~1¡~ 1;: . . ~~Bm~) ~~Iir~~¡¡ 7050' TVD I<~~~;:':·,::,:':,::~~~~:::. I~Ç":~~~:::::'~:;:~:~~'I -';~~5';1 .....,~...... .........'........'.. '. '...............'.. ....... w 3350' ) Pioneer Natural Resources Alaska Inc. N atchiq#l Production Liner Liner Hanger & Liner Top Packer 7-5/8",29.7#, L-80, BTC-M Pi = 6,890 psi Pc = 4,790 psi 5-1/2" x 4" CSR & 3-1/2" X-Q 3-1/2" Liner Tail 8088' MD I;~':~Z. ,~é"'/"~ .;:~S§;: 1~if~' :;.~';..:>;~, III I! I~~ III 3350 ' m~rJ: :~t~t~ .,·..··,·"',·".··'1·"·;" r::5~' {:: t~ 3500' i j"'i' . I,~~~~ ':;:;ts e:;;{~ :~i~~:~ I"m~ :,m~ I:S~:~~ ì;sti 4350' ì.:·.:S~.:ill.. I,~~~%$I ìi~~~~~: ~lii ) -"~j;>"1 ' ':~...'.'.'.."..;'....'.'.'.'..'..~...:...r....;,.....'...".... "'''' ¡U'1 íf¡1 õõ 4f :1~~ì :~f~~~ ø.!:;>::;~ 7<;~[~ti . ,'.,'.,'.,'., ........'\.................... g~~:~:~:i~j 'II JIll ~~i~¡ ~~)f~¡ :::'.. .~.::..~ I : :::'. ': '. .' I 7050' TVD :.~ ~.' ".. ~:: ) Pioneer Natural Resources Alaska Inc. Natchiq #1 Completion Assembly: Test 1 Liner Hanger & Liner Top Packer 7-5/8", 29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' TVD 5-1/2" x 4" CSR & 3-1/2" X-Q Kuparuk "c" at 6100' TVD 3-1/2" Liner Tail 8088' MD ) I.'~.'.l'~.:.:.~' - ..'.......·.·.'·.'..'.·.'.'1 :i:%~~: ....'.:.....::'..':,......;:::..~:.,¡i...:...:.:,',..:.,'...·.~:: ,,: ;~~¡~~ J,;s~s::': , Ci:~;':': I : :m:1~:~ III 3350 ' 1;i'~I!.......i.::......i...·.·.....lli....:..¡:.¡.::,.....:,...'::.:,~.,:....:,.'........:... iî¡!~~ 3500' iII~~ ~~~ I'f§f; t:~;m Ig:~~(~':il i~;1{~ 0 ' .' 'J I .....!2. :4.;.·..~:...¡.i::::..,:.:.!. 1.:...·.·,..'¡...:,..·,..1.,·..,~,i.·.:.;"'''' ,.',.. ,;{;gJ ~~;~~, .. 1 , . Ii! 4250' ~ì. ..,;..:....,~,:.::.:....~..~..,.I" tgf;š_ ~:..:. I . , ·:%i:~m~t ::,...:.~...¡....:.::.:;.:.i:::.·.:::,:1:.::·..:::.::.,:.·..:::,..,1:.::':.::..:'.,".'::::'i:::::...·.::........ " '. "' '. '. t~r IIIIIII 1 ... '.. .1 I..·.: .... .:. I :...~..:::,..: I . . I I Iii ~:g:~~~~J :~~~:::~~:¿~:~Î: :;::::g~~~:~í .~:~~};~} ::2~~~:i~j . "1 a..... 7050' TVD I,:;;::;;::{::, I:~;~;~~:~: ~~~~~~t~: I~~~~~~~: i¿~¿~g: i~~¿~g:: ~ <~, ........"" I~~:~~~~:::: (t~f:~n . ...... I~··· ) Pioneer Natural Resources Alaska Inc. N atchiq #1 Finish Testing: E-Line Plug Back Liner Hanger & Liner Top Packer 7-5/8", 29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' TVD 5-1/2" x 4" CSR & 3-1/2" X-Q Kuparuk "c" 3-1/2" Liner Tail 8088' MD + 75' RKB I····,',·",·,· ~;i~T} :~.~::.~~~, r:11 Þ : Ji@~:: I ': r':"':' · · · · · · · ') :if1f¿:¿1 ',~:,{.~){'\~ ..',.'.'.'.~:..'..'."..'.' ::;~:~:; '~;~:;i~~: :::;~:;~{:; II! . , . , . , . , , ~..............~ ~ ~II ... : 3500' ~ a.: ') Pioneer Natural Resources Alaska Inc. N atchiq #1 Cement plug: 3600' to 75' MD 7-5/8",29.7#, L-80, BTC-M õ""O . 3-1/2" Sliding Sleeve at 3600' 4350' 1 ^"^'~ ~"'^"I """,31 1£""" IIII 1IIII . . 7050' TVD 1 . .' .' :1 1 ':. ", :. .. . . .,1' I,,' I I.. m.·. 1 I· '. " .1 :1 .', " ":~m~ml ¡.¡.j.:,:.¡.:.\.;.,,;.~,¡...¡¡1~ill! .-....'. Ilillm ..:.~,:.: :.:.~.·.~,:.:.:.·.~.:,t.~,~.:,~:., ". ". ". ". ". . .' :Z~·~~~?~:~~I r'~~~~~~:i::~~:~s~~:j .{~~~~~~:~~~~:%~:~~~ 1~&~timlTi Kuparuk "C" 8088' MD ) Chemical Cut 3-1/2" & 7-5/8" I """""1 : """."'::' . . . . . . . - . . .. . . .... . ~. ~ ..'~ 1 ~II 3500' ~ 1 1 1 .~. 1 - 1 1 1 1 1 4350' :, III I·" IIII If.~;%%' .' . '.1 IIIII ~;'j;:~;~;:i: 1 .' :-:." ~ '. "'1 1 ':.1 I.. 1 1 . .:' .... . " . .. ::. 'xl.:.... .: I . . 1 .. ... . 5~:5~:m~Î :1:.·.j...·:.~_.:_~_J...~_·~:¡.::.~.....;.:,.¡ ~~~¡¡ ii '. .' :;:~~~:gj' I~~~~¿~¿: :~m~~:;~! r~t;:~:·~ 1 I·" . ...:~:'.)~: 7050' TVD I':: '··1 :.~....~.: ") Pioneer Natural Resources Alaska Inc. Natchiq #1 Cut off tubing & casing 7-5/8",29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' Kuparuk "C" 8088' MD ') ") Pioneer Natural Resources Alaska Inc. N atchiq #1 Final Abandonment A 15 ft·:' . .. - - - - - - ~ ~I - ~ - - -:-.- - ~ -~ ~ - - - - - - ~.-- ~ - ~ -- Sea 'Level' ----------------------------------------------------- . . 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--- - - -- - -- ---- - ------ - - - -- - - - -- -- - - -- --- ------- - -- - ---- - ---- - ----- --------- - ---- ----- --- ------.-. ------ -.-------. -- ---- -- - ..._-- ---- -------- ---- -------- ---- ---- --- ---- --- - - --- -- - ----- ------- -------------- ... ------- ---- -------- ---- --- --- --- - ------- - -- ------ .----- -- ---- -- ...----- ------ ----... ..... . ---- ----- ----- - --- -------- --------- ------ 1- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- _ _ _ _ __ e _ _ _ _ _ ~ _. _ _ _ _ _ _ _ _ _ _ _ e _... _ _ _ _ _ _ _. _ _ __ - ---- ...--- ---- ------------ ---- -------- --- - -. - -- - - ------- ---- - - - ---- -- - - -- --- - - ---- - --- - .-- --- -------------- - - ---- - ------ -- - ----------- ------------ - ----------- ----- - ------ -_.- -- -- -- - -...- ------ -- ---- -- -- --- ---- ---- - ---- --------- ------- ----- ------- - --- - ----- - ----------- ----- - ---- ---- ---- - -------------~_. ..-.---- ------ ---------- - ---- ---- ---- -------- ------------ ---- --- · -- - - --- - --- - .-- - --------------------. .-- -- -- - - -- -- -- ------- - - - ------ -- - - -- --- --- -------- - ---. -- -------- ---- ---- -- - --- - - -- ----- ---- ------------ -- -- -- -- ---- ------- - --- ---- - .-- -- - ------------------.------- -- -- - - -- -- - --- ---- -- - -- ----- - - -- -- -- ---- ..... ... ______.._ _ ___ ._e _ _ _ e____ _ _ __ ______ __ ._____ .. e___ ________________ ____ ____ ____ ____ ___ - --- - - - - --------------------------------- -- -- - --- --.. -- - - -- - -- - - ------- ----- - ----- ---- ----- ----- - ------------ -------------- ----- ------ ---- ---- --------..- --...--- ----- -- -- ----- ------ ----- --- - - - - -- -- - - - ---- - -- - - - ------- - -- - ---- -- - - ---- --- - ---- -- ---- ~------- ---- - -- --------- - --------. --.---- - ---- ---- ---- ---- ---- ---- ---.. ---- ---- --- --- - ~ - -- - -- -- - ---- ---- - ---- - - - ----- - - - --- -- - - - --- ---- --- -- --- -- ----- - ---- - - -- ---- · - ------ - ---- -------- --- -.- .--- ---------- - ._-- ---- -- -- -- -- ---------- -- ------ ---..- ---- -- --- --- - - - -- - ---- ---. ------ --------- --- --- ~ ---- ---------------- ------- ------ · ___ ____ _____ _____. ___ ________e__ ____ _e__ - -- - - --- - - - - - - -- - - -- - - - ---- - - ---- -- - - --- ---- ---- - ---- ---- ---.- -- ---~- ~ -- ----- - --- - --- - ------ ------------- ------ ---- ---- -- _ ___ ___ _ ______e_ ____ ____ ____ __ _ __ _ _ __ _ ___ ------.. ---------------- -- ---- -- -- ---- --- - ---. - - -- ---- - - - - -- - -- --.-..------. ---. --- - --- - - - - --- - ------ ------- - --- - -- -- - -- - -- .------- ------ .------------ ------ ---.---- .. ---- ---.. ---- -------- ---- ---- -------- --- .--- -- --------------- --- ------------ ----- - --- - --- --- ---------- - - ------- - -- - ---- -- - -- --- -- ----------------- --------- --- ---- -...- -.....- ...--- -.---- ---. ---- ---. ------ ----- Rev: 07110/02 C\j ody\templates ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~-k~/~ / PTD# 702- --2-£7 CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" (If API number last two (2) - digits are between 60-69) The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function - of the original API number, stated above. PILOT (PH) HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION 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. (Company Name) assumes the liability of any protest to the spacing exception that may occur. // 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. DRY DITCH SAMPLE > WELL PERMIT CHEC. KLlST ,COMP~NY f- It:thær WELL NAM~ ¿.f jd;j- . / PROGRAM: Exp ~Dev _ Redrll_ Re-Enter _ Serv _ Wellbore seg_ _ FIELD & POOL OtY')tJCf) ,- ~?ýp _ INIT CLASS I?xP / /-IIDI ( .- GEOL AREA - B'1() UNIT# N4 ON/OFF SHORE C£Ç ADMINISTRATION 1. Permit fee att~ched. .: . . . . . . . . . . . . . . . . . . . . '¡(fY~_ _ N ~. ~p/-/-Þ-u.- klc!-/~. ~~ .¡-¿-V~_<d¢?"'.· ... J?"Y./óÝ ~ ~¥J. !~ " J'J 2. Le~se number appropnate.~. . . . . . . . . . . . .. . . . . N ~ -1lL+:-~ ~.tt!4..,4ð?'-- t.-t.- /7.2>L- ~/:!:fjC¡S I ; .~ ~ - ~ Þ Y"ð-( 3. Umque well ~ame and number. . . . . . . . . . . . . . . . . ) ~ ~ -77::> f.4,A. /'97JI_ 3ff'9qçz..~..42> - () 4. Well located In a defined pool.. . . . . . . . . . . . . . . . . -. Y ŒJ e;t=-¡>~ Þ:Y åJ...e../1 5. Well located proper distance from drilling unit boundary. . N 6. Well located proper distance from other wells.. . . . . . .. . N :¡, DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 3. 3 6 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N . / ~6 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can be issued without administrative approval.. . . . . Y N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#~ Y N (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . . ~ Y N - ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . N \ ~ ~ I~' Qo "';) \ 16. Surface casing protects all known USDWs. . . . . . . . . . . N ~ "ì.;{~" s·,.:)",Ça.c::;j:.. .<:...~S Q; ~ÒD t 17. CMT vol adequate to circulate on conductor & surf csg. . . . . N 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . N 19. CMT will cover all known productive horizons. . . . . . . . . . N 20. Casing designs adequate for C, T, B & permafrost. . . . . . . Y N 21. Adequate tankage or reserve pit.. . . . . . .. . . . . . . . . -v---N-\::)~ ~" ~c::,.~o~\~ ~\()..~~ 22. If a re-drill, has a 10-403 for abandonment been approved. . . '-¥-N- \:J ~ 23. Adequate wellbore separation proposed.. . . . . . . . . . .. NN 'f'..C) ~\\~a,~~ ~c:.:..."'~( 24. If diverter required, does it meet regulations. . . . . . . . . . 25. Drilling fluid program schematic & equip list adequate. . . . . N 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 27. BOPE press rating appropriate; test to L{œ\a psig. NN '\-'\ ~S? c-~ ~ ~C)()a ~"';. \ 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ® (Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . _ ¥-N- ~ ~ . _ ' . . "k~ b GEOLOGY 32. Permit can be issued wlo hydrogen sulfide measures. . . . . ~N d. '¿Vl~ > ,t!~..s ÞU.. #~I ~~ns/g-r wJ4 ¡;~-ÆC?\5 ~I/ . () . l APPR DATE 33. Data presented on potential overpressure zones. . . . . . . . N 4>, ~r'-- '$~' A' ~ ~¿>~ ~ (/~~ 118l!.. :' - _ 0, ~-rt~V~ ~ k~, a.~d-Wl, i\. - 3-13-Q3 34. Seismicanal~~isofshallo~gaszones. . . . . . . . . . . . . N tJ4.-~ c:""£-~",:'1~~ p~U.¿ .'f!r,:.~.h~ "ItA~f1..~~f ~/f~a;/-pf.Þ/riÞ' L::LJ 35. Seabed condItion survey (If off-shore). . . . . . . . . . . . .. Nft-~ N U ~t>~ .sk:¿/{;z,.; ÁA J ~ -L?'-~' (Exploratory Only) 36. Contact namelphone for weekly progress reports. . . . . . . . CD N .1k,r (b~ 3~~q-- h7.,C:,9 GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: TMþ01fV!~/\~ ~'Q~~' ~ \)c.~~~Q~ \L--..)~~~~~Q,~L APPR DATE ~~ ~lL"3 Comments/Instructions: RPC_ JH JR SP RR'"\.., \~...-a~ DS Rev: 2/25/03 SFD~ MW WA \wellJ)erm it_checklist ) @j m,~ lIL r)ì fE ~ ~ Œ\,Cë9 nt7..®. riD L W U!1: lQ) Lf ~ lb l/~ riD U~ !1\~ ,) AI¡ASKA. OIL AND GAS CONSERVATION COMMISSION Kenneth H. Sheffield, Jr. President Pioneer Natural Resources Alaska, Inc. 3900 "C" Street Ste 702 Anchorage Alaska 9951S / I / / TONY KNOWLES, GOVERNOR 333 W. 7fH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Re: Natchiq #1 Pioneer Natural Resources Alaska, Inc. ..~ Permit No: 202-227 Surface Location: SOO' FSL & 900' FWL, Sec. 16, T13N, RSN: UM Bottomhole Location: SOO' FSL & 900' FWL, Sec. 16, T13)(, RSK UM Dear Mr, Sheffield: 1f/.. G _ Enclosed is the approved application for permit to redrill the above referenced exploration well. This permit to redrill 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. 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. 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 to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~/~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 3'="day of December, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole Casing Weight 13-3/8" 72 9-718" 7-5/8" 29.7 6-3/4" 5-1/2" 17 3-1/2" 9.2 ) vJ GA- (Z/210 ¿.. ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1 b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) 10.5' + 32.5' = 43 feet North 6,023,585' East 487,642' 13. Distance to nearest well KRU, 3M-27 BHL, > 9200 Maximum hole angle Specifications Grade' Coupling L-80 PE L-80 BTC-Mod K-55 FJ L-80 BTC-Mod Length 80 3500 900 3250 1a. Type of work: Drill 0 Redrill D Re-entry. DDeepen D 2. Name of Operator Pioneer Natural Resources Alaska Inc. 3. Address 3900 "c" Street, Ste 702, Anchorage, AK 99518 4. Location of well at surface 800' FSL & 900' FWL of Sec 16 T13N R8E UM At top of productive interval same At total depth same 12. Distance to nearest property line _, 800 feet 16. To be completed for deviated wells Kickoff depth: MD 18. Casing program size Total Depth: 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot ~efraction analysis 0Seabed report 020 MC 25.050 requirements 0 21. I hereby certify t~at the:~~ing is ru, e ::d, corre_ct to the best of my knowledge Questions call S. Coyner 339-6269 Signed .1í.t£.({~1:: ~$~ Title: President Date /VtJ y 22 I ZIP 2~ Kenneth H, Sheffield. Jr. ( Commission Use Only Permit Number. _ _ I API numbe~ . ""'\ r / "2 C.. .... I Approval date /p]' h~, 0' Isee cover letter 2-L") 7 -2-.<"2-7 50-7{;,"3·- 2£; )r~o-c.".C /v ,!L~ 'tJ(~ for other requirements Conditions of approval Samples required ~ Yes D No Mud log required M Yes U No Hydrogen sulfide measures 0 Yes [RJ No Directional survey required 0 Yes ŒJ No '-r . (, I' J .-I--V\.L I J14_'tï~ Dì Required working pressure for BOPE D2M; D 3M; 0 5M; 0 10M; 0 0 ....5 _ ,A!J Other: T e. s, t- ~ P t to ~ooO yJ Ý{, . -, U.A- j.i :;l ,.£D Date /01-~h;2- I Effective Depth: Casing Conductor Surface ProdlJctíon Length Perforation depth: Approved by Form 10-401 Rev. 12/1/85· measured true vertical feet feet measured true vertical feet feet Size Cemented measured true vertical ORlntNAL SIGNED BY M L. Bill Development Oil 0 Multiple Zone 0 10. Field and Pool feet 6. Property Desig~ation AD 03899511 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) Natchiq Statewide 8. Well numþer Number 1 103655283 9. Approximate spud date _, Amount March 1, 2003 /' $200,000 14. Number of acres in property 15. Proposed depth (MD and lVD) 640 7500 ' MD / 7500 'TVD ; 17. Anticipated pressure (see 20 MC 25.035 (e)(2)) Maximum surface 3075 psig At 6250' TVD 3700 psig (Kup C) Setting Depth Exploration Top Bottom Quantity of Cement lVD (include stage data) 112 "" Drive Pipe 3500 /~4 x Permafrost L & 223 sx G 4250 67 x of Premium-Microlite & 7500 ~_, sx of Premium-Latex cement MD 32 o 3350 4250 lVD 32 o 3350 4250 MD 112 3500 4250 7500 Plugs (measured) Junk (measured) Measured depth True Vertical depth Commissioner by order of the commission I , , ~ Submit in triplicate REV DATE BY CK APP DESCRIPTION REV DAT~ BY '--'ÇK" - APP DESCRIPTION I ) 29 28 27 26 25 30 29 ~ 28 27 26 Thetis Is. ':t 32 C OOGARUK #1 0- 33 34 35 36 31 32 33 35 NA TCHIQ No. 1 T1 4N T13N LOCA TED WITHIN PROTRACTED 3 6 5 SEC. 16, T 13 N, & R 8 E, -'SQ 01VIK #1 UMIA T MERIDIAN. ?)..z· 900' F.W.L, 800' F.S.L. oS'C 10 >¿,¿/ 12 10 11 LA T = 70'28' 32.32" Q&- LONG = 150·06'03.42" Y = 6,023,585 15 14 13 18 17 16 15 14 X = 487,642 THIS SITE r 0 NA TCHIQ #1 ADL 0389951 24 22 23 19 20 21 22 23 q 27 26 25 30 29 29 N ~ ;;0;;0 t)1l¿, " -...JOO ~ 36 fT1r1 31 32 ïi?()"~\ () 1 3N ~ c ~ \900' ~ ~~ \ \ß 0. NA TCHIQ \ ( No. 1 \ ---- "\ ~ ---10.00' 00 ~. \ ~ p.:z. \~\ \~\ SCALE: 1" = 200' (' (> ~\ ~ ~\ -() ö~ NOTES: a o ro ~7~26 20121 I w 1. COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4, NAD 27. 2. GEOGRAPHIC COORDINATES ARE NAD 27. 3. ALL DISTANCES ARE TRUE. 4. ICE PAD IS ROTATED 70· EAST FROM NORTH. ^v- Pioneer Natural Resources Alaska, Inc. CADD FILE NO. LK601 0478 _l_DRAW.'._NG NO: 11/22/02 __ NA TCHIQ #1 WELL AND ICE PAD PERMIT EXHIBIT SHEET: I REV: N S K 6.01 - d 478 1 OF 1 0 ) ) Pioneer Natural Resources Alaska Inc Exploratory Drilling P.rogram Well Name: Natchiq #1 Classification: Exploration Rig Days: - 16 ADL: 389951 Drill and Complete (Test & Abandon off Rig) Estimated Spud: March 1, 2003 Prepared By: S. Coyner EXPLORA TION OBJECTIVES FOR WELL: 1. Drill the well to the Middle Brookian sands. 2. Cut 60 ft core in the Kuparuk "C" sand. 3. Finish drilling through the Kuparuk as directed. 4. Run the completion as directed. MORT. 5. Perforate and test the well. 6. After testing, plug back as required using E-Line, etc. 7. Properly plug and abandon - without the rig. HSE OBJECTIVES FOR WELL: 1. No Lost time Accidents. 2. No Spills. 3. No environmental damage Natchiq #1 Drilling Program Page 1 ) [Well Name: ) Natchiq #1 Drill and Completion Plan Summary I Type of Well: Vertical I Drill, Case, Complete, Test and Abandon Suñace Location: North 6,023,585' East 487,642' 800 ft FSL & 900 ft FWL of Section 16, T13N, R8E UM I AFE Number: I I Drilling Rig: I Nabors 27E ,.,/ I Estimated Spud Date: 12/15/2003 I Estimated Rig days: 116 I MD: 17,500' I I TVD: 17,500' I I Pad Elev: 110.5' I I RKB: 143.0' I Proposed Well Design: I Slim Hole to minimize drilling waste I Objectives: Kuparuk "c" Formation and Middle Brookian Formation Mud Program: (attached) Bit Proaram: 9-7/8" 6-3/4 24 36 ROP 125 125 RPM 200/300 200/300 WOB 1 0-30 5-15 Interval Surf - 3,000' 3000' - 7500' Size Type 1-1-5 PDC Footage 3000' 4500' Hours Surveys & LWD: Directional Program: While Drilling: At Suñace Casing Point: At TD: 9-7/8" Hole: MWD Surveys every 300' / 500' to 3500' MD 6-3/4" Hole: MWD Surveys every 300' - 3500' to 7500' MD (additional surveys to maintain the wellbore ~ 500 ft FSL) Drop a Magnetic Multi-Shot Survey Before POOH Drop a Magnetic Multi-Shot Survey Before POOH Natchiq #1 Drilling Program Page 2 ') Logging Program: Suñace Hole: LWD: Open Hole: E-Line: LWD: Open Hole: E-Line (OH): Production Hole: E-Line (CH): ') MWD 1 GRI RES Mud Logging & Gas Detection Cased Hole GR MWD 1 GR 1 RES Mud Logging & Gas Detection GRlCNL/FDC/Sonic/Caliper MDT's, SWC's SCMT in the Liner (bond & correlation) Formation Markers: Formation Tops MD TVD Sagavanirtok 950' 950' Possible gas hydrates: 1100' to 1600' Ugnu 2400' 2400' Colville 2750' 2750' Middle Brookian 4250' 4250' Hydrocarbon Bearing, 9.0 ppg EMW Torok 5350' 5350' Hydrocarbon Bearing, 8.6 ppg EMW T/HRZ 5950' 5950' Kalubik 6120' 6120' T/Kuparuk 6200' 6200' Hydrocarbon Bearing, 9.6 ppg EMW Kuparuk "C" 6300' 6300' Hydrocarbon Bearing, 9.8 ppg EMW TIM iI uveach 6400' 6400' Alpine Sand 6500' 6500' Hydrocarbon Bearing, 9.8 ppg EMW Jurassic Sands 6650' 6650' Hydrocarbon Bearing, 9.6 ppg EMW PTD 7500' 7500' CasinglTubing PrOgram: (see schematics) Hole Csg/Ln rl WtlFt Gr~e C0J'" Length Top Btm Size Tbg OD's MD/TVD MD/TVD Driven 13-3/8" 72.0# L-80 PE 80' 35' 115' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 3500' 0' 3500' 5-1/2" 17# K-55 511 1400' 3350' 4250' 6-3/4" 4250' 3-1/2" 9.2# L-80 BTC-M 3250' 7500' Tubing 3-1/2" 9.2# L-80 BTC-M 4250' GL 4250' Natchiq #1 Drilling Program Page 3 Integrity Testina: Test Point: Surface Casing Shoe ") Depth: ± 3520' (20' below the shoe) ) Test Type: Expected EMW ~ 13.7 ppg// LOT (based on offset data) 1. After NU & testing BOPE, RIH. Test the 7-5/8" casing to 3500 psi. Record the volume of mud required to pressure up to 500 psi, 1500 psi, 2500 psi and 3500 psi. 2. Drill out the shoe track. Drill 20 ft of new hole and circulate the hole clean with consistent mud weight in/out. Pull up into the casing shoe. 3. Perform a Leak Off Test: · Shut the well in. RU cement pump. · Record the fluid volume in the cement unit's tanks. · The estimated Leak Off surface pressure with 9.5 ppg mud is = 764 psi. · As a future guide, use the data from the casing test to determine the approximate volume of mud required to reach 764 psi on the LOT. · Bring the pump on line at 0.1 - 0.2 bpm & keep the rate constant. · Record the pressure for every tenth of a bbl pumped. · Continue pumping until the pressure breaks over plus 1 bbl. · Plot the data to determine the Leak off pressure at the shoe as EMW. · Repeat the test if needed. Cementina Program: (attached) Well Control: /' Surface hole will be drilled with a diverter. The production hole will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer capable of handling maximum potential surface pressures. · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: 11.4 ppg EMW at 6250' = 3705 psi, Kuparuk "C" 3705 psi - a full column of gas @ 0.1 0 p~ = 3080 psi 4000 psi (unless otherwise designated) Disposal: · Cuttings Handling: Cuttings generated from drilling operations will be ground on site using Nabors' ball mill. All drilling waste will be trucked to KRU disposal well 1 R-18 for underground injection subject to Ballot 260. · A cuttings bin fitted for use with Nabors rig #27E will be used as needed to catch and hold excess drilling waste until the ball mill and/or trucks can catch up. · In the event of an equipment failure, drilling waste will be trucked to Prudhoe Bay's G & I facility on DS-04 for disposal. H2S: / H2S has not been seen/reported on any of the offset wells: Kalubik #1, Kalubik #2, Kalubic #3, E. Harrison Bay #1 & Thetis Island #1. As a precaution, however, H2S monitors will be used at all times and 30-minute air packs will be available. I .' .-,- '-..,~/-v J;::,cvL ..:J/!{- -"- "l!- ( '1-( -5E)/l/-Ü¡"U,-t!..d /t...,,-: ~~ .-¡,; ~ 'ð~ ~ Natchiq #1 Drilling Program Page 4 - DRILL AND COMPL~ liON PROCEDURE ') Pre-Rig Work: 1. The 13-3/8" non-insulated conductor will be driven to ±. 115' RKB. 2. NU the multi-bowl casing head on the 13-3/8" conductor. 3. Spot and fill the reserve fuel tank with spill containment. 4. Spot and fill the reserve water tank with spill containment. 5. Stockpile mud and cement materials on/near location. 6. Stockpile casing and tubing on/near location. 7. Ensure communications are up and running. 8. Ensure the permits are in order. 9. Ensure all training requirements have been met. 10. Establish polar bear perimeter and watch. 11. Notify the AOGCC 24 hours prior to spud and BOP test. 12. Notify ACS prior to MIRT. Drilling Hazzards: 1. The shallow hazard survey indicates the presents of no discernable hazards. In addition, none of the offset wells reported any hazardous conditions while drilling near surface. 2. Gas generated from drilling through "hydrates" is expected to be minimal. Again, offset wells reported only minor volumes of gas while drilling the surface hole. The reduced hole size planned for this well with minimize the volume of gas generated while drilling. 3. Gumbo and other reactive formations constitute potential hazards from surface to TD. The planned use of inhibitive drilling fluid should miMimize this problem, however, caution should be used at all times because swabbing and packing off could occur at any depth. 4. No H2S is expected in this well, however, H2S monitors will be used at all times and the crews should be made ware of this potential hazard. 5. The Kuparuk "C" could have ±. 3700 psi BHP if connected to KRU, 3M-20i. The expected equivalent mud weight is 11.4 ppg and the crews should be alert to this potential hazard. BOP tests "kick drill" will be conducted in accordance with AOGCC regulations. 6. Lost circulation represents a potential hazard in this area. An adequate supply of LCM will be stockpiled on location for use if needed. The drilling fluid will be maintained to minimize ECD, surge and swab pressures. Lost circulation is considered to be a low potential hazard and little if any losses were reported on the offset wells. Ria Operations: 1. MIRU Drilling Rig, camp and ball mill with berms and herculite as required. 2. Take on water and mix spud mud. Make sure all solids control equipment is operating at capacity. Set the solids control van/skid (if used) and be sure it's operational. Set the cutting tank, etc. 3. NU the BOP's on the wellhead with the diverter and diverter spool. RU the diverter lines (10" minimum) as per AOGCC regulations. Function test the diverter system. Use a test plug; test the rams, casing head and flanges to 2000 psi before the rig is accepted. 4. Clean out the 13-3/8" drive pipe. PU the 9-7/8" BHA with MWD/GRlRES and a performance (straight hole) motor. While drilling the surface hole, stop and circulate the hole clean at 1000', 2000' and at 3000'. Try not to "out drill" the solids control equipment: control drill if necessary. Record MWD surveys every 300 ft. Drill the surface hole to +/- 3500'. Drill the hole to fit the casing including 10-15' of rat hole. Natchiq #1 Drilling Program Page 5 5. At casing point, circulóÅhe hole clean. Rotate the drill strin~ ì ~ 120 rpm to help clean the hole. ' Make a 20 stand wiper trip. Circulate bottoms up again. Drop a magnetic multi- shot and POOH. LD BHA. If the hole is "tight", pump out of the hole using the top drive. 6. NU and test 7-5/8" casing rams. RU casing tools. Make up the "Combo Tool" on a stand of drill pipe and stand it back. Run and cement the 7-5/8",29.7# surface casing. A port collar will be run in the casing string one full joint below the mandrel hanger (± 25' below the mud line). Use PDC drill-able float equipment and centralizers on every third joint to surface. Run a cement basket 1 joint below the port collar. Land the fluted hanger. 7. Circulate at least one full casing volume and adjust the rheology of the mud as needed. Pump a "marker pill" and record the pump strokes (bbls) shoe to surface. Calculate the annular volume and adjust the cement volume as required. Cement as per the attached program. Displace with drilling mud. Bump the plug with 1000 psi over final pump pressure. Record cement returns. 8. ND the cement head. RIH and open the port collar. Circulate the 13-3/8" x 7-5/8" annulus clean from the port collar to surface. Spot freeze protect fluid (brine & methanol) in the annulus. Close the port collar. LD the "combo tool" and landing joint. - LD the surface BHA. 9. Drain and wash out the BOP stack. Set and test the 7-5/8" packoff. ND the diverte~nd diverter lines. NU the drilling riser. Test the BOPE to 250 psi and 4000 psi on chart. 10. MU 6-3/4" drilling assembly with MWD/GR/RES, and a perfg.rmance motor with a 1° bend. RIH to the float collar. Test the 7-5/8" casing to 4000 psi. / 11. Drill out the shoe track and 20' of new formation. Displace the well with clean '(low LGS %) 9.5 ppg brine-based, drilling fluid (per attached program). Pull up into the shoe and perform a Leak Off Test. The expected LOT should be about 13.7 ppg based on offset data. a. Shut the well in. RU cement pump. b. Record the fluid volume in the cement unit's tanks. c. The estimated Leak Off surface pressure with 9.5 ppg mud is = 764 psi. d. As a guide, use the data from the casing test to determine the approximate volume of mud required to reach 764 psi on the LOT. e. Bring the pump on line at 0.1 - 0.2 bpm & keep the rate constant. f. Record the pressure for every tenth of a bbl pumped. g. Continue pumping until the pressure breaks over plus 1 bbl. h. Plot the data to determine the Leak off pressure at the shoe as EMW. i. Repeat the test if needed. 12. Drill the 6-3/4" hole using the performance motor and LWD tools. Adjust the mud weight as dictated by hole conditions. Survey every 300ft as needed. Slide if needed to keep the well bore at least 500 ft from the south line. Stop and circulate bottoms up every 1000' rotating the drill pipe at ~ 100 rpm to aid hole cleaning. Increase the mud weight to 9.8 ppg before drilling the Middle Brookian sands and to ± 10.0 ppg before drilling the HRZ. Ensure the mud is conditioned to ~ 11.0 ppg before drilling into the Kuparuk "C". Test often for free potassium in the system which inhibits the reactive clays. Let the chloride content climb with additions of KCI: the salt increases the mud density without adding solids. 13. At the Kuparuk"C" core point, displace the hole with LWL coring fluid. Make a wiper trip to ensure adequate "trip margin". Circulate & condition the hole. POOH (SLM). 14. RIH with 60 ft core barrel and PDC core head. Carefully wash to bottom. Space out the drill string to eliminate connections while coring. Drop the ball and cut the 60 ft core. Keep the pump rate to a minimum to avoid washing the core out. After cutting 60 feet, break the core off and POOH. LD the core and core barrel 15. RIH and finish drilling the 6-3/4" hole to TD as directed using the performance motor and L WD tools. Adjust the mud weight as dictated by hole conditions. Continue surveying Natchiq #1 Drilling Program Page 6 every 300 ft as needeL~topand circulate bottoms up every. }O' rotating the drill pipe at ~ 100 rpm to aid hole cleaning. At TD, circulate and condition hole for- logs, cores and RFT's. Make a wiper trip, circulate and drop a magnetic multi-shot. POOH for logs. 16. RU E-Line, riser and packoff. Log the hole as directed: GRlCNL/FDC/Sonic/Calip. RFT's and SWC's are expected. Run the SWC's last. Make a wiper trip between E-Line runs only if needed. RD E-Line. Load the liner in the pipe shed. Install turbolators, centralizers, etc. 17. RIH with a bit and BHA. Ream any tight spots. Circulate bottoms up at least twice. POOH. If the BOP's do not,ave the necessary VBR's, install and test 5-1/2" casing rams. 18. RU and run the 5-1/2" x 3-1/2" tapered liner, CSR, liner hanger, liner-top PKR and setting tools on drill pipe. The CSR is to be run ± 150' above the Middle Brookian test zone. Set the liner hanger ~ 150' above the 7-5/8" shoe. Circulate and set the liner h~er. 19. RU - cementers. Mix and pump the liner cement job as programmed with the volume adjusted as per the caliper log. Displace with drilling mud. Bump the plug. Set the liner-top PKR and dis-engage from the liner. Circulate the hole clean. Test the liner top PKR beyond the 7-5/8" LOT using the pressure-volume data from the casing test as a guide. 20. Shut down the pumps and flow check the' well for 30 minutes. LDDP and liner setting tools. RIH with a polish mill and 3-1/2", 9.2# L-BO BTC 1ubing on 'drill pipe from the derrick. Polish the CSR. Test the casing, liner top PKR and the liner to 3500 psi for 30 minutes on chart. Circulate the well clean. POOH. LDDP & BHA. Rack the tubing in the derrick., 21. RU and run the 3-1/2" completion tubing, CSR seal nipple, sliding sleeve, GLM (wI RP shear valve) and SSSV (see attached diagram). Tag the CSR and space out the tubing string. Displace the well with ± 110 bbl of "clean" KCI mud followed by a 10 bbl Hi-Vis spacer and ± 40 bbl of diesel. String into the CSR, land the hanger and RILDS. Test the IA to 3500 psi for 30 minutes on chart. Test the SSSV control lines to 5000 psi. 22. RU Slick Line unit. Drift the tubing and liner to PBTD as required. Pull the "lock out" sleeve from the SSSV. POOH and RD SLU. Close the SSSV. 23. Set a BPV in the tubing hanger. Wash out the BOP's and LD the landing joint. ND the BOP's. NU and test the upper tree assembly to 4000 psi with diesel. Leave the tree freeze protected with diesel. Secure the well. 24. RD and MORT. 25. Set the well house and prepare to test the well. Well Testina: 1. RU well test unit, storage tanks, SSSV control pump, flare stack, etc. Pull the BPV and open the SSSV. 2. RU E-Line with lubricator. Run a correlation log as follows: GRlSCMT/CCL in the lower (3- 1/2") portion of the liner. Perforate the test zone #1 as directed. RD E-Line. 3. Test the well as directed and in accordance with the applicable permits. Produced liquids are to be disposed of at KRU facilities subject to ballot 260. 4. After testing zone #1, spot kill weight mud across the perforations. RU E-Line. Set a CIBP ~ 50 ft above the perforations. Test the CIBP to 1000 psi. Dump bail ~ 25 ft of cement on top of the CIBP. 5. Perforate the test zone #2 as directed. RD E-Line. 6. Test the well as directed and in accordance with the applicable permits. Produced liquids are to be disposed of at KRU facilities subject to ballot 260. Natchiq #1 Drilling Program Page 7 7. After testing zone #2, I:, ~ead the tubing with kill weight mud. . )E-Line. Set a CIBP ~ 50 ft above the zone #2 perforations. Test the CIBP to 1000 psi. Dump bail ~ 25 ft of cement on top of the CIBP. RD E-Line. PLUG AND ABANDONMENT /' 1. After testing and plugging back with, E-Line, RU SLU, cementers and a "slop tank" as required and continue plugging the well. Open the sliding sleeve and establish circulation. Set a Halliburton "Pump Thru Valve" in the sliding sleeve profile. RD SLU. /"" 2. RU a squeeze manifold. Mix and pump a 148 bbl cement plug: 3600' to MSL. Displace with water to the tree (clear the lines) and allow the plug to equalize. Pressure up on the IA to open the RP shear valve (± 2500 psi) and then reverse circulate the well clean from that depth. Freeze protect. RD ce'menters. 3. RU E-Line with a crane. Use a riser and packoff as needed. Tag-test the cement plug. Pressure-test the plug as required. Circulate with hot water through the GLM. Chemically cut the 3-1/2" tubing between the GLM and the SSSV. RD E-Line. Flow check for 1 hour. 4. ND the tree and return it to the vendor. Using a short landing joint and elevators, pull the tubing hanger, tubing (± 40 ft) and SSSV with the crane (~ 1000 Ibs): 5. NU a 7-5/8" pup joint and E-Line packoff. RD E-Line with a crane. Use a packoff. Chemically cut the 7-5/8" casing above the port collar. RD E-Line. PLiIl the casing hanger packoff. Use the crane to pull the 7-5/8" casing hanger and cut off joint (± 30 ft) (1000 Ibs). 6. ND the multi-bowl wellhead leaving only the 13-3/8" drive pipe. 7. Pick up a mechanical casing cutter, pup joint and power swivel with the crane. RU to circulate while sucking returns from the cellar. Anchor the power swivel torque arm to the crane or other fixed object. Cut the 13-3/8" drive pipe ± 5 ft below the mud. Circulate hot seawater while cutting the casing. LD all tools. 8. Pull the 13-3/8" stub. Spot 5 sx of permafrost "L" cement over the casing stubs. RD. 9. Clean out the cellar and properly dispose of the waste. 1 o. Retrieve the cellar and close the hole with clean ice chips, etc. Prepared by: !Þ~~ Skip Coy~ Senior Drilling Engineer Natchiq Technical Services Attachments: · Drill time graph · Wellbore diagrams · Offset mud weight graph · Offset LOT graph · Cement program · Drilling Fluid Program Natchiq #1 Drilling Program Page 8 13-3/8" Drive Pipe 3500' 1·.'-.-",··'-' ....,.". ".'''..". ,."..". ',-'.,"', ~..'. ,w, ~..".. .. ........ .~..... ",.'".". f:/~ Î:\(~ {·;:m ÜtH f>~:::~ ¡:.};::::~ n~:;:~ I~\\:: r;m f~:~~:;. f;:g;~ ,:+~:; f§;::; ï:~m~ em f::::} (:~n I~{{ f:Q (:;:? f}} (~~:;~:; ~--~..:.::.:: ...... , "..~ 7 500' ------ ) ') :,,:;,1 Pioneer Na~:t:;;~r;; Alaska Inc. \\?:I Surface Casing & Production Hole ~:/::>I /::::::.J r::~\::1 m~:-~:~I ~:}:>I ::i:::/}:I ~~?::::';104-- 9-7/8" Hole ::~:·::,tl ;:-::':/1 ~ ~:~X::;:I \.:::tl m/:::I f/:?I {:U~I ?~@I ~~~:~:~~:I fg:~:~_1 f:~:~?-:I ::2:~:::,1 :}i:/:I 7-5/8",29.7#, L-80, BTC-M f/\I Pi = 6,890 psi I: Pc = 4,790 psi Cement with 347 sx (257 bbl) of Permafrost "L" followed by 223 sx (46 bbl) of"G" + 2% CaC12. +-- 6-3/4" Hole ') I¡¡ ¡!!;!!I Jr::.::~ :,<:_::'::.' rŒ1 !::(m:~:: t·:·:~/ ~'\\~I f::;:::: /:::-:::;1 :./:/ ~~::?,,~:: ¡:::};:; :::~::;":~} f:::::§: 1 hi; :.~_.:::.:.~.':",.,::_:,:,,:;,..::.:..~,'.:II i/\:; : í~;;'":';': ~t~~:~:~~:~1 ~'m~~ ?D~~) ì'/?:~ ~/:::::) (:~m ~\:;::~~] fm :':':".~.'_::.:.~.¡:.,:.:.:¡.:,11 i}::~:::'~ .' f?S mr:~1 I~" mWI 3350' i¡b~1 rx,1~m: i\~,~~ tI ~ ~t/?I ~/?~Hœ .. ···1 3500' .m; ¡¡¡¡Ii t?:? f::-~j b) E:A f); ~~~j f:(~ ,~'::::;'I 1 ". '. m~~1 r:~m ~úú IS? ~:}j i?:;:; }::::::j t\ :::-::n 4250' mil I¡~~ t;:.-:' '::::::'1 n~è~ dN~~~ t:~~n~ ~gmj tmm ~m~m~ì ~<> n:e;:)' ümm .":.:.:::.:::.:::_'.~.:.:"".:.:::.~.:.:::.:::.~.".:.'.:::.~.II~. ü:}:\ . 6:~:n:: \:::::::;:~:::::í t../:..::~.:.: :~'~:':':'/':'::J (\W ?{}}) WE:> ············1 f/:::>? ~¡J}?>i~ If:.:.:.:,:.::.:.:.:.:.·~.·:.:.':.':.:,:.:..:,' ?/f:::::::) ;:.:-:,::.:.::,'.:.:.] t:~:·:::/·:· \\}:::::/I (::::::::::::::::: ~:/::;:/~:j (/:::\::: ·::·:·::·:·::·:~·d I':::':':-:':':':':':~ . . . . I f'::::?\ h?t:{)¡ i~:~: ::::~:.;::: ::: ::::; ::: ::: ~:::; j t,:,:·::·?: :::::;://(1 f\\}: ?/::::::\::¡ (/\ ~~!f:':::) 7500' }ga;Y:E~:::~~.m: ) Pioneer Natural Resources Alaska Inc. Natchiq #1 Production Liner Cement the Liner with 267 sx (87 bbl) of Premium-Micro lite followed by 351 sx (73 bbl) of Premium-Latex LWL cement. Liner Hanger & Liner Top Packer 7-5/8",29.7#, L-80, BTC-M Pi = 6,890 psi Pc = 4,790 psi 5-1/2" x 4" CSR & 3-1/2" X-Q 5-1/2" x 3-1/2" Liner (top-down): · 7-5/8" x 5-1/2" Liner-Top Packer · 7-5/8" x 5-1/2" Liner Hanger · 900', 5-1/2",17#, FJ Liner · 4.0" Bore CSR x 12 ft · x-o to 3-1/2" BTC · 3250', 3-1/2", 9.2#, IBT-M Liner 3-1/2" Liner Tail ') li~] ,i1!11 ~}}~ ~/::f:1 f:.}::~ :'::??I .<:</ :;;:')':":1 C::~i~ :.·:.:,t.·:.:.·:.:,·,i.·..: :.::.~, i.:.11 I'::~'::':~ t>~? ~;:;':-:,:J f:?:::; ::::<":,::'::1 h-::~~ \~'t:1 ~:tW ~m:~~: iX:~/~ ~:;)}I n:::~~ ?U) f:/~~ ~\:(::J I- . . ~::':'::;'~I ü~m ~t2:1 (m~ ?~~~) ft:~~ ~mh f·::·::, m~::':;1 3350' ;i;¡ ~ ~I I.,}}; I E :::~'f?1 ~%m ~:~m mH mWI 3500' F~t[.::..~,:..,~.:.:.::;.',:.:.', ~:\~~?:I ~ ::.:::~:;_. (::.: ??~ì ëm t?;; 2£. .~f¡! ~}~~j fXI t% Û~:j t;} :}~/I t;:,S. ?::.j i>:~! f::j 4250' mil .Jil: ì~;.::;~ Ir?~:j f}~~~ ~~+tij f~$tf~~ ~~?f{j hr5 :.~:;~::~:.:::] f?W~~ mwm. C?U Lt?j tL:Y ~($) fè:~g ~::;:\?::::::~j Ü/)~ \~:::}:::::j (XX /}?H¡ i\:}% 1 f/'::/ ?t?~Ù t:::~zu :~':::':-:~':':~':'::~ t:!-:\\(:! nut) «:\( :}:::Y$ï (::~>~ ,.:.:,','¡f rÆ:~:t >:,.::..'::.:.;, ....,...... :.:.:.:::<.::.:-:,-:.) (:::>::::::: :.:.:;-:.;:,:.:::.:-'1 r?::}::::! ~t::::\::::J {:::/::::::;:~ ?:::::::!/::~j ~!{:\:;~ :::::i::::::::':~ 7500' ~m.;;}::Y~::;~E\: ) Pioneer Natural Resources Alaska Inc. N atchiq #1 Completion Assembly: Test 1 Liner Hanger & Liner Top Packer 7-5/8", 29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' 5-1/2" x 4" CSR & 3-1/2" X-Q 3-1/2" Tubing (Top-Down): · Mandrel Hanger wI control line ports · 30',3-1/2", 9.2#, IBT -M Tubing · 3-1/2" x 5000 psi SSSV · Pup Joint x 10' · CAMCO MMG GLM wI RP shear valve · 3560', 3-1/2", 9.2#, IBT-M Tubing · Baker 3-1/2" Sliding Sleeve wI 2.81 "X" profile · 650', 3-1/2", 9.2#, IBT-M Tbg · CSR seal nipple Kuparuk "c" 3-1/2" Liner Tail ') I!~ ','iil (::-~;:!: >~?;I t/':s ,<,-:::-:1 L~::/ ~:·{::~:'I f':::':::: ~:::::-<:~I .'\}g: ;,/}/I f:::<X:- :::::~:~·:I (:i:(: :~:?/J 1·:>::·:-:·:; ~:::;f:) f;:':-'~ :\::.::;:1 éÆ ~::-r:\.1 n!:t ;Y·{/I i.{;)i: ~:~:~:):I L~?~ f\n fQ~: n?~1 n:?:~ ~?;;~-I I:;:;:?::~ ~m:~:;1 ':.;':::::'.: - . -I ~":-:;:':';' (;\::.:- U:'{; /:}:::I (, ~;}::FI 3350' j~m~~ i ¡:. ~~tm:: Hn~·:. .......,... t~·~:~·::.: ~"::,~::~ :.w.... -·-;'·:'·'1 ()!: ¡~Ç.~~ :n~ ~:{~~h 3500' .m~ ~m.~ J~~:m X::;i fW mj :I;..i.:.·~.;.¡.¡.i 0 0 · m:m , ~+~~ e:~~ }{:I It::.~.:.-:.~..:.:.·:.~... &}I :;:;/.1 fk Y:j 4250' ~ml ..¡:~ f:!:~~~ Ie::::s.~ f.~\\ ~~}:)J ümm ~:\}}::::J t\3:~~ ~:~:<X:i ¡:n~t: ~nn?t i.~n< ::~n~\;j fi://~ {}rmt t./::?:~~ ;//;::':\1 ëYW :~:Y\:::j f:~~:):/ t::\//:- f):~~:'}:j 1 - -31-'1 L::-::/--:-; F/::-:::::d ';'.:.-. - ...: ,:~: ..~. ~....., ,...,\.\., L:'::':>': \;.:.:.:.::;.::.:.J (/:\:) ~:/<~t:t f/::::::::r; ::?:\?;:j (:::?/? ~r:?\:3 kH%· Wm~~:4 (/:\\ ?\\\::. (?:-:{::; ~:\?\?i 7500' ~ilmm\)I¡;! ') Pioneer Natural Resources Alaska Inc. Natchiq #1 Finish Testing: E-Line Plug Back Liner Hanger & Liner Top Packer 7-5/8",29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' 5-1/2" x 4" CSR & 3-1/2" X-O Kuparuk "c" 3-1/2" Liner Tail ) + 75' RKB I::::::: :'>::::':::1 ..~.~ ~_:~ ~. j,:~:¡¡:.::~ ~mr: mf~:i r;æ. ........ .:::_~:\ . : ::.::,:\.: f·"-;"·;· ;-';-_:~:'::I .'~:;:::::: LL ':':'::_-':' ¡¡¡íj !¡!!~¡i tm¡!~!lli!!!' ~;¡~: f:~n n~n¿ ~w~n:~ ~nmg ~:;Y::::I ili 1111'11 r,'1 rl! t> i" .....:.,....¡.I (g:~g f:N~::~:) (~¿~¿~g %\~j (:{@ m:;~tw I\nm ~:n:;:~xì (::wm W)~:Wt m~m:m: ::w:?n ~~mm~ f'>:'/?':: ::?::}\:; ?:":·:>:f) I·:'-:.'~.::.···.:I (:~r;?::x::~:~:/::i ~&;J~ 1t:;..';~ P\::.;-;:; ::::::';\\4 (::::>\/ :\\>:::\i f/f\; ~//~::::::J I~:::::::::::::::::::: //:::/J [.:\.:::-:.:::.\ ~\//:j f:::::::::}¿; \?:::::\) I//\~: . . . t (}??~ ~~~~:r:~\ 7500' :'::::jI:):{::œ:~E~l 3500' 4250' ) Pioneer Natural Resources Alaska Inc. Natchiq #1 Cement plug: 3600' to 75' MD 7-5/8",29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' Kuparuk "c" 3-1/2" Liner Tail ') Chemical Cut 3-1/2" & 7-5/8" '~'" 'n- 0-"" ~, . "'~,.'. ..".,.', :-:'::~:: I .:-:::\ l" (--~,~¿:¿ ~~m mm~~ \W~:~~:zrtmm~j mm r~:::{:~ mm~~ ~m~~~~~ ~m~n: W:!tl f:\~ g~;:~::~~ ~n:!~:~~~ ~é~:~~g ~;.::/::;.I tm¡¡ ¡1¡lm! ¡¡~i¡¡¡¡ im¡¡¡j ¡m~~ II Iii rllll II¡IIII ~II t" ,-', .' " ......... ,. '.' ·,········1 3500' l¡tn!IÎ¡!n¡~~1 ~i;!~ ~! ~J 1~!j ({~; >j ~~m~ ¡~;¡~~f: tt ;::~;:~:i () g:j 4250' ii~t ,,¡It¡ GW~~~ ~~mm~t ~tW~ ~:}:}}. fn;:~~ :Xè?:i (?~:@ ~n~H) 1\\2:: >~~>:rr (em ??:??:j t}/\::: \\{f:i f:::::};\~ :://Wi (/n~ ?\\:/f: ~:?:\> ?:/:r?::?:\\?i (:::::/\! //}:) ??:::(j ~~:I~t:@ '::~'~~:wm¡~~ i<':\":·:':' .k":·:i:·:':j ~- ."'.1.:W/ ':-:~-"i.\ f::::~:::\:: ' \:\://i f: ::: ::: ~ ::: ::: ~ : ::: ;: ~ :~~: ~': ::~ ~: ~~ 1-: ~ ':-::..,:::.: .::- ':::::- --::¡: i):~~/~:: :;{:>::::{. I~ \:~~:::~~: ::::: -'. 0" o"·"·"f .......":-":- :.~,~-"'. :,~,- ::,;.:.::,~,·,-:,;-;,:.:,·:I' I?::\:;::~! I:::\::_!::::} {t::~,) 7500' ~m.~r:):~:m'¡L}t· ,",.,,,.. ~'.' ".,', ...,...... '''.0'',_''. 0"·"'''''·'' ...,...... ) Pioneer Natural Resources Alaska Inc. N atchiq #1 Cut off tubing & casing 7-5/8",29.7#, L-80, BTC-M 3-1/2" Sliding Sleeve at 3600' Kuparuk "c" 3-1/2" Liner Tail ') Pioneer Natural Resources Alaska Inc. N atchiq #1 Final Abandonment -_ -_- _-... - _ - _- _w_ -~ -ø - _-_- _- _-_ -_- _...._-_1""_-_-_-_1""_ -...-_-....- ...-_ ....~............-.... -_-_-_ -.. -..." ....~_ ---------------------------------------- ._------------~--------------- .---------- -----_._---------~------------_...._----~-- -------~ ----------~--------------------- ---------------------------------------- -----------------------~---_..._---------- 11111!1111~~III~II~IIII~ril!¡I-IIIII¡-II: ---------------~------------------------ .---------------------------------------- ---------------------------------------- ----------------~---._~----------------- -------------------------------~-------- ---------------~-------------.---------- ---------------------------------------- ... --- - --- -- ...----... -- ...--- -.............. - -....- - --- ..........-.. ----~---------------------------_._----- .---------------------------------------. ---------------------------------------- ...--------- - -----.. ----------- - - -- - ------... -------------~---------_._-------------- ._-----------------------~---~---~----~~. ---------------------------------------- ---------~~---~~-~------~-~-~-~....~----~-- -_-: _- _- _- _- _- - -_-_-_-_- _-_'"r' _- _-... -_.. _-....-_-_-_ "'_-p..-.. .....- _- _-_ -....-_.... _- _-... -_-,..-_-...,-_ -_..._--------------------------------~--- ____________________________h_________~_ -------------~--_._------------_._-_.._-- ------------~------~~-~------~..._--~~---- ---------------------~------------------ ----~-----------------~----------------~ -_._-_.~----.----...---------------_..~---- ---------------------------------------- ---------------------------------------- .---------------------------------------- ---------------------~------------------ ---------------------------------------- ---------------------------------------- ----------------.-----------------_....~--- ----------_..._------..._-------~-------_...-- -----_._--------~-------------_..._------- ---------------------------------------- ----------------------------~----------- -_....------------------~-----------_..._---- -.------------.--------------...---------- ---------------------------------------- ------------------------------------~--- ---------------------------------------- ---------------------------------------- ---------------------------------------- ---------~----------------~----------~-- --------------..----_.~---_.------------- ---------------------------------------- ---------------------------------------- -------~-------------------------------- -.....------------------------------------- ---------------------------------------- ------------------------------------.--- ----------------------~----------------- -----_._--------------------------~----- ---------------------------------------- ---------------------------------------- ----~-----_...._~--------------------_..._...._- ---------------------------------------- ------------~--------------------------- -----------------------------------~---- --_.~-------~-_.------------------------ --------------------------------------.- -------------~-------------------------- ---------...------------------------------ -----~--------.------------------------~- --------..------------~------------------ ----------------------------------------- ____________________________________________________________ø ---_...-..._.."-_.--...-._-----_.~_.......--~_........_---------_.._-----_..---- ------------------------------------------------------------. ____________....._______ _ __ _ ~ __ r _. _ _..._ _ ___....__ _ ____~ ___.________ ------------------------------------------------------------. -...---....------- - -_..---- --------- ~-~_... ~ -..----- - ...--_.. ........~-- - ---- ------~-----------------------------------------------------. _________ _ _ _ _...._ __ __ r.. ..._.._ _ _ r.. ...___ _ ~____~_. __r_ _... _ ___ _ _..._ _ _ ~ -----------------------------------~------------_..._---------. -----...--.---- -------------- ---- -......-..------...- _...--_.~------ ~~~~_~~__ ø________________________. ...-+-.......,..,.-...- ...._.~ ~--.... - ._---~..-.....~--- ---------------------------------------- ---------------------------------------- ---------------...------------------------ ._-~--------------------~----~----------- ---------------------------------------- ---------------~----~------------------- _______________________..____M__________ ---------------------------------------- ---------------------------------------- --------------------------------~------- -------._------------~-~---~._----.~---- ---------------------------------------- ---------------------------------------- ._----------------------~---------------- ---------------------------------------- ___________...._~__ø__~____________~--_____ ---------------------------------------- -------------------~-------------~------ ----------------------------~----------- -------~-------------------------------- ---------------------------------------- ._----~-----------------------~---------- ----------~--------------------------~.- -------~------------------_._------~---- ---------------------------------------- ._"-----------------~--------------------- -----------------------------~---------- .___...._w_________________....__~__________.__ 13-3/8" Drive Pipe ~------------------------~ --~---------~---~._---~-~ ._______________~--______a ------------------------- .------------------------. ~----~-----------~--_.~-- ~----~---------~.-------_. ) ) Natchiq #1 o 1000 2000 3000 Set 7-5/8" Casing .c ...... g. 4000 C 5000 6000 1 X 60' Core in Kuparuk 7000 \ Logs, RFT's & SWC's 8000 o 5 10 Days 15 20 1000 2000 3000 4000 .J: ..... c. CD C 5000 6000 7000 8000 9000 ) ) Offset Mud Weight O~Jj~~~ ~~: ~~:~,-: ~~T~r:~T~r: ~~T:::::: :~Ijj:::::T~r~ ~~~r:: I I It' I I I I I I I 'I I I I I I I I' 'I I' I' I . - - ~.. - - - _I_ - R - .. -.. -........ - - -I-" .. "1- .. - - - _.. - - - - .. - _.. -1-" .... t' ....... ...... _1_ _....... _ _ _ _ _ _ -1-""" I I' . I I' I' I I I, I I I' I' , I I I I I I I I I , I I' , ·---.,----1---- --- --------...--- "1----1----.. ·.,----1---- --.,-------- ---.,----,----...---.----1----...--- ____,___.. I , I I I I I I I' I I , I , I I I I I I I j I I I , I I I I I I I I I I I I I , ........,"" - -1-...... .. -.. .... - -...... -1""""" .... - -1-...... ....,...... -1-"" -.. -.,-.............. """"I""" -1- - - - r - -... .... - .,- -.... r""" ...... -1-...... I I I I I ,t t I I I 'I I , I I I I" I 'I I 'I , I t I I I I" t . I 'I I .---~-...-:---.. --.. --------:----.. ...--:---- ...-¡........; -r---:-------- ---¡----;----;---- ----;----;--- ---.;-...... :J ~t~: ::~ :~~: ~~~r: :- -')': :,--: : ::'::J ~ tT ~~: ::: :jj:: r: ~~ ~:I:~J:: :::I::: -- _::..: :-:i::::l::::;:::]:::::::: :::]:~-K~I-~b~k-#~--- ---L-- __;_m ---~----¡-mi----¡-------- ---~-~Kalubik #2 -i---- ..+---i----i---~-------- ---~-.....Kalubik #3 : : ¡ j : ......Harrison Bay . --- t - i--- T . - r --- -- -- - 00; ....... 3M-27 - --- r U¡U - T - - r m - --- - 00; ...... Thetis Island #1 ---..----,----..---.,-------- ---.,... I '" I I I I I I I I . I I I I I I I I , .. - ~ - -.. -;- -.. -; - -.. ~ - -.. - ...... - -- - ~.... - -:- -.. - -.. - ...... -:- .. - -:.... - -- - -1- - -- -m;----1----i---- u-N--j---- -1-00, --- - i____:____;_._~u------ ---~----:----~---- uu!----fmi----!u-- I I I I It' I' I t I I I I -:::;:::r::t::: :::: ::- -¡-::: : : ~-: '--:: :_:1__ --C:¡:::r:: :::: :::;:::::::::;:::: :::::: :::;:::;::::::::: : :: : I::: ::: :::: ._--~----:----~--- --------~--- - - --~-- ---~- -: --~--..~-------- ---~----:----~--_. ----:----~---~----:---- : ::: : ' :: ::::::: , , , , , , , , , ... -..,...... -,- - -.. ...... ...... -...... -,""" .. , , , , , , , , , ----'----1--- --- --------,---- - , , , , , , , , , --.. -1 --.. -1-" -.. .. -- .............. -t-.... ____J____I_ .. ____________ _ U 00; 00 u!m _~ ___ _ _ __ ____~ _ _ _ _~_ ~ L ___ _.. __ _ ~_ _ 00;___ _ ~ _ 00 _ . _ ..;_ ___ ~ ___ j __ _ _j____ I t " I , I I I I , I ..... -~ --.. -:- -- -~ - -- .... --...... -~...... -.. - ~_.... -:--.. .... ~-.. --.. ........ ~-.. --:-.... -;....... .. -.. -:- -- -~ - -- ~ -- - -:- - -- : :: ::: :: ::::::: .---~----!----~--- --------¡---- ----!----¡---- ---: ---¡-- ~ ._~--uu-- ---~----r---i---· ----¡----~---1----~---- IT:r: :-:-:J_:_ :::Lr: :__<___:::::_ T::--- -J-__::::r-::--C:¡_::LL_ ::-FFr: -__:::E: ::IE: :::i_ :r:r::::-::: :--Ff:r: -j:::r:Cf- " , I I I I I. I , I I I I I I I " I , : I I I - -. - - - ~ - - q~-- - . t u - ~ - - -- -- - - -- - ~. - - -~- - - - ~ - - - . - - q~- - - - ~ - - - ~ - - - -~-- - - -FEF_:--F-_ u:· -: -FLIF:-- -J-____l_::r+J--:] II" "" II .111 8 10 13 9 11 12 Mud Weight o 1000 2000 3000 .c .... g. 4000 C 5000 6000 7000 8000 10.0 sc 11.0 ) ) Offset LOT's (Frac Gradient) . . . . .. . . ~~ . . . . . . . . . . . . . . . . . . . . ~ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .... . 12.0 ! . . 113.71 I I 13.0 14.0 16.0 17.0 15.0 EMW (ppg) 9/02 ) ') Pioneer Natural Resources Alaska Inc. N atchiq #1 Cement Recommendation 7.625" Surface Casing 5.5 / 3.5" Production Liner Prepared for: Skip Coyner November 19,2002 Version 4.00 Prepared by: Eric Dompeling Halliburton Energy Services 6900 Arctic Blvd. Anchorage, Alaska 99518 907-275-2637 HALLIBURTON The Future Is Working Together. Natchiq #1 Well Oetai1.doc HALLIBURTOt~) ) 2 Cement Recommendation Surface Casing Well Conditions Casing Size & Wt. Hole Size MD TVD Top of Tail 7 5/8" 29.7# 9 7/8" 3,500' 3,500' 2,750' Volume Excess Mud Wt. BHST BHCT Previous Casing Depth 200% / 400/0 9.6 ppg 70°F 50°F 110' Slurry Recommendation: Preflush I Spacer 20 bbl Water, 75 bbl Alpha Spacer Lead Slurry: ~ks. (1,442 Ft') PERMAFROST L Tail Slurry: é:J!'kS. (256 Ft') Premium Cement, 2% Calcium Chloride (257 bbl) (46 bbl) Density (ppg) Yield (cu ft / sk) 8.34 / 10.5 Lead Slurrv f:!? 20.3 Tail Slurrv Svacer Water requirements (gal/sk) Fluid Loss (cc/30 min.) /Y) ff 5.00 Free Water % Thickening Time Hr: min. 6:00+ 3:00 Compressive Strength - PSI 12 hr (est.) 24 hr (est.) (48 Hr.) 25 (72Hr.) 260 1650 1800 Volumes based on: Top of Lead cement @ Surface /' 110 feet cased hole + 0% excess, 1390' open hole + 200% excess, 1250' open hole + 40% excess. Top of Tail slurry 1000 feet above shoe@ 2,750' 750' calculated annulus volume +40% excess + 120 foot shoe joint. Lead slurry: Tail slurry: Casing Equipment 1 ea. - 7 5/8" 29.7# Halliburton Super Seal II Float Shoe 1 ea. - 7 5/8" 29.7# Halliburton Super Seal II Float Collar 1 ea. - 7 5/8" 29.7# Top Plug 1 ea. - 7 5/8" 29.7# Bottom Plug Pioneer Natural Resources Inc. Natchiq #1 11/22/2002 HALLIBURTC~ '4) ) 3 Cement Recommendation Surface Casing Pumping Schedule Stage Liquid Number Description Density Rate Volume Tracer lbl gal bpm bbl 1 Spud Mud 9.60 5.00 0.0 0 2 Water Spacer 8.34 5.00 20.0 0 3 0 4 Alpha Spacer 10.20 5.00 75.0 rgJ 5 Permafrost L 10.70 8.00 256.8 0 6 Surface Tail 15.80 8.00 40.2 0 7 Surface Tail Shoe 15.80 8.00 5.5 0 8 0 9 Spud Mud 9.60 8.00 145.1 0 10 Spud Mud 9.60 2.00 10.0 0 Critical Velocity - Fracture Zone Based on annular segment at 3500.0 Critical Rate Stage Description Spud Mud Water Spacer Alpha Spacer Permafrost L Surface Tail Surface Tail Shoe Spud Mud Spud Mud Time min 2.20 4.20 9.20 23.45 30.95 32.20 42.20 55.55 60.01 60.01 64.26 78.01 86.15 86.15 86.25 ECD at Zone Fracture I Reservoir lbl gal 9.80 9.80 9.80 9.83 9.80 9.72 9.91 10.50 10.75 10.75 10.66 11. 04 11.99 11.99 11. 77 9.80 9.80 9.80 9.83 9.80 9.72 9.91 10.50 10.75 10.75 10.66 11. 04 11.99 11.99 11.77 Pioneer Natural Resources Inc. ft Critical Velocity bpm 13.08 1.17 8.19 13 .40 19.34 19.34 13.08 13.08 ftJs 4.07 0.36 2.55 4.17 6.02 6.02 4.07 4.07 Time of Events S tarts Pumping Stage Enters Annulus Water Spacer 3.00 min shutdown Alpha Spacer Permafrost L Water Spacer Alpha Spacer Permafrost L Surface Tail Surface Tail Shoe 3.00 min shutdown Spud Mud Surface Tail Spud Mud Prior to plug landing Plug landed Natchiq #1 Shutdown mm 3.00 3.00 Critical Reynold's Number 4004 5895 4401 4362 2383 2383 4004 4004 11/22/2002 HALLIBURTO. ..) } 4 Cement Recommendation Surface Casing OptiCem Summary ECD at 3500 ft TVD, Pump Pressure, Pump Rate, and Density YS. Time Fluid Density Rate IECD Pump Pressure::- 16 15- ~ 14- 13- ------...-.--.--..-,----,..." 12- 11- "'- I ~~' .... ,cp~) ------ -- 10- YD, Fluid ¥sity In (lb/gal) , I ' , , , I ' , , , I ' , , , I 10 20 30 40 50 Time (min) 7.625 in Surface Casing o OptiC em Final Density & Hydrostatic Profile Annular Fluid Density YS. Measured Depth ------- 500- 1000- 1500- 2000- 2500- Measured ~epth (ft) ~ JOO~ ~ 3500- 4000 10 I II I I I 12 13 14 Density/Hydrostatic Gradient (lb/gal) 7.625 in Surface Casing Pioneer Natural Resources Inc. Natchiq #1 60 , I ' 70 0p , I ' 80 I IS 700 -9 -8 -600 -7 -500 -6 -5 -400 -4 ~ate (bpm) -300 -3 Pump ?ressure (psi) -2 I -200 -1 100 -0 90 I 0 HALLIBURTON OptiCl11l v3.1.0 19·Nov-U212:01 1- Density I - Hydrostatic Gradient 16 I OHALlIBURTON OpliCc'll v3.I.U 19·Nov-U2 12:0 I 11/2212002 ìl) HALLIBURTO.,·. ) 5 Cement Recommendation Surface Casing I Pore Pressure GradieuL Minimum Hydrostatic Gradieul O~!.l.:~,,~t~l,t>,\ (~..',1!.1~ ~~I.l,¡"r OptiC em Downhole Pressure Profiles Minimum Hydrostatic Pressure and Maximum ECD VS. TVD ~:~i~~~~~~~-_·__·_-------·_-------------_·_-------------··-----------1 1000- l~ ------.... -~..._-~'---.,~....--'-.... 2000- 3000- TVD (ft) 4000- 5000- 6000 8.5 , I ' 9.0 , I ' 9.5 , I ' 10.0 I I I I I I ' , I ' 10.5 11.0 ECD (lb/gal) 11.5 , I ' 12.0 , I ' 12.5 13.0 7.625 in Surface Casing I W HALLIBURTON OptiCcm v3.1.0 19-Nov-0212:01 OptiCem CirculatinQ: Pressure and Density at Fracture Zone. Dow'1íhole Annular Pressure and ECD VS. Time I CirculatinA Pressu.c Hydrostatic Pressurc I 2400 1800- -~ -12 Fluids Pumped Œ) Water Spacer CD Shutdown CD Alpha Spacer CD Permafrost L @ Surface Tail (j) Surface Tail Shoe CD Shutdown CD Spud Mud GQ) Spud Mud -13 2300- FI.';,I\~lUl t P!"!-~~~l.I.',./F([) ,\1, .~ ".oi) n, YV,I) 2200- 2100- 2000- -11 P1900- .) res sure ~pSl ECD (lb/gal) -10 1700- -w 1600 ,I, o , I ' 10 î 20 ",cr~ 40 50 60 Time (min) , I ' 70 GfJ , I ' 80 -9 , I ' 30 90 7.625 in Surface Casing I W HALLIBURTON OptiCcm v3.I_O 19·Nov·02 12:01 Pioneer Natural Resources Inc. Natchiq #1 11/2212002 ~ ) HALLIBURTOI~) Well Conditions Liner Size & W t. Hole Size MD/TVD TOC Slurry Recommendation: Preflush / Spacer Lead Slurry: Slurry: Density (ppg) Yield (cu ft / sk) 6 Cement Recommendation Production Liner 5.5" 17# / 3.5" 9.2# 6.75" 7,500' 3,350' / 5,800' Volume Excess Mud Wt. BHST Previous Casing Depth Casing Size change @ 30% 11.6 ppg 190°F 3,500' 4,250' (3.5" to TD) ~bb ater, 35 bbl Alpha Spacer 6 . -Ks. (490 Ft3) Premium Cement + 15 LB/SK. Micro1ite, . .2% CFR-3 (Friction Reducer), + 0.75% Halad 344 (Fluid Loss Additive), ~o 5 glsk D-Air-3 (Anti-foam), + HR-5 (Retarder) as required (87 bbl) 5,Sks. (407 Ft3) Premium Cement+ 1 % Bentonite, + 2.0 G/SK. LATEX 2000, . 0.4% CFR-3 (Friction Reducer), + 0.36 glsk. 434B (Latex Stabilizer), + 0.05 glsk D-Air-3 (Anti-foam), + HR-5 (Retarder) as required (73 bbl) Thickening Time Hr: min. Free Water % Spacer Lead Slurrv Tail Slurrv 8.34 / 11 13.4 ¡;J Q2 13.38 5.11 <75 <75 0 0 >3:00 3:00 Water requirements (gal/sk) Fluid Loss (cc/30 min.) Compressive Strength - PSI 12 hr (est.) 24 hr (est.) 350 @ 90 <>P 625 @90 of 1,440 @165°F >1,000 @165°F >2,000 @ 165°F Volumes based on: Spacer I Pre-Flush: Volume based on 1,000 ft. of annular volume and lor 10 minutes contact time. Lead Slurry: 2,300 ft. calculated open hole + 30% e~ss, + 150' Liner Lap + 150' excess. Final Top of Cement at 3,350'MD Tail Slurry: 1700 ft. calculated open hole volume,+ 30% Excess.+ 120 foot shoe joint. Top of Cement at 5,800' Casin~ Equipment 1 ea. - 3.5" 9 .2# Halliburton Super Seal II Float Shoe 1 ea. - 3.5" 9.2# Halliburton Super Seal II Float Collar Pioneer Natural Resources Inc. Natchiq #1 11/22/2002 HALLIBURT01..) ) 7 Cement Recommendation Production Liner Pumping Schedule Stage Liquid Number Description Density Rate Volume lb/ gal bpm bbl 1 LSND 11.60 6.00 0.0 2 Alpha Spacer 11.00 3.00 5.0 3 4 Alpha Spacer 11.00 3.00 20.0 5 Microlite Slurry 13 .40 6.00 7.6 6 Microlite Slurry 13 .40 6.00 24.2 7 Microlite Slurry 13 .40 6.00 65.2 8 Pt MC Super CBL 15.90 7.00 71.5 9 Pt MC Super CBL 15.90 7.00 1.0 10 11 LSND 10.00 7.00 54.2 12 LSND 10.00 3.00 25.0 Critical Velocity - Fracture Zone Stage Description Based on annular segment at 7500.0 Critical Rate bpm 12.69 5.66 5.66 4.82 4.82 4.82 15.97 15.97 12.69 12.69 LSND Alpha Spacer Alpha Spacer Microlite Slurry Microlite Slurry Microlite Slurry Pt MC Super CBL Pt MC Super CBL LSND LSND ft Critical Velocity ft/s 5.03 2.24 2.24 1.91 1.91 1.91 6.33 6.33 5.03 5.03 Tracer Shutdown mm D D D 3.00 D D D D ~ D D 3.00 D D Critical Reynold's Number 8950 5471 5471 2013 2013 2013 2480 2480 8950 8950 Time of Events ECD at Zone Stage Time Fracture I Reservoir Starts Pumping Enters Annulus min lb/ gal 1.83 12.10 12.10 Alpha Spacer 1.83 12.10 12.10 3.00 min shutdown 6.50 12.09 11.09 Alpha Spacer 12.77 12.23 12.23 Microlite Slurry 13.60 12.23 12.23 Microlite Slurry 16.02 12.23 12.23 Microlite Slurry 20.18 12.24 12.24 Alpha Spacer 21.02 12.25 12.25 Alpha Spacer 24.35 12.32 12.32 Microlite Slurry 25.18 12.37 12.37 Microlite Slurry Pioneer Natural Resources Inc. Natchiq #1 11122/2002 HALLIBURTC. '4) ) 8 Cement Recommendation Production Liner OptiCem Summary ECD at 7500 ft TVD, Pump Pressure, Pump Rate, and Density vs. Time Fluid Density Rate--.--.·-----.---------- IECD Pump Pressure:; 16 2250 -8 :-2000 -7 :-1750 -6 -j 15- 14- :-1500 -5 13- :-1250 -4 :-1000 12- ~!tte (bpm) :-750 _ : Pump ':)ressure (psi) - -2 :- 500 11- 10- ECD at 7~ ft 9 ' , o G) VD, ~4 De~y In (lb/galÇp , I I I I ¡ I I I I I I I I 10 20 30 Time (min) :-250 -I 0 -0 60 ,cr I 50 I 40 I c.,HALLlBURTON OptiCc,n v3.1.0 19-Nov-02 12:06 Armstrong Oil & Gas 3.5" / 5.5" Cement Production Liner OptiCem Final Densitv & H vdrostatic Profile Annular Fluid I1énsity vs. ~easured Depth o 1- Density I - Hydrostatic GradieIi 1000- 2000- 3000- 4000- 5000- Measured 'Jepth (ft) 6000- 7000- 8000 9 I 10 I II 12 13 14 Density/Hydrostatic Gradient (lb/gal) 15 16 I OHALlIBURTON O¡1IiCC"l11 v3_I.O 19-Nov-0212:06 3.5" / 5.5" Cement Production Liner Pioneer Natural Resources Inc. 11/22/2002 Natchiq #1 HALLIBURTOh.) I Pore Pressure Gradient Minimum Hydrostatic Gradictlt o 1000- 2000- 3000- 4000- TVD (5Ð'b0- 6000- 7000- 8000 8 I 9 ) 9 Cement Recommendation Production Liner OptiC em Downhole Pressure Profiles Minimum Hydrostatic Pressure and Maximum ECD vs. TVD ~:~~:~~~~~-- ------------------------1 (j) 1 CD I @ cp I ' 40 \ I 10 I 11 I I 12 13 ECD (lb/gal) I 14 I 15 I 16 17 3.5" / 5.5" Cement Production Liner I G HALLIBURTON QptiCem v3.1.0 19-Nov-02 12:06 OptiCem Circulating Pressure and Density at Fracture Zone. Downhole Annular Pressure and ECD vs. Time I Circulating Pressure Hydrostatic Pressure I 7000 6500-:: _ I,'r m'~ ur~~. f~(. (·\~.HJ ,l,..r:ç I) a I..? ~(1(1, :I).."l,\:' ,I ,). 6000- 5500-:: 5000-:: P 4500- .) ressure ~rSl 400O-=~ 3500-:: ~ 3000 - I, o (§) Cfi I ' 10 Pioneer Natural Resources Inc. Fluids Pumped CD Alpha Spacer CD Shutdown Q Alpha Spacer CD MicroLite SLurry CD MicroLite SLurry Ci) MicroLite SLuny CD PI MC Super CBL CD PI MC Super CBL @ Shutdown ® LSND -12 @ LSND ECD (lb/gal) -16 -14 I 20 I 30 Time (min) 3.5" I 5.5" Cement Production Liner -10 @ -8 I I 50 60 I 0 HALLIBURTON OptiCc,,, v3.1.0 19-Nov·02 12:06 Natchiq #1 11/22/2002 ') Pioneer Natural Resources Alaska Inc. Natchiq #1 Drilling Fluids Program . General Discussion ) This exploration well will be drilled from an off-shore ice island west of Oliktok Point on the North Slope of Alaska. The well will be drilled as "slim hole" to minimize waste. The well will be spudded with a 9-7/8" bit and drilled to the surface casing point of ± 3500' TMD where 7-5/8" casing will be run and cemented to surface. A 6-3/4" hole will then be drilled to a final well TD of ± 7500' TMD. At TD, a 5-1/2" x 3-1/2" tapered liner will be run and cemented. Primary targets for this well will include the middle Brookian sands and the Kuparuk sands with other possible oil. bearing sands being present. An inhibited KCI/Polymer mud will be used to drill this well from spud to the core point on this well which is ± 6250' (the Kuparuk "c" target). At the core point, a specially formulated 11.4 ppg core fluid (BaraDril-N System) will be used to core the well. After coring the well, the BaraDril-N system will be run and maintained as an inhibited KCI/Polymer mud to the final TD of the well. As a general drilling fluids plan, spud the well with inhibited 9.0 ppg KCI/Polymer mud. The mud weight will then be held between 9.0-10.0 ppg to the surface casing point unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for hole cleaning. This spud mud is formulated with several mechanisms to provide effective wellbore stabilization and to reduce drilling waste,' i.e., ionic inhibition (KCI), polymer encapsulation (PHP A) and anionic bonding (Clayseal). From the surface shoe to TD, the continued use of the inhibited KCI/Polymer mud is suggested with again the primary focus being to provide effective wellbore stabilization and the reduction of drilling waste. When drilling this interval of the well a certain amount of new mud will be required coming out of the surface casing to re-adjust the low gravity solids content to acceptable limits for continued drilling operations. The mud weight for this interval will range from 9.6 ppg at drill-out of the surface casing to 9.8 ppg by 4000' (middle Brookian target) and to 10.0 ppg into the Kalubik. The Kuparuk "c" pressure could require 11.4 ppg mud if it is connected to KRU, 3M-27 & 3M-20i. As a precaution, the mud weight will be increased to at least 11.0 ppg prior to penetrating the Kuparuk "C". The mud weight will then be adjusted as dictated by hole conditions including the necessary "trip margin". U sing the current mud plan, the mud filtrate salinity range for drilling the pay-zones will be between 60,000 - 90,000 ppm. Formation Tops/Casing Program Formation Spud/SV -1 Ugnu Colville Mudstone Set 7-5/8" casing Middle Brookian Torok HRZ Kalubik Kup "c" Miluveach Alpine Sand Jurassic Sands Jurassic Shale Comments 9.0 ppg density flspud occasional "heavy oil" occasional shale instability Expected LOT ± 13.7 ppg EMW secondary target secondary target occasional shale instability occasional shale instability target sands occasional shale instability secondary target secondary target TD TMD 0' 2400 ' 2700' 3500' 4200' 5300' 5900 ' 6100 ' 6250' 6350' 6450 ' 6650' 7500' Natchiq # 1 Page 1 Mud Wt 9.0-9.3 9.0-10.0 9.8-10.0 9.8-10.0 9.8-10.0 9.8-10.0 9.8-10.0 11.0-12.0 10.0-10.3 ./ 10.0-10.3 10.0-10.3 11/22/2002 ') Special Considerations ) 1. Maintain a sufficient quantity of Driltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. 2. Lime and zinc carbonate should be on location for H2S contingency. 3. Maintain an adequate supply of barite to increase the mud weight by 1.5 ppg at all times. 4. Due to the remote nature of this location, maintain an adequate supply of LCM and the other mud additives, which may be required to support this drilling program. Surface Interval (9-7/8" Hole to 3,500' TVD/TMD) The surface interval of this well will be drilled with a KCI/Polymer mud as formulated below: 9.0 ppg Formulation Fresh Water KCI NaCI EZ Mud DP Clayseal P AC-L/R Barazan-D KOH Aldacide-G Baroid Baracor 700 .95 bbl 44 lbs o .751bs .84 gal .5lbs 1-2 lbs .llbs .2lbs o 1.0 (ionic inhibition) (polymer encapsulation) (anionic bonding) (API filtrate of6-12 cc's) (as required for an initial 35 YF) (pH = 8.5-9) ( X-Cide 207 for rig maintenance) (as needed) (corrosion inhibitor) Spud the well with maximum flow rates (550-650 gpm assuming 9-7/8" hole w/ 3-1/2" drill pipe) to ensure good cuttings transport. Target an initial YF in the 45 range then adjust as dictated by the actual hole cleaning requirements of the well (minimum gravel is anticipated -:- mostly clays and sand). Reduce viscosity as allowed (previous wells in the area have TD'd the surface hole with a ± 25 YF). However, if hole cleaning appears to be inadequate, do not hesitate to quickly raise the viscosity as required; Polymer viscosity in the form of Barazan-D additions should be utilized to provide rheological support as needed. Utilize high viscosity sweeps to supplement the hole cleaning capabilities of the system. Circulate while rotating at ~ 120 rpm for maximum hole cleaning. With an initial mud density of 9.0 ppg, please note the other issues of concern as listed below: 1. Alert all members of the drilling team of the potential of encountering gas hydrates. 2. A mud weight of ± 9.6 ppg is currently programmed for drilling the gas hydrate interval of the well, if encountered. Note: offset wells encountered only minimal gas hydrates. 3. If gas hydrates are encountered, treat the system with 2.0 ppb of Driltreat (Lecithin) and Ih% by volume BDF-263. Also, control drill if necessary. 4. Maintain the mud as cool as possible (under 50°F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. The freeze point of the base fluid is less than 20° F. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of fluid for the spud. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment application. As this mud will be formulated with soluble salts for the mud density requirement, the Baroid Solids Van should be considered for use to enhance/support the overall solids control efforts. Mud maintenance issues for this interval of the well are as follows: Natchiq #1 Page 2 11/22/2002 ') ) 1. If possible, use pre-mixed KCl water to maintain volume while drilling ahead. The density of the KCl solution should be based upon mud weight requirements at any given point of the well. 2. Use PAC's for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface casing point. 3. Hold the pH in the 8.5 - 9.0 range with KOH. 4. By material balance, maintain the Clayseal concentration in the 2% by volume range. 5. By material balance, maintain the EZ Mud DP in the .75 - 1.0 ppb range. 6. Control penetration rates based upon the ability of the surface system to process the drilling mud. Use as "fine mesh" shaker screens ,as possible. 7. Daily additions ofX-Cide 207 are needed to control bacterial action. 8. Corrosion inhibitors should be run (1 ppb Baracor 700 / .5 ppb Barascav D). 9. Keep MBT as low as possible (generally <12 ppb). Heavy amounts of clay may be present and may require additions of ConDet and BDF-263 to reduce BRA balling and screen blinding. Sweeping the hole with high viscosity sweeps prior to the short trip at TD and again prior to coming out of the hole to run the surface casing is recommended. If possible, reduce the fluids rheology to <20 yP after the casing is on bottom prior to starting the cement job. Surface Hole Mud Properties (9-7/8") Mud Density Viscosity Properties (ppg) (sec/qt) Initial 9.0 80 - 120 Final 9.0-10.0 50 - 80 yP 35 - 45 15 - 30 PV 13 - 21 15 - 23 10 Second Gel 10 - 15 10 - 15 API FL (cc's/30 min) <15 6-8 Production Interval (6-3/4" Hole to ~7500' TVD/TMD) Prior to drilling out the surface casing condition the spud mud to ± 9.6 ppg density with <4% LGS and an MBT of <6 ppb (a certain amount of new mud or brine additions could be considered in terms of re- adjusting the properties of the mud to insure a quality fluid for the initial drilling operations of the 6-3/4" hole). Increase the mud weight as needed with KCl so as to allow maximum application of centrifuge support to optimize solids control efforts. KCl will be used for ionic inhibition and for the basic density requirements of the system. CaC03 may be used as necessary. Initially, target a mud density of± 9.6 ppg with a yP in the 10 to 20 range and maintain until out of the sticky clays often found within this interval of the well. Then, adjust yP as required with Barazan-D polymer as needed for efficient hole cleaning. If screen blinding from heavy clays is a problem, use ConDet and BDF-263 treatments. Once through the sticky clays, increase the yP to the 15-25 range with Barazan-D to ensure good hole cleaning support. Flow rates of 250 - 275 GPM will provide an annular velocity of 200' /min which should suffice in this near vertical hole. Maintain the 9.6 ppg mud weight down to 4000'. Increase the density as needed (9.8 ppg) prior to drilling the middle Brookian target. Maintain the mud weight at ± 10.0 ppg into the Kalubik formation at ± 6150' then increase the mud weight to ± 11.0 ppg prior to penetrating the Kuparuk. Flow check all drilling breaks in the Kuparuk and increase the mud weight as dictated by hole conditions. Make a wiper trip prior to coring and ensure that enough "trip margin" is provided by the mud weight before POOH to pick up coring tools. Minimize LGS's through the constant/efficient use of solids control equipment and dilution as required. Below 4000', maintain the API filtrate S 6 with PAC's. Use KCl brine for daily volume additions (the brine density should be based on the mud weight objectives at the time). Daily additions of X-Cide 207 should be made to control bacterial action. KOH should be used for pH control. Keep MBT as low as possible « 12 ppb), however, do not revert to "dump & dilute" practices unless absolutely necessary. Natchiq # 1 Page 3 11/22/2002 ) ) Kuparuk "c" Coring (6250') A specifically designed core fluid (BaraDril-N System) will be prepared to satisfy the coring obj~ctives of the middle Brookian target on this well. The fluid will be very similar in chemical design to the KCl/Polymer muds used to drill to core point and should be compatible with the displacement objectives of the well. The core fluid design will include KCl for ionic inhibition, starch and "specially" sized calcium carbonates for effective filtration control and bridging and "clean" bio-polymers for effective rheological support. For fluid density on this well, the sized calcium carbonates will be sufficient. After drilling to the core point, circulate the hole clean. Make a wiper trip to the shoe, circulate bottoms up and then displace the hole with core fluid as follows: 1 Barrel (11.4 ppg) 7% KCl Core Fluid Water Soda Ash Aldacide G Aquagel Dextrid PAC L N-Vis KCl Baracarb KOH Baroid .827 bbls .1 ppb .25 ppb (X-Cide 207 for rig maintenance) 5 ppb 8ppb 1.75 ppb 1.75 ppb (as required for a 15-25 YP) 21.9 ppb 85 ppb (blending specific to target sand penn) as needed for an 8.0 pH. 82 ppb Target Properties Density HTHP (200 deg. F) yp PH 11.4 ppg or as required. ~ 7.5 cc's 15 - 25 lbs/lOO sq-ft 7.5 - 8.5 After coring, maintain the mud system as before adding KCl for ionic inhibition and CaC03 as needed for weight and filtration control. Drill to TD maintaining the mud weight as dictated by hole conditions. Production Hole (6-3/4") Mud Density Properties ppg Initial 9.6 T/Kup "C" 9.8 - 10.2 Final 11.0 - 12.0 yp 10 - 15 10 - 20 15 - 25 PV 6 - 12 15 - 20 15 - 25 10 Second Gel 2-5 2-6 2-6 API FL (cc's/30 min) 6 - 10 ~6 <6 PH 9-9.5 9.0 - 9.5 9.0 - 9.5 Natchiq #1 Page 4 11/22/2002 ................... .... ".... ........... ......... .-... .... .... ...-.-.-....-.-.-..-...-... + ...-.-.-.-.-..-...-.-.-.-..-..:...: -+ "'.:..:..:...-..-.,...-.-..-.,......... + ....~..:.-.~..:~-.-.-...-.-...... .... "'.-...-...-.-..:...,.-.-.:.'...,.... + ....,...-.-.:...-..-.:.,.:.-.-..... .... "'.-..-....-.-....,....-.,.-.:.-.-.:.... .... "'.-.-.....-.-.,..-.-.:.'.....-..., -; NORTHERN CONSULTING GROUP 2454 TELEQUANA DRIVE 243-7716 ANCHORAGE, AK 99517 0329 89-720213252 .(. -----. PAY TO THE ,\-<'tó·-r¡ N. . Air,,,, ¿. ORDER OF :J Y .ë.rU.- .~ ¿_J /1 ttaJ.L?t ' P.O. Box 196613 . Anchorage, AK. lP51.9-6613 .' ~ j L / / FORþklc.1u ~ ¡¿Jd!.-r {&/tæ;r- /r?~ ~/~ M> it .-/:t----- .-----------.-- I: ~ 2 5 2 l' 2 0 2 ¡. I: BOil' B 2 '7 8 5 g II' 2 III - 0 3 2 g ¡¿!JaY;:<:2 2ß.tØ 2:- I O¿} I $/?f;J -~ ~_ ..... _.......... .... .... ... .-.." ." ~...... .... -+- ....-.-. .-.-. ."~. ... .-. ..... ..... ",.-.-.-.-.. ..-..:.-. .-.-. .-.... ;.. ",.:.-.-.:.-. .-..:.'...-.-.-.-.... ;.. ",.-.:. .-.:.-.'. ....-.:.,.,...-... .... "'.-.-.:.-.,..-....:..,.-.-.-.:.... ...... ",.,.:.:.-.-.-.~. ..-.:.-.:.:.:.:.... .... "'.:.-.-.,.:.-.-.~,...-.-.~...-.... .... .-0:.:.,.-.-.:.-.:........-.,.:...:...: J ) ) Drilling Permit Check List N atchiq #1 /- Form 10-401 Filing fee $100 Location Plat: section line calls & northings/ eastings v Information on drilling hazards: gas, BHP, H2S, etc. , ~oe [J" '.7Jl~ It-\. ,/ Potential causes· of hole problems 5~ ð),.!7 f':J /1--, ,// Procedure for conducting LOT's. 5 (-c ¡J,.IJ ¡J7 ¡/'V\ v· Proposed casing & cementing program ?~.-(. [),.!f P:J r-- v Diagram ofBOPE & Diverter system _ t./ - Drilling fluid program v Predicted abnormal pressures /' Seismic analysis S"("'oc () J 'T rfJ 7 "- ~(C p, 11 P'J~_ Analysis of seabed conditions 1/ Drilling Program (,/ Waste disposal plan 5 ~ (: f)"'7 f"J rz-. ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER :::NA:¡f ~~~ # / CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) "CLUE " The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function - of the original API number stated above. HOLE 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). PILOT (PH) SPACING EXCEPTION /DRY DITCH / SAMPLE Rev: 07/10/02 C\jody\templates 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. (Company Name) assumes the liability of any protest to the spacing exception that may occur. 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. !I;ë~~ERMIT CHECKL~~ FIELD & POOL ADMINISTRATION APPR SFD }}ì COMPANY WELL NAME Natchiq #1 Initial Classrrype EXP /1-0IL PIONEER 000000 - Exploratory 1. Permit fee attached ................................................................................................ 2. Lease number appropriate...... ........................... ..................... ................................. 3. Unique well name and number ................................................................................. 4. Well located in a defined pool................................................................................... 5. Well located proper distance from drilling unit boundary ................................................. 6. Well located proper distance from other wells ... ............... ... ... ... ... ......... ......... ... ...... ...... DATE 7. Sufficient acreage available in drilling unit................................................................... 8. If deviated, is well bore plat included.......................................... ...... ........................ ... 11/29/2002 9. Operator only affected party ... ... .., ...... .., ... ...... ...... ... ... ... .................. ... ... ... ... ... ... ... .... 10. Operator has appropriate bond in force ..................................................................... 11. Permit can be issued without conservation order ......... ......... ... ...... ......... ......... ... ... ... ... 12. Permit can be issued without administrative approval...... .................................... ...... ... 13. Can permit be approved before 15-day wait........................ ...... .............................. .., 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified...... ... ............ ...... ...... ......................... 16. Pre-produced injector: duration of pre-production less than 3 months.............................. 17. ACMP Finding of Consistency has been issued for this project... ...... ... ...... ............ ...... ... (For Service Well Only) (For Service Well Only) (For Service Well Only) 18. Conductor string provided ... ............ ... ... ...... ...... ...... ......... ......... ...... ......... ... ...... ...... 19. Surface casing protects all known USDWs ................................................................. 20. CMT vol adequate to circulate on conductor & surf csg ................................................. 21. CMT vol adequate to tie-in long string to surf csg ......................................................... 22. CMT will cover all known productive horizons............................................................. 23. Casing designs adequate for C, T, B & permafrost....................................................... 24. Adequate tankage or reserve pit...... ...... ...... ...... ...... ... ... ........................ ......... ...... ... 25. If a re-drill, has a 10-403 for abandonment been approved............................................ 26. Adequate well bore separation proposed ......... ...... ......... ............ ... ... ...... ...... ... ...... ..... 27. If diverter required, does it meet regulations......... ... ... ...... ............ ... ......... ............ ...... 28. Drilling fluid program schematic & equip list adequate... ...... ............... ...... ......... ... ...... .. DATE 29. BOPEs, do they meet regulation..................... ...... ...... ...... ... .................. ............... ... I /!1 ¿ 30. BOPE press rating appropriate; test to ....................... .4000 psig ........................... t ¿ ¿. V 31. Choke manifold complies w/API RP-53 (May 84) ........................................................ 32. Work will occur without operation shutdown ...... ......... ... ...... ... ... ......... ......... ... ......... .... 33. Is presence of H2S gas probable ... ... ... ............... ...... ... ... ......... ... ... ... ... ...... ... ... ... ..... (For Service Well Only) 34. Mechanical condition of wells within AOR verified........................................................ ENGINEERING APPR lJJ4A- GEOLOGY APPR SFD f~ J 35. Permit can be issued w/o hydrogen sulfide measures... ......... ...... ......... ... ......... ............ 36. Data presented on potential overpressure zones...... ... ......... ...... ... ...... ...... ............... ... DATE 37. Seismic analysis of shallow gas zones ...................................................................... 38. Seabed condition survey (if off-shore) ... .................. ........................... ......... .., ........... 11/29/2002 39. Contact name/phone for weekly progress reports [exploratory only] .............................. GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: RPC: TEM: JDH: COT: êCY\ I t1~/D2- SFD: SFfþ WGA: X MJW: DTS: I ~/()~ )0 ( MLB: /;J../o 11f) z.. PROGRAM GEOLAREA Exploratory (EXP) -.!... Development (DEV) _ Redrill ~ervice (SER) _Well bore seg _ Annular disposal para req 890 UNIT No. Explor. ON/OFF SHORE Off Yes #0329: Northern Consulting Group Yes Yes No Exploratory well Yes 800' from property line Yes Nearest well (KRU 3M-27) is 9500' to southeast Yes NA Not Applicable - vertical well Yes Yes Yes Yes Yes i' .1:, NA Not Applicable NA Not Applicable NA Not Applicable Yes ACMP Consistency Determination (AK 0208-01 OG) issued Nov 14, 2002. Yes Yes Yes Yes Yes Yes Yes 13-3/8" @ 112' &k; S . '. i~~ urface casing wIll be set at~ MD an TVD and cemented to surface. Well is 6 miles offshore within the Beaufort Sea. SFD .,..., Yes Yes Yes Yes Yes Yes Yes Nabors 27E. NA Not Applicable Max MW 10.3 ppg. MSP 3080 psi. 1 No NA Not Applicable Yes* Yes Yes * No evidence of H2S in offset exploration wells. However, caution is advised: see below. Pressure gradient est 0.45 psi/ft down to UHRZ, increases to 0.53 psilft from UHRZ - TD; may reach 0_59 psi/ft if Kup C in commun. w KRU 3M-20i Minor gas from hydrates expected from b/ Permafrost (1000' MD/TVD) to 1600' MD/TVD. No other shallow hazards anticipated. Not Applicable: offshore ice island. Skip Coyner, Senior Drilling Engineer, Natchiq Technical Services, 339-6269 NA Yes Comments/I nstructions Well will be mudlogged and gas detectors will be used to minimize gas hydrate hazards. Inclination only survey required as this vertical well is more than 500' from a properly line. * In Dec. 2001, KRU 3M-27 (1.8 miles to the SE) measured 103 ppm H2S and 3M-23 (2 miles to the SE) measured 222 ppm H2S. Natchiq #1 appears to be fault separated from these wells_ H2S section of Natchiq #1 drilling plan states that H2S monitors will be used at all times and 30-minute air packs will be available. Drilling fluids program "Special Considerations" section notes that lime and zinc carbonate should be on location for H2S contingency. 12-2-02: Phoned Skip Coyner: Pioneer is aware of potential for H2S and have planned accordingly; rig crew will be informed of potential for encountering H2S; contingency measures and equipment are planned. SFD ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Peffilitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ( ( ( [j EPOCH ~ ~'t'~Ff,'VE"'''D !: . ~b ~,:aJ 0='" W JUN l"l i~003 ~~~~~\~ Aiaa~a Oi'i [1¡ Com~. Comm¡~ f\nGbor~e 8û8--;)& ':¡- (' PIONEER NATURAL RESOURCES ( Natchiq #1 Winter 2003 Exploration Program Northwest Kuparuk Prospect North Slope Borough, Alaska Final Well Report March 17, 2003-March 26,2003 Andrew Buchanan - Sr. Logging Geologist Ralph Winkelman- Sr. Logging Geologist John Lundy - Logging Geologist Kent Dickens - ~ogging Geologist Ola Ettu-Petroleum Engineer Russell Wardner-Sample Catcher ( t~ECEIVED JUN 1 -( 2003 Alaska o¡\ & Gar~ CoriS. CommilØQn Anch01'S'Jc 2 [J EPOCH ( MORNING REPORTS. ........... ............... ............... ............ .................. ........... .......... APPENDIX 1 FI NAL LOGS........................................................................................................... APPENDIX 2 ( DAILY MUD PROPERTIES...................................................................................................... 13 BIT RECORD... ............................... .......... .................. .......... ................. .............. ......... ...... ..... 14 LITHOLOGY AND COMMENTS .............................. ................ ............. ..................... ......... .......9 SURVEY I NFORMA TION.................................................................................... ..................... 12 RIG TIME DiSTRIBUTION.............................................. ........ ............ .......... ............................. 8 DAILY ACTIVITY SU MMARY ........................................ ............................................................ 6 FORMATION TOPS.................... ..................................................................... ...........................5 WELL SUMMARy....... ............ .............. ............... ............. ...... ..................... ......................... ..... 4 WE LL RE SUM E ......................................................................................................................... 3 Pioneer Natural Resources Natchiq #1 Exploration - Northwest Kuparuk North Slope Borough, Alaska ( . Pioneer Natural Resources Natchiq #1 TABLE OF CONTENTS II Pioneer Natural Resources Natchiq #1 WELL RESUME ( Company: Pioneer Natural Resources Well: Natchiq #1 Field: Kuparuk Region: North Slope, Alaska Location: Sec. 6, T13N, R8E, Umiat Meridian Coordinates: Y=6,034,820 X=476,790 1450' FSL & 500' Lat 70°30'22.57" Long 150°11 '23.58" Elevation: RKB 50.0' Ice Pad ± 19.5' County, State: North Slope Borough, Alaska API Index: 50-703-20436 Spud Date: 3/17/03 Total Depth: 7500'MD Contractor: Nordic Company Representatives: Garry Goerlich Rigffype: Nordic #3 ( Epoch Logging Unit: #15 Epoch Personnel: Andrew Buchanan Ralph Winkelman John Lundy, Russell Wardner Kent Dickens, Ola Ettu Company Geologists: Dick Owens Kevin Schmidt Casing Data: 13 3/8" @ 152' (Conductor) 7· 5/8" @3529' Hole size: 9 7/8" t03550' 6 %" to 7500' Mud Type: KCI Polymer spud to TO Logged Interval: 351' to 6943' MWD Company Baker Hughes Inteq Tools Run Electric Logging Co: Schlumberger ( ~ EPOCH 3 II Pioneer Natural Resources Natchiq #1 WELL SUMMARY ( Pioneer Natural Resources spudded the Natchiq #1 exploration well on March 17,2003 with Nordic Drilling, Inc. Rig #3. Natchiq #1 is located offshore west of Oliktok Point and south- southwest of Thetis Island on the North Slope of Alaska. The well was drilled as a directional hole with a 97/8" bit to surface casing at 3550' MD and 6 %" hole size to TD at 7500' MD. Clays washing out were a minor problem before surface casing was set. No other significant drilling problems were encountered. The primary objective of this well was the Kuparuk "C" sands. Secondary objectives were Middle Brookian, Torok, and Nuiqsut Sand. The Middle Srookian did not yield any more than a trace of sand in cuttings samples, however, C 1 through C5 were present. The Torok target yielded low gas, but only trace sand and abundant siltstone. Maximum gas was 20u at 5735' MD with the following chromotography in ppm: C1 444, C2 20, C3 9. The Kuparuk "C" was encountered at 6613' as a very thin layer with only trace amounts of sand and glauconite, but with abundant siltstone and claystone. No visible hydrocarbon shows were observed. The Nuiqsuit sand 7035' with only trace amounts of sand entrained in siltstone. No visible hydrocarbon shows were observed. ( Epoch Well Services provided RIGWA TCH 2000™ Drilling Monitoring services and DML TM Mudlogging Service. Hydrogen flame ionization (FIO) Total Gas and (FID) Gas Chromatograph detectors were employed to detect and analyze formation gases. Constant mud gas was generated by Texaco's patented Quantitative Gas Measurement (QGMTM) electrically driven gas trap located at the shale shaker header box and extracted continuously from the trap to the unit by sample pumps. The gas trap was frequently cleaned and positioned to obtain optimum sampling, and the gas system was tested and calibrated on a regular basis. Cuttings samples were collected at regular 30' intervals, beginning at 400'. ( UEPOCH 4 · Pioneer Natural Resources Natchiq #1 (' FORMATION TOPS Marker MD INC AZ TVD TVDSS X Y Saganavirktok 925.0 0.8 122.8 924.9 872.7 8.4E -8.4 Ugnu 1690.0 0.8 113.2 1689.8 1637.6 17.9E -12.7 West Sak 2170.0 1.1 124.0 2169.8 2117.6 25.2E -17.4 Colville Mdst 2850.0 1.6 120.2 2849.6 2797.4 38.6E -25.3 Mid Brookian 4404.0 37.0 284.8 4343.1 4290.9 14.3 -213.5 Torok 5735.0 42.8 284.3 5311.6 5259.4 243.6 -1095.6 THRZ 6295.0 38.1 281.9 5735.7 5683.5 327.2 -1451.4 Put Mrkr 6552.0 36.0 282.0 5941.0 5888.8 358.7 -1602.7 Kalubik 6580.0 35.8 282.1 5963.7 5911.5 362.2 -1618.7 Kuparuk "C" 6613.0 35.6 282.1 5990.5 5938.3 366.2 -1637.5 Miluveach 6620.0 35.5 282.2 5996.2 5944.0 367.0 -1641.5 Alpine 6690.0 35.0 282.4 6053.4 6001.2 375.6 -1681.0 Nuiqsut 7035.0 32.6 283.6 6339.9 6287.7 419.5 -1868.1 ( ( U EPOCH 5 · Pioneer Natural Resources Natchiq #1 ( DAILY ACTIVITY SUMMARY March 17,2003: Continue to rack casing. Thaw cuttings boxes. Install Baker encoder on Draw Works. Bring on spud mud. Build volume. Set torque. M/U drilling BHA. Tag bottom @ 81'. Spud drilling to 334'. Orient Baker. POOH. P/U BHA & MWD tools & load same. Pick up & run in with collars. Drill ahead 331' to 731.14'. March 18,2002 Continue drilling ahead, 731.14' to 2163' March 19,2003 Continue drilling to 2612'. Survey. Work on liner. Wash. Continue drilling to 2901'. Survey @2899'. Continue drilling to 3004. Continue drilling to 3192'. T.D. for Casing at 1930 hrs, 3519'. CBU BDTD monitor. POOH. Tight hole stands 233 & 22. Back ream hole to 3100'. Pump sweep at 3100 - 3200. Rotate and recip. Continue to back ream out of hole. ( 20 March 2003 Continue to back ream out of hole to 1641' BDTD. POOH to 331'. Service rig & blocks. RIH to 3018' Tag Kelly. Wash & ream to bottom. Circ & cond hole. Pump sweep. Rot @ 98K with pumps & recip pipe. Pump carbide. Continue circ & condo Rotate & pump 8 stds working tight spots. Pulled 5K next 16 stds. Stand back HWDP. Rig to LD BHA. Lay down BHA. Pull wear ring & throw latching. Clean stack W wash tool. R/U to run csg. Dummy run Hancock. Drain stack. Verify hanger lanes. PJSM & RIH W7 7/8 csg. Floats OK. March 21, 2003 Cont RIH W 7718 csg. Work csg to bottom. Tight hole from 3150'. M/U csg hanger & land at 0900. Circ & condo Pump carbide, back in 4606 strokes. R/U cmt head. PJSM on cmt job. Pump 10 bbls red dye. Pressure test 2500 psi. Cont W cmt program. Bumper plug at 1700', 2077 strokes. RID csg tools. Change bails. LD landing joint. Run pack off test to 5Kpsi. LD ram tool. M/U Ram combo tool. Latch port collars. Test 800 psi. Open & pump 15 bbls away. Nipple dn diverter tube/knife blind same. Open ram doors to verify ram size. Circ 13318 X 7718 annulus to keep warm. Nipple up cementers. March 22, 2003 Continue Nip up blind on diverter tube & R/U cementers. Open PC & pump 75 bbls cmt. Clean lower annulus W 20 bbls H20. Freeze protect lower annulus. Cont to Nip up BOPs. CIO pipe rams. Test BOPs. Change top pipe ram to 3 %. Test plug in sideways. Remove 16 % blind flange & retrieve test plug. Reinstall blind flange. Test blind. Outside kill. Test pipe ram 3" manifold. Test annulus to 2500 psi. Draw down test. Pull test plug. Set wear ring. LD test tools. Bring in stabs. Send out well head equipment. cIa jars in derrick. . P/U BHA & orient. Scrine. Load nukes, RIH 2 stds wt pipe. Shallow test MWD. BOTD. Continue RIH. Marck 23,2003 Continur RIH w DP singles. Tag 3416. LD singles. Fill pipe. R/U to test csg. Test csg to 4Kpsi, 30 min. RD test equipment. Finish cutting drill line. Drill float equipment. Tag rubber @ 3443'. Drill shoe & 10' new hole to 3559'. Circulate. Leak off test at 70 SPM to 7770 psi. LOT equivalent MW of 14.0 ppg. Continue drilling to 2629'. Slide 2629' to 3701'. Rotate 3701' to 3729'. Slide 3729' to 3825'. Rotate 3825' to 3877'. Slide 3877' to 3920'. Rotate 3920' to 3970'. Slide 3970' to 4019'. Rotate 4019' to 4066'. Slide 4066' to 4114'. Rotate 4114' to 4158'. Slide 4158' to 4210'. Rotate 4210' to 4261'. Slide 4261' to 4307'. Rotate 4207' to 4356'. Slide 4356' to 4405'. Rotate 4405' to 4439'. CBU 2500 strokes. March 24,2003 POOH. Tight on std 33, backream. Cont POOH. Std back DP, HWDP & collars. PLSM. Unload nuke sources. cIa bits. Download MWD. PJSM. Load nukes. P/U rest of BHA. Service rig & TD. Shallow test BL TD. P/U singles off rack. RIH W same. Fill pipe. Wash 170' to bottom. No fill. Tag bot @ 4439'. Slide 4439' to 4460'. Rotate 4460' to 4459'. Slide 4459' to 4550'. Rotate 4550' to 4693'. Slide 4693' to 4750'. Rotate 4750' to 5079'. Slide 5079' to 5133'. Rotate 5133' to 5245' ( [j EPOCH 6 f" ( ( ( II Pioneer Natural Resources Natchiq #1 March 25, 2003 Continue Roate to 5274'. Service TD @ 5274'. Cont rotate 5440'. Flow check. @ 5440'. Cont rotate to 6000'. Continue rotate to 6300. Circulate & pump sweep 39 bbls. POOH 20 stds smooth no tt spots. RIH 20 stds, no fill no tt spots. MUTD. Ream last std W pump. Cont drill to 6300. Pump 30 bbl sweep. Make conn. Cont drlg to 6520'. March 26, 2003 Continue drlg 6520' to 6535'. Service TD. Continue drlg to 7312'. Survey. Drill to 7500' T.D. . [J EPOCH 7 . Pioneer Natural Resources Natchiq #1 RIG TIME DISTRIBUTION Casing & Cmting O%Survey 1% U EPOCH ""-" ,-,,- Drill 54% -. Drill · Circulate DTrip o Rig Svc. · Survey II Casi ng & Cmti ng · Core DReam · Test · Logging o Repair II Other 8 ."-,,, · Pioneer Natural Resources Natchiq #1 ( LITHOLOGY AND COMMENTS 400' Clay Olive gray to dark greenish gray; very soft; thick; sticky; appears as amorphous lumps; dries to matte, earthy luster; moderately silty texture; non calcareous; scattered very fine sand grains; scattered to common organic material. 500' Sand/gravel Light gray to black, mod brown to dusky yellowish brown, becoming increasingly lighter colored with depth. Upper part is dominantly coarse to pebble size grains; angular to well rounded; poorly sorted; composed of 30% quartz and other siliceous minerals, 70% mafic and metamorphic minerals; trace clusters of microcrystalline pyrite; clay matrix. 700' Sand Light gray to light greenish gray overall with slight salt and pepper appearance; clasts range from upper fine lower to coarse upper, dominantly very fine to fine range; subangular to subround; mod sorted in the very to fine range; composed of 60% quartz, 40% metamorphic and volcanic lithics; - silty matrix. 800' Clay Light gray with slight olive hues; very soft; thick to fluffy; pasty; mod to very adhesive; mostly as soft amorphous lumps; dries to earthy luster; mod silty texture; non calcareous; scattered to common black carbonaceous material; locally silty, scattered very fine sand grains. 1100' Sand Light gray to greenish overall with salt and pepper appearance; clasts range from very fine lower to coarse upper, dominantly very fine to fine range; subangular to subround; mod sorted in the very to fine range; composed of 60% quartz, 40% metamorphic and volcanic lithics; silty, argillaceous matrix. ( 1300' Clay Light gray with occasional brown hues; very soft; thick, fluffy, occasionally runny; mod to very adhesive; mostly as soft amorphous lumps; dries to earthy luster; very silty texture; non calcareous; scattered to common black carbonaceous material; locally common very fine to medium sand grains. 1600' Sand Dominantly light gray overall; clasts range from very fine to coarse, dominantly fine grain; angular to rounded, dominantly subangular to subround; moderately sorted; composed of 70% quartz, 30% lithics; trace clusters of microxln pyrite; clay/silt matrix inferred. 1875' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous scattered to common black carbonaceous material; common very fine to medium sand grains. 2070' Sand Light gray overall; common salt and pepper appearance; very fine to coarse lower; dominantly medium lower with trace of very coarse conglomerate grains subangular to subrounded; moderate sphericity overall; poor to fair sorting polished occasionally frosted texture; present as unconsolidated loose grains; approximately 50-70% quartz, 30-50% various dark gray to black lithic clasts, trace wood in samples; probable clayey matrix in part; non calcareous; no sample fluorescence. 2400' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; common very fine to medium sand grains entrained in cuttings. ( [j EPOCH 9 II Pioneer Natural Resources Natchiq #1 ( 2850' Siltstone Light brownish gray to brownish gray overall with occasional olive gray secondary hues; mostly loose clasts with mushy to stiff consistency; trace well indurated cuttings with very tough and crunchy tenacity; blocky to earthy fracture; tabular to blocky cuttings habit; dull, earthy luster; silty to slightly gritty texture; massive bedding; no calcareous reaction on fresh surfaces. 3550' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; occasional very fine to medium sand grains entrained in cuttings. 4100' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; occasional very fine to fine sand grains entrained in cuttings. 4550' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; occasional very fine to fine sand grains entrained in cuttings. 5000' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; occasional very fine to fine sand grains entrained in cuttings. ( 5150' Sand Light tan to medium gray overall; common salt and pepper appearance with a variety of colors in larger grains; very fine to pebble sized grains; subangular to rounded, most pebbles well rounded moderate sphericity overall with individual clasts of high sphericity; poorly sorted; present as unconsolidated loose grains of quartz and a variety of chert, igneous and metamorphic lithics. 5220' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; occasional very fine to fine sand grains entrained in cuttings. 5770' Sand Medium gray overall; common salt and pepper appearance with a variety of colors in larger grains; very fine to pebble sized grains; subangular to rounded, most pebbles well rounded moderate sphericity overall with individual clasts of high sphericity; poorly sorted; present as unconsolidated loose grains of quartz and a variety of chert, igneous and metamorphic lithics. 6060' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to runny consistency; -no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; common fine to medium sand grains entrained in cuttings. ( 6185' Sand (j EPOCH 10 (I Pioneer Natural Resources Natchiq #1 ( Light gray overall; common salt and pepper appearance; very fine to very coarse; dominantly fine with continued trace of rounded pebble size grains subangular to subrounded; moderate sphericity overall; poor to fair sorting polished occasionally frosted texture; present as unconsolidated loose grains; approximately 50-70% quartz, 30- 50% various dark gray to black lithic clasts, trace massive pyrite in samples; probable clayey matrix in part; non calcareous; no sample fluorescence. 6310' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to pasty consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; common very fine to medium sand grains entrained in cuttings. 6700' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to pasty consistency; no noticeable fracture; amorphous to blocky cuttings habit; dull earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; common very fine to coarse sand grains entrained in cuttings. 7100' Clay Light brownish gray to brownish gray with olive gray secondary hues; very soft; mushy to pasty consistency; no noticeable fracture; amorphous cuttings habit; dull, earthy luster; clayey to gritty texture; non calcareous to trace very slight HCI reaction; scattered to common black carbonaceous material; common very fine to medium sand grains entrained in cuttings. ( 7200 Sand Light gray to light brownish gray overall with individual translucent to clear grains of quartz and opaque lithic clasts yielding a common salt and pepper appearance; very fine to very coarse grain size with a dominant medium lower fraction; angular to subrounded; moderate to low sphericity; poor to fair sorting; chipped to frosted texture; present as unconsolidated loose grains; approximately 50-70% quartz and 30-50% gray to black lithic clasts and chert; probable grain support with clay matrix in part; non to slightly calcareous in parts. 7500' Siltstone Light to medium gray, medium brownish gray; very soft to soft; mushy to crumbly; irregular and occasionally subblocky cuttings; matte luster with common sparkles; gritty, grainy texture; non calcareous; argillaceous, grades to and is interbedded with claystone; common; locally common very fine sand grains disseminated throughout. minerals, 40% metamorphic lithics and mafic lithics; trace clusters of microcrystalline pyrite; grains are loose in sample but probably have a clay/silt matrix in situ. ( ~ EPOCH 11 · Pioneer Natural Resources Natchiq #1 ( SURVEY INFORMATION Measured Depth TVD Inclination Azimuth Coordinates Dog Leg Feet Feet Degrees Degrees N(+) S(-) E(+) W(-) Degrees/100' 272.76 272.75 0.97 138.80 -1.73 +1.52 0.35 549.50 549.45 0.79 135.99 -4.86 +4.38 0.07 825.96 825.89 0.79 123.34 -7.28 +7.30 0.06 1103.66 1103.56 0.79 121.93 -9.35 + 10.53 0.01 1389.95 1389.82 0.79 111.73 -11.13 +14.04 0.05 1681.25 1681.09 0.79 112.79 -12.65 + 17.76 0.00 1970.52 1970.32 1.14 126.15 -15.13 + 21.93 0.14 2262.53 2262.28 1.14 122.98 -18.43 +26.73 0.02 2554.64 2554.32 1.32 119.12 -21.65 +32.11 0.07 2845.06 2844.65 1.58 119.82 -25.27 +38.50 0.09 3135.77 3135.26 1.49 141.26 -30.22 +44.36 0.20 3426.80 3426.14 2.20 175.37 -38.74 +47. 18 0.44 3544.19 3543.44 2.53 180.8 -43.57 +47.33 0.34 3641.53 3640.66 3.30 229.2 -47.55 +45.18 2.56 3738.87 3737.46 8.75 267.6 -49.70 +35.66 6.67 3835.87 3832.61 13.52 271.1 -49.81 +16.94 4.96 3932.93 3926.25 16.95 279.6 -47.24 -8.36 4.21 4028.87 4016.86 21.36 284.7 -40.4 7 -39.06 4.91 4124.48 4104.57 25.51 288.4 -29.56 -75.46 4.61 4223.32 4192.18 29.59 288.4 -15.16 -118.84 4.12 ( 4321.64 4275.90 33.64 288.1 +0.93 -167.80 4.13 4414.63 4351.58 37.39 284.30 +15.89 -219.68 4.66 4511.21 4426.81 40.28 284.36 +30.88 -278.35 2.99 4608.68 4500.69 41.13 283.22 +46.03 -340.07 1.16 4704.26 4572.46 41.55 284.35 +61.08 -401.39 0.89 4799.87 4642.71 43.87 285.18 + 77.62 -464.09 2.50 4897.82 4713.92 42.86 286.01 +95.69 -528.87 1.19 4996.96 4787.47 41.36 285. 17 +113.56 -592.89 1.61 5094.90 4860.40 42.93 284.63 +130.45 -656.40 1.65 5190.03 4927.33 47.06 283.75 +146.92 +721.61 4.38 5285.43 4992.90 46.12 283.79 +163.42 -788.92 0.99 5383.12 5060.79 45.83 283.97 +180.27 -857.11 0.32 5480.12 5128.64 45.40 285.53 +197.91 -924.14 1.61 5771.26 5338.27 42.48 284.07 +249.57 -1119.41 -0.50 6061.97 5555.69 40.70 283.17 +295.04 -1306.94 0.65 6354.23 5782.56 37.45 281.55 +334.56 -1486.82 1.17 6643.72 6015.57 35.34 282.21 +369.90 -1654.91 0.74 6935.32 6256.31 33.36 283.63 +406.64 -1815.27 0.73 7227.08 6503.07 31.12 283.62 +443.31 -1966.52 0.77 7416.84 6666.97 29.39 282.86 +465.23 -2059.58 0.94 7499.00 6738.56 29.39 282.86 +474.20 -2098.89 0.00 ( [j EPOCH 12 II Pioneer Natural Resources Natchiq #1 DAILY MUD PROPERTIES Date Depth Weight FV PV YP Gels APIFL Cake Solids OillWater Sand MBT PH ALK CI Ca 03/17/03 715 9.6 46 14 17 15/18/24 8.0 1.0/1.0 3.3 0.5/92.0 0.75 0.0 9.5 0.0 51000 40 03/18/03 2190 9.7 48 18 18 15/21/29 5.6 1.0/1.0 3.9 0.5/89.0 1.00 7.0 9.0 0.0 81000 20 03/19/03 3549 9.7 52 16 22 13/20/29 8.8 1.0/1.0 3.6 0.0/89.5 2.00 5.0 8.6 0.0 81000 80 03/20/03 Csg 03/21/03 3549 9.7 52 16 22 13/20/29 5.8 1.0/0.0 3.6 1.0/88.0 2.00 0.0 8.9 0.0 83000 80 03/22/03 3549 9.6 47 17 19 8/20/26 7.0 1.0/0.0 3.1 1.0/89.0 1.00 4.0 8.0 0.0 84000 40 03/23/03 4439 9.8 43 15 12 8/20/28 7.8 1.0/1.0 4.6 2.0/86.0 1.00 10.0 9.8 0.0 92000 40 03/24/03 5500 10.0 47 15 14 5/22/26 5.6 1.0/0.0 4.3 3.0/83 0.50 12.5 9.2 0.0 12000 180 0 03/25/03 6819 10.0 49 16 15 9/26/36 5.0 1.0/0.0 4.5 2.0/86.0 0.75 17.5 9.0 0.0 93000 120 03/26/03 7500 10.0 51 18 15 9/24/30 506 1.0/2.0 5.5 4.0/84.0 0.50 12.5 8.8 0.0 84000 120 U EPOCH 13 ',,-, '---' '~ · Pioneer Natural Resources Natchiq #1 BIT RECORD Bit Grading I 0 D L B G 0 F N U U 0 E A T E N T L C A U H J. E E L A R G E ~ R R T I E R ( C I N ~ R R H 0 G C 0 0 A N S H F W W R A l DEPTH S S R L BIT SIZE MAKE TYPE SIN JETS (FT) FTG HRS AVE AVE AVE FLOW L (INCH) (/32") (FT) (FT/HR) WOB RPM (Gallmin) E IN OUT [ 1 9.857 HC MXC1 501516 1X12,3X16 152 3550 3398 40.0 84.95 2 6.75 HC STX1 5000811 3X14 3550 4439 889 12.48 90 3 6.75 HYC DS69FNPV 202397 5X13 4439 7500 3061 39.24 78.01 U EPOCH 14 -',--~ '~ --- PIONEER NATURAL RESOURCES ( DAILY WELLSITE REPORT U EPOCH NATCHIQ#1 REPORT FOR Gary Gorlick DATE 3/27/03 TIM E 00:00:00 DEPTH 7500 YESTERDAY 6917 PRESENT OPERATION= POOH for E-Log run 24 Hour Footage 583 CASING INFORMATION 6.875- ID @ 3529' SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE SIN JETS IN OUT FOOTAGE HOURS TIB/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 145.5 @ 6947 10.5 @ 7065 69.3 67.3 ftIhr SURFACE TORQUE 0 @ 7500 0 @ 7500 0.0 amps WEIGHT ON BIT 55 @ 7212 6 @ 7211 0.2 0.0 Klbs ROTARY RPM 0 @ 7500 0 @ 7500 0.0 RPM PUMP PRESSURE 500 @ 6917 500 @ 7470 474.3 psi DRILLING MUD REPORT DEPTH: MW VIS P\I yp FL Gels Cl- FC SOL SD Oil MBl pH Ca+ eCI MWD SUMMARY ( INTERVAL TO TOOLS GAS SUMMARY(units) HIGH LOW AVERAGE DITCH GAS 16 @ 7213 2 @ 7327 7.2 TRIP GAS= CUTTING GAS 0 @ 7500 0 @ 7500 0.0 WIPER GAS:; 145 CHROMA TOGRAPHY(ppm) SURVEY= METHANE(C-1) 1406 @ 6927 103 @ 7327 484.2 CONNECTION GAS HIGH:; 15u ETHAN E(C-2) 48 @ 6917 1 @ 7359 14.3 AVG:; 8 PROPANE(C-3) 20 @ 6917 1 @ 7372 6.8 CURRENT 4 BUT AN E(c-4) 6 @ 7048 1 @ 7074 0.4 CURRENT BACKGROUND/AVG 3 PENTANE(C-5) 15 @ 7354 1 @ 7463 3.6 HYDROCARBONSHO~ INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY 10% Claystone, 10% Sandstone, 80% Siltstone. DAilY ACTIVITY SUMMARY Drill ahead to T>D> @ 7500', POOH for E-log runs. Epoch Personel On Board= 4 Daily Cost 2535.00 Report by: John Lundy ( ( ( ( FINAL LOGS