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Home My WebLink About205-056• ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Silfven, Laurie A (DEC) Sent: Wednesday, July 02, 2008 9:55 AM To: Maunder, Thomas E (DOA) Subject: RE: Kerr-McGee -Anadarko Two Bits and NW Milne wells Thank you, Tom! Laurie Silfven Ph: (907) 269-7540 From: Maunder, Thomas E (DOA) Sent: Wednesday, July 02, 2008 8:26 AM To: Silfven, Laurie A (DEC) Cc: Gould, Greg M (DEC); 'Bob Britch'; Foerster, Catherine P (DOA) Subject: RE: Kerr-McGee -Anadarko Two Bits and NW Milne wells ~~~~ os6 Laurie, et al, As requested, i have competed a file review of 8 Kerr-McGee operated exploration penetrations- that were drilled and plugged and abandoned nominally in 2Q 2004 and 2Q 2005. Total work accomplished was 6 grass-roots wells. and 2: redrills as listed below. Permit # Well Name 204-018 Nikaitchuq #1 204-038 Nikaitchuq #2 204-249 Tuvaag State #1' ~~~~ ~UL ~; ~ ~~~$ 205-025 Kigun #1 (redrill of Tuvaaq State #1') 204-260 Nikaitchuq #4 205-001 Nikaitchuq #3 205-039 Ataruq #2 05-056 Ataruq #2A (redrill of Ataruq. #2) Based an the fide review, it is my opinion that these wells were plugged and abandoned according to the requirements of 20 AAC 25.112 (plugging-all wells), 20 AAC 25.120 (well abandonment. marker, onshore well. Ataruq 2/2A), 20 AAC 25.170 (onshore location clearance, Ataruq 2/2A) and 20 AAC 25.172 (offshore location clearance, remaining wells). Please contact me if further information is needed. Tom Maunder, PE Sr. Petroleum Engineer AOGCC From: Silfven, Laurie A (DEC) Sent: Thursday, June 26, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Gould, Greg M (DEC); Bob Britch Subject: Kerr-McGee -Anadarko Two Bits and NW Milne wells Hi Tom, We received a request from Anadarko to rescind two Anadarko (formerly Kerr-McGee) exploration oil discharge prevention and contingency plans. The contingency plans are for Two Bits (Ataruq) and Northwest Milne Point (Nikaitchuq). In order to do this, we need AOGCC verification that the wells were properly abandoned. Bob Britch, consultant for Anadarko, let me know that an a-mail request to you would be sufficient. According to 7/2/2008 • Page 2 of 2 Bob, the drilling performed for the two plans essentially covered two exploration wells from the Two Bits (Ataruq) Prospect and six exploration wells from the NW Milne Point (Nikaitchuq) Prospect. At your convenience, please provide confirmation that all wells were properly plugged and abandoned. Thanks! Laurie Laurie Silfven Alaska Department of Environmental Conservation Exploration, Production & Refineries Section 555 Cordova Street Anchorage, AK 99501 Ph: (907) 269-7540 Fax: (907) 269-7687 E-mail: laurie. silfven@alaska.gov 7/2/2008 • • WAYBILL obn C Nalisnick LIBURTON I ate Shipped: _ August 8, 2005 6900 Arctc BLVD Time Shipped Anchorage, AK 99518 TO FROM ALASKA OIL & GAS Sperry Drilling Services Conservation Commission 6900 Arctic Blvd. .----------------------------------------- 333 W. 7th Ave. Ste. 100 Anchorage Alaska 99518 Anchorage, Alaska 99501 Special Insruction s/Comments Reason For Shipment ttn: Steve Davies Steve Carroll ITEM NO. QTY. PART # SERIAL # Descri tion 1 6 Boxes LG. WASIIED & DRYED 2 ATARUQ#2A 3 C3-51 4 C3-S2 5 C3-S3 6 C3-S4 7 C3-S5 8 C3-S6 9 10 11 l2 13 1~ $t Gc1S ~Oi}S. ~,OITIiC)15SI0(T 14 ~t1Ght1K8 e 15 16 17 18 19 20 SIGN w OTE: SPECIAL CONDTTIONS (indicate applicable) 1. Inner Packages in Item(s) comply with perscribed Specifications listed on Attached Shippers Declaration 2. Inner Packages in item(s) _ comply with perscribed Specifications for "Flammable Solids Dangerous Goods See Attached Shippers Declaration Inner Packages in item(s) _ comply with perscribed Specifications for" Radioactive Materials Dangerous Goods" See Attached Shippers Declaration ~ ~ APR ~ ~ 2008 ~- JVt~-L- DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 5,&¿cJ ' 7 Aø.A..dO)- Permit to Drill 2050560 Well Name/No. Ataruq 2A Operator KERR-MCGEE OIL & GAS CORP API No. 50-103-20508-01-00 MD 11242 ,.............. TVD 6134 ,- Completion Date 5/5/2005 " Completion Status P&A Current Status P&A UIC N ~-~--~- REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey ('!fP ~ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: e Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~ --~~--~--- Mud Log 5 Col 1,2,4,5 3319 11242 Open 6/1/2005 MC Combination Mud Log Mud Log 5 Col 1,2,4,5 3319 11242 Open 6/1/2005 Me Combination Mud Log ~g Mud Log M. 2 Col 1,2,4,5 3319 11242 Open 6/1/2005 Me Combination Mud Log I og Mud Log t-¡,b 2 Col 1,2,4,5 3319 11242 Open 6/1/2005 MC Combination Mud Log ~t6 C 13145 Report: Final Well R 0 0 Open 6/1/2005 End of Well Report D Asc Directional Survey 3280 11242 Open 9/26/2005 IIFR I Rpt Directional Survey 3280 11242 Open 9/26/2005 IIFR ./b'~ C 13358 Report: Final Well R 0 0 Open 10/20/2005 Directional Drilling & ~D MWD/LWD Services C 13146 Report: Final Well R 0 0 Open Second copy of Data Set # 1ED 13145 C 13147 Report: Final Well R 0 0 Open Third copy of Data Set # - 13145 ~g Induction/Resistivity f'\ð 2 Col 1-2-4-5 3319 11242 Open 11/2/2005 ROP DGR EWR I Log Induction/Resistivity iflr) 2 Col 1-2-4-5 3074 6135 Open 11/2/2005 ROP DGR EWR I~ Induction/Resistivity ""0 5 Col 1-2-4-5 3319 11242 Open 11/2/2005 QUAD Combo ROP DGR EWR CTN SLD BAT Ë Induction/Resistivity ""V,,> 5 Col 1-2-4-5 3074 6135 Open 11/2/2005 QUAD Combo ROP DGR EWR CTN SLD BAT og Induction/Resistivity ~O 5 Col 1-2-4-5 3319 11242 Open 11/2/2005 ROP DGR EWR GOM (Gulf of Mexico) Format pt.Ð I -t-: Pressure Col 1-2-4-5 3319 11242 Open 11/2/2005 ROP DGR EWR PWD I Temperature C Las 13363 Ind uction/Resistivity 0 11243 Open 11/2/2005 ROP DGR Res CTN Dens BAT LAS & DLlS Formats I L__~_ Plus Graphics _.~ DATA SUBMITTAL COMPLIANCE REPORT 5/31/2007 Permit to Drill 2050560 Well Name/No. Ataruq 2A Operator KERR-MCGEE OIL & GAS CORP API No. 50-103-20508-01-00 MD 11242 TVD 6134 Completion Date 5/5/2005 Completion Status P&A Current Status P&A UIC N Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMA\!ON Well Cored? Y / ~ Daily History Received? 'bN ~ e Chips Received? ~ Analysis '¥"1'1J Received? Formation Tops Comments: Compliance Reviewed By: /L Date: --I / J~ ~ 7 e . WELL LOG TRANSMITTAL To: Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian RE:MWD Formation Evaluation Logs - Kerr-McGee Ataruq#2A API #: 50-103-20508-01-00 . November 1,2005 AK - MW -0003663836 Ataruq#2A: 2" MD DGR I RES: 2" TVD DGR I RES: 5" MD Quad Combo: 5" TVD Quad Combo: 5" MD DGR I RES (GOM Format) Logs: 2" MD PWD wi Temperature Logs: CD ROM with Graphic Images & LWD-DLIS/LAS data of above logs: 2 Color Prints ; 2 Color Prints ./ 2 Color Prints 2 Color Prints --- 2 Color Prints ./ 2 Color PrintsV' 1 CD Rom i I y>~j, THE ATTACHED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Fax: (907) 273-3535 Date:;<lJtv~r 1L10JjJ Signed: Äð ~-- 0 fb p,'/-t . . 21-Sep-05 Alaska Oil & Gas Conservation Commission 333 W. ih Ave., Suite 100 Anchorage, AK 99510 DEFINITIVE Re: Distribution of Survey Data for Ataruq #2A Attn: Librarian: Enclosed are 1 survey hard copy(s) and a disk with the *.NO, *.PTT, and *.PDF files. Tie-on Window / Kickoff Projected Survey: 3,280.35 ' MD 3,320.00 I MD (if applicable) 11,242.00 I MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date~~~~- Signed Please call me at 273-354 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager ?--Ù)--ü S-G ¡:¡J , , !,~ 1 .="" , I ¡I , i.':=¡ ~ ~. ! J i~ ¡ J iJ . (rw ~ l~1 ',~ \.. ,"" I J J I\l '\ '~~\_~'\. jj .! L '\ ~ 1 '1 ¡ :1'.\ L~)U U=U ! ¡ "9 ~ CCÙ \'~~."\< ~:.~j FRANK H. MURKOWSKI, GOVERNOR i ~ ~ AItASIiA OIL AND GAS CONSERVATION COMJIISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 15,2005 Ms. Adele Hartrick, Regulatory Affairs Kerr McGee Oil and Gas Corporation 16666 Northchase Drive Houston, TX 77060 Re: Location Clearance, Atar'Uq 2A (prO 205-056) Dear Ms. Hartrick: The Alaska Oil and Gas Conservation Commission received photographs from Kerr McGee Oil and Gas Corporation ("'Kerr McGee") by electronic mail on September 13, 2005 documenting a location clearance inspection at the Ataruq 2A well site. The Commission was unable to participate in the site visit because of scheduling conflicts. Ataruq 2A was drilled during April 2005 from an ice pad; well abandonment operations were completed on May 5, 2005. The Commission witnessed plug and abandonment operations on the Ataruq 2A well to verify compliance with the regulations and approved permit requirements. The photographs show the location to be in compliance with 20 AAC 25.170, "Onshore Location Clearance". The Commission requires no further work on the subject well or location. However, Kerr McGee remains liable if any problems were to occur in the future with the Ataruq 2A well. Sincerely, ())¿' I - II,; .,./ 1 '0' , jV,' 1.., /, /, / , ù-l r ~v?-ltv--/7Y' John KfNorman /' Chairman cc: Steve McMains, AOGCC :-. It to IS 0 It 10 .. so i - - - Ion, k moo. ',�a, - i A !- L � ` '/M1• > .?I) r mil, 'y "�....:,, - �`�. •� qn i. � - -. ,/,� 1 ... 'r 3^" l •� - i •yls — M,,... ,• 4.r •y, 7R VIlk C, _.if a•+± .�� .'7F.`!F"" T Ile It IC ImII It al � � �" �l: r �` i• do %` } w G `4`' _ .• a :J • � - - .- - �� - �� - •��Ift -. :r' - 64 /' ` :.t .-� - T 1 i ��J ttI tI n7.4t ItlNp •'�ooL.r► ',r r' 'S• i 4 " a is 9." .� < _ � `e .�_ ".�"P fir. .+A.'1`- w.• 7 _ • • 41� llwI _ T 'il'. t r� Ahr- J:. R - - > y �1 ay�"� �• w ♦ �! •�. a A - " 'a=T1s .'-.�5'`��L .,krs "�- e. r ..,mac y I<. _4.. � -♦ S^ w. .. i R. ♦ '\.w �•'-i sal• .a ♦ � IV 4 Id If ldl- It 14 I I Al Ilk IN Of it low IN lb t r •1y, �.._� > .�• >: - _ •.•i '' ' aH a.. r .t '' . -" - •. - - �R, -Yly _� .- _ ._ _ _ ., _ _ •- _ •. YTS._ 1 � �.4`u/ • �. � � 4. R �T Fi' _'71ir". .. � - _ � - ..err.-. -. _., - �`f � _ .�yF- - ��-i�-.x•.t � �" - --%1' -ram •w = 1_ _ - _ _ - r _ got �`alil� jf'-4 -- - i. _} t . e - S .gyp _ _ ��♦1� — - _ . 7m Apr-*,.; l+� .�� I ' ,, ,+•fib/ 7 plow Ir low riy J_ x M�f/!,►tea, L. �I ; , �j„ _ y yr I'`JNei! 1 . r ✓. f.Y„ , ,.q -•�..;'(if/�: . Or kw ea fee Te . r ,- ' -7 +< . j Afoo.RT t ''' ... 4w _ ♦ _If W Air N J . t.� 'ted L')cations / Kerr McGee's 10,407's . . see the attached sheet with the corrected locations. I appreciate your patients with me/us. Skip Content-Description: Kerr McGee Corrections. doc McGee Corrections.doc Content-Type: application/msword Content-Encoding: base64 ¿; k ....I?tS(p (),..~~... C/ ~" / of 1 Â.~r- ~)'\ç 6/8/2005 9:07 AM Nikaitchuq #3 TPI = 7" Shoe Section 16, T N=6,054,679' . . at 9,281' MD / 8,893' TVD 14 N, R 9 E, 198' FSL & 2413' FWL E=520,597' BHL at 12,066' MD / 8,825' TVD Section 21, T 14 N, R 9 E, 630' FNL & 207' FWL N=6,053,858' E=523,261' Nikaitchuq #4 TPI = 7" Shoe Section 16, T N=6,056,657' at 4,851' MD / 4,145' TVD 14 N, R 9 E, 2128' FSL & 677' FWL E=518,850' BHL at 7,577' MD / 4,164' TVD Section 17, T 14 N, R 9 E, 1752' FNL & 768' FEL N=6,058,000' E=517,398' Ataruq 2A BHL at 11,242' MD / 6134' TVD Section 6, T 11 N, R 8 E, 1124' FNL & 1995' FEL N=5,974,177' E=475,274' _ STATE OF ALASKA .; ALAS~AND GAS CONSERVATION COMMIS MAY 2? 2005 WELL COMPLETION OR RECOMPLETION REPORT AND,LQG 1a. Well Status: OilU Gas U Plugged L:J Abandoned L:J 20AAC 25.105 Suspended U WAG U 1 b. Well Class: 20AAC 25.110 Development D Explora'tOl"y[ZJ Other Service D Stratigraphic Test D 5. Date Comp., Susp.,,ºr.~_ 12. Permit to Drill Number: Aband.: l¡dJ.;,i)" 205-056 6. Date Spudde.d: -~·;2.7.<-Ç 13. API Number:Sb ·/tJ:J-~ðrOa -(II 4,1"7-6;; 3900 C Street, Suite 744, Anchorage, AK 99503 ...4F18/65 , 50-6~1 ')-\.0 4a. Location of Well (Governmental Section): 7. Date TD Re~9~~.4!3. ':'>~.' . 14. Well Name and Number: Surface: 477' FNL & 1835' FEL, Sec 8, T11N, R8E, UM .. 4f24'Q6-..- .¿.Þ Ataruq # 2 A Top of Productive Horizon: N/A 8. KB Elevation (ft): ç .z.!; .:.,' 15. Field/Pool(s): k~_~ 105ft Total Depth: 7400' MD; 61i'OO~in Kup~k Interval ~ þ~ 9. Plug Back Depth(MD+TVD): Exploration IJ:J.L¡ .,2.3.ie'1=NL & ~'1'EL, Sec):"T11N, R8E, UM 3100 feetTVD for STH 4b. Locatibn of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): Surface: x- 480,716E y- 5,969,528N Zone- 4 ".1' 11,242'MD/6,134'TVD ,. TPI: x- N/A '11/ y- N/A 7'7 ~IM 11. Depth Where SSSV Set: Total Depth: x- 475,2~ y- 5,974,~N Zone- 4 n/a 18. Directional Survey: Yes 0 No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 1452' MD /1452' TVD Surface hole: MWD Directional/Cassandra Surveys; LWD Triple Combo. Production Hole: MWD Directional Cassandra Surveys; LWD Triple Combo. ; E-Line. Run #1 MDT; Mud Log: from Surface Casing Shoe to TMD. GINJ 0 WINJ D WDSPL D 2. Operator Name: No. of Completions Kerr McGee Oil & Gas Corporation 3. Address: --., 16. Property Designation: ADL 390502 17. Land Use Permit: 21. Logs Run: 22. CASING WT. PER GRADE FT. 13-3/8" 68# L-80 9-5/8" 40# L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE TOP BOTTOM TOP BOTTOM 33' MD 113' MD 33' TVD 113' TVD 33' MD 3,319' MD 33' TVD 3,051' TVD / ¿"of';XP ~;?-- mÞ _;:{f')7~ Wi.> ...... I -"~- ..-- .ð:Þ ..'_ AMOUNT -; 2,7,6< PULLED : CEMENTING RECORD Drive Pipe 12-1/4" n/a 520 sx Permafrost L (385 bbl) & 300 sx G (60 bbl) 0' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): none 24. SIZE n/a TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Date of Test: none Hours Tested: Production for Oil-Bbl: Test Period ... Calculated Oil-Bbl: 24-Hour Rate -. Gas-MCF: Water-Bbl: Choke Size: IGaS-Oil Ratio: Oil Gravity - API (corr): Flow Tubing Press. Casing Press: Gas-MCF: Water-Bbl: 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". t;:.-;:'::.::,:-::,:-··.o_ " '"'Vi..,.:........ ':q. ¡. ¡'i P.,:: '.Ii,: . ~~'~~~j= .1. \..n" 1'..\ , . --.&L"V ~-::.-.- RBDMS 8Ft .JUN 0 6 7005 Form 10-407 Revised 12/2003 . t r,nL{'~t\\If\' í \ r{ClVtJiTTN. I ...._ '; ;. I '\'J! t' ~¡: RSE NAME GEOLOGIC MARKERS MD TVD 29. FORMATION T Include and briefly summarize test result attach detailed supporting data as necess state "None". TS 'ntervals tested, and f no tests were conducted, 28. "NONE" Base Permafrost T / Colville T/ Middle Brookian T/Tam T /Moraine T/HRZ T /Kuparuk LCU T/Kuparuk A TOTAL DEPTH 1453' 3199' 7743' 10042' 10212' 10850' 11068' 11074' 11074' 11242' 1453' 3002' 4615' 5210' 5303' 5784' 5953' 5983' 5983' 6134' 30. Contact: S. Co ner, 339-6269 31. Title: Drilling Manager I Kerr McGee Oil & Gas Corp. Phone: 907 339-6370 Date: ~~?j6'5' 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for I njection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 . REV DESCRIPTION 1. BASIS OF HORIZONTAL AND VERTICAL LOCA TION IS DS2M MONUMENTS SET BY LOUNSBURY & ASSOCIATES. 2. COOROINA TES SHOWN ARE ALASKA STA TE PLANE ZONE 4, NAD 27. 3. GEOGRAPHIC COORDINATES ARE NAD 27. 4. ELEVA TIONS ARE BPMSL, DERIVED FROM GPS, REFERENCED TO GEOID 96. 5. ALL DISTANCES ARE TRUE. 6.ICE PAD IS ROTATED 42' EAST FROM NORTH. ATARUQ #2 LOCA TED WITHIN PROTRACTED SEC.8 T 11 N, R 8 E, UMIAT MERIDIAN. 477' F.N.L., 1835' F.E.L. LAT = 70' 19' 40.485" N LONG = 150' 09' 23.000" W ALASKA STATE PLANE ZONE 4 NAD 27 Y = 5,969,528.36 X = 480,716.30 GROUND ELEVATION = 69' TOP OF RIG PAD ELEV. = 72.2' TOP OF CONDo ELEV. = 73.0' . ! I ¡ ._~_ Ii) / .:~ co ./ //;-~ / / / / / / / - / / / J"'-/ i:;~// ~J ///// ,/"/-' . /r' /'// . / .. / // //- /.. //, / 5<.: REV DA TE BY ........., ·········....····1 ~(,;(:\~:) ¿),,, .......\._~._-,_.-\.~-_.._. " ';;j ! \ :z ./ VICINITY MAP " -". "- . . ......--.-" // ¡ "T83Q' "...." -'---... '-""'-, <l? / N + SCALE: 1" = 200' @KERR-MCGEE CORPOfIÅ T/ON CADD FILE NO. LK601D606 DRAWING NO: J/ , " " " " " ''''6~-)'"", " /~ . DESCRIPTION 1" = 2 MILES I ill 819 SURVEYOR'S CERTlFlCA TE I HEREBY CERTIFY THA T / AM PROPERL Y REG/STERED AND LICENSED TO PRACT/CE LAND SURVEYING /N THE STA TE OF ALASKA AND THA T TH/S PLA T REPRESENT. A SURVEY DONE BY ME OR UNDER MY D/RECT SUPER VIS/ON AND THA TALL D/MENSIONS AND OTHER DETA/LS ARE CORRECT AS OF MARCH 20, 2005. ~~""'" ~"~r: OF I\¿ '-_ .. ~\ 'C- ........... Affi.. . ^ r ~ .... ....; ì. ..... .. ( -." .... .... t .-J~ *~ ~ · ... ... Yf: ¡~! 49th \*~ " .....:........ .................. ..........~.....I " " ~..........................I...........I..I........ r.'Ã!~ :9::" ~ ~ \ BRIAN G. MANGOLD i f?" ~ / .. .. w ,...... J'", ". LS-8626 ..' ,is. . ,...... '" '. .' . '" . ~.'~ '. .' 0:>'-'. .. <')() *.... ..... . j:) .............. ~\). -_.1i'OF'E'SSIONI\L ~..... """'~~ ßl LOUNSBURY Be ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS 'q¡¡ ATARUQ #2t;¡,lJ EXPLORATORY WELL CÓNDUCTOR AS-BUlL T LOCATION PART: LK6010606 1 OF 1 REV: o - Surf _ 1000' 1452' - 2000' - 3000' - 4000' EZSV @ 3219' c ¡:: Rig RKB = 105 ft Pad Elev = 72 ft 13-3/8",68#, l-80 Conductor Set Surface Plug from 300' to Surface with 15.2 bbls of 15.8 cmt. (75 sxs) Ataruq #2A Actual P & A Below 9-5/8" casing at 3319' MD: · Build to .±.75.3° inclination · Turn left to .±.300.7° azimuth · Hold inclination & azimuth to .±.8896' MD. · Drop inclination to .±.42° · Hold Inclination & azimuth to TO 9-5/8",40#, l-80, BTC 3319' MD /3051' TVD lOT = 13.7 ppg EMW 42.5° .... .... .... 8-1/2" Hole Plug # 4 SET THRU EZSV SET AT 3219' WITH CEMENT From 3219' to 4955'with 125.5 bbls of 15.8 ppg Cement (610 sxs) .... .... .... .... 75.3° .... KCll Polymer Mud MW::: 9.8 to 11.3 ppg .... .... .... .... .... .... .... .... .... .... - 5000' -. -.-. -. -. -.-. -. - .-.-. _. -. -.- Tam at 5210' TVD -. -.-. -. -. -. -. 2nd Plug #3 From 9651' to 7714'with 88 bbls of 15.8 ppg Cement (425 sxs) Plug # 2 From 10163' to 9212' with 83.5 bbls of 13.2 ppg Cement (407 sxs) Plug #1 From 11113' to 10163' MD with 83.5 bbls 13.2 ppg Cement (407 sxs) .-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.- -.-.-.-.-.-.. ":':'-6'òÖÖ"'-'-'-'-'-'-'-'-'-'-Kuparuk C at 5953' TVD-'-'-' - 7000' 11242' MD /6134' TVD J. Mosley: 5/26/2005 . Halliburton Global Company: Kerr McGee Field: Ataruq Site: Ataruq Well: Ataruq #2 Wellpath: Ataruq #2A .- . r m,ld, Atarnq I Map System:US State Plane Coordinate System 1927 I Geo Datum: NAD27 (Clarke 1866) . Sys Datum: Mean Sea Level Date: 9/21/2005 Time: 16:42:46 Page: Co-ordinate(NE) Reference: Well: Ataruq #2, True North Vertical (TVD) Reference: Ataruq#2: 102.6 Section (VS) Reference: Well (O.00N,0.00E.31 0.36Azi) Survey Calculation Method: Minimum Curvature Db: 1 l I I I I Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 i I I i I I I I I J -¡ . = _-I Well: Ataruq #2 Slot Name: Well Position: +N/-S +E/-W Position Uncertainty: 0.00 ft 0.00 ft 0.00 ft Northing: 5969528.36 ft Easting: 480716.30 ft Latitude: Longitude: 70 19 40.485 N 150 9 23.000 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Ataruq #2 3280.35 ft Mean Sea Level 24.06 deg 80.70 deg Direction deg 310.36 Wellpath: Ataruq #2A 50103205080100 Current Datum: Ataruq#2: Magnetic Data: 4/16/2005 Field Strength: 57569 nT Vertical Section: Depth From (TVD) ft 30.42 Height 102.62 ft Survey Program for Definitive Wellpath Date: 5/2/2005 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft -- 146.15 3280.35 Ataruq #2 (146.15-7330.84) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3320.00 11212.07 Ataruq #2A (3320.00-11212.07) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey MD Inel Azim TVD Sys TVD N/S EIW MapN MapE Tool ft deg deg ft ft ft ft ft ft 30.42 0.00 0.00 30.42 -72.20 0.00 0.00 5969528.36 480716.30 TIE LINE 146.15 0.71 218.66 146.15 43.53 -0.56 -0.45 5969527.80 480715.85 MWD+IFR-AK-CAZ-SC 239.04 0.67 226.67 239.03 136.41 -1.38 -1.20 5969526.98 480715.09 MWD+IFR-AK-CAZ-SC 333.82 0.57 226.04 333.80 231.18 -2.09 -1.94 5969526.28 480714.35 MWD+IFR-AK-CAZ-SC 422.06 0.71 216.14 422.04 319.42 -2.84 -2.58 5969525.53 480713.71 MWD+IFR-AK-CAZ-SC 514.99 0.84 219.97 514.96 412.34 -3.82 -3.36 5969524.55 480712.93 MWD+IFR-AK-CAZ-SC 601.09 0.82 218.11 601.05 498.43 -4.79 -4.15 5969523.58 480712.14 MWD+IFR-AK-CAZ-SC 692.39 0.79 224.71 692.34 589.72 -5.75 -4.99 5969522.62 480711.29 MWD+IFR-AK-CAZ-SC 782.96 0.76 222.52 782.90 680.28 -6.64 -5.84 5969521.74 480710.45 MWD+IFR-AK-CAZ-SC 874.53 1.05 218.98 874.46 771.84 -7.74 -6.78 5969520.64 480709.51 MWD+IFR-AK-CAZ-SC 960.01 1.25 227.98 959.93 857.31 -8.97 -7.96 5969519.41 480708.32 MWD+IFR-AK-CAZ-SC 1052.85 1.31 230.94 1052.74 950.12 -10.32 -9.54 5969518.07 480706.74 MWD+IFR-AK-CAZ-SC 1148.98 1.59 226.51 1148.84 1046.22 -11 .93 -11.36 5969516.46 480704.91 MWD+IFR-AK-CAZ-SC 1242.78 1.79 225.50 1242.60 1139.98 -13.85 -13.35 5969514.54 480702.92 MWD+IFR-AK-CAZ-SC 1336.85 1.54 215.21 1336.63 1234.01 -15.91 -15.12 5969512.49 480701.14 MWD+IFR-AK-CAZ-SC 1432.68 2.07 230.01 1432.41 1329.79 -18.08 -17.19 5969510.33 480699.06 MWD+IFR-AK-CAZ-SC 1526.01 2.15 228.27 1525.68 1423.06 -20.33 -19.79 5969508.09 480696.46 MWD+IFR-AK-CAZ-SC 1623.58 2.30 228.58 1623.18 1520.56 -22.84 -22.62 5969505.58 480693.62 MWD+IFR-AK-CAZ-SC 1717.97 2.22 226.51 1717.49 1614.87 -25.35 -25.37 5969503.08 480690.87 MWD+IFR-AK-CAZ-SC 1812.84 1.97 338.01 1812.33 1709.71 -25.10 -27.32 5969503.33 480688.92 MWD+I FR-AK-CAZ-SC 1906.46 7.53 7.49 1905.60 1802.98 -17.52 -27.12 5969510.91 480689.14 MWD+IFR-AK-CAZ-SC 1999.86 11.39 7.85 1997.71 1895.09 -2.31 -25.06 5969526.11 480691.24 MWD+IFR-AK-CAZ-SC 2094.43 14.30 10.37 2089.91 1987.29 18.43 -21.68 5969546.84 480694.67 MWD+I FR-AK-CAZ-SC 2186.87 î7.37 12.54 2178.83 2076.21 43.14 -16.63 5969571.53 480699.78 MWD+IFR-AK-CAZ-SC 2281.99 2268.66 2166.04 5969601.95 480706.90 I 20.98 13.42 73.57 -9.59 MWD+tFR-AK-CAZ-SC I 2375.23 24.25 15.03 2354.72 2252.10 108.31 -0.75 5969636.66 480715.83 MWD+IFR-AK-CAZ-SC 2470.04 29.20 15.70 2439.37 2336.75 149.40 10.56 5969677.72 480727.25 MWD+IFR-AK-CAZ-SC 2565.28 33.53 14.18 2520.68 2418.06 197.29 23.30 5969725.57 480740.11 MWD+I FR-AK-CAZ-SC 2659.74 37.99 11.91 2597.31 2494.69 251.06 35.70 5969779.30 480752.64 MWD+IFR-AK-CAZ-SC .. .-. ..- ~)-'- Ò )b . Halliburton Global . - I Company: Kerr McGee Date: 9/21/2005 Time: 16:42:46 Page: 2 Field: Ataruq Co~ordinate(NE) Reference: Well: Ataruq #2, True North Site: Ataruq Vertical (TVD) Reference: Ataruq#2: 102.6 J Well: Ataruq #2 Section (VS) Reference: Well (0.00N,0.00E,31 0.36Azi) Well path: Ataruq #2A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S EIW MapN MapE Tool l ft deg deg ft ft ft ft ft ft d 2755.83 42.17 11.13 2670.82 2568.20 311 .67 48.03 5969839.88 480765.13 MWD+IFR-AK-CAZ-SC I I 2849.43 45.63 10.99 2738.25 2635.63 375.36 60.48 5969903.53 480777.74 MWD+IFR-AK-CAZ-SC I 2944.67 45.33 9.47 2805.03 2702.41 442.18 72.54 5969970.31 480789.97 MWD+IFR-AK-CAZ-SC I 3036.21 45.15 7.77 2869.49 2766.87 506.44 82.28 5970034.54 480799.88 MWD+IFR-AK-CAZ-SC 3132.07 44.16 7.62 2937.68 2835.06 573.21 91.31 5970101.28 480809.07 MWD+IFR-AK-CAZ-SC I 3227.17 42.34 6.67 3006.95 2904.33 637.86 99.42 5970165.90 480817.35 MWD+IFR-AK-CAZ-SC 3280.35 42.13 5.85 3046.32 2943.70 673.39 103.32 5970201.42 480821.34 MWD+!FR-AK-CAZ-SC 3320.00 42.14 5.70 3075.73 2973.11 699.86 105.99 5970227.87 480824.08 MWD+IFR-AK-CAZ-SC 3423.42 44.15 0.15 3151.21 3048.59 770.43 109.54 5970298.43 480827.80 MWD+IFR-AK-CAZ-SC 3517.97 44.33 355.00 3218.97 3116.35 836.29 106.74 5970364.29 480825.18 MWD+I FR-AK-CAZ-SC 3612.72 44.82 349.89 3286.48 3183.86 902.17 97.99 5970430.18 480816.60 MWD+I FR-AK-CAZ -SC 3705.48 44.91 345.18 3352.25 3249.63 966.02 83.87 5970494.07 480802.65 MWD+IFR-AK-CAZ-SC 3800.95 46.58 340.06 3418.89 3316.27 1031.22 63.42 5970559.31 480782.36 MWD+IFR-AK-CAZ-SC 3893.75 49.20 337.67 3481.12 3378.50 1095.41 38.58 5970623.56 480757.69 MWD+IFR-AK-CAZ-SC 3989.12 51.83 332.22 3541.78 3439.16 1162.01 7.37 5970690.23 480726.65 MWD+IFR-AK-CAZ-SC 4084.04 53.32 328.46 3599.48 3496.86 1227.48 -29.94 5970755.79 480689.52 MWD+IFR-AK-CAZ-SC 4179.15 55.98 324.58 3654.52 3551.90 1292.14 -72.75 5970820.55 480646.87 MWD+IFR-AK-CAZ-SC 4273.66 59.32 321.27 3705.09 3602.47 1355.79 -120.90 5970884.32 480598.89 MWD+IFR-AK-CAZ-SC 4368.10 61.12 317.43 3752.01 3649.39 1417.94 -174.30 5970946.60 480545.66 MWD+IFR-AK-CAZ-SC 4461.00 63.30 314.95 3795.32 3692.70 1477.23 -231.20 5971006.03 480488.92 MWD+IFR-AK-CAZ-SC 4556.14 65.97 310.73 3836.09 3733.47 1535.63 -294.24 5971064.59 480426.04 MWD+IFR-AK-CAZ-SC 4651.06 68.41 308.81 3872.89 3770.27 1591.59 -361.49 5971120.71 480358.94 MWD+IFR-AK-CAZ-SC 4745.29 70.70 304.85 3905.81 3803.19 1644.48 -432.15 5971173.78 480288.42 MWD+IFR-AK-CAZ-SC 4840.13 74.57 301.63 3934.12 3831.50 1694.06 -507.85 5971223.55 480212.86 MWD+IFR-AK-CAZ-SC 4932.35 76.30 301.06 3957.31 3854.69 1740.48 -584.07 5971270.17 480136.76 MWD+IFR-AK-CAZ-SC 4987.24 76.35 303.43 3970.29 3867.67 1768.94 -629.18 5971298.73 480091.73 MWD+IFR-AK-CAZ-SC 5080.05 76.14 303.14 3992.36 3889.74 1818.41 -704.54 5971348.39 480016.51 MWD+I FR-AK-CAZ -SC 5173.29 77.07 302.88 4013.96 3911.34 1867.82 -780.60 5971398.00 479940.58 MWD+IFR-AK-CAZ-SC 5267.34 77.34 302.46 4034.79 3932.17 1917.33 -857.80 5971447.70 479863.51 MWD+IFR-AK-CAZ-SC 5360.54 77.15 301.81 4055.36 3952.74 1965.68 -934.78 5971496.24 479786.67 MWD+IFR-AK-CAZ-SC 5456.84 76.59 300.98 4077.24 3974.62 2014.54 -1014.83 5971545.30 479706.75 MWD+IFR-AK-CAZ-SC 5549.58 76.26 301.24 4099.01 3996.39 2061.11 -1092.01 5971592.07 479629.70 MWD+IFR-AK-CAZ-SC 5647.31 75.94 300.54 4122.48 4019.86 2109.82 -1173.42 5971640.98 479548.42 MWD+IFR-AK-CAZ-SC 5739.02 75.47 300.74 4145.13 4042.51 2155.11 -1249.88 5971686.46 479472.08 MWD+I FR-AK-CAZ-SC 5832.00 76.92 301.15 4167.32 4064.70 2201.54 -1327.32 5971733.09 479394.77 MWD+I FR-AK-CAZ-SC 5926.41 76.87 301.37 4188.72 4086.10 2249.26 -1405.93 5971781.00 479316.30 MWD+IFR-AK-CAZ-SC 6021.67 76.45 299.89 4210.70 4108.08 2296.48 -1485.68 5971828.42 479236.68 MWD+I FR-AK-CAZ-SC 6116.76 75.96 299.01 4233.38 4130.76 2341.88 -1566.09 5971874.03 479156.39 MWD+IFR-AK-CAZ-SC 6209.62 76.51 298.54 4255.47 4152.85 2385.30 -1645.15 5971917.64 479077.45 MWD+I FR-AK-CAZ-SC I 6301.47 77.01 298.67 4276.51 4173.89 2428.11 -1723.64 5971960.65 478999.07 MWD+I FR-AK-CAZ-SC I 6396.84 76.45 298.42 4298.40 4195.78 2472.46 -1805.18 5972005.21 478917.66 MWD+I FR-AK-CAZ -SC 6490.52 76.45 298.87 4320.35 4217.73 2516.12 -1885.11 5972049.07 478837.85 MWD+I FR-AK-CAZ-SC 6582.82 76.68 300.06 4341.79 4239.17 2560.28 -1963.27 5972093.42 478759.81 MWD+I FR-AK-CAZ-SC 6676.63 75.96 300.39 4363.98 4261.36 2606.16 -2042.03 5972139.50 478681.18 MWD+I FR-AK-CAZ-SC 6771.49 75.41 300.67 4387.43 4284.81 2652.85 -2121.20 5972186.39 478602.14 MWD+IFR-AK-CAZ-SC 6867.59 76.24 300.32 4410.97 4308.35 2700.13 -2201.48 5972233.87 478521.98 MWD+IFR-AK-CAZ-SC 6963.02 76.58 301.22 4433.39 4330.77 2747.59 -2281.18 5972281.53 478442.41 MWD+I FR-AK-CAZ-SC 7057.67 76.27 301.03 4455.61 4352.99 2795.15 -2359.94 5972329.28 478363.78 MWD+! FR-AK-CAZ-SC 7153.03 77.81 299.52 4476.99 4374.37 2841.99 -2440.20 5972376.33 478283.66 MWD+IFR-AK-CAZ-SC 7247.33 77.22 299.93 4497.38 4394.76 2887.64 -2520.15 5972422.18 478203.83 MWD+IFR-AK-CAZ-SC 7341.78 75.62 301.20 4519.56 4416.94 2934.32 -2599.20 5972469.06 478124.91 MWD+IFR-AK-CAZ-SC I I 7435.08 75.81 301 .40 4542.58 4439.96 2981.30 -2676.46 5972516.23 478047.78 MWD+IFR-AK-CAZ-SC 1 "_.~~----~ -~~_.- --_.-- -------~._-- . Halliburton Global . - _w_ I Company: Kerr McGee Date: 9/21/2005 Time: 16:42:46 Page: 3 Field: Ataruq Co"ordinate(NE) Reference: Well: Ataruq #2, True North Site: Ataruq Vertical (TVD) Reference: Ataruq#2: 102.6 Well: Ataruq #2 Section (VS) Reference: Well (O.00N,0.00E,31 0.36Azi) Wellpath: Ataruq #2A Survey Calculation Method: Minimum·Curvature Db: Oracle Survey -- - MD Incl Azim TVD Sys TVD N/S EIW MapN MapE Tool ! ft deg deg ft ft ft ft ft ft i -- MWD+IFR-AK-CAZ-SC l 7529.15 77.08 302.23 4564.63 4462.01 3029.51 -2754.16 5972564.63 477970.21 7622.54 76.15 301.95 4586.25 4483.63 3077.77 -2831.13 5972613.09 477893.37 MWD+IFR-AK-CAZ-SC I 7717.01 75.82 301.95 4609.12 4506.50 3126.28 -2908.91 5972661.79 477815.73 MWD+IFR-AK-CAZ-SC I 7809.39 76.13 302.72 4631.51 4528.89 3174.21 -2984.63 5972709.92 477740.13 MWD+IFR-AK-CAZ-SC i 7904.35 76.44 302.36 4654.03 4551.41 3223.84 -3062.40 5972759.73 477662.50 MWD+IFR-AK-CAZ-SC I 7997.65 76.41 302.75 4675.93 4573.31 3272.64 -3138.85 5972808.73 477586.19 MWD+IFR-AK-CAZ-SC I 8093.60 75.75 302.47 4699.01 4596.39 3322.83 -3217.30 5972859.12 477507.87 MWD+IFR-AK-CAZ-SC 8187.41 75.45 302.63 4722.34 4619.72 3371.72 -3293.89 5972908.19 477431.42 MWD+IFR-AK-CAZ-SC 8283.45 75.08 301.59 4746.77 4644.15 3421.09 -3372.56 5972957.76 477352.88 MWD+I FR-AK-CAZ-SC 8378.52 76.17 300.17 4770.37 4667.75 3468.35 -3451.60 5973005.22 477273.97 MWD+IFR-AK-CAZ-SC 8474.23 75.86 300.32 4793.50 4690.88 3515.13 -3531.83 5973052.20 477193.87 MWD+IFR-AK-CAZ-SC 8569.14 76.61 299.40 4816.08 4713.46 3561.02 -3611.77 5973098.30 477114.05 MWD+I FR-AK-CAZ-SC 8663.75 77.97 299.05 4836.90 4734.28 3606.08 -3692.31 5973143.56 477033.63 MWD+IFR-AK-CAZ-SC 8758.49 77.33 299.18 4857.16 4754.54 3651.11 -3773.17 5973188.79 476952.90 MWD+IFR-AK-CAZ-SC 8851.55 76.90 298.38 4877.91 4775.29 3694.79 -3852.68 5973232.67 476873.51 MWD+IFR-AK-CAZ-SC 8946.35 76.81 298.96 4899.4 7 4796.85 3739.08 -3933.67 5973277 .16 476792.64 MWD+IFR-AK-CAZ-SC 9039.83 77.32 299.43 4920.40 4817.78 3783.52 -4013.21 5973321.80 476713.23 MWD+I FR-AK-CAZ-SC 9135.33 77.98 299.86 4940.82 4838.20 3829.66 -4094.29 5973368.15 476632.28 MWD+IFR-AK-CAZ-SC 9225.16 76.76 300.62 4960.47 4857.85 3873.80 -4170.01 5973412.48 476556.67 MWD+IFR-AK-CAZ-SC 9320.29 75.93 300.85 4982.92 4880.30 3921.05 -4249.47 5973459.93 476477.34 MWD+IFR-AK-CAZ-SC 9413.91 75.36 301.80 5006.13 4903.51 3968.20 -4326.94 5973507.27 476400.00 MWD+I FR-AK-CAZ-SC 9508.78 75.83 302.44 5029.74 4927.12 4017.05 -4404.77 5973556.32 476322.31 MWD+IFR-AK-CAZ-SC 9603.90 75.98 302.84 5052.90 4950.28 4066.81 -4482.45 5973606.28 476244.76 MWD+IFR-AK-CAZ-SC 9699.48 74.17 302.78 5077.52 4974.90 4116.86 -4560.07 5973656.51 476167.28 MWD+I FR-AK-CAZ-SC 9794.22 71.57 302.66 5105.42 5002.80 4165.79 -4636.24 5973705.64 41t091.25 MWD+IFR-AK-CAZ-SC 9889.02 67.81 301.07 5138.32 5035.70 4212.73 -4711.72 5973752.76 476015.89 MWD+IFR-AK-CAZ-SC 9982.43 63.46 299.39 5176.85 5074.23 4255.57 -4785.21 5973795.80 475942.52 MWD+IFR-AK-CAZ-SC 10075.49 59.50 299.28 5221.27 5118.65 4295.63 -4856.47 5973836.03 475871.37 MWD+IFR-AK-CAZ-SC 10169.72 55.73 299.13 5271.73 5169.11 4334.45 -4925.92 5973875.02 475802.03 MWD+IFR-AK-CAZ-SC 10265.71 51.54 298.70 5328.64 5226.02 4371.82 -4993.56 5973912.56 475734.49 MWD+IFR-AK-CAZ-SC 10360.17 47.70 298.16 5389.82 5287.20 4406.08 -5056.82 5973946.98 475671.32 MWD+IFR-AK-CAZ-SC 10455.69 43.02 298.67 5456.92 5354.30 4438.40 -5116.59 5973979.46 475611.64 MWD+IFR-AK-CAZ-SC 10551.30 38.91 299.65 5529.10 5426.48 4468.92 -5171.32 5974010.11 475556.99 MWD+IFR-AK-CAZ-SC 10646.54 34.71 301.23 5605.34 5502.72 4497.79 -5220.53 5974039.10 475507.87 MWD+IFR-AK-CAZ-SC 10740.50 30.22 300.64 5684.59 5581.97 4523.72 -5263.77 5974065.14 475464.70 MWD+IFR-AK-CAZ-SC 10835.71 27.88 300.27 5767.82 5665.20 4547.16 -5303.62 5974088.68 475424.92 MWD+IFR-AK-CAZ-SC 10932.04 27.17 298.64 5853.25 5750.63 4569.05 -5342.37 5974110.67 475386.22 MWD+I FR-AK-CAZ -SC 11026.12 26.92 299.30 5937.04 5834.42 4589.77 -5379.80 5974131 .48 475348.85 MWD+IFR-AK-CAZ-SC 11120.86 24.00 301.79 6022.57 5919.95 4610.42 -5414.88 5974152.22 475313.82 MWD+IFR-AK-CAZ-SC 11212.07 21.68 301.86 6106.63 6004.01 4629.09 -5444.96 5974170.97 475283.79 MWD+IFR-AK-CAZ-SC I 11242.00 21.68 301.86 6134.44 6031.82 4634.92 -5454.36 5974176.83 475274.42 PROJECTED tO~J .. . @SJ""" ,...". OPERATIONS SUMMARY: Ataruq #2A APD No.: 205-056 4/17/05 4/18/05 4/19/05 4/20/05 4/21/05 4/22/05 4/23/05 4/24/05 4/25/05 4/26/05 3.560' MD / 3.248' TVD Spotted balanced cement plug 3600' to 3100' MD. POOH 6 stands & CBU.x 2. POOH. Rack back the 3-112" stinger. PIU directional drilling BHA. RIH. Tagged cement at 3100' MD. Drilled cement and new hole to 3360' MD. CBU. - FIT to 13.5 ppg EMW. Drilled ahead building and tuñllng as programmed. 4.975' MD / 3.967' TVD Drilled ahead with 8-112" bit and directional drilling BHA to 4975' MD / 3967' TVD. Finished the "build & turn" section. CBU x 3. POOH for new BHA. 6.331' MD /4.283' TVD UD directional BHA. PIU rotary steer-able BHA with quad-combo & PWD. RIH. Drill ahead to 6331' MD / 4283' TVD. MW = 9.3 ppg 7.967' MD / 4.668' TVD Drilled ahead with 8-1/2" bit and rotary steer-able BHA to 7967' MD / 4668' TVD. Increased the MW = 9.5 ppg while drilling. ECD = 11.0 ppg EMW. The 12 stand Start wiper trip was slick. 9.585' MD / 5.049' TVD Drilled ahead with 8-112" bit and rotary steer-able BHA to 9585' MD / 5049' TVD. Will increase the MW to ±11.3 ppg while drilling through the HRZ & Kuparuk. Expect to TD Saturday am. 11.115' MD / 6.016' TVD Drilled ahead with 8-112" bit and rotary steer-able BHA to 11115' MD / 6016' TVD. Increase the MW to 11.3 ppg while drilling through the HRZ & Kuparuk. 11.242' MD / 6.134' TVD Drilled ahead with 8-1/2" bit and directional drilling BHA to 11242' MD / 6134' TVD. TD'd in the Miluveach CBU. 12-atand wiper trip. MAD pass 10000' to TD. CBU x 3. Pull / pump / backream out to 6700' MD this am. 11.242' MD / 6.134' TVD Pumped / backreamed to the shoe. CBU. POOH & UD ghost reamer. RIH. Reamed several tite spots. Elected to POOH & UD the LWD's. CBU. POOH. 11.242' MD / 6.134' TVD Downloaded LWD's. Tested BOPE. Repaired Top Drive. RllI with 8-1/2" bit and clean out BHA. 11.242' MD / 6.134' TVD Washed and reamed to 11118' MD. CBU. POOH for E-Line. R/U Schlumberger. RllI with MDT tools on 5" DP. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 .. . @SJIfEM.IIt:t& c.wA". 4/27/05 4/28/05 4/29/05 4/30/05 5/01105 5/02/05 5/03/05 5/04105 5/05/05 11.242' MD / 6.134' TVD Continued RIH with MDT tools on 5" DP. 11.242' MD / 6.134' TVD Finished running MDT's. CBU. POOH. RID Schlumberger. RIH with 3-1/2" stinger on 5" DP. Broke circulation. Lost partial returns. 11.242' MD / 6.134' TVD POOH to 8300'. Established circulation. RIH to TMD. Circulated & R/U Halliburton. Spot cement plug #1 (83.5 bbl). POOH 10 stands + sgl. CBU. Spot cement plug #2 (83.5 bbl). POOH 10 stands + sgl. CBU. Spot cement plug #3 (83.5 bbl). POOH 10 stands + sgl. CBU. Spot cement plug #4 (83.5 bbl). POOH 15 stands. CBU. DP plugged. POOH. 11.242' MD / 6.134' TVD / PBTD = 9.152' MD POOH. UD plugged 3-112" stinger. RIH with 8-112" bit to tag plug #4. Did not find plug #4 or plug #3. TOC at 9152' MD. POOH. 11.242' MD / 6.134' TVD / PBTD = 8.667' MD RIH with OEDP to 9152' MD. Circulated. Spot cement plug #5 (72 bbl). POOH 9 stands. CBU. RIH to 8325' MD. Spot cement plug #6 (72 bbl). POOH 15 stands. CBU. POOH to the shoe. CBU. RIH. Tagged TOC at 8667' MD. 11.242' MD / 6.134' TVD / PBTD = 3.166' MD Hole packing off. C & C mud. Spot cement plug #7 (88 bbl). Estimated TOC at 7714' MD. POOH 15 stands. CBU. POOH. RIH with 9-5/8" EZSV. Set EZSV at 3219' MD. Test to 2500 psi. Down-squeezed the shoe with 125.5 bbl cement. Dumped 4 bbl of cement above the EZSV. POOH 5 stands. CBU. LDDP. 11.242' MD / 6.134' TVD / PBTD = 110' RKB LDDP. Re-tested 9-5/8" casing & EZSV to 2500 psi. Cut & re-cut 9-5/8" casing at 90' RKB. UD cut off joint. RIH to 300' RKB. Spot cement plug (15.2 bbl). POOH. Flushed the BOP stack. N/D BOPE. 11.242' MD / 6.134' TVD / PBTD = 45' RKB N/D BOPE and wellhead. Set 13-3/8" EZSV at 52' RKB. Down-squeezed 4 bbl cement: bridged off. Pulled out of EZSV. Filled the casing with cement to 4' below tundra level. Cleaned out the cellar. Released 27E at midnight. 11.242' MD / 6.134' TVD Welded on maker plate as per AOGCC regulations. RID & MlO 27E. Cleaned location. P & A. Final report. 3900 C Street Suite 702, Rm 744 Anchorage, AI( 99503 (907)-339-6370 it . . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P. I. Supervisor 17 r I .'- DATE: t-.~11 '? Iî o~ May 9, 2005 THRU: FROM: Lou Grimaldi, Petroleum Inspector SUBJECT: P&A Kerr McGee, Ataruq #2A PTD #205-056 Explorato ry-Confidentia I Tuesday. May 3. 2005: I witnessed the verification of abandonment plug by Pressure test on Kerr McGee's exploratory well "Ataruq #2A". The rig was pulling out of the hole after setting a C.I.B. and pumping cement. The rig broke circulation and pressure tested the plug to 2500 psi. A 15 minute pressure test was held with no loss of pressure. I left location at this time. Friday. May 6. 2005: I returned to this location to witness the cutoff of surface equipment and verification of surface cement plug. The wellhead was cutoff with good cement showing inside the 13 3/8 conductor. The plate was welded on and the hole was back filled with clean gravel and concrete that showed no staining. I did observe a significant ice lens under the tundra line to the side of the well. This appeared to be natural and should pose no problem. SUMMARY: I witnessed a good pressure test of the bottom hole plug on Kerr Mcgee's exploratory well "Ataruq #2A" followed by the verification of cement to surface and marker plate attachment. Attachments: Ataruq 2A cutoff casing.jpg Ataruq 2A plate closeup.jpg Ataruq 2A with cap.jpg Ataruq 2A Ice lens.jpg Ataruq 2A being back-filled.jpg NON-CONFIDENTIAL -' " Ataruq #2A (Kerr McGee) Surface Abandonment Inspection Photos from Lou Grimaldi May 3 and 6, 2005 I Casing Cut Marker Plate 2005-0506_P&A_ Surface_Ataruq2A_lg.doc 2 , 2005-0506_P&A_ Surface _Ataruq2A_lg.doc Marker Plate installed Ice lens Backfilling after cut and plate installation 3 . . (~O~- - 050 FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Stuart Boggan Kerr McGee Oil and Gas Corporation 3900 C Street Ste 744 Anchorage AK 99503 Re: Ataruq #2A 305-097 Dear Mr. Boggan: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd ay following the date of this letter, or the next working day if the 23rd day falls on 0 iday or weekend. A person may not appeal a Commission decision to erior ou unless rehearing has been requested. _/. . )}'in« ¡.1 / t^Pc j DATED this -nay of M1fÍl, 2005 Encl. . ~ KERR-Ml:6EE CDRPORATlIJN . April 22nd, 2005 RECEIVED APR 2 2 2005 Alaska Oil & Gas Cons. Commission Anchorage Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Ataruq #2A APD# 205-056 Kerr McGee Oil & Gas Corporation Application for Sundry Approval (10-403) Plug and Abandon (prior to sidetrack) Attached for your review and expedited approval is our Application for Sundry Approval to plug and abandon the open hole portion of the Ataruq #2A exploration well located approximately four (4) miles north-northwest from KRU's 2M Pad. This original application is submitted along with one (1) copy. The package includes: L WD log of the open hole section, detailed plugging procedure, directional surveys and a wellbore diagram. It is our intention to plug and abandoned the well completely in accordance with AOGCC regulations and the applicable C-Plan. It is likely that we will TD the well Saturday morning and be ready to P & A before the start of business Monday morning, 4/25/2005, therefore we asked for expedited review and verbal approval of this application. If you have any questions or concerns about the APD or the drilling plan, please call me at 339-6269 and I will do my best to address your questions or concerns. Sincerely, i;i?ynr-- ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK. 99503 (907)-339-6370 ()RIGlr~AL Abandon .J Alter casing 0 Change approved program 0 2. Operator Name: Kerr McGee Oil & Gas Corporation 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 7. KB Elevation (ft): 12. Attachments: Description Summary of Proposal Detailed Operations Program [] BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correc to t Printed Name Stuart Boggan 1. Type of Request: 8. Property Designation: 11. Total Depth MD (ft): 11,318' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: . .. STATE OF ALASKA A~ Oil AND GAS CONSERVATION COM liON APPLICATION FOR SUNDRY APP VAL 20 MC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: ~ <::>~ ~ ,S' ~ AI ;f;)- Suspend Repair well 0 Pull Tubing 0 Other .J Development Stratigraphic o o 6'j{pNumber:s-a_10 - OS'ØB-ol R 2~1 t'~ rasks Oil & Gas Cons Comm- . . Ataruq # A . - - I$Slon Exploratory [2] o Service 9. Well Name and Number: 105 ft 10. Field/Pools(s): ADL: 390502 Exploration Total Depth TVD (ft): 6,200' Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): N/A Collapse Plugs (measured): N/A Size TVD 13-3/8" 113ft 113ft 9-5/8" 3319 ft 3051 ft Burst 80 ft 3286 ft N/A N/A N/A Perforation Depth TVD (ft): N/A 5750 psi 3090 psi Tubing Size: Tubing Grade: Tubing MD (ft): N/A N/A N/A N/A N/A 13. Well Class after proposed work: Exploratory [] Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged [;] Abandoned [] WAG 0 GINJ 0 WINJ 0 WDSPL 0 Phone my knowledge. Contact Title Drilling Manager 907-339-6370 Date COMMISSION USE ONLY 22 April, 2005 Skip Coyner: 907-339-6269 Signature Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 2;05-09'7 PI"" 'ot",òty þi. BOP T", 0 M",,,o,,,,,ote':W T", 0 '-""'00 C'"mo," ~ (' Other: Ccf'-.\oc...\-- :r ('~re.~ \~ \\.) M-t'eS- ~ ~~\,()t-.'> Q¡~ ~ \C9.~~~c/ Approv RBDMS BFL MAYO 3 2005 COMMISSIONER APPROVED BY THE COMMISSION Form 10-403 Revised 11/2004 Submit in Duplicate . . E CORPORA RECEIVED APR 22 2005 A ta ru q #2A At',k, Oil &AGahs Cons. Comrní3:;ìon nc Drage . Abandonment Program I AFE No.: 140146-01 I Plug and Abandon 1 AOGCC Permit No.: 205-056 I Drilling Rig: Nabors 27E Surface Location: 477' FNL & 1334.6' FEL of Section 8, T11 N, R8E UM X = 480,716' Y = 5,969,528' Bottom Hole Location: 1100' FNL & 2055' FEL of Section 6, T11 N, R8E UM X = 475,228' Y = 5,974,199' 1 Operating Rig days: 12.5 1 Pad Elev: 172 ft 1 I DF: 1105 ft I I Estimated P & A Date: 14/24/05 1 I TMD: 111,318' 1 1 TVD: 16,200' I After drilling and evaluating the well, it is planned to plug and abandon the Ataruq #2A in accordance with AOGCC regulations. Casing - Actual: Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD I TVD MD I TVD 24" 13-5/8" 68# L-80 BTC 80' 33' 113' / 113' 12-1/4" 9-5/8" 40# L-80 BTC 3,286' 33' 3,319' / 3,051' S Coyner 1 4/22/2005 . . Formation Markers: Formation Tops MD TVD Pressure (psi) EMW B/Permafrost 1,453' 1 ,453' T/Colville 3,199' 3,002' 1,335 _..8 T/Middle Brookian 7,743' 4,615' 2,052 . 'L " r.: " lJ T/Tarn 10,042' 5,210' 2,273 AD nðn ,'''''' T/Moraine 10,212 5,303' 2,358 .-11 " ¿;¡;.¡ , ~, T/HRZ 10,850' 5,784' 3~nìl¿ Po"... I"nl T/Kuparuk C 11,068' 5.953' .13 t 3,450 LCU 11,074' 5,983' T/Kuparuk A 11,074' 5,983' 3,460 11.12 Proposed TD 11,318' 6,200' ABANDONMENT PROCEDURE 1. After geologic evaluations are complete, RIH with .!,1200' of 3-1/2" DP and cement sub. RIH to TMD. Circulate bottoms up while cooling and thinning the mud down. R/U cement unit and test lines to 3000 psi. 2. The P & A procedure must be approved by AOGCC before plugging operations commence. Spot four (4) 950 ft, bottom-founded, balanced cement plugs starting at TD. Each plug will be placed directly on top of the preceding plug: Plug #1 11,300' - 10,350' ODen Hole Pluas: Plug #2 10,350' - 9,400' 407 sx, 83.4 bbl, 15.8 ppg Plug #3 9,400' - 8,450' Premium "G" Cement, with Plug #4 8,450' - 7,500' 25% excess over open hole Spot balanced Plua #1: 11300' to 10350' MD. Pull 12 stands and CBU x 2. Note any cement returns. Check the bottoms up pH, etc. RIH (if necessary) to TOC of plug #1. 3. Spot balanced Plua #2: 10350' to 9400' MD. Pull 12 stands and CBU x 2. Note any cement returns. Check the bottoms up pH, etc. RIH (if necessary) to TOC of plug #2. 4. Spot balanced Plua #3: 9400' to 8450' MD. Pull 12 stands and CBU x 2. Note any cement returns. Check the bottoms up pH, etc. RIH (if necessary) to TOC of plug #3. 5. Spot balanced Plua #4: 8450' to 7500' MD I 4558' MD. Pull 15 stands and CBU x 3. Note any cement returns on bottoms up. Check the bottoms up pH, etc. LDDP while WOC. RIH and tag plug #4 as per AOGCC regulations. POOH. UD the 3-1/2" stinger. 6. RIH with a 9-5/8" EZSVon DP. Set the EZSV at 3260' MD at test same to 2500 psi.. Mix and pump Plua #5: 110 sx (22.5 bbl) of "G" cement. Dump the last 3.8 bbl of cement on top of the EZSV. Pull 5 stands and reverse circulate bottoms up x 2. Pressure test again to 2500 psi. POOH. UD Excess DP. Plug #5: 3420' - 3210' MD 110 sx, 22.5 bbl of "G" cement mixed at 15.8 ppg & 1.15 cf/sk S Coyner 2 4/22/2005 . . 7. Pull the 9-5/8" packoff. RIH with a casing cutter and cut the 9-5/8" casing at .::!:.90' RKB. POOH. Spear the 9-5/8" casing. UD the 9-5/8" cut off and the mandrel hanger. 8. RIH to +300' RKB with 5" DP. Spot balanced Plua #6: 310' to 110' MD inside the 9-5/8" casing. Pull up above the cut and CBU. POOH. Plug #6: 310' - 110' MD 125 sx, 21.1 bbl of Permafrost C mixed at 15.6 ppg & 0.96 cflsk 9. Set a 13-3/8" EZSV at .::!:.50' RKB [15' b original GL]. At very low pressure [gravity +50 psi], down-squeeze Plua #7 wit sx (21.1 bbl) Permafrost C. Leave the last % bbl on top on the EZSV. Cut 0 13-3/8" conductor 5 ft below original ground level.. .'\ \ Plug #7: - 250' MD . ~e£ ê."'^-.Q.\ {) \') 125sx, 21.1 bblofPermafrostC RECEIVED .~~ c~ mixed at 15.6 ppg & 0.96 cf/sk APR 2 2 2005 ' - ð- " , O. RID and MIO Nabors 27E. 11. In accordance with 20 AAC 25.120, weld a Y4" x 18" di~~t~~pgt~*as cfns. ~¥~~1f~j~~/8" conductor. " . ,to n fAAt Flbove origin~1 €round level. Orangc l5eel dlld wdd lh~ lU(J or lIl~ pu:sl. ''¡v'dd ~. <."#011 marl(u" to the po;:,l willi tile follevJing data bead welded 011 it. . {' C\ a. Kerr McGee Oil & Gas Corp f\C\.\~ ,"> r-'~,,~J b. APD No.: 205-056 \U\-~\-\-\--o-\"--- ros~ ~~ ~:lr~~~~0-103-20508-01 12. Remove the cellar. Scraper and dispose of dirty ice. Backfill the cellar. Obtain site clearance from the appropriate agencies. S Coyner 3 4/22/2005 - Surf _ 1000' 1452' - 2000' - 3000' - 4000' - 5000' Rig RKB ::: 105 ft Pad Elev::: 72 ft 13-3/8", 68#, l-80 Conductor at 113' RKB 9-5/8", 40#, BTC 3319' MD /3051' TVD lOT::: 13.7 ppg .... .... .... .... 42.5° ........ .... .... .... .... .... .... .... .... .... .... .... .... .... .... c > ¡.... / Mud MW::: 11.3 ppg .... .... .... .... .... .... .... ... -,-.-.-.-.-.-.-.-.-.-.-.-. -Tarnat5210'TVD------------- -- ---------- ---- Ataruq #2A P&A · Plug #1: 11 -10350' MD, 407 sx G #2: 10350' - 9400' MD, 407 sx G · Plug #3: 9400' - 8450' MD, 407 sx G · Plug #4: 8450' - MD, 407 sx G at 3260' MD 3419'- 3210'MD,110sxG · Plug #6: 310' -110' MD, 125 sx · Cut & pull 9-5/8" at RKB · 1 at +50' · Plug #7: Low pressure down-squeeze through EZSV with 125 sx Permafrost C -' -' -. -. -. - . - . - . -. -. -. - . -' - . -K"n""r..i~ C ""t 5953' TVD _ 6000' "'I"''' ",r\ .. -.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.->-.-.-.-.-.-'-'-'- - 7000' 1 MD/ S. Coyner: 4/22/2005 SurveyReport HALLIBURTON, SPERRY-SUN DIRECTIONAL SURVEY REPORT Kerr McGee Ataruq #2 A Exploration North slope Borough Alaska USA 50-103-20508-01 Measured verti cal verti cal . Depth Inclination Direction Depth Latitude Departure section Dogleg (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (degj100f) 0.000, 0.000, 0.000, 0.000, 0.000 N, 0.000 E, 0.000, TIE IN 146.150, 0.710, 218.660, 146.146, 0.707 5, 0.566 w, -0.770, 0.486 239.040, 0.670, 226.670, 239.030, 1.529 5, 1.320 w, -1.677, 0.112 333.820, 0.570, 22 6 . 040 , 333.804, 2.237 5, 2.063 w, -2.470, 0.106 422.060, 0.710, 216.140, 422.038, 2.983 5, 2.701 w, -3.287, 0.202 514.990, 0.840, 219.970, 514.960, 3.970 5, 3.478 w, -4.361, 0.151 601.090, 0.820, 218.110, 601.051, 4.938 5, 4.264 w, -5.417, 0.039 692.390, 0.790, 224.710, 692.342, 5.900 5, 5.110 w, -6.474, 0.107 782.960, 0.760, 222 .520, 782.904, 6.786 5, 5.955 w, -7.456, 0.047 874.530, 1. 050, 218.980, 874.462, 7.886 5, 6.893 w, -8.661, 0.322 960.010, 1. 250, 227.980, 959.925, 9.119 5, 8.079 w, -10.028, 0.315 1052.850, 1. 310, 230.940, 1052.742, 10.465 5, 9.655 w, -11.555, 0.096 1148.980, 1. 590, 226.510, 1148.841, 12.076 5, 11. 476 w, -13.374, 0.314 1242.780, 1. 790, 225.500, 1242.600, 13 . 998 5, 13.465 w, -15.523, 0.216 1336.850, 1. 540, 215.210, 1336.630, 16.061 5, 15.242 w, -17.785, 0.413 1432.680, 2.070, 230.010, 1432.413 , 18 . 22 5 5, 17.310 w, -20.183, 0.732 1526.010, 2.150, 228.270, 1525.680, 20.474 5, 19.908 w, -22.729, 0.110 . 1623.580, 2.300, 228.580, 1623.176, 22.987 5, 22.742 w, -25.567, 0.154 1717.970, 2.220, 226.510, 1717.493, 25.498 5, 25.489 w, -28.391, 0.121 :.b: 1812.840, 1. 970, 338.010, 1812.328, 25.251 5, 27.433 w, -28.381, 3.653 ii" eo. 1906.460, 7.530, 7.490, 1905.599, 17.670 5, 27.236 w, -20.832, 6.297 :r 1999.860, 11. 390, 7.850, 1997.712, 2.461 5, 25.178 w, -5.485, 4.133 0 ;0 2094.430, 14.300, 10.370, 2089.906, 18.283 N, 21. 799 w, 15.515, 3.133 ::::.: :J::> 2186.870, 17.370, 12.540, 2178.828, 42.988 N, 16.747 w, 40.650, 3 . 3.&2 Qo -0 [1j 2281. 990, 20.980, 13.420, 2268.656, 73.422 N, 9.710 w, 71. 711, 3. &-e7f> ;::0 2375.230, 24.250, 15.030, 2354.716, 108.161 N, 0.868 w, 107.263, 3 . ff>9;; ~ 2470.040, 29.200, 15.700, 2439.372 , 149.255 N, 10.447 E, 149.423, t~~ ~ 117 2565.280, 33.530, 14.180, 2520.676, 197.146 N, 23.183 E, 198.503, N -- 2659.740, 37.990, 11.910, 2597.312, 250.914 N, 35.580 E, 253.375, 4.92,t c::::> ~ c::::> §' t..11 page 1 .t;; 0 M æ;' ::;;¡ SurveyReport 2755.830, 42.170, 11.130, 2670.819, 311.526 N, 47.915 E, 315.033 , 4.381 2849.430, 45.630, 10.990, 2738.252, 375.213 N, 60.362 E, 379.758, 3.698 2944.670, 45.330, 9.470, 2805.032, 442.036 N, 72.423 E, 447.548, 1. 181 3036.210, 45.150, 7.770, 2869.491, 506.296 N, 82.166 E, 512.515, 1. 333 3132.070, 44.160, 7.620, 2937.681, 573.062 N, 91.188 E, 579.882, 1. 039 3227.170, 42.340, 6.670, 3006.947, 637.712 N, 99.302 E, 645.038, 2.032 3280.350, 42.130, 5.850, 3046.321, 673.244 N, 103.200 E, 680.781, 1.109 3320.000, 42.140, 5.700, 3075.724, 699.709 N, 105.876 E, 707.376, 0.255 3423.420, 44.150, 0.150, 3151. 206, 770.283 N, 109.418 E, 777.861, 4.151 3517.970, 44.330, 355.000, 3218.966, 836.143 N, 106.624 E, 842.901, 3.804 3612.720, 44.820, 349.890, 3286.481, 902.020 N, 97.874 E, 907.237, 3.820 3705.480, 44.910, 345.180, 3352.245, 965.877 N, 83.757 E, 968.921, 3.583 . 3800.950, 46.580, 340.060, 3418.889, 1031.077 N,63.304 E, 1031.172 , 4.220 3893.750, 49.200, 337.670, 3481.116, 1095.266 N,38.459 E, 1091.888, 3.409 3989.120, 51. 830, 332.220, 3541. 782, 1161.866 N,7.252 E, 1154.229, 5.200 4084.040, 53.320, 328.460, 3599.478, 1227.336 N,30.059 w, 1214.711, 3.515 4179.150, 55.980, 324.580, 3654.515, 1291.989 N,72.871 W, 1273.718, 4.346 4273.660, 59.320, 321.270, 3705.089, 1355.642 N,121.021 w, 1331. 086, 4.608 4368.100, 61. 120, 317.430, 3752.006, 1417.795 N,174.419 w, 1386.332, 4.011 4461.000, 63.300, 314.950, 3795.322 , 1477.081 N,231.317 w, 1438.309, 3.329 4556.140, 65.970, 310.730, 3836.090, 1535.486 N,294.352 w, 1488.670, 4.892 4651. 060, 68.410, 308.810, 3872.888, 1591.441 N,361.603 w, 1536.089, 3.175 4745.290, 70.700, 304.850, 3905.812, 1644.334 N,432.266 w, 1580.056, 4.627 4840.130, 74.570, 301.630, 3934.120, 1693.911 N,507.962 w, 1620.124, 5.210 4932.350, 76.300, 301. 060, 3957.310, 1740.339 N,584.189 w, 1657.000, 1. 969 4987.240, 76.350, 303.430, 3970.289, 1768.792 N,629.294 w, 1679.795, 4.196 5080.050, 76.140, 303.140, 3992.356, 1818.266 N,704.653 w, 1719.801, 0.379 5173.290, 77 .070, 302.880, 4013.956, 1867.679 N,780.714 w, 1759.662, 1.034 5267.340, 77.340, 302.460, 4034.785, 1917.187 N,857.918 w, 1799.478, 0.522 5360.540, 77.150, 301. 810, 4055.362, 1965.538 N,934.892 w, 1838.174, 0.710 5456.840, 76.590, 300.980, 4077.238, 2014.393 N,1014.942 w, 1876.998, 1. 021 5549.580, 76.260, 301.240, 4099.005, 2060.971 N,1092.126 w, 1913.910, 0.448 .:b . i.i'" 5647.310, 75.940, 300.540, 4122.483, 2109.676 N,l173.536 w, 1952.420, 0.769 - ~ 5739.020, 75.470, 300.740, 4145.127, 2154.968 N,1249.999 w, 1988.142, 0.554 aJ ;0 5832.000, 76.920, 301.150, 4167.313 , 2201.398 N,1327.438 w, 2024.875, 1. 617 Q -. » - 5926.410, 76.870, 301. 370, 4188.720, 2249.114 N,1406.040 w, 2062.743, 0.233 :z:,.t20 ." m 6021. 670, 76.450, 299.890, 4210.700, 2296.338 N,1485.794 w, 2099.985, 1. 575 ::JC') :::0 () 6116.760, 75.960, 299.010, 4233.375, 2341.742 N,1566.206 w, 2135.340, 1. 036 C") Q) :::r t:4 ~ 6209.620, 76.510, 298.540, 4255.470, 2385.158 N,1645.262 w, 2168.885, 0.770 OC"':) rn ... Q t:..:> 6301. 470, 77 .010, 298.670, 4276.506, 2427.964 N,1723.757 w, 2201. 893 , 0.562 Q) ::J - 6396.840, 76.450, 298.420, 4298.397, 2472.320 N,1805.296 w, 2236.072, 0.640 'ä:!'" ~~ C") 6490.520, 76.450, 298.870, 4320.346, 2515.978 N,1885.222 w, 2269.753, 0.467 Q 6582.820, 76.680, 300.060, 4341.792, 2560.137 N,1963.382 w, 2304.144, 1. 279 § 0 6676.630, 75.960, 300.390, 4363.978, 2606.021 N,2042.139 w, 2340.175, 0.840 ¡:;¡. .c. ëï page 2 ~ SurveyReport 6771.490, 75.410, 300.670, 4387.432, 2652.712 N,2121.311 W, 2376.958, 0.647 6867.590, 76.240, 300.320, 4410.965, 2699.994 N,2201.596 W, 2414.193, 0.933 6963.020, 76.580, 301. 220, 4433.389, 2747.448 N,2281.295 W, 2451. 669, 0.983 7057.670, 76.270, 301.030, 4455.604, 2795.007 N,2360.055 w, 2489.363, 0.381 7153.030, 77.810, 299.520, 4476.992, 2841.852 N,2440.309 w, 2526.168, 2.234 7247.330, 77.220, 299.930, 4497.378, 2887.503 N,2520.263 w, 2561.824, 0.756 7341. 780, 75.620, 301.200, 4519.555, 2934.185 N,2599.313 w, 2598.612, 2.140 7435.080, 75.810, 301.400, 4542.576, 2981.157 N,2676.569 w, 2635.905, 0.291 7529.150, 77.080, 302.230, 4564.624, 3029.368 N,2754.276 w, 2674.373, 1.599 7622.540, 76.150, 301. 950, 4586.243, 3077.634 N,2831.247 w, 2712.985, 1.038 7717.010, 75.820, 301. 950, 4609.121, 3126.137 N,2909.019 w, 2751. 736, 0.349 7809.390, 76.130, 302.720, 4631. 509, 3174.075 N,2984.746 w, 2790.173, 0.876 . 7904.350, 76.440, 302.360, 4654.023, 3223.697 N,3062.516 W, 2830.034, 0.492 7997.650, 76.410, 302.750, 4675.923, 3272.500 N,3138.959 w, 2869.242, 0.408 8093.600, 75.750, 302.470, 4699.005, 3322.690 N,3217.409 w, 2909.586, 0.744 8187.410, 75.450, 302.630, 4722.334, 3371.578 N,3293.999 w, 2948.861, 0.360 8283.450, 75.080, 301. 590, 4746.763, 3420.948 N,3372.671 w, 2988.365, 1.116 8378.520, 76.170, 300.170, 4770.366, 3468.210 N,3451.708 w, 3025.730, 1.846 8474.230, 75.860, 300.320, 4793.496, 3514.991 N,3531.938 w, 3062.473, 0.358 8569.140, 76.610, 299.400, 4816.080, 3560.886 N,3611.884 w, 3098.372, 1. 229 8663.750, 77.970, 299.050, 4836.895, 3605.945 N,3692.426 w, 3133.369, 1. 482 8758.490, 77.330, 299.180, 4857.158, 3650.975 N,3773.279 w, 3168.300, 0.689 8851. 550, 76.900, 298.380, 4877.910, 3694.650 N,3852.789 w, 3202.048, 0.957 8946.350, 76.810, 298.960, 4899.469, 3738.940 N,3933.786 w, 3236.227, 0.603 9039.830, 77.320, 299.430, 4920.394, 3783.381 N,4013.319 w, 3270.732, 0.733 9135.330, 77.980, 299.860, 4940.820, 3829.525 N,4094.397 w, 3306.741, 0.819 9225.160, 76.760, 300.620, 4960.461, 3873.669 N,4170.124 w, 3341. 411, 1.589 9320.290, 75.930, 300.850, 4982.919, 3920.912 N,4249.581 w, 3378.708, 0.904 9413.910, 75.360, 301.800, 5006.130, 3968.063 N,4327.056 w, 3416.152, 1.156 9508.780, 75.830, 302.440, 5029.732, 4016.919 N,4404.877 w, 3455.247, 0.820 9603.900, 75.980, 302.840, 5052.896, 4066.679 N,4482.564 w, 3495.255, 0.437 9699.480, 74.170, 302.780, 5077 .513 , 4116.720 N,4560.183 w, 3535.551, 1. 895 . 9794.220, 71.570, 302.660, 5105.415, 4165.655 N,4636.347 w, 3574.925, 2.747 .:to. w 9889.020, 67.810, 301.070, 5138.316, 4212.593 N,4711.830 w, 3612.398, 4.267 tn ;zr;- 9982.430, 63.460, 299.390, 5176.845, 4255.440 N,4785.317 w, 3646.052, 4.936 Qo) 10075.490, 59.500, 299.280, 5221.269, 4295.493 N,4856.584 w, 3677.200, 4.257 9 » ÃJ CALCULATION BASED ON MINIMUM CURVATURE METHOD. )::0..0:1 ." m ::::J C) .::0 0 n Q) =r"" ~ SURVEY COORDINATES RELATIVE TO WELL SYSTEM REFERENCE POINT. ~ n ts:ì m 0) <:;) TVD VALUES GIVEN RELATIVE TO DRILLING MEASUREMENT POINT CQ ::.:I - Q; "" ~~ VERTICAL SECTION RELATIVE TO WELL HEAD. C") 0 VERTICAL SECTION IS COMPUTED ALONG A DIRECTION OF 6.940 DEGREES (TRUE). ~ 0 ë;¡. page 3 "" õ' ::::! surveyReport HORIZONTAL DISPLACEMENT IS RELATIVE TO THE WELL HEAD HORIZONTAL DISPLACEMENT(CLOSURE) AT 10075.490 FEET IS 6483.646 FEET ALONG 311.492 DEGREES (TRUE) . HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY OTHER THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING COMPLETION AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THIS SOFTWARE, THE USE OF THIS SOFTWARE TO DISPLAY ANY INFORMATION OR DATA FROM ANY SOURCE, ANY INTERPRETATION BASED ON SUCH DISPLAY, OR THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF THIS SOFTWARE, ANY INFORMATION OR DATA DISPLAYED OR PROVIDED THROUGH THE USE OF THIS SOFTWARE, OR ANY INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC . :Joo ¡¡- c.. :=00:- '; ;C ;~m ]> C) ;::c ". ::J Q) \. .I g.. rn is) m. ~~~-- ~ i '" < C'D. 0 C'"')°m o U1 ~. 0 '" rn ær ::::J page 4 3800 4100 4300 4400 4500 4600 4700 o 4900 5000 5'100 6400 6600 6 7500 00 8400 '1 0000 Re: Ataruq 2A /10-403 . . Subject: Re: Ataruq 2A /10-403 From: Thomas Maunder <tom_maunder@admin.state.akus> Date: Fri, 22 Apr 2005 16:38:15 -0800 To: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> CC: AOGCC North Slope Office <aogcc-prudhoe_bay@admin.state.akus> Skip, I will modify the procedure as requested. I think the changes will meet the plugging objectives. By copy of this email, you have "verbal approval" to proceed. Unless you need it, I am not planning to fax anything back to you tonight. I will be sending a copy of the plugging procedure to the NS Inspectors. As you proposed, notify them so they can witness the tag on plug #4 and to witness the cutoff. As their discretion, they may wish to witness other portions of the P&A. Good luck Tom Maunder, PE AOGCC Coyner, Skip wrote: I appreciate your thoughts on the surface plug(s) I proposed for the captioned well. As we discussed, please modify the P & A procedure as follows: · Spot balanced plug #6 as proposed. · Pull up to +/- 40' RKB, close the annular and squeeze away 3 - 5 bbl of cement into the 13-3/8" x 9-5/8" annulus. · Set the 13-3/8" EZSV right on top of plug #6. · Cut off the 13-3/8" as proposed · Spot a surface plug from the EZSV to G/L. S!üp Coy1l£r 907-339-62690fc 907-748-3689 cell 1 of 1 4/22/2005 4:38 PM Re: Ataruq 2A / 10-403 . . Subject: Re: Ataruq 2A / 10-403 From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 22 Apr 2005 16:45:48 -0800 To: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> CC: AOGCC North Slope Office <aogcc-.rrudhoe_bay@admin.state.ak.us> Skip, As long as the volumes are the same, changing blends does not present a problem. One other point I forgot in our earlier messaging was that a marker post is no longer the preferred marker. Check the regs at 20 AAC 25.120(a). The preferred marker is a plate covering all stubs and welded to the outside casmg. We have talked again and you confirmed the need for that change. Again, good luck with the operations. Tom Maunder, PE AOGCC Coyner, Skip wrote: I have been informed by Halliburton that class G cement stocks are running short. More class G is on the way from Anchorage. We request that plugs #1 through #3 be changed to class G + 8% gel. The volumes will remain the same. Plug #4 & #5 will be class G. S!ijp Coyner 907-339-62690fc 907-748-3689 cell 1 of 1 4/22/2005 4:46 PM Re: ataruq2a P A Plan.ppt . e Subject: Re: ataruq2a P A Plan.ppt From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 02 May 2005 16:34:31 -0800 To: "Boggan, Stuart" <SBOGGAN@KMG.com> CC: aogcc north Slope Office <aogcc-prudhoe_bay@admin.state.ak.us> dO '5 -0 S-Cp Stuart, Thanks for sending the updated information. Due to the large volume of cement that has been necessary to achieve the cement height verified so far, Kerr-McGee is proposing to alter the remaining open hole plugging program. In the interval that will potentially remain open, the mud weight originally used was 9.3 ppg with only minor hydrocarbon shows noted. The mud weight presently in the open hole is 11.3 ppg and was used to aid wellbore stability at the 75 deg sail angle. You propose to set a retainer near the surface casing shoe and then to squeeze 123 bbls of cement below the retainer and dump 4 bbls on top, test the casing and then proceed with the surface plugging activities. Your plan as updated is acceptable. You may proceed as planned. Good luck with the operations. Have your rig personnel keep the Inspectors informed of the activities. I will provide them with a copy of the revised procedure. Tom Maunder, PE AOGCC Boggan, Stuart wrote: Tom, Please find the attached revision to the Ataruq 2A P&A. We spotted plug #7, but as we discussed, we have pumped 478 bbls, excluding plug #7 and have not been able to get much height out of the plugs. We are to the point where available cement volumes are quickly running out. Could you review the attached to see if it meets with the state's needs. Thanks, Stuart A. Boggan KERR-McGEE OIL & GAS CORPORA TION cIa ASRC Energy Services 3900 C Street, Suite 702 Anchorage, Alaska 99503 Office: (907) 339-6370 Cell: (281) 659-5046 Fax: (907) 339-6276 e-mail: sboÇjç¡an(Ã!kmç¡.com Important Notice! If you are not the intended recipient of this e-mail message, any use, distribution or copying of the message is prohibited. Please let me know immediately by return e-mail if you have received this message by mistake, then delete the e-mail message. Thank you. 1 of 1 5/3/20058:48 AM - Surf - 1000' - 2000' - 3000' - 4000' - 5000' - 6000' - 7000' - 8000' - 9000' Pad Elev = 3 ft GLto RKB = 31 ft Rig RKB = 34 ft Ataruq 2A Exploratory Well Revised P&A Schematic 12-1/4" Hole EZSV @ +/-3219' MD/3076' TVD 9-5/8", 40#, L-80, BTC 3319' MD /3051' TVD I I I I 11.3 ppg I Mud I I I I I :~ I I ~ Cement Plug 1:88 Bbls Cement 8,667'-1,771' MD/4,837'-4622' TVD Not Tagged Cement Plugs 1-6:478 Bbls Cement 11,242' -8,667' MD/6, 138' -4,837' TVD Tagged 8-1/2" Hole TD-11,242' MD/6,138' TVD \- , Revised P&A Procedure 1. RIH w/OEDP 2. Spot plugs 1-6: Plugs 1-3, 5:321.4 bbls Class G + 8% Gel @ 13.2 ppg Plugs 4 & 6:154.7 bbls Class G @ 15.8 ppg 3. Tag Cement @ 8,667'MD/4837'TVD 4. Spot plug 1:8,667-7771'MD/4837'-4622'TVD. Plug 7:90.2 bbls Class G @ 15.8 ppg. 5. Pick-up and Trip in hole w/EZSV. 6. Set EZSV at 3219'MD/3076'TVD and test to 2500 psi. 7. Squeeze 123 bbls below EZSV & Dump 4 bbls on top. Plug 8:103.3 bbls Class G @ 15.8 ppg & 22.5 bbls Class G + 1 % CaCI @ 15.8 ppg 8. Test retainer/squeeze to 2500 psi. 9. Cut & Recover the 9 5/8". 10. RIH to +300' RKB. Spot Plug #9 310'-110' MD. Plug #9:16 bbls Perfmafrost C @ 15.6 ppg. 11. Set 13 3/8" EZSV @ +/-50'. Sqz Plug #10. Plug #10:21.3 bbls Permafrost C @ 15.6 ppg. 12. Cut 13 3/8" 5' below GL. 13. RDMO Nabors 27E. N/D BOPs. 10. Cut & recover 95/8" & 13 3/8". 13. Clean & Clear Location with DNRlDEC/AOGCC. 5/02/05, SAB . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, 'Ua S-/11{tJ5" DATE: P. I. Supervisor ~(r1 April 30, 2005 FROM: Chuck Scheve, SUBJECT: Petroleum Inspector Open Hole Plug ~ Ataruq#2 A PTD#205-056 ~ Saturdav. April 30.2005: I traveled to the Kerr-McGee Ataruq #~xploratory location to verify location of the open hole cement plugs in this well. A continuous cement plug had been spotted in 4 stages from TD to 7227 estimated top of cement. After 12 hours woe drill pipe was run in the hole to locate the top of cement. There was no indication of cement until a depth of 9152 where the DP tagged up solid, the top of the Middle Brookian formation is at 7743. Mondav. Mav 2.2005: I returned to the Ataruq #2þJ~tion where a cement plug had been spotted in 2 stages form 9152 to 7527 estimated top of cement. Drill pipe was run in the hole and cement tagged at 8667. SUMMARY: I witnessed two failed attempts to verify open hole cement plugs covering the Middle Brookian formation at 7743' MD. . ~ KERll-M . CORPORATION April 14th, 2005 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED APR 1 5 Z005 Alaska Oil & Gas Cons. Commission Anchorage Re: Ataruq #2A - Revised / Kerr McGee Oil & Gas Corporation Revised Application for Pennit to Drill (10-401) Attached for your review is our Application for Pennit to Drill the Ataruq #2A which is planned as a sidetrack to the Ataruq #2 exploration well located approximately four (4) miles north-northwest from KRU's 2M Pad. If time allows, we plan to drill this sidetrack immediately after evaluating and plugging back the mother-bore, Ataruq #2 (APD 205-039). This revised original APD is submitted along with one (1) copy and the $100.00 filing fee. The APD packages include fonn 10-401, a pressure analysis, drilling program, directional drilling plan, mud program, plats, graphs and diagrams as required. The Ataruq #2A is a "build, hold and drop" sidetrack with a bottom hole location in section 6 TIIN R8E. The planned sidetrack KOP is the base of the Ataruq #2 surface casing at 3319' MD. The well will be kicked off from a cement plug placed below the casing shoe. From the KOP, we will build and turn toward the new target in section 6. Then we will drop angle through the Tam and Kuparuk fonnations. At TMD (below the Kuparuk A) we may run MDT's on drill pipe. After evaluating the well, we plan to plug and abandon the well. If you have any questions or concerns about the APD or the drilling plan, please call me at 339-6269 and I will do my best to address your questions or concerns. Sincerely, S~yn~ ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 RECEIVED APR 1 4 2005 Alaska Oil & Gas Cons. Commission Anchorage (907)-339-6370 1 a. Type of Work: Drill LJ Redrill D 1 b. Current Well Class: Exploratory o la~l1:'fipmEÐwriCOI1lJ' e U Re-entry D Stratigraphic Test D Service D A ~evelopm'" n. Cl Single Zone D 2. Operator Name: 5. Bond: Blanket LJ Single Well D 11. Well Name and Number: Kerr McGee Oil & Gas Corporation Bond No. 3-798-381 / Ataruq #2A 3. Address: I 6. Proposed Depth: 12. Field/Pool(s): 3900 C Street, Ste 744, Anchorage, AK 99503 MD: 10,813' / TVD: 6,200' , 4a. Location of Well (Governmental Section): 7. Property Designation: Exploration Surface: 477' FNL & 1834.6' FEL Sec. 8, T11 N, R8E UM / ADL 390502 / Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1883' FNL & 740' FEL Sec. 6, T11 N, R8E UM 4/16/2005 Total Depth: 9. Acres in Property: 14. Distance to Nearest 1334' FNL & 1662' FEL, Sec. 6, T11 N, R8E UM 2469 I Property: 1334'/ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Surface:x- 480716 ' 5,969,528 .r Zone- 4 - (Height above GL): 33 feet Within Pool: 4727' to Ataruq 2 y- 16. Deviated wells: Kickoff depth: '3~t6~feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: /J't> 75.3 degrees Downhole: 3450 psi Surface: 2792 psi / 18. Casing Program: ,,'£: ff'·o," Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Structural Conductor 80' 13-3/8",68#, L-80 20 yards 113' 113' Surface 3286' 9-5/8",40#, L-80 319 sx Permafrost L (235.6 bbl) & 3319' 3051' 286 sx G + 2% CaCI2 (58.7 bbl) Production Liner Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments: Filing Fee lJ BOP Sketch lJ Drilling Program lJ Time v. Depth Plot lJ Shallow Hazard Analysis U Property Plat 0 Diverter Sketch D Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name ,,-... J<1r. Todd D_ -... . Title Drilling Manager, Kerr McGee Oil & Gas Corporation r À Signature I. \}.{ (, è Phone ~~'-~3iO Date 14-Apr-05 ,-.-\ ..-- Commission Use Only Permit to Drill API Number: Ù 9 permitAPPro~~ .~ ~ See cover letter for other Number: 2-D$"" -0% 50- / 3 -:J-DW --ð I Date: 4- tS D~ requirements. Conditions of approval: Samples required Yes g¡ No D Mud log required Yes ~ No D H~~~ y~ No D Directional survey required Yes ~ No D Other: STJc:J::.J \'?\ \S~ ~ ),O~ \a..~' , APPROVED BY t//Þí I)) p?"/<e(/(~~ Jj¿/~ Approved by: ..,... ~ ~ ~ THE COMMISSION Date: Form 10-401 Revised o~ '-.. I (bmit inDuplicate .KA OIL AND ~~;~g~~L:~:;;ON C.lsslorRECelVED PERMIT TO DRILL APR 1 5 2005 20 MC 25 005 ~It( / . . Ataruq #2A Sidetrack Drilling Prognosis Drilling Rig: Nabors 27E Sidetrack, Drill, Evaluate, P & A Suñace Location: 477' FNL & 1835' FEL of Section 8, T11 N, R8E UM X = 480,716' Y = 5,969,528' / 1883' FNL & 740' FEL of Section 6, T11 N, R8E UM X = 477,139' Y = 5,973,055' 1448' FNL & 1470' FEL of Section 6, T11 N, R8E UM X = 475,811' Y = 5,973,850' 1334' FNL & 1662' FEL of Section 6, T11 N, R8E UM X = 476,454' Y = 5,973,465' ,/ Target (T1) at 5113' TVD (L. Tarn Sand) Target (T1) at 5978' TVD (Kuparuk C sand) Bottom Hole Location: / 1 Estimated Spud Date: 14/17/05 1 1 Operating Rig days: 18 1 Pad Elev: 172 ft I DF: 1105 ft 1 I TMD: 110,813' 1< 1 TVD: 16,200' 1 < Geologic Objectives: L. Tarn sand, Kuparuk A & C sands Mud Program: 8-1/2" Production Hole Density PV 9.8 - 11.5 10- 18 pH 9.0-9.5 KCUPol mer API W/L LG Solids < 6 < 10 Recommended Bit Program: Bit Hole Size Depth (MD) Footage Bit Type RPM GPM 1 8-1/2 in 3,319' - 5,000' 1,681' MXC-1 100 - 120 450 - 550 2 8-1/2 in 5,000' -10,813' 5,813' PDC 120 - 180 450 - 550 S Coyner 1 4/14/2005 . . Casing Program Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD I TVD MD I TVD NIA 13-3/8" 68# L-80 STC 80' 30' 110' 1110' NIA 9-518" 40# L-80 STC 3,286' 33' 1 33' 3319' 13051' Mud Logging: Intermediate Hole: 8-3/4" Rig instrumentation: PVT, Flow-Show, gas [H2S] detectors. ; Mud loggers to intermediate casing point: samples every 30 ft: every 10 ft through pay zones, gas detection & drilling parameters '" Surveys & MWD: While Drilling: Window to TD: MWD surveys every 90 to 180 ft '" IIFR Casandra for magnetic survey verification E r P va ua Ion rogram: 8-1/2" Build & Turn 3319' to 5000' MD Open Hole: MWD 1 LWD: MWD/GR/RES / Open Hole: Gas Detection, Mud Logging, samples ..,c 8-1/2" Hold & Drop 5000' to 10813' MD Open Hole: MWD 1 LWD: MWD 1 Quad-Combo LWD's 1 PWD , Open Hole: Gas Detection, Mud Logging, samples '" E-Line: Possible TLC 1 MDT's Formation Markers: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (Ib/gal) 9-5/8" Casing Shoe 3,319' 3,051' T/Middle Brookian 8,541' 4,615' 2,052 8.55 T/Lower Tarn 9,280' 5,113' 2,273 8.55 T/Moraine 9,524' 5,303' 2,358 8.55 T/HRZ 10,011 ' 5,784' 3,008 10.00 T/Kuparuk C 10,480' 5.953' 3,450 11.13 LCU 10.520' 5,983' T/Kuparuk A 10,520' 5,983' 3,460 11.12 Proposed TD 10,813' 6,200' ¿ S Coyner 2 4/14/2005 . . Integrity Testing: Test Point: 9-5/8" Shoe MD / TVD 3319' I 3051' Kick Tolerance ~ 50 bbls Test Type: FIT EMW: 13.5 ppg Well Control: The 9-5/8" surface casing was set and cemented while drilling Ataruq #2. Nabors' 13- 5/8" (5M) BOP stack will already be N/U and tested when we sidetrack below surface casing. The production hole section will be drilled with well control equipment consisting of 13-5/8" (5000 psi) working pressure pipe rams(2), blind rams, and annular preventer capable of handling maximum potential surface pressures. BOP's will be tested prior to sidetracking and then on a weekly basis thereafter. The rams, valves and manifold will all be tested to 250 psi low / 5000 psi high, the annular tested to 250 psi low / 3500 psi high, the casing to 2500 psi. The maximum anticipated Surface Pressure is calculated from nearby Kuparuk C BHP data and a gas gradient of 0.11 psi/ft to surface as required: Kuparuk C BHP = 3450 psi Maximum Surface Pressure = 3450 psi - (5983 ft x 0.11 psi/ft) = 2792 psi " ~osal of DrillinQ Waste: · Cuttings Handling: Cuttings generated from drilling operations will be hauled using super suckers to G & I #3: located on DS-04, Prudhoe Bay, for disposal. · Fluid Waste Handling: All drilling and completion fluid wastes will be hauled to 1 R-18 at Kuparuk for disposal. · Sewage (grey/black water): Camp waste water will be hauled to the sewage treatment plant(s) at Kuparuk I Prudhoe Bay I North Slope Borough where it will be treated and injected. H2S: · H2S has been reported from wells on 2T Pad that produce from the Tabasco sand. " H2S concentrations of 700 ppm have been measured at the wellhead. Minor / concentrations of H2S have also been reported from the Kuparuk sands as well. · No H2S was reported while drilling Ataruq #2 · H2S monitors will be used at all times in accordance with State Regulations. ./ S Coyner 3 4/14/2005 . . DRilLING PROCEDURE Pre-Rig Work: 1. Ensure the permits are in order. 2. Notify the AOGCC 24 hours prior to sidetracking, and prior to the BOP tests. Standard Orders: 1. All personnel must sign in at the camp and no unauthorized personnel are allowed on site. 2. For travel safety and location security, all travelers must sign in/out at the security guard post near the spine road AND sign in/out at the assigned camp. 3. A full opening safety valve (with correct threads) will be kept on the drill floor in the open position at all times and the appropriate hex-wrench will be readily available. 4. Pit drills/kick drills will be conducted one with each crew in each hole section. 5. 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. 6. The toolpusher and company man will witness the first ten (10) stands off bottom for all trips. Use the trip tank. Keep a trip sheet. Keep the hole full. Watch for swabbing. Pre-Sidetrack: 1. Plug back Ataruq #2 into the 9-5/8" casing shoe in accordance with the approved 10-403 form. POOH. WOC. 2. Test BOPE to 250 psi / 5000 psi except the annular which is tested to 250 psi /3500 psi. Notify the AOGCC Field Inspectors 24 hours prior to testing BOPE. 3. RIH with 8-1/2" bit & directional drilling BHA. Test the 9-5/8" casing to 2500 psi on chart. 4. Drill out the cement inside the 9-5/8" casing. Orient the bent housing motor "High Side" and slide drill for 50'. CBU. Perform an FIT to 13.5 ppg EMW. Drilling Operations: Production Hole Section: 5. Drill ahead, sliding to build inclination and turning according to the attached directional drilling plan. Once the inclination and azimuth are satisfactory drill ahead in rotary mode to ±5000' MD. CBU x 3. Pump out to the casing shoe and CBU again. POOH. LID M/M. 6. RIH with a rotary steer-able BHA, quad-combo LWD, and PWD. Rotary drill the 8-1/2" hole to TMD following the approved directional plan and the approved mud program. Maintain high rotary speed and pump rate for hole cleaning. Add lubricants as needed for torque. Bit Hole Size Depth (MD) Footage Bit Type RPM GPM 2 8-1/2 in 5,000' - 10,813' 5,813' PDC 120 - 180 450 - 550 7. At TD, CBU x 4. Make a wiper 10-stand trip above the HRZ. Return to bottom and CBU x 4 again. POOH to the 9-5/8" casing and CBU from there. Finish POOH. LID LWD tools. S Coyner 4 4/14/2005 . . 8. ODtional: if the decision is made to run TLC / MDT's, RlU E-Line. RIH with MDT tools, side-door sub, etc. Run the MDT's as directed. POOH. LID MDT tools. RID E-Line. 9. RIH with a 1200' x 3-1/2" stinger on 5" DP to TMD. Plug the well in accordance with an approved 10-403 form. 10. Cut off the casing strings and abandon the well in accordance with AOGCC regulations. 11. De-Mobilize Nabors 27E and all associated equipment. 12. Scrape the ice pad and ice road as needed, and properly dispose of the soiled ice. 13. Obtain site clearance from State agencies as required. Attachments: · Location Plat · Well bore diagram · Day -vs- Depth curve · Directional Drilling Program · Drilling Fluids Program · Abnormal Pressure Analysis · Drilling Hazard Analysis · Nabors 27E BOP & Choke Manifold Diagrams S Coyner 5 4/14/2005 . . · Production Hole Section: 14. Drill ahead adjusting the mud weight as dictated by hole conditions and in accordance with /' the attached mud program. Maintain the mud properties to minimize the PV, surge, swab and ECD while still cleaning the hole. Watch for mud losses, seepage and differential sticking in the Tarn sand at ±5553' MD. Adjust the MW up to ± 10.6 ppg to drill the HRZ. ,,/ 15. At ±6700' MD, Make a 15 stand wiper trip. Then, adjust the MW up to ± 11.5 ppg to drill /' the Kuparuk C sd. Be sure the hole is clean and minimize the ECD. Drill ahead watching for mud losses, seepage and differential sticking. Keep the pipe moving at all times. 16. At TD, CBU x 3 and then as needed to clean the hole. Make a 20 stand wiper trip. RIH and CBU x 3 again. POOH to the 7-5/8" shoe and then CBU from there. POOH for logs. 17. RlU E-Line. Run Log suite as directed, followed by MDT's and SWC's as/if directed. 18. RID E-Line. RIH with OEDP and prepare to plug and abandon. Attachments: · Assignment of Operator - Approved by DNR · Survey plat (Lounsbury) · Geographic Plat (PowerPoint) · Days -vs- Depth Graph (Excel) · Wellbore Schematic (Excel) · Wellbore Diagram (PowerPoint) · Directional Drilling Plan (Sperry) · Drilling Mud Program (Baroid) · Abnormal Pressure Analysis · Nabors 27E BOP Diagram · Nabors 27E Choke Manifold Diagram S Coyner 6 4/14/2005 April 14, 2005 .., Co ~ ~ M 00 00 ~ 1 BHl 0,.. +- 740' .. Kuparuk C Set At 5953' TVD ., ..... ..... T,: Tarn Sd. at 5113' ND 6 7 1662' 1470' ADl 0390502 (2469 acres) Armstrong 0 & G Kerr McGee 0 & G ~II"'I .......... i'¡-9'/<9", " ;>ð:",o Ataru No. 2A..Revi Surface location: 700 19' 40.5" N & 150009' 23.0" W 477' FNl & 1834.6 FEl of Section 8 T11 N R8E 5,969,528' N & 480,716' E NAD 27, Zone 4 Kuparuk: C (T 2) location: 1448' FNL & 1470' FEL of Section 6 T11 5,973,850' N & 475,811' E NAD 27, Zone 4 Bottom Hole location: 1334' FNL & 1662' FEL of Section 6 T11 N 5,973,465' N & 476,454' E 5 ..... ..... ..... ..... "' , \ \ \ :!:1730'FSL 1834.6' FEl---tJo. Ataruq No.2 & 2A 477' FNL 8. 1834.6' FEL Surface Location 8 1000 2000 3000 4000 ~ 5000 CD C "'C ~ 6000 :s fJ) m ~ 7000 SOOO 9000 10000 11000 12000 Ataruq #2A Days -v- Depth o ----- ---î---- I I -1 - - - t- I I ~I~ I I -1- - - I _ J _ _ I I I I -[- - - - I ----¡------- ------ -----..,.- I I I - -+ - - - ....¡ I I I I I I _ J _ _ I I I ----i- I I I - - _1- ____L___ 9-5/S" at 3319'MD - - -I- I I I r-----j- ~ ~ ~ ~ - .- >-- - - - - ----- -------- ----,- I I Possible MDT's P&A _ _ L I _ _ _ .J ..------- o 5 Rig Days I I I _____1_ I I I 10 I I J I~ - I I I I I I ,- -t-----j- - ~ 1 KCLlPolymer Drilling Mud -- - --¡ I I I I I -~----- I I I I I I I I ---ï I I I _. _ _ -,_. I ~ --~~ - I I I J_ ~ I- I I ----I-- I I -------- 15 - Surf - 1000' 1452' - 2000' - 3000' - 4000' c ~ Rig RKB ::: 105 ft Pad Elev::: 72 ft 13-M3", 68#, l-80 Conductor 9-5/8",40#, L-80, BTC 3319' MD /3051' TVD lOT:::: 13.7 ppg EMW 42.5° .......... 75.30 ..... ..... ..... ..... ..... ..... ..... ..... ..... ........ - 5000' - . - . - . - . - . - . - . - . - . - . - . - . - . - . - Tam at 5113' TVD - . - . - . - . - . - . - . - . - . - . - . - . - . - . - -. - . - . - . - . - . - . - . - . - . - . - . - . - . ..... ..... ..... .......... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... ..... 8-1/2" Hole -'-'-'-'-'-'-'-'-'-'-'-'-'-'-Ku P""rul, C ""t 5953' TVI"L - 6000' ... 1\ .. Lr' - . - . - . - . - . - - . - . - . - - - - 7000' I Ataruq #2A I · Build to inclination · Turn left to .:t300.7° azimuth · Hold inclination & azimuth to .:t8896' MD. · Drop inclination to .:t42° · Hold Inclination & azimuth to TD KCL / Polymer Mud MW = 9.8 to 11 ppg ... ..... ..... ..... , " " " " " 420 " " " " ..... , , " " " " " " " .-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-.-. 10813' MD /6200' TVD S. Coyner: 4/14/2005 Halliburton Sperry-Sun Western North Slope, Kerr McGee .. Ataruq #2AWP7.0·· .'. .............................. ......./.. ",';'.:'/:... ..:.:::<,< posal Report 13 April, 2005 Your Ref: New WP Out of CSG. spe""""y-sul! DRILLING seRVices A Halliburton Company . . Proposal Ref: pro44BO 3500 .r:::.. ....... 0... (!) 0 ro 4500 0 t (!) > ..... 5500 II ID ro (,,) (/) 6500 DrillQuest 3.03.06.008 Scale: 1 inch = 1500ft Eastings -4500 -3000 -1500 o Total Depth @ 10812.77ftMD ~~O: 5900.Oft 62000TVD ~<9 9733.100 MD. 5397.65ftTVD TVO: 5100.0ft Hold Angle at 42.000" to 10816.30ft MD V 9283.1 Oft MD. 5114.77ftTVD Continue Drop at 4.000" /100ft to 42.000" 8896.49ft MD. 4967.83ft TVD Start DroplTum at 4.000" 1100ft to 80.000" Inc., 300.790" Azlm. 4500 NO: 4800.Oft TVO: 4600.Oft 3000 NO: 4400.Oft NO: 4200.Oft 4909.57ft MD. 3958.15ft TVD Hold Angle at 75.464" to 8896.49ft MD 1500 3370.00ft MD, 3112.80ft TVD Start BuildlTurn at 4.000"/1 OOft to 75.464" Inc.. 300.729' Azim. 3320.000 MD. Drop/Turn at2.500"/100ft to 41.523' Inc.. 4.064" Azim. ..... o ID ro (,,) (/) 3075.73ft TVD at 2.500'/100ft Inc.,4.0646 Azim. 3112.80ft TVD at 4.000"/100ft Inc.. 300.729' Azlm. 4909.57ft MD. 3958. 15ft TVD Hold Angle at 75.464" to 8896.49ft MD 8896.49ft MD. 4967.83ft TVD Start DroplTum at 4.000'/100ft to 60.000' Inc.. 300.790' Azlm. 9733.1 Oft MD. 5397.65ft TVD Hold Angle at 42.000' to 10816.301t MD Total Depth @ 10812.77ftMD 6200ftTVD o 1000 Scale: 1 inch = 1000ft 2000 3000 4000 5000 Section Azimuth: 6.940° (True North) Vertical Section spl-ry-Sun Drilling sttvices Proposal Data - Ataruq #2 - Ataruq #2 Wp 7.0 13 April, 2005 - 17:37 -1- DrillQuest Halliburton Sperry-Sun Proposal Report for Ataruq #2A Wp 7.0 Your Ref: New WP Out of CSG. Western North Slope, Kerr McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 3320.00 42.136 5.697 2972.88 3075.73 699.71 N 105.88 E 5970227.79 N Drop/Tum at 2.5000/100ft to 41.523° Inc., 4.064° Azim. 3370.00 42.151 3.834 3009.95 3112.80 733.14 N 108.66 E 5970261.22 N 740.90 Start Build/Tum at 4.0000/100ft to 75.464° Inc., 300.729° Azim. 3400.00 42.376 2.081 3032.15 3135.00 753.29 N 109.70 E 4.000 761.02 3500.00 43.313 356.361 3105.50 3208.35 821.22 N 108.75 E 4.000 828.34 . 3600.00 44.524 350.863 3177.56 3280.41 890.09 N 101.00 E 4.000 895.78 3700.00 45.987 345.620 3247.98 3350.83 959.57 N 1 480805.26 E 4.000 962.99 3800.00 47.678 340.648 3316.41 3419.26 1029.31 N ON 480784.25 E 4.000 1029.66 3900.00 49.571 335.952 3382.53 3485.38 1098.98 N .24 N 480756.66 E 4.000 1095.46 4000.00 51.644 331.524 3446.00 3548.85 1 .57 N 480722.62 E 4.000 1160.07 4100.00 53.875 327.352 3506.53 3609.38 5970765.18 N 480682.30 E 4.000 1223.17 4200.00 56.241 323.417 3563.82 3666.67 5970832.71 N 480635.89 E 4.000 1284.46 4300.00 58.726 319.699 3617.58 3720.43 5970898.84 N 480583.63 E 4.000 1343.64 4400.00 61.312 316.175 3667.56 3770.41:< 5970963.25 N 480525.75 E 4.000 1400.42 4500.00 63.985 312.824 3713.51 3816.~~ 5971025.63 N 480462.56 E 4.000 1454.52 4600.00 66.731 309.624 3755.21 3858.06 . 5971085.67 N 480394.35 E 4.000 1505.69 4700.00 1613.69 N 398.99 W 5971143.07 N 480321.46 E 4.000 1553.66 4800.00 1667.99 N 476.35 W 5971197.57 N 480244.24 E 4.000 1598.21 4900.00 1719.10 N 557.66 W 5971248.89 N 480163.06 E 4.000 1639.12 4900.89 1719.54 N 558.39 W 5971249.33 N 480162.33 E 4.000 1639.47 4909.57 1723.82 N 565.61 W 5971253.63 N 480155.12 E 0.000 1642.85 Hold Angle at 75.464° to 8896.400 MD 5000.00 3878.21 3981.06 1768.50 N 640.83 W 5971298.50 N 480080.02 E 0.000 1678.11 . 5100.00 3903.53 4006.38 1817.90 N 724.01 W 5971348.11 N 479996.97 E 0.000 1717.10 5200.00 3928.85 4031.70 1867.30 N 807.18 W 5971397.73 N 479913.92 E 0.000 1756.09 5300.00 3954.18 4057.03 1916.70 N 890.36 W 5971447.34 N 479830.87 E 0.000 1795.08 5400.00 3979.50 4082.35 1966.10 N 973.54 W 5971496.96 N 479747.82 E 0.000 1834.06 5500.00 75.330 300.707 4004.83 4107.68 2015.50 N 1056.71 W 5971546.57 N 479664.77 E 0.000 1873.05 5600.00 75.330 300.707 4030.15 4133.00 2064.90 N 1139.89 W 5971596.19 N 479581.72 E 0.000 1912.04 5700.00 75.330 300.707 4055.48 4158.33 2114.30 N 1223.06 W 5971645.80 N 479498.67 E 0.000 1951.03 5800.00 75.330 300.707 4080.80 4183.65 2163.70 N 1306.24 W 5971695.41 N 479415.63 E 0.000 1990.02 5900.00 75.330 300.707 4106.13 4208.98 2213.10 N 1389.42 W 5971745.03 N 479332.58 E 0.000 2029.01 6000.00 75.330 300.707 4131.45 4234.30 2262.50 N 1472.59 W 5971794.64 N 479249.53 E 0.000 2067.99 6100.00 75.330 300.707 4156.78 4259.63 2311.91 N 1555.77 W 5971844.26 N 479166.48 E 0.000 2106.98 6200.00 75.330 300.707 4182.10 4284.95 2361.31 N 1638.94 W 5971893.87 N 479083.43 E 0.000 2145.97 6300.00 75.330 300.707 4207.43 4310.28 2410.71 N 1722.12 W 5971943.48 N 479000.38 E 0.000 2184.96 6400.00 75.330 300.707 4232.75 4335.60 2460.11 N 1805.30 W 5971993.10 N 478917.33 E 0.000 2223.95 13 April, 2005 - 17:51 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Proposal Report for Ataruq #2A Wp 7.0 Your Ref: New WP Out of CSG. Western North Slope, Kerr McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 6500.00 75.330 300.707 4258.08 4360.93 2509.51 N 1888.47 W 6600.00 75.330 300.707 4283.40 4386.25 2558.91 N 1971.65 W 6700.00 75.330 300.707 4308.73 4411.58 2608.31 N 2054.82 W 6800.00 75.330 300.707 4334.05 4436.90 2657.71 N 2138.00 W 6900.00 75.330 300.707 4359.38 4462.23 2707.11 N 2221.18 W 7000.00 75.330 300.707 4384.70 4487.55 2756.51 N 47841 .04 E 0.000 2457.88 . 7100.00 75.330 300.707 4410.03 4512.88 2805.91 N 478335.99 E 0.000 2496.87 7200.00 75.330 300.707 4435.35 4538.20 2855.31 N 478252.94 E 0.000 2535.86 7300.00 75.330 300.707 4460.67 4563.52 2904.71 N 478169.89 E 0.000 2574.85 7400.00 75.330 300.707 4486.00 4588.85 2954.11 N 478086.85 E 0.000 2613.83 7500.00 75.330 300.707 4511.32 2720., 5972538.86 N 478003.80 E 0.000 2652.82 7600.00 75.330 300.707 4536.65 2803.4f'W 5972588.47 N 477920.75 E 0.000 2691.81 7700.00 75.330 300.707 4561.97 i3?86.58 W 5972638.08 N 477837.70 E 0.000 2730.80 7800.00 75.330 300.707 4587.30 2969.76 W 5972687.70 N 477754.65 E 0.000 2769.79 7900.00 75.330 300.707 4612.62 3052.93 W 5972737.31 N 477671.60 E 0.000 2808.78 8000.00 75.330 300.707 3136.11 W 5972786.93 N 477588.55 E 0.000 2847.76 8100.00 75.330 300.707 3219.29 W 5972836.54 N 477505.51 E 0.000 2886.75 8200.00 75.330 300.707 3302.46 W 5972886.15 N 477422.46 E 0.000 2925.74 8300.00 75.330 300.707 3385.64 W 5972935.77 N 477339.41 E 0.000 2964.73 8400.00 75.330 300.707 3468.81 W 5972985.38 N 477256.36 E 0.000 3003.72 8500.00 4867.42 3497.52 N 3551.99 W 5973035.00 N 477173.31 E 0.000 3042.71 8541.18 4877.85 3517.86 N 3586.24 W 5973055.43 N 477139.11 E 0.000 3058.76 Top Tam 55 8600.00 4892.75 3546.92 N 3635.17 W 5973084.61 N 477090.26 E 0.000 3081.70 8700.00 4918.07 3596.32 N 3718.34 W 5973134.23 N 477007.21 E 0.000 3120.68 . 8800.00 4943.40 3645.72 N 3801.52 W 5973183.84 N 476924.16 E 0.000 3159.67 8896.32 300.707 4864.94 4967.79 3693.30 N 3881.63 W 5973231.63 N 476844.18 E 0.000 3197.23 8896.49 300.707 4864.98 4967.83 3693.39 N 3881.78 W 5973231.71 N 476844.03 E 4.000 3197.29 Start DroplTum at 4.0000/100ft to 60.000° Inc., 300.790° Azim. 8900.00 75.183 300.708 4865.88 4968.73 3695.12 N 3884.69 W 5973233.45 N 476841.12 E 4.000 3198.66 9000.00 71.183 300.728 4894.80 4997.65 3744.01 N 3966.97 W 5973282.55 N 476758.97 E 4.000 3237.25 9100.00 67.183 300.749 4930.33 5033.18 3791.77 N 4047.29 W 5973330.52 N 476678.77 E 4.000 3274.96 9200.00 63.183 300.771 4972.30 5075.15 3838.19 N 4125.27 W 5973377.14 N 476600.91 E 4.000 3311.61 9279.58 60.000 300.790 5010.15 5113.00 3874.00 N 4185.40 W 5973413.10 N 476540.87 E 4.000 3339.89 Target - Ataruq #2 T1 9283.10 59.859 300.790 5011.92 5114.77 3875.56 N 4188.02 W 5973414.67 N 476538.25 E 4.000 3341.13 Continue Drop at 4.0000/100ft to 42.000° 9300.00 59.183 300.790 5020.49 5123.34 3883.02 N 4200.53 W 5973422.16 N 476525.76 E 4.000 3347.02 9400.00 55.183 300.790 5074.67 5177.52 3926.03 N 4272.71 W 5973465.36 N 476453.69 E 4.000 3380.99 13 April, 2005· 17:51 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Proposal Report for Ataruq #2A Wp 7.0 Your Ref: New WP Out of CSG. Western North Slope, Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Easüngs Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9500.00 51.183 300.790 5134.59 5237.44 3967.00 N 4341.47W 5973506.50 N 9524.33 50.210 300.790 5150.00 5252.85 3976.64 N 4357.64 W 5973516.18 N 9600.00 47.183 300.790 5199.94 5302.79 4005.73 N 4406.47 W 5973545.40 N 9700.00 43.183 300.790 5270.41 5373.26 4042.04 N 4467.39 W 5973581.86.N 9729.58 42.000 300.790 5292.18 5395.03 4052.28 N 4484.59 W 597359;2'1p:~ 9733.10 42.000 300.790 5294.80 5397.65 4053.49 N E 0.000 9800.00 42.000 300.790 5344.52 5447.37 4076.40 N 476201.72 E 0.000 9900.00 42.000 300.790 5418.83 5521.68 4110.66 N 476144.33 E 0.000 10000.00 42.000 300.790 5493.14 5595.99 4144.91 N 476086.94 E 0.000 10010.57 42.000 300.790 5501.00 5603.85 4148.53 N 476080.87 E 0.000 10100.00 42.000 300.790 5567.46 5973719.58 N 476029.54 E 0.000 10200.00 42.000 300.790 5641.77 5973753.98 N 475972.15 E 0.000 10252.78 42.000 300.790 5681.00 5973772.14 N 475941.86 E 0.000 10300.00 42.000 300.790 5716.09 5973788.38 N 475914.76 E 0.000 10400.00 42.000 300.790 5790.40 5973822.78 N 475857.36 E 0.000 10480.19 42.000 300.790 5850.00 4916.06 W 5973850.37 N 475811.34 E 0.000 10500.00 42.000 300.790 5864.72 4927.44 W 5973857.18 N 475799.97 E 0.000 10520.56 42.000 300.790 5880.QO 4939.26 W 5973864.25 N 475788.17 E 0.000 10600.00 42.000 300.790 5939103 4984.92 W 5973891.58 N 475742.58 E 0.000 10700.00 42.000 300.790 :6013.3ß 5042.40 W 5973925.98 N 475685.18 E 0.000 10800.00 6ÒSs'li6è 6190.51 4418.93 N 5099.89 W 5973960.38 N 475627.79 E 0.000 f 10812.77 6097.15 6200.00 ~ 4423.30 N 5107.23 W 5973964.77 N 475620.46 E 0.000 All data is in F otherwise stated. Directions and coordinates are relative to True North. Vertical depths B = 102.65· MSL. Northings and Eastings are relative to 47TFNL, 1834.6'FEL. Global Northing gs are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Se 'ty is in Degrees per 100 feet (US Survey). Vertical Section is from 47TFNL, 1834.6'FEL and calculated along an Azimuth of 6.940° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10812.77ft., The Bottom Hole Displacement is 6756.43ft., in the Direction of 310.895° (True). The Along Hole Displacement is 7351.24ft. The Total Accumulated Dogleg is 153.746° The Planned Tortuosity is 1.873°/1000. The Directional Difficulty Index is 5.9. Kerr McGee Comment Moraine 3481.67 Hold Angle at 42.000° to 10816.30ft Me 3499.77 3526.83 3553.88 3556.75 Top HRZ 3580.94 3608.00 3622.28 Base HRZ 3635.05 3662.11 3683.80 Top Kup C ss 3689.16 3694.73 Leu / KUP A ss 3716.22 3743.28 3770.33 3773.79 e 13 April, 2005 - 17:51 Page 4 of 4 DrillQuest 3.03.06.008 Halliburton BAROID Kerr McGee Mud Program KERR-MCGEE CORPORAl ! BAR 010 Ataruq #2A Revised Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Skip Coyner Version No: Date: 1.0 April 14th, 2005 Ataruq #2A v3.0 4/15/05 Halliburton BAROID Kerr McGee Mud Program Ataruq #2A Mud Program General Discussion This exploration well will be drilled near the West Sak 18 gravel pad .±4 miles north-northwest of KRU's 2M Pad. This 8-112" hole will be sidetracked out of the Ataruq #2 surface casing shoe at approximately 3200' MD. The inclination will then be built at 4° / 100' to 75°. This inclination will be held to 8,900' MD. A drop to 42° will begin at this depth and end at 9729' MD. This angle will hold to the proposed TD-MD of 10,813' MD (6200' TVD). As a general drilling fluids plan, drill out the cement and begin the kick off with the existing mud system from the Ataruq #2 well. Centrifuge back this mud to -9.0 ppg while circulating. A large dilution or complete mud swap should be made once we are assured we're off the cement plug. The current system is laden with LGS and needs replaced/diluted. The mud weight for this interval of the well will range from 9.0 ppg at drill-out of the casing to 10.8 ppg by the top of the HRZ. The weight will then be gradually raised to 11.3 ppg for the Kuparuk. The Kuparuk C is over-pressured due to injection and a minimum of 11.3 ppg will probably be necessary. Minimizing drilling waste, effective use of recycled mud, hole-stability, and hole-cleaning are the primary objectives of this drilling fluid system. Special Considerations 1. Waste minimization is critical to the success of this well. 2. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@1500 sxs barite on location at all times). 3. 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. 4. The Tabasco formation (if present) is possibly depleted and volumes must be monitored carefully to detect losses. Also, LCM should be strung in while drilling this formation to minimize losses and the potential for differential sticking. The Tarn formation may also be depleted and similar measure should be taken while drilling it. Well Specifics: Casing Program MD TVD Footaae 9-5/8" casing 3320 3075 3320 8-1/2" hole ( casing) 10813 6200 7493 Formation Tops/CasinQ ProQram TMD TVD 9 5/8" casing 3319' 3051' Colville 3319' 3051' Tarn Target 9280' 5113' Morain 9524' 5253' TopHRZ 10111' 5603' Kuparuk C 10480' 5953' LCU/Kuparuk A 10552' 5983' TD 10813' 6200' All geologic picks should be referenced from the geologist. Comments Mud Wt 8.8-9.0 8.8-9.0 Weight up Over-pressured 10.8 11.3-11.5 Ataruq #2A v3.0 2 4/15/05 Halliburton BAROID Kerr McGee Mud Program Production Hole Mud Properties: (8 %" Hole to 1 0,813') Mud Type: KCL I Polymer System Mud Properties: Density PV YP WL HTHP a!:! CI Initial 9.0-9.2 10-20 25-30 <6 N/A 8.5-9.5 50K T/HRZ - TD 10.8-11.5 10-32 11-20 <4 <10 8.5-9.5 50K . Additional mud weight may be required tripping and logging purposes. System Formulation Fresh Water KCI EZ Mud DP PAC-L Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav D Production Interval Mud Type: 1. Mud weight: 2. Rheology: 3. Other issues: .95 bbl 37 ppb .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb 1 .0 ppb .5 ppb (ionic inhibition/50.5K ppm chlorides) (polymer encapsulation) (API filtrate of 6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) ( X-Cide 207 for rig maintenance) (as needed) (corrosion inhibitor) (to be added at rig) 9.0 ppg KCI/EZ MUD System. Maintain the density at 9.0 ppg, weight up to 10.8 ppg by the T/HRZ, then gradually increase the mud weight to .±11.3 ppg by the Kuparuk C; use solids control and whole mud dilution. Increase density as required for hole stability. Maximize solids control usage. Maintain a YP between 11 and 20. Pump weighted or Barolift sweeps throughout the interval as needed, particularly prior to POH for logging. Optimized mud rheology, RPM's and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated well bore. Maximize pipe rotation (ideally 2:: 150 RPM). The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. By the T/HRZ, reduce the HTHP to < 10 cc 30 min with BARANEXlBAROTROL treatments. Operations Summary: The existing mud from Ataruq #2 will be used to drill the cement and get kicked off. A whole mud swap out is then recommended as there is a build up of LGS in the existing system. Drill out with a 9.0 ppg, weight up to 10.8 ppg by the T/HRZ, then gradually increase the mud weight to .±11.3 ppg by the Kuparuk C. Additions of BARAZAN D should be made to maintain the YP. Maintain the filtrate at <6 with PAC Land DEXTRID. A 4-6 ppb BARAN EX treatment should be made prior to entering the HRZ. Target a <10 HTHP. A spike fluid is recommended for the Ataruq #2A v3.0 3 4/15/05 Halliburton BAROID Kerr McGee Mud Program weiaht UP and BARAN EX treatment. The pH will be kept in the 8.5 - 9.5 range with KOH. Additions of KCI will be made to keep the chlorides in the 50K range. Daily additions of X-Cide 207 should be made to control bacteria. Lubrication will be required. Additions of ~% Drill-N-Slide and 2% of EZ Glide or Torq Trim II can be made. These additions can be raised to 5% if required. If metal to metal torque is present, additions of up to 1 % EP Mudlube should be made. Always ensure that calcium levels are below 120 and at least ~% Drill-N-Slide is present prior to adding EP Mudlube For formation bridging/LCM, graded calcium carbonate (Baracarb(s», cellulose fiber material (Barofibre) and SteelSeal are available. Baracarb 50 and I or Micatex should be strung into the system should seepage losses occur. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM- 450 500 550 120 rpm 201 284 361 150 rpm 224 332 408 Risks and Continaencies for the well: Lost Circulation: Preventing the initiation of lost returns should be a primary goal of the drilling fluid in the well. To that end the rheology of the system has been reduced while still providing ample hole cleaning. Maintaining a low ECD while circulating, and eliminating high pressure spikes while tripping, will both go a long ways toward reducing the risk of lost returns. Wellbore Instability: The possibility for running shale exists, particularly in the HRZ. Should this occur, weight up in increments if 0.4 ppb. BAROTROL additions should be made to plaster the walls. Also, maintaining a tight filtrate and high water-phase salinity (50K) will help minimize the risk. Stuck pipe: Two forms of stuck pipe are possible. One is from hole pack-off as related to poor hole cleaning, i.e. cuttings bed. Stuck pipe can occur if a cuttings bed forms, or if the wellbore exhibits severe instability. The best cure is to pro-actively prevent the occurrence of either scenario in the first place, and if they do occur, correct drilling practices must be employed. If pulling up into a tight spot, do not jar up further, but attempt to get below the problem. Backreaming a large cuttings bed is an invitation to packing off and resulting stuck pipe, and backreaming must be done with care and only when necessary. If stuck pipe occurs across a sand and there are indications of differential sticking, there are drilling fluid solutions. If possible, reducing the mud weight by at least 0.5 ppg may provide some relief (unless the HRZ is open - do not reduce weight in this case). Hole Cleaning: Maintaining the programmed flow properties is essential to successful completion of this well. Any indication of a failure to keep the annulus clean of excess cuttings (PWD increases, drag, torque, partial packing off) should be countered by increasing the circulation time on subsequent connections and prior to trips. Pipe rotation should also be used in conjunction with the pumping of high viscosity sweeps in the pay sands. The returns at surface of all pills should be monitored Ataruq #2A v3.0 4 4/15/05 Halliburton BAROID Kerr McGee Mud Program at the shakers and documented to gauge their effectiveness. When circulating bottoms up prior to POH, it is advisable to pull one stand every half hour to reduce the hole washout effects of circulating over one short interval. Long circulation times should be avoided if the bit/BHA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. Hiqh speed pipe rotation is the most critical factor for hole cleaninq. ROP rates above the recommended levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: · wiper trips · back reaming · extended periods of circulation (with maximum pipe rpm, targeting ~ 100 rpm) · hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) · connection practices - employing extended gpm, rpm and back reaming during the connection Fluid Volumes: Production Interval: Reconditioned mud from Ataruq #2 will be used to drill the cement. Prior to drilling out, approximately 500 bbls will be in the pits and 120 bbl will be in the hole. Dilution rates for the 8- 1/2" hole section are anticipated to be .±.0.35 bbl/ft. Estimated Fluid DisDosal Volumes: P10 P50 P90 Initial Volume 520 620 720 Dilution 1000 1300 1780 Total 1520 1920 2500 Estimated Drill Solids DisDosal Volumes: P10 P50 P90 ... Cuttings Volume 140 200 200 Wettinq Fluid 70 200 350 Total 210 320 550 Fluid Costs: P10 P50 . P90 .. .' 8 1/2" Production $150,500 221,000 $319,000 Total $150,500 $221,000 $319,000 Ataruq #2A v3.0 5 4/15/05 BAROID Kerr McGee Production Hole Cleaning bOoo 5 10 15 20 250 50 1000 230 459 i IlkrnlT rÎo'~ 1000 2000 3000 4000 5000 7000 8000 9000 10000 At an ROP of 200'/hr, ECO will be 12.4 ppg by TO. The above graph illustrates a mode with excellent hole cleaning. The pump rate can be lowered to 450 gpm with cleaning and a reduced ECO (at 150 rpm). · . @ KEIlR-MCSEE CORPORA 110N April 14th, 2005 Ataruq #2A - Revised Kerr McGee Oil & Gas Corporation Abnormal Pressure Analysis Attached is a graphical representation of the known offset fonnation pressures and extrapolations/predictions made based upon that data. This well, Ataruq #2A, is located just west of the KRU near the West Sak 18 location. Ataruq #2 is due west of the Tabasco field, and lies between Tam and Palm. The pressure gradients used to extrapolate/predict fonnation pressures in Ataruq #2A came from nearby field data and will be updated with Ataruq #2 actual data. ~ As always, gas hydrates are of concern and /' precautions will be taken, however since the KOP is below existing surface casing set in the Colville, the presence of hydrates are unlikely. This sidetrack will be drilled with a BOP stack. The predicted pressures in potential hydrocarbon-bearing fonnations were derived in the following manner using predicted TVD's and known gradients: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (I bIg a I) T/Middle Brookian 8,541' 4,615' 2,052 8.55 T/Tarn 9,280' 5,113' 2,273 8.55 T/Moraine 9,524' 5,303' 2,358 8.55 T/HRZ 10,011' 5,784' 3,008 10.00 T/Kuparuk C 10,480' 5,953' 3,450 11.13 T/Kuparuk A 10,520' 5,983' 3,460 11.12 » Due to potential inaccuracies with the seismic velocity, these formation tops may change The Ataruq #2A will be drilled using experience gained while drilling Ataruq #2 and at ./ Palm, which includes abnonnal pressure in the Kuparuk "C" with nonnal pressure in the Moraine and Tam above. / ¿1£/7~ ASRC Energy Services 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6269 Predicted Formation Pressures "\, I I I " " \, ~', -'I" , "''I" wJi?l1 U_M m -'\ þ~/ (P, IT' n 1/ r ., 1"\ / "'I, f', '\ I r',. I I I I I I f'", i I I í I I í I I I I I r'~ ~"'''Sdl ! i"', - T'" ~ t'" I firt, 1/\ < , , "''I, , I', . I I , I I I i I I I I , i I i I I I I I ] I I I I I I I i I I I I I I I I o 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 Predicted Pressure ·0 -500 -1000 -1500 -2000 -2500 -3000 -3500 - -4000 m G) UJ . .a -4500 ~ UJ - J: - -5000 Q. G) C -5500 -6000 -6500 -7000 -7500 -8000 . . Shallow Drilling Hazards Evaluation Kerr McGee Ataruq #2 and 2A Locations Alaska State Lease ADL 390502 Colville Delta Area, North Slope, Alaska Summary Pursuant to 20AAC 25.061, available data from proximal wells (Sinclair Colville #1, Atlantic Richfield West Sak #18, Kuparuk River Unit 2T pad) and pertinent geophysical data have been evaluated for evidence of any shallow to intermediate depth drilling hazards. Mudlogs and wireline logs from these wells indicate insignificant amounts of natural gas hydrates and/or free gas in sands and gravels of the Ugnu Formation associated with or immediately below ice in the permafrost wedge. Either of these wells may encounter moderately low gravity, low GOR oil in the Tabasco Sandstone. None ofthese conditions are considered pit of the realm of normal drilling conditions. Additionally, available seismic data does not define any anomalous shallow hazard zones. Location The Ataruq Prospect is located immediately east of the southwestern lobe of Kuparuk River Unit, situated on the low-relief Arctic coastal plain east of the Colville River Delta (Fig. I; location map). Both Ataruq wells will be drilled from an ice pad. The proposed surface location is 477' FNL and 1834.6' FEL of Section 8, TIIN, R8E of the Umiat Meridian. The bottom hole location of Ataruq #2A is projected to be 1334' FNL, 1662' FEL, Sec. 6, TIIN, R8E. This well will be drilled to a maximum depth into the Miluveach Formation. Geology: Local Stratigraphy Ataruq #2A will penetrate strata ranging from the top of the Colville Formation, and into the uppermost beds Miluveach shale (Fig.2; wellbore diagram). Reservoirs that may contain significant hydrocarbons include several Cretaceous-age intervals including the Middle Brookian, and Tam sandstones, as well as the underlying Kuparuk Formation (Fig. 3: strat column). The Late Cretaceous Colville Group is comprised (from younger to older) of the Ugnu Formation, Schrader Bluff Formation (also known as the West Sak Formation) will all be behind pipe in this sidetrack. The KOP is in the Colville Mudstones. The Colville Mudstone is approximately 3000' thick in the Ataruq Prospect area. This thick sedimentary package consists of inter-bedded shale and siltstone. The Tam Sandstone occurs at the base of the Colville Mudstone. The Tam Sandstone is the main hydrocarbon reservoir at the Tam Field located 6 miles south of the Ataruq location. Underlying the Tam and Morain sandstones is the radioactive shale known as the HRZ (highly radioactive zone) and the silty shales ofthe Kalubik Formation. The Kalubik overlies the Kuparuk Formation. The Ataruq 2A borehole should encounter potentially oil productive sandstones in the Kuparuk C and Kuparuk A members. This wildcat well will reach total depth in siltstones and shales of the Miluveach Formation. . . Geophysics The 3D seismic grid (WBA Survey - 1997) covering the Ataruq area was analyzed for potential shallow and intennediate depth drilling hazards (Fig. 4). This seismic data was then compared to wireline logs, mud logs and scout infonnation from uphole sections in wellbores in the immediate area. There is no geophysical evidence such as amplitude anomalies or velocity sag suggesting the proposed Ataruq #1 and #2 wells will encounter any fonn of shallow entrapped natural gas, or intersect any conductive faults. Potential Shallow Drilling Hazards Pennafrost This interval is behind casing in this sidetrack well. Shallow Hydrocarbon Accumulations This interval is behind casing in this sidetrack well. Anomalous Geopressured Zones Data from offset wells including mudlogs, scout tickets, and data from the Alaska Oil and Gas Conservation Commission indicates that the Ataruq #2A borehole should encounter "nonnally" pressured strata through and including the Morain sandstone. Geo-pressure nonnally increases in the HRZ which typically requires 10.6 ppg mud weight or higher to drill through. Kuparuk Fonnation sandstone reservoirs in the Ataruq wells are likely to be above nonnal pressure gradient. The original reservoir pressure at Kuparuk Field was 3135 psi; current reservoir pressure is 3450 psi. This "supercharging" due to injection at Kuparuk Field was also observed during the drilling of the Palm extension to Kuparuk Field. Here, in a geologically analogous setting to the Ataruq Prospect, reservoir pressures when drilled were approximately 500 psi over projected original reservoir pressure due to the enhanced oil recovery program at Kuparuk Field. Conclusions No drilling hazards associated with natural gas hydrates, shallow trapped natural gas or oil are anticipated in the drilling of the Ataruq #2A well, primarily because these anomalies are behind casing. The only applicable hazards are geo-pressures encountered in the HRZ and the Kuparuk C. The Kuparuk C, of course, is induced pressure from nearby injectors. . ::~----------------- ~ -------~-------------- \rl ';:::- 2' 6 1/8" ; 3/8.1 ___~:o~!~~ V~VE ___ r ;s" 5000; HeR VALVE " ID 5/B' T--- ,: ~ .;..- 2' Ii 1/8" 3/8" ------- - - - CUS'TOMER FURNISHED ::-... BOP STACK ELEVATION ~ :~~ T 2' O· ------- i I --+--- I I ~ 24" DIA. '-16" KNIFE GAlE WI H'tD. AC1'UAlOR SURFACE DIVERTER CONFIGURATION 16"-150# FLG 13 5/B" 5000' HYDRIL ANNULAR BOP BOLTED FlJiNGE SINGLE 13 5/8" 50001 HYDRIL MPL PIPE RAM BOLTED FlANGE SINGI..E 13 5/8" 500Di HYDRIL MPL BUND RAM BOLTED FlJiNGE <II." SOOOf HCR VALVE II .. 4" CHOKE UNE 4" 50001 GATE VALVE BOlTED FlANGE SlNGI.f 13 5/8" 5000' HYDRIL MPL PIPE RAM BOLTED FlANGE ADAPTER SPOOL - HUB x FlANGE 21 1/4" 2000# HYDRtL BOP/DIVERTER ..-..-..--.-..-..-..-.. .._.._.._.__.._.._u "-"-..-"-"-..-"-O·l ..-.,-..-,,-..-..-.. 25'-11" ,,,-' ""', I \ I 0+ ' I " \ I , I '... ' REWAUS---~ SURFACE DIVERTER PIPING CONFIGURATION PLA~ VIE'« 12/011III1 E J,A R.Ie, 08/0411II B TB '1M 02/21/87 C RIB RIB 07/27/85 B DWB LA 08/01/83 " 10£ LA lIME U·" 7 1 5' . i ¡ , ¡ t ~ ° ! f I :¡. J ~ ' I Proposal for Arctic Drilling Rig with Crew 'L.",OF Nabara AIøúa DIlling Inc. Z525 C StrMt. SUII1i 2DD Ancharage. J\IaIIa 11503 107-w-;eooo MODIPIED ONER'IER SZE (II") I CONFlGURA'IICIN CHIINØED Cl.WP CONNECTION 11) BOLTED FlANGE REVISED DNERIER AS PI!R OCN '3 GENERo\L ISSUE GENERo\L ISSUE Di!SCRfPIIDN ~ .~ ~~ ~'j cQ¡ . . . FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 April 14, 2005 Mr. Ted Moore Department of Environmental Conservation 555 Cordova Street Anchorage, Alaska 99501-2617 Re: Revised Response Planning Standard for Kerr-McGee Ataruq Exploration Well Sidetrack (Permit to Drill #205-056) Dear Mr. Moore, This document confirms receipt of your request, dated April 12, 2005, regarding validation of the potential flow rate from an uncontrolled flow of the Ataruq #2A Sidetrack ("Ataruq #2A") well. Kerr-McGee ("KM") has applied to revise the Response Planning Standard ("RPS") for this well, reducing the regulatory default volume of 5,500 barrels per day ("bpd") to 2,000 bpd. KM is basing this request on information obtained from production test of the Kuparuk River 2A-22, 2A-25, and 2T-22 wells obtained in 1995 through 2005. Determination For the purposes of the RPS, the most likely case would be 2,500 bpd, based on drilling and test information from two exploratory wells located less than 5 miles away. Discussion The Kuparuk River Formation ("Kuparuk") has proven productive across the North Slope. During 2005, KM planned two wells to the Kuparuk at the Ataruq drill site, which is located on the west side of the Kuparuk River Unit ("KRU"), three miles west of the KRU 2T-Pad. The initial well, Ataruq #2 has been drilled and KM has presented plans to plug that penetration. There are several exploratory wells within 6 miles: West Sak #18, about 1 mile to the south, West Sak 25548 #11 ("West Sak #11") about 4-1/2 miles east-northeast, and Palm #1 and Palm #lA (since renamed KRU 3S-26), about 5 miles north- ,. Mr. Ted Moore April 14, 2005 Page 2 of 4' . . # northwest. In addition, there are several Kuparuk production wells within 1- 1/2 miles of the Ataruq drill site. These include 2A-22, 2A-25, 2T-22, and 2T- 39. Commission records from these wells were examined to estimate the open hole flow potential from the Ataruq #2A well. West Sak #11 was drilled and tested in January and February of 1978. The mudlog records 9.0 ppg at 530 feet, 9.3 ppg at 1,500 feet, 9.0 ppg at 2,820 feet, 9.0 ppg at 3,530 feet, 9.2 ppg at 4,220 and 4,670 feet, 9.6 ppg at 5,780 feet, and 10.0 ppg at 5,680 feet. The well logs record 9.4 ppg mud at 2,311 feet and 10.3 ppg at TD of 6,062 feet. This well encountered a total of 58 feet of net, oil-bearing sand between 5,726 and 5,890 feet. The well was perforated from 5,778 to 5,806 feet at four shots per foot, and from 5,822 to 5,850 feet with eight shots per foot. The maximum reported rate during the ensuing flow test was 2,160 barrels of oil per day ("BOPD"). West Sak # 18 was drilled, then plugged and abandoned without testing in March and April of 1981. The well encountered 64 feet of net, oil-bearing Kuparuk sand between the measured depths of 6,319 to 6,383 feet. Mud information is sparse for the well: the mud log records 9.0 ppg at 275 feet, 9.1 ppg at 1,000 feet, 9.0 ppg at 1,850 feet, 9.2 ppg at 2,552 feet, 9.4 ppg at 4,100 feet, 9.5 ppg at 5,301 feet, and 10.3 ppg at 6,340 feet. The well log records 9.5 ppg at 2,535 feet, and 10.4 ppg at TD of 6,625 feet. Conventional core recovered from the well displayed 50 - 90% light to moderate, irregular oil stain, with some dead oil on fresh, fractured surfaces, and oil bleeding from sparse, hairline fractures. The operator's geologist described the core as displaying a very poor show. Palm # 1 was drilled, then plugged and abandoned without testing in February 2001. Petroleum News Alaska reported on May 28, 2001 that Palm No.1 encountered 30 feet of oil-saturated Kuparuk at a depth of about 5,800 feet subsea. While drilling Palm # 1, operations reports indicate that pressure increased abnormally below a depth of 4,306 feet. The well flowed twice. The first flow occurred at 6,286 feet, while drilling with 10.2 ppg mud. The second flow occurred at 6,442 feet while drilling with 11.0 ppg mud. The operator ultimately increased the weight of the mud to 12.2 ppg before drilling ahead to total depth. The source of this unexpected pressure was injection within the Kuparuk field, approximately 4 miles to the east. Palm # 1A was drilled about 1-1/4 miles to the east-northeast of Palm # 1 during February and March of 2001. Operational records from Palm #lA show that 12.2 ppg mud was also needed to control the well while drilling through the Kuparuk. Again, the source of this abnormal formation pressure was injection within the Kuparuk field, approximately 3 miles to the east. Palm # 1A was tested during April 2001. Petroleum News Alaska also reported on Mr. Ted Moore April 14, 2005 Page 3 of 4' . . I May 28, 2001 that "Palm No. lA tested at an unstimulated rate of about 2,500 barrels per day of 26-degree API gravity oil." Commission records indicate that a 90-foot Kuparuk interval from 5811' to 5,845' true vertical depth ("TVD") was perforated underbalanced with five shots per foot. During testing, production stabilized at a rate of 2,350 BOPD, 873 thousand standard cubic feet of gas per day ("MSCFPD"), with 0 barrels of water per day ("BWPD"). The gravity of the oil was reported to be 27 degrees API. Production information supplied by Kerr-McGee for KRU wells 2A-22, 2A-25, and 2T-22 indicate un-stimulated wells flow a maximum of 1,634 barrels of fluid per day (1,586 BOPD with 48 BWPD), and 1,538 MCFPD of gas, and that stimulated wells flow a maximum of 1,773 barrels of fluid per day (1,759 BOPD with 14 BWPD), and 2,531 MCFPD of gas. Other than the specific comments regarding the Palm penetrations, Commission records do not show any unusual events during drilling operations in the Kuparuk in the remainder of these KRU exploratory or development wells. In Ataruq #2A, KM hopes to encounter rock similar in quality to that found in West Sak #11, West Sak #18, and Palm #1 and Palm #lA. There are no plans to test the Kuparuk reservoir in Ataruq #2A. This wellbore section will be drilled to total depth, logged and plugged with cement according to AOGCC regulations. Assessments Well Flow Rate The Kuparuk has been demonstrated capable of flowing without stimulation in this area. West Sak # 11, drilled prior to field development, flowed 2, 160 barrels per day unstimulated. Palm # lA was capable of flowing about 2,350 barrels of oil per day unstimulated. The nearby production wells further demonstrate that un stimulated Kuparuk reservoir sands are capable of flowing at substantial rates. Palm # 1 and # lA indicate that injection pressure can be transmitted long distances through the reservoir. For the purposes of the RPS, the most reasonable case would be 2,500 bpd, based on well and test information from the Palm #lA and West Sak #11 exploratory wells. Control Scenario KM has employed the knowledge available from the other Kuparuk penetrations in the area, especially Palm # 1 and Palm # lA. The mud program employed drilling Ataruq #2 was designed specifically to control elevated formation pressures due to communication with the Kuparuk enhanced recovery project and a similarly weighted mud is planned for Ataruq #2A. With the wellbore overbalanced prior to penetrating the Kuparuk, a portion of the hydrostatic overbalance would need to be lost in order for formation fluids to Mr. Ted Moore Apri114, 2005 Page 4 of 4 . . enter the wellbore. Lost circulation was not reported in Ataruq #2 nor in the offset wells examined for this determination. A BOP stack with redundant closure devices will be in place on the well as required by AOGCC regulations. KM is planning to pressure test the BOP prior to beginning drilling operations on Ataruq #2A. Given the overbalanced well bore condition planned prior to penetrating the Kuparuk and the BOP stack, loss of well control is highly unlikely. In the unlikely event that well control is lost, KM plans to regain control within three days by employing weighted mud. As discussed, kill weight mud should already be in the hole. Increasing the weight if necessary and pumping such fluid is an acceptable way to further overbalance the productive formation and prevent flow. KM's control plan should be effective. Please contact either Steve Davies (793-1224) or myself (793-1250) with any questions. A.omas E. Maunder, PE Sr. Petroleum Engineer SinCerelY.' ~... .. ~=+ . Stephen F. Davies Petroleum Geologist ~ cc: Lydia Miner, ADEC Reading File e e Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and lor privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: ~~KJ J -~ '\ C>-- \-\.\: Nè c-- From: \ô~~vS0«ç [ ~<è ~\<.:..?- Fax#: d-Gq-~Coç~ Date: ~c\ \ '--\ \~ S Pages (including r::-- cover sheet): ':> Phone #: Subject: Q·,\/S ~~"U<:.... ~ d-~ y Message: T~ (L't'&~t ~(è ,,\"'J \ ~ \- ~C\J V\E: 0-...~ V ~(éCcC;t2 CC'- ,-" w r CÀ~ 'i '\,.-0'èSVt <Ð I'-... '> , If you do not receive all the pages or have any problems with this fax, please call for assistance at 907 793-1223. e JOB STATUS REPORT e TIME NAME FAX# TEL# SER.# 04/14/2005 14:32 AOGCC 9072757542 BR02J2502370 DATE, TIME FAX NO./NAME DURA TI ON PAGE(S) RESULT MODE 04/14 14:31 2597587 00:01:01 05 OK STANDARD ECM Re: Kerr McGee's Atarug Exploration Project e e Subject: Re: Kerr McGee's Atarug Exploration Project From: Thomas Maunder <tom _ maunder@admin.state.akus> Date: Thu, 14 Apr 2005 12:16:51 -0800 To: "Miner, Lydia" <Lydia_Miner@dec.state.akus> CC: "Moore, Ted" <ted_Moore@dec.state.akus>, Steve Davies <steve_davies@admin.state.akus> Probably gets to splitting hairs. The objective hydrocarbon formation is about 3000' vertical feet below the presently set casing shoe. There is a significant length of "non-hydrocarbon" bearing formations that must be drilled before maybe 80' to 100' of payzone will be encountered. Steve and I are wrapping up our work with regard to the RPS change and would hope to have it to you later today. Tom Miner, Lydia wrote: The condition of approval in the plan states that "all drilling operations into hydrocarbon bearing formations for the Kerr-McGee Two Bits Prospect must be completed by April 15th of each drilling season that the plan approval is in effect." I guess we can have a discussion about what "drilling operations" actually entail at some point in the future, but until then, if KM is drilling in a hydrocarbon formation, not just penetrating, but drilling, after April 15, they are in violation of their c-plan. If KM is conducting operations to abandon the well, and those operations go past April 15, that is OK. Lydia. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, April 14, 20058:11 AM To: Moore, Ted Cc: Miner, Lydia; Steve Davies Subject: Re: Kerr McGee's Atarug Exploration Project Thanks, Steve and I are working on the response to your request. If the extension is not approved, KM will still need to conduct operations to abandon the Ataruq 2 that will likely take them beyond 2400 April 15. Tom Moore, Ted wrote: Based on conversation with Lydia the lack of an approved plan will result in the total halting of operations. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, April 14, 2005 7:44 AM To: Moore, Ted Cc: Miner, Lydia; Steve Davies Subject: Re: Kerr McGee's Atarug Exploration Project Ted, Is the "prohibition" to penetrating a hydrocarbon bearing interval or a total halting of operations?? They will be plugging the initial penetration (I have their proposal) and then preparing to exit the 9-5/8" casing at about 1900'. They will set a "short" liner so the 2A is configured similar to the initial well before they even begin to drill the hole section that will be used to "look" for the Kuparuk sands. I would estimate that they will not be ready to start drilling that final hole section until about Tuesday or so. Thanks, Tom Maunder 10f2 4/14/20052:55 PM Re: Kerr McGee's Atarug Exploration Project e . Moore, Ted wrote: They'll need an approval from us before April 15th in order to keep on drilling otherwise they'll have to stop. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 12,20057:41 AM To: Moore, Ted Subject: Re: Kerr McGee's Atarug Exploration Project Ted, What is the timing on this matter?? Tom Moore, Ted wrote: Tom, As you are aware Kerr McGee is amending their plan to reflect a lower response planning standard volume (rps) for their Atarug exploration project in an effort to get approval to drill beyond April 15, 2005. In the scenario sent to us the new rps is 2,000 bblslday with the well being capped in 3 days with drilling mud with a total rps of 6,000 bbls. Before we can approve such an amendment we will need written concurrence from you with the Kerr McGee submittal. Thanx Ted 20f2 4/14/20052:55 PM RE: Ataruq RPS change e e Subject: RE: Ataruq RPS change From: "Durkee, Todd" <TDURKEE@KMG.com> Date: Wed, 13 Apr 2005 13:25:51 -0500 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Bob Britch <bbritch@alaska.net>, "Ext - Coyner, Skip (ASRC)" <Skip.Coyner@asrcenergy.com> Tom, The basis of the 2000 BOPD scenario is based on production data available on the AOGCC website. Below is well test data from wells along the fringe of the field and closest to our Ataruq prospect for your review. We would expect the reservoir character to be analogous to our prospect. Based on the non-stimulated / flowing test data available, we believe 2000 BOPD event is reasonable. Well Date Comments 2A-22 June 1995 Non-stimulated - Flowing 2A-22 July 31, 1995 1634 Stimulated - Gas lift 2A-22 Feb 2005 Stimulated - Gas Lift 2A-25 July 07, 1995 Stimulated - Gas lift 2A-25 Feb 2005 Stimulated - Gas lift 187 2T-22 Sept 29, 1995 Stimulated - Flowing 2T-22 Feb 2005 Stimulated - Gas Lift 1773 Regards, Todd Durkee BFPD BOPD MCFPD BWPD 790 461 329 1586 48 1538 965 187 778 175 12 180 4216 708 3509 1759 14 2531 341 281 60 348 175 555 1244 ---------------------------------------------------------- KERR-McGEE OIL & GAS CORPORATION Drilling & Completions Operations Manager 16666 Northchase Drive, Houston, TX 77060 Office: 281-673-6423 eFax: 281-673-4423 Cell: 281-639-3463 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, April 12:-'20-6-Š-1Õ"744 --Aï\1----------------------- To: Durkee, Todd; Ext - Coyner, Skip (ASRC) Cc: Bob Britch Subject: Ataruq RPS change All, I did get a message from Ted Moore at DEC on this matter and I have received the scenario from Bob. AOGCC will also need documents similar to what was sent directly to us on the "design basis/analogue" for Nik #3. I am aware of some of the flow analogues from discussions with Todd, however we will need the case in writing. As I understand, the "stop drilling date" is presently April 24 correct?? Tom Maunder, PE AOGCC 1 of 1 4/14/20052:54 PM Additional data e e Subject: Additional data From: "Durkee, Todd" <TDURKEE@KMG.com> Date: Wed, 13 Apr 2005 13:42:45 -0500 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: Bob Britch <bbritch@alaska.net>, "Ext - Coyner, Skip (ASRC)" <Skip.Coyner@asrcenergy.com> «KRU 2A-22 well tile.pdt» «KRU 2A-25 well tile.pdt» «KRU 2T-22 well file.pdt» «KRU 2T-38A well tile.pdt» «KRU 2A-22 production data.xls» «KRU 2A-25 production data.xls» «KRU 2T-22 production data.xls» «KRU 2T-38A production data.xls» Thanks tor your help. Todd Durkee ..............- KERR-McGEE OIL & GAS CORPORA TION Drilling & Completions Operations Manager 16666 Northchase Drive, Houston, TX 77060 Office: 281-673-6423 eFax: 281-673-4423 Cell: 281-639-3463 hnportant Notice! If you are not the intended recipient of this e-mail message, any use, distribution or copying of the message is prohibited. Please let me know immediately by return e-mail if you have received this message by mistake, then delete the e-mail message. Thank you. KRU 2A-22 well Content-Description: KRU 2A-22 well file.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: KRU 2A-25 well file.pdf 2A-25 well file.pdf Content-Type: application/octet-stream Content-Encoding: base64 2T-22 well Content-Description: KRU 2T-22 well file.pdf Content-Type: application/octet-stream Content-Encoding: base64 2T -38A well Content-Description: KRU 2T-38A well file.pdf Content-Type: application/octet-stream Content-Encoding: base64 10f2 4/14/20052:54 PM Additional data It e Content-Description: KRU 2A-22 production data. xIs 2A-22 production data.xIs Content-Type: application/vnd.ms-exceI Content-Encoding: base64 Content-Description: KRU 2A-25 production data.xIs 2A-25 production data.xIs Content-Type: appIication/vnd.ms-exceI Content-Encoding: base64 Content-Description: KRU 2T -22 production data.xIs 2T -22 production Content-Type: application/vnd.ms-exceI Content-Encoding: base64 Content-Description: KRU 2T-38A production data. xIs 2T -38A production Content-Type: application/vnd.ms-exceI Content-Encoding: base64 20f2 4/14/20052:54 PM Ataruq Exploration idetrack Determ ination Map SFD Ataruq 2 Exploration Sidetrack 2050560 SFD N ~ . VERIFY THE CITY OF·HIIS UND .AREA CHANGE '-;/~Y7¡'}~~~; l~F~;~~~fST~ ¡..~ . . , . /.' ;::hffk?f<::7:~~/ . ~ / ¡ ~ ?; c;.; ,-, ," ~ \ ,\ : SJ<A; NA ; ;; j, 13 '7 AP~ , "'/' \?J)?"~S~,=,'e:~e~~~}~~~~i~~~")' Ji ,~~'" "'/t~~~ AS~A,n,(/) (,)Ji. '- "PAYt ¡SA OUMJ;.;cJ";.:::¡ :',/ ., "'" ~\",·,~;.""~,,,;;,(·~·"'~"'r·~ if':ê; '.'¡'.{¡.. i..,i /,;'.,:~>.~.t':,'.'<.:":"'",'.''''',''_,'' .,,~ ~'" '. ...:...~...,'-$:ID./: O.i.. .qt{·"'c,/ l,,/ 3~ÓO~.ST~Ú (,; ~/,\ i) ';: ~,:/; C / './J'" \~PA.y~..,.·, .0,.. ,~~~'~~~~~;~LASK~'~,?5b3 ' ,,/:.. ";</ /~ONL~CTšcTS> '. '(> ,,~" n >':.::."":'" ':'; :': :' è :'-'_<">" '~~.,~" ,,'-';~; -"::','~ ":, :~. ': -,' ..._""" PAY. ONE HUNDRED DOLLÂ.RS 'AND 00 CÈ.NTS **~'**~, *\**~*~*¡* ** * ****'* **~* *.****;**~* * * * * *** *** Ú****** ************* ********~ '" * * *' * * * *** * *** * * * VOID OVER $100.00 . ~ ~ o z ~ f1 STATE OF ALASKA ¿;urlOFOIL & GAS CONSERVATION COMMISION 333 WEST 7TH AVE STE 100 ANCHORAGE, AK 99501 ~ ' r II' ~ 01:.1, ~oll' .: ~ 25 WOO 5 1': ~ 1°' 182 1 ~ ~II' Ix.lCx~(~ ~I~ ~ 1-V x:V ret f~(~'I[L~G lor.~\)Y' ;J ~I. ~ l/V' , ~~~ to¡. d:Þ' D0 ý. '~Itt .(ìV rJI6 I v'J1 ;/' tk' ~ e . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANS MITT AL LETTER WELL NAME ~ 2A PTD# ZO.Ç - 0 E~/~~~..:$J~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well _, Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(t), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/iniect is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. ~. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01105 C\jody\transm ittal_ checklist l<-e-~'^- f¿¿ -!o ~4-r. ~O· k {/~DS- __ Well bore seg Annular Disposal On - Ataruq 2. EXP Uni 00000 On/Off Shore -- for _a_ ~idetraGkof exi~tiog exploratol)' wel Program Well Name: Ataruq 2A EXP /1-0IL GeoArea ~ 1\10 tee require_dJor _thi~ r_evised_application Entifl~ weJlÞorewithin ADL39Q502. 133~'Jo N, nei~ Lease ADL 3905Q7, located 4700' Jo SI;. prop_erty Pool injector ExploraJory sidetrack_ tar!:eting Kuparuk_ C and_A sand~. Ne_arest Conforms 10_ CO 432C, l\IeaJest well is Ataru~2, a Kuparuk OJ This ~ideírack_ will be_ the onlY_weJlbore in Section_ 6. . Kerr:McGee js_ OperatorJon:nJorADL390_502 recei\(ed 9n 3/18/200_5, in_ o_nly AD_L _039o_502 Designation 9f de_signated_ operatoJ Yes Xes _Yes No_ Xes Yes Xes Xes Xes Xes Yes Yes Yes NA NA NA NA nitial ClassfType Field & Pool Q1L. & GAS CORP Permit fee attached _Leas_e _number _appropriate_ n_arne _and Ol!mb_er in a define_dpool _U_nique well re(¡uired. CO ~32C goYern~ Kup_ here, 500' setba_c~ from driJling unitb9undary_ located proper _distance_ from otber wells located located proper distance We WeJ Well Sufficient _acreageayailable in_drillio9 unit It deviated Oper_ator only affected Party _Oper_ator bas_appropriate_ bond inJorce js weJlbore platincJuded Permit cao be issued witbout Permit can be iSSl!ed witbout Can permit . ~ ~nn' ~'I~'" ....~.~ Well locate( , strata _authorized by lojectioo Order # (Put co_nservaJion order administrati\(e_ approval (For in_ cPlJlrn_eots) 10# 15-day wait Dc ............·..,'IJ....U Uwlvre service well onJy) review ideotified (Fpr ~ervjce well only) duration of pre-pro_ductiOo less than 3 montbs_ (For A.CMP Finding 9f Con_sisteocyh_as been i$sued for_ tbis Project AJI WeUs_withinJl4J'uile_area_of Pre-produ_ced injector '1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 Administration Date Appr SFD 4/15/2005 ~ process. well, Ataruq #2 (205-039). ... 1-47.'102 ell ACMI=' doe_snotaffectAOGCCpermit to drill Con_ductor _set All aquifers ex_ernpted,40CF" Sl!rf'ace iO origin_al M(3). jn_ original casing set 1\10 Ip09 st(in~_pJa_noed, I='lan is to driJI aod I='M. PM cem_e!1t wi coyer any by_dro_carbon_. No reseNepjtplanned, All waste to_approve~Ldisposalwell(s). Rig is_e_quippedwith steelpits. 30_5:092 Well trajecto_1)' is away_ frorn original well. _ No directional_conflicts, 601=' stack will already_b_eJn place, . .5ppg. toJj I='lanned MW EMW. Maximl!m expected fprmaíion pressure _1 j J MASI=' calcuJaíedat 27:92 psi, 50QO_p-sißOF> testpJanoed, 1::125 bas been reported at2T_p_ad. _NA NA NA No Yes Yes Yes Yes Yes NA Yes Yes Xes Yes Yes No NA _Cooductor _S_urfaceca~ing_pJotects al _CMT v_ol adequate_ to circ_ul",v string_ provided known_ USDWs ,'.~ o_n _cond_uctor_ ¡string to_surf c&g & SUJtcsg tie-in know_npro_ductiye borizons C, CMT v_ol adeq uate to _CMTwil! coyer_a] C_asi!1g designs ade(¡uaJe fpr _T" B _&_ permafrost _Mequatetan_kage_oJ reserve pit beeo apPJoved Ifa re-drilt bas_ a_ to-403 for abandonment Adequate we!lbore separation proposed Jtdiverter required, does Jt meet reguJations_ DriUiog fJuid_ program schematic_& equip list BOPEs,do adequate reguJation they meet psig in_comlJlents) Jest to (puJ _C_hokeJ'lJanifold complies_w/APIRP-53 (May 84) Work will occur _BOPEpress ra_tiog appropriate; withoutoperationshl!tdown H2S gas_ prOQable condition pt Is presence of 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering Appr Date T~5I2005 Rig_has sensors and_ alarms. Mud Sh9Uld preclude H2S onrig._ wellS within AOR verified (for_service welJ only) Meçba_nical Offset Expected_ risiog tp 11 J ppg EMW in Kup. _Will be drjlled with_ mud weights_ up to 1 t5 pp~, Hydrates possible._ 1\10 sh_a!low hazards ha_ve beenJdentifted in_s_eisrnicor offset wells (see Sballow Hazards Survey ~ file 2Q50390) Contact: Todd Durkee907:-339~6370 respe.c:;tively . & 2T-38 (3mi _awªy) hªl[emeasured 2tO _&_ 30_ppmH2S, normaJ toJop I::IRZ,then _10.0 ppg EWM within _HHZ_ Kup_PJod_ucers 21-2t pre$suœ ~radient No Yes Yes NA Yes ecan be iSSl!ed wlo_ hydrogen sulfide measures Permit D_atapresented on pote_ntial oveJlJressuœzones _SeLsmicanªlysis of sbaJlow gaszPoes_ -Of off-shpre) _Seªbedcondition survey Date 4/15/2005 Geology Appr SFD Kerr-McGee The bottom hole location of this well has been moved 1-3/4 miles northwest of the originally permitted location is designated to operate this lease (ADL 390502 only). Date Contact namelphoneforwee~ly progress reports [expIQratoryonly] s-2ðtJS- Date Engineering Commissioner Date: 4/6/2005 Geologic Commissioner: DTS .@lr·1FF., Qi) U uilÌ U L6 . íñì.·"""u, ~ IfP.· ·F' ¡ l II \~ W . AIfASIiA. OIL AlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA99501·3539 PHONE (907) 279-1433 FAX (907)27~7542 Todd Durkee Drilling Manager Kerr McGee Oil & Gas Corporation 3900 C Street, Ste 744 Anchorage, Alaska 99503 Re: Ataruq #2A Kerr McGee Oil & Gas Corporation Permit No: 205-056 Surface Location: 477' FNL, 1834.6' FEL, SEC. 8, TIIN, R , UM Bottomhole Location: 1959' FSL, 2153' FEL, SEC. 8, Tl , R8E, UM )) I,j 0° ~ ç. ~ rP ~/"v.\ ~J.6· Dear Mr. Durkee: above referenced exploration well. Enclosed is the approved application for permit to drill This permit to drill does not exempt you from obtai . ng additional permits or approvals required by law from other governmental agencies, and d s not authorize conducting drilling operations until all other required permits and approvals ave been issued. In addition, the Commission reserves the right to withdraw the permit in e event it was erroneously issued. A weekly status report is required from the time the w 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 inte al use. Please note the Ataruq #2A shou be mudlogged from the window to TD. All dry ditch sample sets submitted to the Commisso n must be in no greater than 30' sample intervals from below the permafrost or from where s pIes are first caught and 10' sample intervals through target zones. Operations must be Co tlucted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrati~ Code unless the Commission specifically authorizes a variance. Failure to comply with applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative ode, or a Commission order, or the terms and conditions of this permit may result in the vocation or suspension of the permit. Please provide at least twenty-four (24) hours notic for a representative of the Commission to witness any required test. Contact the Commis . n's petroleum field inspector at (907) 659-3607 (pager). DATED this S day of April, 2005 ~/ Daniel T. Seamount, Jr. Commissioner cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. IJ . @O MCGEE . March 31 st, 2005 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED MAR S I 2005 Alaska Oil & Gas Cons. Commi$sicm Anchorage Re: Ataruq #2A Kerr McGee Oil & Gas Corporation Application for Pennit to Drill (10-401) Attached for your review is our Application for Pennit to Drill the Ataruq #2A which is planned as a sidetrack to the Ataruq #2 exploration well located approximately four (4) miles north-northwest from KRU's 2M Pad. If time allows, we plan to drill this sidetrack immediately after evaluating and plugging back the mother-bore, Ataruq #2 (APD 205-039). This original APD is submitted along with one (1) copy and the $100.00 filing fee. The APD packages include fonn 10-401, a pressure analysis, drilling program, directional drilling plan, mud program, plats, graphs and diagrams as required. The Ataruq #2A is a "build and hold" sidetrack with an azimuth basically opposite of the mother-bore, Ataruq #2. The planned KOP is in the vertical portion of the mother-bore at 1700' (below the B/Pennafrost). The mother-bore will be exited using a whipstock set in the 9-5/8" surface casing. The intennediate hole section contains the "build section" which will be cased with a liner set in the Colville. At TMD (below the Kuparuk A) we will log with E- Line and run MDT's if applicable. After evaluating the well, we plan to plug and abandon. If you have any questions or concerns about the APD or the drilling plan, please call me at 339-6269 and I will do my best to address your questions or concerns. Sincerely, sif£cr~~- ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK. 99503 (907)-339-6370 · STATE OF ALASKA . ~SKA Oil AND GAS CONSERVATION ~MISSION PERMIT TO DRILL RECEIVEDv.' _ MAK 3 I Z005 ~.. 20 MC 25.005 """,..,,, n" r¡, r- r"....... ..... 1 a. Type of Work: Drill [] Redrill D 1 b. Current Well Class: Exploratory [] Development Oil ~ h MUltiple Lone U Re-entry D Stratigraphic Test D Service D Development Gas j ~r~Zone D 2. Operator Name: 5. Bond: Blanket 0 Single Well D 11. Well Name and Number: Kerr McGee Oil & Gas Corporation Bond No. 3-798-381 ~ Ataruq #2A 3. Address: 6. Proposed Depth: 12. Field/Pool(s): , , 3900 C Street, Ste 744, Anchorage, AK 99503 MD: 7,063' TVD: 6,203' 4a. Location of Well (Governmental Section): 7. Property Designation: Exploration ./ Surface: 477' FNL & 1834.6' FEL Sec. 8, T11 N, R8E UM /' ADL 390502 - / Top of Productive Horizon: 8. Land Use Permit: 13. APpr~ (SPUd Date: 2110' FSL & 2135' FEL Sec. 8, T11 N, R8E UM / 4/10/2005 - Total Depth: 9. Acres in Property: ~ance to Nearest. ,I' b.. 1959' FSL & 2153' FEL, Sec. 8, T11N, R8E UM ./ 2469 R perty: .~ ¡'9Ç9 ;.f.~ 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 30.4 fee/ 15. Distance to Nearest Well Surface:x- 480716 ./ y- 5,969,528 Zone- / 4 (Height above GL): Within Pool: None 16. Deviated wells: Kickoff depth: 1700 feet / 17. Maximum Anticipated preSSU~i9 (see 20 MC 25.035) Maximum Hole Angle: 34.1 degrees Downhole: 3450 psi ' Surface: 2792 psi / 18. Casing Program: Specifications settin~ Quantity of Cement Size Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVjÝ MD TVD (including stage data) 8-3/4" 7-5/8" 29.7# L-80 STL 1786' 1500' ßOO' 3286' 3075' 87 sx "G" MicroLite at 12.5 ppg, ./ & 2.35 cf/sx (36.4 bbl), followed /' by 63 sx "G" + 2% CaCl2.at 15.8 / ppg & 1.15 cf/sx (12.8 bbl. / / 19. PRESENT WELL CONDITION SUMM¢ (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): PI7asured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length / Size Cement Volume MD TVD Structu ral . /; Conductor 80' l/ ,,:13-3/8",68#, L-80 20 yards 111' 111 ' Surface 3,300' 2///1 )/9-5/8", 40#, L-80 319 sx Permafrost L (235.6 bbl) & 1700' 1700' ft ~\l.' 286 sx G + 2% CaCI2 (58.7 bbl) Production W \ " - Liner v"V X 1 II / Jk'\ µ~.IÇ .0' Perforation Depth MD (ft): ~..) None Perforation Depth TVD (ft): None 20. Attachments: .%Fee ~ BOP Sketch ~ Drilling Program .j Time v. Depth Plot U Shallow Hazard Analysis U Pro erty Plat [] Diverter Sketch [] Seabed Report D Drilling Fluid Program [] 20 Me 25.050 requirements [] 21. V<>bal ,":~m;"';oo Rop'05e"lati,e, Date 22. I hereby certify t t the foregoing is true and correct to the best of my knowledge. Contact Printed Name Mr. Todc,t1¡)u~e-......... ~ Title Drilling Manager, Kerr McGee Oil & Gas Corporation I \j V \ ))~.-- Signature J) V{ /} Phone ~ 7/'9 63·7-Õ Date 31-Mar-05 "-/ ..../.. Commission Use Only Permit to Drill API Number: Permit Approval tf!š-jtJt<) See cover letter for other Number: 20 S--é.:6'b 50- /ð3 - zj)5'O 9 -0 I Date: requirements. Conditions of approval: Samples required Yes 'g] No D Mud log required - \0\ \) Yes I No D Hydrogen sulfide measures . Yes 'KJ No D Directional survey required ~ Yes No D Other: 5\:)ao(>~\~rØtt>o...""'~<t~. 4\J~\G C1.~~,,~\o.~ ~ J ~~\\"t: . 45/05 DAN SEAMOUNT APPROVED BY Approved by: THE COMMISSION Date: "" > Form 1 0-401 Revised 06/2004 ( L. Submit in Duplicate . . Ataruq #2A -> " Sidetrack Drilling Prognosis ADL: 0390502, 2469 acres Sidetrack, Drill, Evaluate, P & A I AOGCC Permit No.: I Drilling Rig: Nabors 27E Suñace Location: 477' FNL & 1835' FEL of Section 8, T11N, R8E UM ./ X = 480,716' Y = 5,969,528' ./ 477' FNL & 1835' FEL of Section 8, T11 N, R8E UM X = 480,716' Y = 5,969,528' 2110' FSL & 2135' FEL of Section 8, T11 N, R8E UM ' X = 480,409' Y = 5,966,836' 1959' FSL & 2153' FEL of Section 8, T11 N, R8E UM ' X = 480,391' Y = 5,966,684' Exit Point at 1700' TVD (whipstock) Target (T1) at 5978' TVD (Kuparuk C sand) Bottom Hole Location: 1 Operating Rig days: 110 I Pad Elev: 172 ft I I DF: 1102 ft I / I Estimated Spud Date: 14/10/05 1 1 TMD: 17,063 /1 1 TVD: 16,203' 1/ 1 Geologic Objectives: Kuparuk A & C sands / Mud Program: 12-1/4" Intermediate Hole (1700 - 3286'): Density PV YP HTHP 9.0 - 9.8 9 - 18 12 - 20 10 - 11 pH 9.0-9.5 MOBM (LVT200) API W/L LG Solids < 6 < 10 8-1/2" Production Hole (3286' - 7063'): Density PV YP HTHP 9.3-11.5 9-18 12-20 10-11 pH 9.0-9.5 MOBM (LVT200) API W/L LG Solids < 6 < 10 S Coyner 3/20/2005 . . Recommended Bit Program: Bit Hole Size Depth (MD) Footage Bit Type RPM GPM 1 8-3/4 in 1 ,700' - 3,286' 1,586' GTC-1 100 - 120 450 - 550 2 6-3/4 in 3,386' -7,063' 3,777' PDC 80 - 1 00 275 - 325 Casing Program Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD 1 TVD MD 1 TVD N/A 13-3/8" 68# L-80 BTC 80' 30' 110' 1 110' N/A 9-518" 40# L-80 BTC 3,300' 35' 1 35' 1700' 1 1700' 8-3/4" 7-5/8" 29.7# L-80 STL 3,300' 1500' 1 1500' 3286' 1 3075' Cement Program: Casin Size Parameters: 7-5/8",29.7#, L-80, STL Intermediate Liner: 1500' - 3286' MD 25% excess in open hole. Shoe track = 85'. 200' of over lap. 100' above TOL. TOC of Tail Slur = 2886' MD 400' . Wash 10 bbl water S acer 10 bbl of dual s acer mixed at 10.5 Lead 36.4 bbl, 87 sx MicroLite, 12.2 & 2.36 ft Is x Tail 12.8 bbl, 63 sx "G" mixed at 15.81bl al & 1.15 ft Isx Tern Casin Point BHST 850 F from Halliburton Cement: 49.2 bbl Mud Logging: Intermediate Hole: Rig instrumentation: PVT, Flow-Show, gas [H2S] detectors. / 8-3/4" Mud loggers to intermediate casing point: samples every 30 ft: ./ every 10ft through pay zones, gas detection & drilling parameters Production Hole: Rig instrumentation to TD: PVT ~w-?hO"Y~ gas [H2S] detectors. v 6-3/4" & ·'1'6> Mud loggers to intermørl' I"Ø::)lny poiflt: samples every 30 ft: - every 10ft through pay zones, gas detection & drilling parameters ./ S Coyner 2 3/20/2005 . . Surveys & MWD: While Drilling: Window to TO: MWD surveys every 90 to 180 ft IIFR Casandra for magnetic survey verification E f p va ua Ion rogram: 8-3/4" Intermediate Hole Open Hole: MWD / LWD: MWD / Triple-Combo LWD's v'~ Open Hole: Gas Detection, Mud Logging, samples E-Line: None planned 6-3/4" Production Hole Open Hole: MWD 1 LWD: MWD / Triple-Combo LWD's / PWD Open Hole: Gas Detection, Mud Logging, samples E-Line: Quad-Combo, dipole sonic, / MDT's and SWC's ./ v' / Formation Markers: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (lb/gal) B/Permafrost 1,473' 1,473' / WhipstocklWindow 1,700' 1,700' / T/Tabasco 3,048' 2,877' 900 6.40 T/Colville 3,169' 2,978' 1,316 8.55 T/Tarn 5,553' 4,953' 2,202 8.55 T/Moraine 5,928' 5,263' 2,340 8.55 T/HRZ 6,354' 5,616' 2,920 10.00 T/Kuparuk C 6,791' 5,978' 3,450 11.10 LCU 6,827' 6,008' 3,468 11.10 T/Kuparuk A 6,827' 6,008' 3,468 11.10 Proposed TD 7,063' 6,203' 3,580 11.10 ./ / / / ,/ » Due to potential inaccuracies with the seismic velocity, these formation tops may change Integrity Testing: Test Point: 9-5/8" Shoe 7-5/8" Shoe MD 1 TVD 1700' / 1700' 3286' / 3075' Kick Tolerance 'Y 50 bbls 'Y 50 bbls Test Type: FIT LOT EMW: 11.5 ppg 13.5 ppg S Coyner 3 3/20/2005 . . Well Control: The 9-5/8" surface casing will be set and cemented while drilling Ataruq #2. The 13-5/8" (5M) BOP stack will already be N/U and tested when we mill the window. The intermediate and production hole sections will both be drilled with well control equipment consisting of 13-5/8" (5000 psi) working pressure pipe rams(2), blind rams, and annular preventer capable of handling maximum potential surface pressures. BOP's will be tested when installed and then on a weekly basis thereafter. Any ram changes and 1 or flange "breaks" will be tested before continuing. The rams, valves and manifold will all be tested to 250 psi low / 5000 psi high, the annular tested to 250 psi low / 3500 psi high, the casing to 2500 psi. The maximum anticipated Surface Pressure is calculated from nearby Kuparuk C BHP data and a gas gradient of 0.11 psi/ft to surface as required: Kuparuk C BHP = 3450 psi Maximum Suñace Pressure = 3450 psi - (5978 ft x 0.11 psi/ft) = 2792 psi / Q!!posal of Drillina Waste: . Cuttings Handling: Cuttings generated from drilling operations will be hauled using super suckers to G & I #3: located on DS-04, Prudhoe Bay, for disposal. " · Fluid Waste Handling: All drilling and completion fluid wastes will be hauled to r 1 R-18 at Kuparuk for disposal. · Sewage (grey/black water): Camp waste water will be hauled to the sewage ' treatment plant(s) at Kuparuk 1 Prudhoe Bay 1 North Slope Borough where it will be treated and injected. H2S: · H2S has been reported from wells on 2T Pad that produce from the Tabasco sand. H2S concentrations of 700 ppm have been measured at the wellhead. Minor concentrations of H2S have also been reported from the Kuparuk sands as well. · H2S monitors will be used at all times in accordance with State Regulations. ./ ,/ S Coyner 4 3/20/2005 . . DRilLING PROCEDURE Pre-Rig Work: 1. Ensure the permits are in order. \-.) ~.\ ",.., ~~ \ \ 2. Notify the AOGCC 24 hours prior to spud, div~st, and the BOP test. Standard Orders: 1. All personnel must sign in at the camp and no unauthorized personnel are allowed on site. 2. For travel safety and location security, all travelers must sign in/out at the security guard post near the spine road AND sign in/out at the assigned camp. 3. A full opening safety valve (with correct threads) will be kept on the drill floor in the open position at all times and the appropriate hex-wrench will be readily available. 4. Pit drills/kick drills will be conducted one with each crew in each hole section. 5. 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. 6. The toolpusher and company man will witness the first ten (10) stands off bottom for all trips. Use the trip tank. Keep a trip sheet. Keep the hole full. Watch for swabbing. Drilling Operations: Suñace Hole Section: ,~ >ù~"-I Q.~~~a..\ /~CC>'3ú..~ 1. Properly plug and abandon the motherbore, Ataruq #2, back to .±1700' MDITVD. Set and EZSV at .±1700' MDITVD. Test the 9-5/8" casing to 2500 psi. 2. RIH and set the whipstock using a gyro & UBHO sub. Shear off and mill the window. CBU x 2. POOH. LID the mills. Wash out the BOP stack. 3. RIH with 8-3/4" bit & BHA. Drill 20' of new hole. CBU. Perform an FIT to 11.5 ppg EMW. Intermediate Hole Section: 4. Drill ahead, sliding to build inclination in accordance with the attached directional drilling plan. Then, rotary drill to the intermediate liner point in the Colville mudstones. Use Super Suckers and vac trucks to haul off the waste generated while drilling. 5. At liner point, CBU x 2. Make a wiper trip to the window. Return to bottom and CBU x 2 again. Pump out up into the 9-5/8" casing and CBU from there. Then finish POOH. LID LWD tools as required. RIU to run the 7-5/8" liner. 6. Run and cement the 7-5/8", 29.7#, flush joint liner as programmed. Wash the liner to bottom. Circulate. Cement the liner as programmed, circulate out excess cement. POOH. WOC until the cement in the liner lap has set up before putting any pressure on the liner lap. 7. RIH with a 8-3/4" bit and clean off TOL. CBU. POOH. 8. RIH with a 6-3/4" bit and BHA. RIH to the TOL and carefully enter the liner. RIH to the landing collar. Test the casing to 2500 psi on chart for 30 minutes. Drill out the shoe and 20 ft of new hole. CBU. Perform a LOT expected to be ~ 13.5 ppg EMW. S Coyner 5 3/20/2005 . . Production Hole Section: 9. Drill ahead adjusting the mud weight as dictated by hole conditions and in accordance with the attached mud program. Maintain the mud properties to minimize the PV, surge, swab and ECD while still cleaning the hole. Watch for mud losses, seepage and differential sticking in the Tarn sand at ±5553' MD. Adjust the MW up to ± 10.6 ppg to drill the HRZ. 10. At ±6700' MD, Make a 15 stand wiper trip. Then, adjust the MW up to ± 11.5 ppg to drill the Kuparuk C sd. Be sure the hole is clean and minimize the ECD. Drill ahead watching for mud losses, seepage and differential sticking. Keep the pipe moving at all times. Bit Hole Size Depth (MD) Footage Bit Type RPM GPM 2 6-3/4 in 3,286' - 7,063' 3,777' PDC 70 - 1 00 275 - 325 11. At TD, CBU x 3 and then as needed to clean the hole. Make a 20 stand wiper trip. RIH and CBU x 3 again. POOH to the 7-5/8" shoe and then CBU from there. POOH for logs. 12. RIU E-Line. Run Log suite as directed, followed by MDT's and SWC's as/if directed. 13. RID E-Line. RIH with OEDP and prepare to plug and abandon. . (\ ~ ~.~~~ ~p~~\ 'R~0\~ Attachments: · Assignment of Operator - Approved by DNR · Survey plat (Lounsbury) · Geographic Plat (PowerPoint) · Days -vs- Depth Graph (Excel) · Well bore Schematic (Excel) · Well bore Diagram (PowerPoint) · Directional Drilling Plan (Sperry) · Drilling Mud Program (Baroid) · Abnormal Pressure Analysis · Nabors 27E BOP Diagram · Nabors 27E Choke Manifold Diagram S Coyner 6 3/20/2005 . . FRANK H. MURKOWSKI GOVERNOR DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS 550 WEST 7TH A VE, SUITE 800 ANCHORAGE, ALASKA 99501 PHONE: (907) 269-8800 FAX: (907) 269-3484 Stuart Gustafson, VP Operations ARMSTRONG OIL & GAS, INC. 700 17~ St. Suite 1400 Denver CO. 80202 January 28, 2005 David A. Hager, President KERR McGEE OIL AND GAS CORPORATION 16666 Northchase Dr. Houston Texas 77060 Re: Assignment of Plans of Operation from ARMSTRONG OIL & GAS, INC., to KERR-McGEE OIL AND GAS CORPORATION LOINS 04-11 Two Bits Dear Mr. Gustafson The Division of Oil and Gas (DO&G) has reviewed your letter dated January 27, 2005, requesting the above referenced Plans of Operations issued to ARMSTRONG OIL AND GAS, INC. by the DO&G, August 30, 2004 be assigned to KERR-McGEE OIL AND GAS CORPORATION. Effective this date, and under 11 AAC 82.605 the Division of Oil and Gas approves the assignment of these plans of Operations approvals, from ARMSTRONG OIL AND GAS, INC. to KERR-McGEE OIL AND GAS CORPORATION. If you have any further questions regarding the assignment of these Plans of Operation, please do not hesitate to call me at 269-8777. Sincerely ~ Steven Schmitz Natural Resource Specialist III ecc: Leon Lynch, DMLWM Kathy Sheehan Dugan, OPMP David Hager, Kerr-McGee O&G Corp. "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans. " Ataru 70° 19' 40.5" N & 150° 09' W 477' FNl & 1834.6 FEl of Section 8 T11 N R8E 5,969,528' N & 480,716' E NAD Zone 4 2837' FSL & of 5 T11 N R8E 5,972,841' N & 481,128' E NAD Zone 4 3064' FNL & 1393' FEL of Section 5 T11 N R8E 5,973,068' N & 481,156' E NAD Zone 4 ADL 0390502 (2469 Armstrong 0 & G Kerr McGee 0 & G 5 Ataruq 477' FNL & FE Surtace Location 8 Kuparuk C Sd. ~ m ... 1(.1 '" ~ FEL Þ FEl~ FEL 9 taruq #2A Days -v- Depth o ~~-*-- 1000 3000 -g 4000 ii- :s en «S Q) :E 5000 8000 o 5 10 Days I ,j. - - - +- I ~ I I -, - - I I -----_.~ _ L _ 15 NONE GR / RES IIFR/Cas 9 10 11 Base Permafrost Whipstock Ataruq #2A End Build Section 2,248' 2,215' T/Tabasco Sd. 3,048' 2,878' Top ofTail Slurry 2,886' 2,743' 9 10 11 LWD's Triple-Combo PWD IIFR/Cas E-Line: Diploe Sonic MDT's, SWC'g T /Colville Tarn Sand T/Moraine T/HRZ T/Kuparuk C lCUlKuparuk A 5,553' 4,853' 5,928' 5,263' 6,354' 5,616' 34.1° 34.1° 34.1° 34.1° 34.1° 34.1° 9-S/S" 40 Iblft L-80, BTC Int. Yield 5750 psi Collaspse 3090 psi ----------~------- ----------------- --------------- 0° 6.75" Inter. Casing 7 -5/S" 29.7# L-80, STL (FJ) Int. Yield 6890 psi Collaspse 4790 psi Float Eauip: 1 ea Float Shoe 1 ea Float Collar Test 7-5/8" liner to 12.5 ppg 2.36 ft3/sx Cement 12.8 bbls, 63 sx 15.8#,1.15 cf/sx 25% Excess __ Surf 13-3/8" l-80 Conductor 1000' 1452' TOl at 1500' __ 2000' Whipstock at 1100' (Build at 6° 1100 ft) 34.10 __ 3000' , 29.1#, MD I 3075' TVD} I I I I I I I I I I I I I 6-3/4" Hole / I / I / I 34.1° I I / / -. ...-.-...-.-. -_._,-, _. ._,_._._,- I I ,_._.- -·---·-'-·-·Ta·rn I / I I I I I I I I I / - _. - . - - - ~ . - - - - - / I - - - - - - - - - - . - - - . - . ~ "Kuparuk A at I / / I I / / I _ 4000' Q > ¡.... __ 5000' _ 6000' 7063' MD 1 6203' TVD ....- 7000' <r; Kerr-McGee Corporation Western North Slope, Alaska Two-Bits Exploration Ataruq 2A (wp05) Revised: 2 March, 2005 Sperry-Sun PrgRiP$8'1 Report 2 f!liarch, 2005 Surface Coordinates: 5969528.00 N, 480716.00 E (70019' 40.4816" N, 150009' 23.0084" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 /' Surface Coordinates relative to Global Coordinates: 86269.49 S. 38953.03 W (Grid) Surface Coordinates relative to 47TFNL, 1834.6' FEL: 0.00 N, 0.00 E (True) /' Kelly Bushing Elevation: 102.65ft above Mean Sea Level " Kelly Bushing Elevation: 30.65ft above Pad Elev = 72' MSL Proposal Ref: pro980 HALLIBURTON . . Kerr McGee Corporation Comment 34.09 186.37 2972.35 3075.00 740.89 S 82.59 W 5968787.33 N 480631.51 E 0.00 -745.44 7-5/S" Csg Pt... Begin 6-314" Hole Current Well Properties Ref. RKB Elevation Coordinates North Reference: Units True North Feet (US Survey) DrillQuest 3.03.06.008 1000 ¡¡; (ij Q (/) Scale: 1 inch = 1000f! 2000 3000 .L: Q. '" CJ <õ Q 'E " > 4000 5000 ¢' <:> <:> <:> ~ 6000 Ii .L: Q .£ -4000 -1000 o -3000 -2000 Scale: -1000 -1500 Horizontal Coordinates: Ref. Global Coordinatas ~ Raf. Geographical Coordinates: RKB Elevation North Reference: Units -2000 -2500 Eastings Scale: 1 inch = 500ft -500 ¡¡; ~ f;j) -1500 -1000 Dir. f/) 0> <:: :ë 1:: o Z ¡¡:: o o I.Q II .s::. '" .5 MO, -3000 -1000 Scale: 1inch Kerr-McGee Corporation HALLIBURTON tern North Slope, Kerr McGee Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 Measured True Sub-Sea Vertical Local Coordinates Global Vertical . Depth Incl. Azim. Depth Depth Northings Eastings Northings Section Comment (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -102.65 0.00 0.00 N .0.00 E N 0.00 SHL (477' FNL & 1834.6' FEL, flS6'9S28.00 N Sec. 8 - T11N - R8E) 100.00 0.000 0.000 -2.65 100.00 0.00 '(MOB· 480716.00 E 0.000 0.00 200.00 0.000 0.000 97.35 200.00 0.00 OIoo 1£ 5969528.00 N 480716.00 E 0.000 0.00 300.00 0.000 0.000 197.35 300.00 0.00 OX)OE 5969528.00 N 480716.00 E 0.000 0.00 400.00 0.000 0.000 297.35 400.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 500.00 0.000 0.000 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 600.00 0.000 0.000 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 700.00 0.000 0.000 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 800.00 0.000 0.000 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 900.00 0.000 0.000 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1000.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1100.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1200.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1300.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1400.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1350.00 1452.65 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 Base Permafrost . 1397.35 1500.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 1497.35 1600.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 I 1597.35 1700.00 0.00 N 0.00 E 5969528.00 N 480716.00 E 0.000 0.00 Set Whipstock in 9-5/8" Csg ... Assume 12.0o/100ft across / Whipstock: 1700.00ft MD, 1700.00ft TVD 9-5/8" Csg Window 1720.00 2.400 186.000 1617.34 1719.99 0.42 S 0.04W 5969527.58 N 480715.96 E 12.000 -0.42 PU Dir Tools and Begin Dir @ 6.0o/100ft in 8-314" Hole: 1720.00ft MD, 1719.900 TVD 1800.00 7.200 186.261 1697.04 1799.69 7.07 S 0.77W 5969520.93 N 480715.22 E 6.000 -7.11 1900.00 13.200 186.321 1795.41 1898.06 24.66 S 2.71 W 5969503.34 N 480713.23 E 6.000 -24.81 2000.00 19.200 186.344 1891.40 1994.05 52.38 S 5.78W 5969475.64 N 480710.08 E 6.000 -52.69 2100.00 25.200 186.356 1983.95 2086.60 89.91 S 9.96W 5969438.11 N 480705.81 E 6.000 -90.46 2200.00 31.200 186.364 2072.04 2174.69 136.86 S 15.19 W 5969391.18 N 480700.45 E 6.000 -137.69 2 March, 2005 - 13:23 Page 2 of 8 Dri/lQuest 3.03.06.008 Corporation HALLIBURTON North Slope, Kerr McGee Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 Measured True Sub-Sea Vertical Local Coordinates Global Vertical . Depth Incl. Azim. Depth Depth Northings Eastings Northings Section Comment (ft) (ft) (ft) (ft) (ft) (n) 2248.10 34.086 186.367 2112.54 2215.19 162.64 S 18.07 W 5~9365¡40 N E 6.000 -163.63 End Dir, 5tart 5ail @ 34.09° : 2248.1 Oft MD, 2215.18ft TVD 2300.00 34.086 186.367 2155.52 2258.17 191.55 21130 Wi 5969336.51 N 480694.21 E 0.000 -192.72 2400.00 34.086 186.367 2238.34 2340.99 247.25 27;q~ W 5969280.83 N 480687.85 E 0.000 -248.76 2500.00 34.086 186.367 2321.16 2423.81 302.94 33.13W 5969225.14 N 480681.50 E 0.000 -304.80 2600.00 34.086 186.367 2403.98 2506.63 358.64 S 39.94 W 5969169.46 N 480675.14 E 0.000 -360.84 2700.00 34.086 186.367 2589.44 414134 S 46.15 W 5969113.78 N 480668.78 E 0.000 -416.88 2800.00 34.086 186.367 47Q)Q~. S 52.37 W 5969058.10 N 480662.42 E 0.000 -472.92 2900.00 34.086 186.367 525.74 S 58.58 W 5969002.42 N 480656.06 E 0.000 -528.96 3000.00 34.086 186.367 581.44 5 64.80 W 5968946.73 N 480649.71 E 0.000 -585.00 3047.99 34.086 186.367 608.17 5 67.78 W 5968920.01 N 480646.66 E 0.000 -611.90 Tabasco 3100.00 637.13S 71.01 W 5968891.05 N 480643.35 E 0.000 -641.05 3168.74 675.42 5 75.29 W 5968852.78 N 480638.98 E 0.000 -679.57 Colville ms 3200.00 692.835 77 .23 W 5968835.37 N 480636.99 E 0.000 -697.09 3286.28 740.895 82.59 W 5968787.33 N 480631.51 E 0.000 -745.44 7-5/8" Csg pt ... Begin 6-3/4" Hole: 3286.28ft MD, 3075.00ft TVD . 7-5/8" Flush Joint Liner 330 2983.71 3086.36 748.53 S 83.44 W 5968779.69 N 480630.63 E 0.000 -753.13 186.367 3066.53 3169.18 804.23 S 89.66 W 5968724.00 N 480624.28 E 0.000 -809.17 186.367 3149.35 3252.00 859.93 5 95.87 W 5968668.32 N 480617.92 E 0.000 -865.21 186.367 3232.17 3334.82 915.63 5 102.09 W 5968612.64 N 480611.56 E 0.000 -921.25 186.367 3314.99 3417.64 971.32 5 108.30 W 5968556.96 N 480605.20 E 0.000 -977.29 186.367 3397.81 3500.46 1027.02 S 114.52 W 5968501.28 N 480598.84 E 0.000 -1033.33 3900.00 34.086 186.367 3480.63 3583.28 1082.72 S 120.73 W 5968445.59 N 480592.49 E 0.000 -1089.37 4000.00 34.086 186.367 3563.45 3666.10 1138.42 5 126.95 W 5968389.91 N 480586.13 E 0.000 -1145.41 4100.00 34.086 186.367 3646.27 3748.92 1194.125 133.16 W 5968334.23 N 480579.77 E 0.000 -1201.46 4200.00 34.086 186.367 3729.09 3831.74 1249.82 S 139.37 W 5968278.55 N 480573.41 E 0.000 -1257.50 4300.00 34.086 186.367 3811.91 3914.56 1305.51 S 145.59 W 5968222.86 N 480567.06 E 0.000 -1313.54 2 March, 2005 -13:23 Page 3 of 8 DrillQuest 3.03.06.008 Kerr-McGee Corporation HALLIBURTON em North Slope, Kerr McGee Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 Measured True Sub-Sea Vertical Local Coordinates Global 'Ðogleg Vertical . Depth Incl. Azim. Depth Depth Northings Eastings Northings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (0/100ft) 4400.00 34.086 186.367 3894.73 3997.38 1361.21 S N E 0.000 -1369.58 4500.00 34.086 186.367 3977.55 4080.20 1416.91 S N 480554.34 E 0.000 -1425.62 4600.00 34.086 186.367 4060.37 4163.02 1472.61 N 480547.98 E 0.000 -1481.66 4700.00 34.086 186.367 4143.19 4245.84 1528.31 N 480541 .62 E 0.000 -1537.70 4800.00 34.086 186.367 4226.00 4328.65 1584.01 5967944.45 N 480535.27 E 0.000 -1593.74 4900.00 34.086 186.367 4308.82 1ê:ª-1:¡.70 S 182.88 W 5967888.77 N 480528.91 E 0.000 -1649.78 5000.00 34.086 186.367 4391.64 1695140 S 189.09 W 5967833.09 N 480522.55 E 0.000 -1705.83 5100.00 34.086 186.367 4474.46 175f.JQ S 195.31 W 5967777.41 N 480516.19 E 0.000 -1761.87 5200.00 34.086 186.367 4557.28 1806~80 S 201.52 W 5967721.72 N 480509.84 E 0.000 -1817.91 5300.00 34.086 186.367 4640.10 1862.50 S 207.74 W 5967666.04 N 480503.48 E 0.000 -1873.95 5400.00 34.086 1918.20 S 213.95 W 5967610.36 N 480497.12 E 0.000 -1929.99 5500.00 34.086 1973.89 S 220.16 W 5967554.68 N 480490.76 E 0.000 -1986.03 5553.44 34.086 2003.66 S 223.49 W 5967524.92 N 480487.37 E 0.000 -2015.98 Top Tarn 55 5600.00 34.086 2029.59 S 226.38 W 5967499.00 N 480484.40 E 0.000 -2042.07 5700.00 34.086 2085.29 S 232.59 W 5967443.31 N 480478.05 E 0.000 -2098.11 5054.20 5156.85 2140.99 S 238.81 W 5967387.63 N 480471.69 E 0.000 -2154.15 . 5137.02 5239.67 2196.69 S 245.02 W 5967331.95 N 480465.33 E 0.000 -2210.20 5160.00 5262.65 2212.14 S 246.75 W 5967316.50 N 480463.57 E 0.000 -2225.75 Moraine ss 5219.84 5322.49 2252.39 S 251.24 W 5967276.27 N 480458.97 E 0.000 -2266.24 5302.66 5405.31 2308.08 S 257.45 W 5967220.58 N 480452.62 E 0.000 -2322.28 6200. 34.086 186.367 5385.48 5488.13 2363.78 S 263.67 W 5967164.90 N 480446.26 E 0.000 -2378.32 6300.00 34.086 186.367 5468.30 5570.95 2419.48 S 269.88 W 5967109.22 N 480439.90 E 0.000 -2434.36 6353.98 34.086 186.367 5513.00 5615.65 2449.55 S 273.24 W 5967079.17 N 480436.47 E 0.000 -2464.61 Top HRZ 6400.00 34.086 186.367 5551.12 5653.77 2475.18 S 276.10 W 5967053.54 N 480433.54 E 0.000 -2490.40 6500.00 34.086 186.367 5633.94 5736.59 2530.88 S 282.31 W 5966997.86 N 480427.19 E 0.000 -2546.44 6579.77 34.086 186.367 5700.00 5802.65 2575.31 S 287.27 W 5966953.44 N 480422.11 E 0.000 -2591.15 Base HRZ 6600.00 34.086 186.367 5716.76 5819.41 2586.58 S 288.53 W 5966942.17 N 480420.83 E 0.000 -2602.48 6700.00 34.086 186.367 5799.58 5902.23 2642.27 S 294.74 W 5966886.49 N 480414.47 E 0.000 -2658.52 2 March, 2005 - 13:23 Page 4 0'8 DrillQuest 3.03.06.008 Measured Depth (ft) 6791.07 Incl. True Azim. Sub-Sea Depth (ft) 5875.00 Local Coordinates Northings Eastings (ft) (ft) 2693.00 S 300,40 W Kerr-,!)1cGee Corporation , em North Slope, Kerr McGee HALLIBURTON Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 186.367 Vertical Depth (ft) 5977.65 Global Northings Vertical Section Comment . 34.086 E -2709.56 Target @ 2110' FSL & 2135' FE Sec. 8-T11N-R8E: 6791.07ft M 5977.65ft TVD Top Kup C ss Ataruq #1 Target, 150.00 Radiu: Current Target 6800.00 34.086 186.367 5882.39 5985.04 5966830.81 N 480408.11 E 6827.29 34.086 186.367 5905.00 6007.65 2713,18 S 302.65 W 5966815.61 N 480406.38 E 6900.00 34.086 186.367 5965.21 275:'£67 S 307.17 W 5966775.13 N 480401.75 E 7000.00 34.086 186.367 6048.03 ~809.37 S 313.38 W 5966719,44 N 480395,40 E --- 7062.75 34.086 186.367 6100.00 2844.32 S 317.28 W 5966684.51 N 480391,41 E 0.000 -2714.57 0.000 -2729.86 LCU I Kup A ss 0.000 -2770.61 0.000 -2826.65 0.000 -2861.81 Proposed Total Depth: 7062.75 MD, 6202.65ft TVD All data is in Feet (US Survey) unless ot Vertical depths are relative to RKB =1 Global Northings and Eastings tãtêd. and coordinates are relative to True North. L';if¡!orthings and Eastings are relative to 47TFNL & 1834.6·FEL. '2'7 Alaska State Planes, Zone 4. (US Survey). 4.6'FEL and calculated along an Azimuth of 6.950° (True). . calculations, at a Measured Depth of 7062.75ft., ent is 2861.96ft., in the Direction of 186.365° (True). The Along, Ie Displacement is 2861.96ft. The Total Accumulated Dogleg is 34.086° The Plannéd Tortuosity is 1.155°/100ft. The Directional Difficulty Index is 4.9. 2 March, 2005 - 13:23 Page 5 of 8 DrillQuest 3.03.06.008 HALLIBURTON Kerr-iVIcGee Corporation em North Slope, Kerr McGee . Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 Comments Measured Depth (ft) 0.00 1700.00 1720.00 2248.10 3286.28 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 1700.00 1719.99 2215.18 3075.00 0.00 N 0.00 N 0.42 S 162.64 S 740.89 S 0.00 E 0.00 E 0.04W 18.07 W . 82.59 W . 6791.07 7062.75 SHL FEL, Sec. 8 - T11 N - R8E) .Set in 9-5/8" Csg ... Assume 12.00/100ft across Whipstock: 1700.00ft MD, 1700.00ft TVD ì=!O Dir Begin Dir @ 6.00/100ft in 8-314" Hole: 1720.00ft MD, 1719.99ft TVD E~pir, Start Sail @ 34.09° : 2248.1 Oft MD, 2215.18ft TVD 7-5¡S~ Csg Pt ... Begin 6-3/4" Hole: 3286.28ft MD, 3075.00ft TVD 5977.65 6202.65 '.<', 3Qq;4,Q.W Target @ 2110' FSL & 2135' FEL, Sec. 8-T11 N-R8E : 6791.07ft MD, 5977.65ft TVD 311.2S'W Proposed Total Depth: 7062.75ft MD, 6202.65ft TVD Formation To"s Profile Penetration Poi n t e Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 1350. 359.853 1452.65 1452.65 1350.00 0.00 N 0.00 E Base Permafrost 2775.00 359.853 3047.99 2877.65 2775.00 608.17 S 67.78 W Tabasco 2875.00 359.853 3168.74 2977 .65 2875.00 675.42 S 75.29 W Colville ms 4850.00 359.853 5553.44 4952.65 4850.00 2003.66 S 223.49 W Top Tarn ss 5160.00 359.853 5927.75 5262.65 5160.00 2212.14 S 246.75 W Moraine ss 5513.00 0.000 359.853 6353.98 5615.65 5513.00 2449.55 S 273.24 W Top HRZ 5700.00 0.000 359.853 6579.77 5802.65 5700.00 2575.31 S 287.27 W Base H RZ 5875.00 0.000 359.853 6791.07 5977.65 5875.00 2693.00 S 300.40 W Top Kup C ss 5905.00 0.000 359.853 6827.29 6007.65 5905.00 2713.18 S 302.65 W LCU I Kup A ss 2 March, 2005 - 13:23 Page 6 of 8 DrillQuest 3.03.06.008 HALLIBURTON cGee Corporation North Slope, Kerr McGee Proposal Report for Two-Bits Exploration - Ataruq 2A (wp05) Revised: 2 March, 2005 Casino details Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> 1700.00 3286.28 1700.00 3075.00 faroets associated with this we//IJath Target Name Casing Detail Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) . Target Target Shape Type Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 5977.65 2693.00 S 300.40 W Circle 5875.00 5966835.78 N 480408.68 E 700 19' 13.9935" N 1500 09' 31.7756" W 150.00ft Current Target e 2 March, 2005 - 13:23 DrillQuest 3.03.06.008 Page 7 of 8 North Reference Sheet for Two-Bits Exploration - Ataruq Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Source: Snyder, J.P., 1987, Map Projections - A Working Manual Datum is North American Datum of 1927 (US48, AK, HI, and Canada) Spheroid is Clarke - 1866 Equatorial Radius: 6378206.400m. Polar Radius: 6356583.800m. Inverse Flattening: 294.978698213901 Projection method is Transverse Mercator or Gauss Kruger Projection Central Meridian is -150.000° Longitude Origin: 0.000° Latitude Origin: 54.000° False Easting: 152400.00m False Northing: O.OOrn Scale Reduction: 0.99990000 Grid Coordinates of Well: 5969528.00 Geographical Coordinates of Surface Elevation of Well Grid Convergence at Magnetic Declination Magnetic Model: BGGM2004 Magnetic North Date: 02-Mar-05 Declination: +24.117 Inclination/Dip: 80.699 Horizontal Component: 9304 nT Component: 8492 nT Component: 3802 n T Component: 56807 nT tal Field Strength: 57564 nT Checksum: 2299234 !nsite v.5.0: 2299234 Grid North True North cGee Corporation North Slope, Ken McGee Hole Direction Grid North is 0.147° West ofTrue North (Grid Convergence) East of True of Grid 2 March, 200S· 13:23 DrillQuest 3.03.06.008 Page of 11 Halliburton BAROID Kerr McGee Mud Program ~ ICER/l-MCGEE CORPtIBA ! BARDIO Ataruq #2A Baroid Mud Program Halliburton Baroid Name (Printed) Signature Date Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Skip Coyner Version No: Date: 1.0 March 10th, 2005 Ataruq #2A, v1 .0 3/10/05 Halliburton BAROID Kerr McGee Mud Program Ataruq #2A Mud Program General Discussion This exploration well will be drilled near the West Sak 18 gravel pad ±4 miles north-northwest of KRU's 2M Pad. The 8-3/4" intermediate hole will be sidetracked out of the Ataruq #2 surface casing at approximately 1700' MD/TVD. The inclination will then be built at 6° 1100' to 34.10. This inclination will be held to casing point at ±3286' MD (3075' TVD), where 7 5/8" casing will be set and cemented. Then, a 6-3/4" hole will be drilled holding 34.1° to the proposed TMD of 7063' MD (6203' TVD). Reconditioned ENVIROMUL mineral oil based mud system will be used to drill the both hole sections. As a general drilling fluids plan, mill the window with the existing ENVIROMUL mud system from the Ataruq #2A well. The mud will need to be centrifuged back to a mud weight of 8.8 - 9.0 ppg and maintained there to the 7-5/8" casing point. Below the intermediate shoe, continued use of recycled ENVIROMUL mud from the Ataruq #2, Kigun #1, andlor Nikaitchuq #3 wells is suggested. The mud weight for this interval of the well will range from 9.0 ppg at drill-out of the intermediate liner to 10.8 ppg by the top of the HRZ. The weight will be gradually increased to 11.3 ppg by the top of the Kuparuk C. The Kuparuk C is over-pressured due to injection and a minimum of 11.3 ppg will probably be necessary. Minimizing drilling waste, hole-stability, and hole-cleaning are the primary objectives of this drilling fluid system. Special Considerations 1. Waste minimization is critical to the success of this well. 2. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@1500 sxs barite on location at all times). 3. 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. 4. The Tabasco formation (if present) is possibly depleted and volumes must be monitored carefully to detect losses. Also, LCM should be strung in while drilling this formation to minimize losses and the potential for differential sticking. The Tarn formation may also be depleted and similar measure should be taken while drilling it. Formation Tops/Casina Proaram TMD TVD Comments Mud Wt Whipstock 1700' 1700' 9-5/8" casing 8.8-9.0 Tabasco 3048' 2878' String in LCM 8.8-9.0 Colville 3169' 2978' 8.8-9.0 7 -5/8" casing point 3286' 3075' Condition for casing 8.8-9.0 Tarn 5553' 4953' Possibly depleted 8.8-9.0 Moraine 5928' 5263' 8.8-9.0 Top HRZ 6354' 5616' Weight up 10.8 Kuparuk C 6791' 5978' Over-pressured 11.0-11.5 LCUlKuparuk A 6827' 6008' TD 7063' 6203' Ataruq #2A, v1.0 2 3/10/05 Halliburton BAROID Kerr McGee Mud Program Wen Specifics: Casing Program MD TVD Footaae Whipstock (9-5/8" casing) 1700 1700 n/a 8-3/4" hole (7-5/8" casing) 3286 3075 1586 6-3/4" hole (no casing) 7063 6203 3777 Intermediate Hole Mud Properties: (8-3/4" Hole, 7-5/8" Casing to 3286' MD) Mud Type: Enviromul System [L VT200 MOBM] Mud Properties: Density PV YP ES HTHP WPS OIW Milling 8.8-9.0 10-20 25-30 800-1100 <6 250-300K 80/20 Drilling 8.8-9.0 10-20 9-18 800-1100 <6 250-300K 80/20 · Additional mud weight may be required tripping and logging purposes. System Formulation Product Concentration LVT-200 0.713 bbl EZ MUL NT 4 ppb INVERMUL 4 ppb GEL TONE V 6 ppb Lime 5 ppb DURA TONE 4 ppb Water 0.182 bbl CaCI2 19.9 ppb BAROID 62 ppb (to 9.0 ppg mud wt) Production Interval Mud Type: 1. Mud weight: 9.0 ppg ENVIROMUL System. Maintain the density at 8.8-9.0 ppg. Centrifuging will be required to decrease the mud weight of the re-used mud from Ataruq #2. Increase density as required for hole stability. Maximize solids control usage. Maintain a YP between 25 and 30 while milling. Additions of VIS-PLUS should be added at 1-2 ppb to achieve this target. The rheology will then relax after a few circulations. While drilling, maintain the YP between 9 and 18. Pump high viscosity or BAROLlFT sweeps throughout the interval as needed, particularly prior to POH for logging. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated wellbore. Maximize pipe rotation (ideally ~ 100 RPM). 2. Rheology: Ataruq #2A, v1.0 3 3/10/05 Halliburton BAROID Kerr McGee Mud Program 3. Other issues: The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. Operations Summary: The existing system from Ataruq #2 should be reconditioned for re-use on this well. It will require centrifuging and chemical additions to condition to acceptable parameters. Additions of VlS- PLUS at 1-2 ppb should be made to increase the YP for milling operations. The effect will dissipate after a few circulations. Maintenance: 1. Additions of Geltone V / RM-63 will maintain/modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECO and surge/swab pressures. Run the rheology checks at 120°F to TD. 2. OMC 2 and OMC 42 will be available to condition (thin) the mud as required; however, caution should be used when using these oil mud thinners (particularly the OMC-2) to avoid over-thinning the system. 3. DURA TONE HT should be used to maintain a tight HTHP filtrate « 6 cc/30 min @ 2000 F). 4. For formation bridging/LCM, graded calcium carbonate (Baracarb(s)), cellulose fiber material (Barofibre) and SteelSeal are available. Baracarb 50 and I or Micatex should be strung into the system should seepage losses occur. 5. The electrical stability of the mud should be run in the 800-1100 volt range with INVERMUL and EZ MUL as the primary and secondary emulsifiers. ORIL TREAT will be available as an effective wetting agent, when needed for weight up. 6. Maintain the water phase salinity between 250,000 - 300,000 mg/I range with sack calcium chloride. This level of salinity will provide an effective mechanism for good wellbore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. 8. The initial oil:water ratio will be 80:20. However if the O/w ratio is higher in any used mud which may be available do not adjust it down unless there are volume constraints. From there, the system will be maintained with base oil and/or reconditioned mud. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real-time use of the OFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM- 400 500 600 1 00 rpm 170 214 261 120 rpm 198 242 296 Ataruq #2A, v1.0 4 3/10/05 Kerr McGee Halliburton BAROID Mud Program Production Hole Mud Properties: (6-3/4" Hole to 7063' MD) Mud Tvpe: Enviromul System [L VT200 MOBM] Mud Properties: Densitv PV YP ES HTHP WPS OIW Initial 8.8-9.0 10-20 9-18 800-1100 <6 250-300K 80/20 T/HRZ - TD 10.8-11.5 10-32 9-18 800-1100 <5 250-300K 80/20 . Additional mud weight may be required tripping and logging purposes. System Formulation Product Concentration LVT-200 0.713 bbl EZ MUL NT 4 ppb INVERMUL 4 ppb GEL TONE V 6 ppb Lime 5 ppb DURA TONE 4 ppb Water 0.182 bbl CaCI2 19.9 ppb BAROID 62 ppb (to 9.0 ppg mud wt) Production Interval Mud Tvpe: 1. Mud weight: 2. Rheology: 3. Other issues: 9.0 ppg ENVIROMUL System. Maintain the density at 8.8-9.0 ppg, weight up to 10.8 ppg by the T/HRZ, then gradually increase the mud weight to .!,11.3 ppg by the Kuparuk C; use solids control and whole mud dilution. Increase density as required for hole stability. Maximize solids control usage. Maintain a YP between 9 and 18. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for logging. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this deviated well bore. Maximize pipe rotation (ideally ~ 100 RPM). The use of good drilling practices to minimize excessive swab and surge pressure should be employed to minimize the chances for losses and differential sticking. By the T/HRZ, reduce the HTHP to < 5 cc 30 min with DURA TONE HT treatments. Operations Summary: The existing mud from the 8-3/4" will be used to drill the production interval. Reconditioned mud and/or mineral-oil will be used to meet dilution requirements. Drill out with a 8.8-9.0 ppg, weight up t010.8 ppg by the T/HRZ, then gradually increase the mud weight to .!,11.3 ppg by the Kuparuk C. Ataruq #2A, v1.0 5 3/10105 Halliburton BAROID Kerr McGee Mud Program Maintenance: 1. Additions of Geltone V / RM-63 will maintain/modify the system rheology to a YP between 9 and 18 to provide effective hole cleaning while controlling ECD and surge/swab pressures. Run the rheology checks at 120°F to TD. 2. OMC 2 and OMC 42 will be available to condition (thin) the mud as required; however, caution should be used when using these oil mud thinners (particularly the OMC-2) to avoid over-thinning the system. 3. Drill this interval with a tight DURATONE HT filtration mechanism « 6 cc/30 min @ 2000 F to top HRZ then <5cc/30 min @ 2000 to TD). 4. For formation bridging/LCM, graded calcium carbonate (Baracarb(s», cellulose fiber material (Barofibre) and SteelSeal are available. Baracarb 50 and I or Micatex should be strung into the system at 10-15 sxlhr when drilling the Tarn as it may be under-pressured. 5. The electrical stability of the mud should be run in the 800-1100 volt range with INVERMUL and EZ MUL as the primary and secondary emulsifiers. DRIL TREAT will be available as an effective wetting agent, when needed for weight up. 6. Maintain the water phase salinity between 250,000 - 300,000 mg/I range with sack calcium chloride. This level of salinity will provide an effective mechanism for good wellbore stabilization. 7. The excess lime content will be maintained in the 3 ppb range to provide an effective reserve alkalinity source and to improve the emulsion stability of the mud system. 8. The initial oil:water ratio will be 80:20. However if the O/W ratio is higher in any used mud which may be available do not adjust it down. From there, the system will be maintained with base oil allowing the ratio to drift to the 90: 10 range by the top Kuparuk. This will help reduce the cost of the original fluid and then help control rheology/ECD's with a higher ratio in the lower depths of the well. 9. A spike fluid should be used to raise the mud weight to 10.8 ppg or greater prior to drilling the HRZ. SUSPENTONE will need to be added at 2 ppb to mitigate barite sag and DRIL TREAT will need to be added at 1 ppb to ensure oil-wet barite. The mud weight should be gradually increased to 11.3 ppg prior to cutting the Kuparuk C. Suggested Drilling Parameters Pump rate and drill string rotation should be optimized through the real-time use of the DFG software for the actual ROP while drilling. The table below highlights the maximum ROP recommendations above which hole cleaning will become an issue. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM- 200 300 400 100 rpm 144 225 294 120 rpm 154 246 316 Ataruq #2A, v1.0 6 3/10105 Halliburton BAROID Kerr McGee Mud Program Risks and Continaencies for the well: Lost Circulation: Preventing the initiation of lost returns should be a primary goal of the drilling fluid in the well. To that end the rheology of the system has been reduced while still providing ample hole cleaning. Maintaining a low ECO while circulating, and eliminating high pressure spikes while tripping, will both go a long ways toward reducing the risk of lost returns. Wellbore Instability: The possibility for running shale exists, particularly in the HRZ Should this occur, consider weighting up in increments if 0.4 ppb. BARABLOK and AK-70 additions can be made to plaster the walls. Also, maintaining a tight filtrate and high water-phase salinity (280-300K) will help minimize the risk. Stuck pipe: Two forms of stuck pipe are possible. One is from hole pack-off as related to poor hole cleaning, Le. cuttings bed. Stuck pipe can occur if a cuttings bed forms, or if the wellbore exhibits severe instability. The best cure is to pro-actively prevent the occurrence of either scenario in the first place, and if they do occur, correct drilling practices must be employed. If pulling up into a tight spot, do not jar up further, but attempt to get below the problem. Backreaming a large cuttings bed is an invitation to packing off and resulting stuck pipe, and backreaming must be done with care and only when necessary. If stuck pipe occurs across a sand and there are indications of differential sticking, there are drilling fluid solutions. If possible, reducing the fluid density by a minimum of 0.5 ppg may provide some relief. Hole Cleaning: Maintaining the programmed flow properties is essential to successful completion of this well. Any indication of a failure to keep the annulus clean of excess cuttings (PWO increases, drag, torque, partial packing off) should be countered by increasing the circulation time on subsequent connections and prior to trips. Pipe rotation should also be used in conjunction with the pumping of high viscosity sweeps in the pay sands. The returns at surface of all pills should be monitored at the shakers and documented to gauge their effectiveness. When circulating bottoms up prior to POH, it is advisable to pull one stand every half hour to reduce the hole washout effects of circulating over one short interval. Long circulation times should be avoided if the bit/BHA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. Hiah speed pipe rotation is the most critical factor for hole cleanina. ROP rates above the recommended levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: · wiper trips · back reaming · extended periods of circulation (with maximum pipe rpm, targeting ~ 100 rpm) · hole cleaning sweeps (change flow regime of base mud by using fibers, density or rheology for carrying capacity) · connection practices - employing extended gpm, rpm and back reaming during the connection Ataruq #2A, v1 .0 7 3/10/05 Kerr Intermediate - Modeled cleaning 2000 1000 3000 Kerr · . ~ KERR-MCBEE CORPtJRATtON March 21 st, 2005 Ataruq #2A Kerr McGee Oil & Gas Corporation Abnormal Pressure Analysis Attached is a graphical representation of the known offset formation pressures and extrapolations/predictions made based upon that data. This well, Ataruq #2A, is located just west of the KRU near the West Sak 18 location. Ataruq #2 is due west of the Tabasco field, and lies between Tam and Palm. The pressure gradients used to extrapolate/predict formation pressures in Ataruq #2A came ÍÌ"om nearby field data and will be updated with Ataruq #2 actual data. As always, gas hydrates are of concern and precautions will be taken, however since the window is > 200' below the PermaÍÌ"ost, hydrates are unlikely to be present. Furthermore, we will not be using the diverter for this sidetrack. The predicted pressures in potential hydrocarbon-bearing formations were derived in the following manner using predicted TVD's and known gradients: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) Ub/gal) T/Tabasco 3,048' 2,877' 900 6.40 T/Tarn 5,553' 4,953' 2,202 8.55 T/Moraine 5,928' 5,263' 2,340 8.55 T/HRZ 6,354' 5,616' 2,920 10.00 T/Kuparuk C 6,791' 5,978' 3,450 11.10 T/Kuparuk A 6,827' 6,008' 3,468 11.10 » Due to potential inaccuracies with the seismic velocity, these formation tops may change The Ataruq #2A will be drilled using experience gained while drilling Ataruq #2 and at Palm, which includes abnormal pressure in the Kuparuk "C" with normal pressure in the Moraine above. Furthermore, the Tabasco sand [if it exists in this location] mayor may not be depleted as is seen within the Tabasco field located a few miles to the east. ~Oyn~L --- ASRC Energy Services 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6269 Predicted Formation Pressures r'\,\ "" I I '\ ", [\, I '" I , "" ^"'--.. tJ:2A " ".,,,.,,,,oo &ill _w " ~" ,/ (P p n ;) '\ // JI I ~~- 1- - .~~ /' " I ~', 1 I \. I \ I I I "'.. I I I '\\ I I I t't~$dl I I I I I """7"" J~ 1 I~ I f't/ I I i/\ I I I < I I I , I , , I ", I " i I I I I , I , (} 200 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 Pressure (Subsurface) -500 -2000 -3000 -3500 -5000 -5500 -7000 -7500 -8000 -0 -1000 -1500 4500 . ::~---------------------- ~ ---------------------- ~r ~ or 6 1/8" ; J/8" I ___~:oo~~~ V~VE ___ r 3" 5000# HCR VAlVE I' 10 5/8" """r-----:: ~ U~- 2' . 1/1" --------- CUS10MER FURNISHED ~ ~~.~ T 2' 0" ------- 24" DIA. . I ::-..... 16"-150# FlG SURFACE DIVERTER CONFIGURATION BOP STACK ELEVATION 13 5/6" 50110 HVDRIL ANNUlAR BOP BOLTED FLANGE SINGLE 13 5/8" 5000# HVDRIL MPL PIPE RAM BOLTED FLANGE SINGLE 13 5/8" 50110 HVDRIL MPL BUNO RAM BOLTED FLANGE 4" 5000' HCR VAlVE II · 4" CHOKE UNE 4" 50110 GAlE VAlVE BOLTED FLANGE SINGLE 13 5/8" 5000' HVDRIL MPL PIPE RAM BOLTED FLANGE ADAPTER SPOOL - HUB x FLANGE 21 1/4" 2000' HVDRIL BOP/DIVERTER i I ---1---- I I t:J '-18" KNIfE GAlE I WI HVD. AC1\JATOR I 2' 0" .._.._.._~.._n_.._.._.. .._.__n_U_"_"__O . 1 ' "-"-"-"-"-"-U_Ul u_.._.._.._n_."_U 25'-11" " ....., , , , \ : ',+ ' \ , , , , , RE ~---~ SURFACE DIVERTER PIPING CONFIGURATION PL6.N VIEW 121Þ1/01 E JA R.K. 08/04/11 I 1'8 1M 112/21/17 C RSI RSI fT1 /27/11 I DWI IA 08/01/13 " 1IIE IA IIA1E '/I' ,. "W' . ~III~ Nabors AlasKa Proposal for Arctic Drilling Rig with Crew OCTOBER 2002 '. ..·L _.':I~ Ait: A ARMSTRONG Oil &: Gas, Inc. =: ê == =n~ftm.~c:..=. OF ..NallanA.... =:-c:' 0::' ~ Q' A__ J_~ ~ AIaUa I95DJ 107-283-8000 RIG 27E BOP STACK AND SURFACE DIVERTER MOOIFIED DNERŒR SIZE (1" I CONFlllURATION CHWIED ClMP CONNÐ:TIDII TO IlIUED fIANOE RIMIED IINERTER fItS PER DCN '3 GENERAL ISSUE GENERAL ISSUE DE!ICIIIPIIDN PIIOoIECF / "", , , "" . ............,.,...,..¡.,....................................................................... VOID OVER $100.00 ."." .,..., .,f;:. ..... C;, IJ)'j~ t! '"¡¡~%~{I¡¡: ",.1..)', ~~S82·¡""I.~~:..B~_~~ ~ .. / """ ~f4,b"ld!¥V ,Of"A~~c :~IO~ R~IO.....I:Ö,,,,POt:."d~r': J:- ,'i, ~, l \1 ) i ~ : t ; f: ;;: / i¡ 390'0 t STREF:t': ..'. ; ; f ANèHÖRAGE¡' ALA'sK'A 99503 (997) ~3906200 '.', , PAY. ONE HUNDREDDQLLÁRSANr> 00 CÈ['JTS e- . STATE OF ALASKA ~~EOFOIL & GAS CONSERVATION COMMISION 333 WEST 7TH AVE STE 100 ANCHORAGE, AK 99501 i g if tr 7 B 2 7 . . II. j 7.. .: . 25 200057.: II· . H; j 2 2 II. . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME 4f~yug Z-óS _OS:-b /Exploration Stratigraphic z4 PTD# Development Service CHECK WHAT ADD-ONS 6JCLUE"· APPLIEs (OPTIONS) ... MULTI The permit is for a Dew weJlbore segmeDt of LATERAL aisting weD . Permit No, APJ No. . (If API Dumber ProductioD. should cODtiDue to be reported as last two. (2) digits a functioD 'of the origiDal API number. stated are between 60-69) above. .. PD..OT HOLE )n accordance with' 20 AAC 2S.00S(t), aU (PH) records, data and logs acquired. .for the pilo1 bole must be clearly differentiated ïD both name (name on penult plus PH) .' and API Dumber (50 - .. 70/80) from records, data and logs acquired for well (Dame on permit). SPACING Tbe permit is approved subjed ·to fuU EXCEPTION .' compliance with 20 AAC 2S~OSS~ Approval to peñora1e and produce is CODtingeat UpoD issuance of ~ conservation order approving a spacing e:l ceptioD. (Company Name) assumes tbe JiabiUty of any protest to tbe spacing .~:lCeptioD tbat .8Y occur. : DRY DITCH All dry ditch sample sets submitted to tbe V/ SAMPLE Commission must be in no greater -tbaD 30' .' sample intervals from below tbe permafrost or from where samples are fint caught and ] 0' samplebiter:vals tbrougb target J.ODes. ." _ Well bore seg On Annular Disposal ____Program EXP On/Off Shore Ataru¡¡ 2 Name: GeoArea Unit - feerequirecl fpr this $idetracls ofexistinge1<ploratpry welJ I;ntire well_bprewithin ADL 390502. 2A Wel PB-IJ:2 EXP targeting Kupan¡k C andA sands. I;¡çp!oratory sidetrack_ CO :432C gOYerns Kup here, 500' setbacls Conforms to_ CO 432C, ~eaJest wel bore ill section. to S, n~js CPAI Jease ADL 390503~ 1959' locate_d.1:114 miJe_sJo I;SE. inlectpr re¡¡uired. Nearest pJoperty is KßU 2T-36,a.Kuparuk OiJ PooJ Ol1lywell . OpeJatorformforADL390_502 received 9n 3/18/20Q5, SfD Designation 9f Y~s Y~s Y~s No_ Y~s Y~s Xes Y~s Y~s Y~s Y~s Xes Yes NA _NA NA NA Initial ClassfType boundacy_ P~rmit fee attaçhed _Leas~ _number ~nnr, _Unique well.n_a ndl1lunb_er IQcated :... .t:".~..l nn^l_ located ; 'rom driJling unit 'rom other welJs l.dJilJil1g unjt :Ju.ded Field & Pool '"1"1"" opriate_ ~.._a_d_e~..~e_u I""'!o'''''' Jocated proper distance_ _S_utficient _acreage_ayailable Jfdeviated, js. weJlbore plat Oper_ator only affected party _Operator bas_apprppriate_ bond in II I I....L._1\o<I!,h_":"'. ....-r""....pvaJ (for inc9mmel1ts) Il1jectipl1 Ord~r I"-'_....""'''-~y ~.IU.I!II! ~Iy~ ""ltU ~_LlII;;oI.La_authori~ed by_ I 12 i3 14 15 6 7 8 9 10 11 12 13 14 15 16 17 Administration Wel Wel Well Date Appr SFD 4/4/2005 ACMP doesnpt affect AOG_C_C. p.ermit to drill. pro~ss. . ~-~.~ (205-039). (b)(3). in origin_at weJ > AtanJq tJ2 n N:r:> 1:47:102_ ell. :e Ijner"wj ! em_el1t wi Con_ductor _set All aq.uifers exempled,A_v ",,:., jn_ original Surface casing set _b~ fully çemented. ~o Ipl1g strin.g_pJanl1ed, Plan i$ to driJI <:Il1d PM. coyer any bydroq¡rbon. All waste to_approve_d dispos.al. well(s) WelJ lrajecto_ry: is away_ from_ original wet!. _ (110 directjonal_conflicts, BOP stackwilJ already_bejn place, e .~ppg Plann_ed MWloJ.1 EMW. Maximum expectecl fprmation pressure 1.1 J 5000_p_siBO~ testp!anned, MASP çalcuJatedat 27:92 psi Mucl Sh9Uld preçlUde H2S on 1-12S ha_sbeen reported at2Tpad. NA NA NA No_ Y~s Yes Yes No_ Y~s NA Y~s Y_es Yes Y~s Xes No_ NA ACMPFïndjngof Con$i$tencyhas beenjssued_ forlbis prolect Conductor stringpJovided _Surfa~ known USDWs _CMT v.ol. adequ.ate_ to çirc.ul.ate_ on _cond_uçtor. casingpJotects al & SUJfC$g to tie~in Jong _string known -Pfo_d uctiye borilons CJ, B& permafrost tosud çsg _CMT v.ol. adequate_ CMTwil! coyer_a] Casil1g designs ade¡¡uaJe f9r No reseJve_pjtplanned, berequired_. ßig isequippe_d_with $t~el_pjts. well will 403 to PM original. beel1 aPPJoved AdequateJankageoJ re_Serve pit If a re-drilL has. a. tOA03 for abandonme_nt Adequatewellbore separation proposed Jfdiveder Jeq,uired, does it meet reguJations_ DJil.lil1g fluid prOgJctm schematic & eq,uip Jistadequate _BOPES, do they meet reguJation cnnL nro.~C!' r~.a.:nn ~"\I.'\rnl"\r:~"'o.· _test to_(puJ 'c I RP-53 (May 84) in _comments) psig !1õ4_1.1o_';:J ~f""-I""~""-f""._I~I.'V, U_""_I-~ .....!~'"'~ _operatjo_n _sbutdown H2S gas_ prob_able MeçhanicaLcondjtion pf wells within AOß yerifiecl (Forse[Vj~ welJ onJy) force Permit call be issued wjtbout conservation order Permit c_al1 be issued wit bout ad_m'"'~·r~.''',:. "nn' Can permit be approved before 15 _Well'~~"·~'" u,'."'" ~rð~ ~"... "..~.- # (PutlO# AJI W! :Fpr se[Vj~ wet onl)'>- _ _ Pre-;) ) less than_ 3 months_ (for service well. onJy) Js presence_ of 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Engineering Date 4/5/2005 ~CNV\ Appr TEM Rig has sen$Of$ and alarms. rig._ KUP_pJoducers 21-21 have measured 210& 30ppmH2S, ,...~ ·"~I· may_b_e.underpressur_ed due_ I Kup. Will be drilled with ..^ "'~r' I' <"') r,'o. ,"'nr::::n"")nn.\ _states 5370 respectively , & 2T-38 (1.5 -2mi normal toJoP I-IßZ, _e)'(cepUor_labas_co Sar,j.I¥ ,,,aL. HRZ 11..1 away) Otfset Expected pressure .gradient thel1 No_ Y~s y~s NA Y~s Permit c_an be issued wlo_ hydrogen_ s_ul.fide meas_ures _D_ata_presel1ted on pote_ntial PveJpreSsure _ZOne$ 35 36 37 38 39 Geology iJ I T'_I.~. '"!Iq 4. I!I~ \-LY'-!V_uÇl"!./ ppg I;MW _11 Sejsmjc Ivelpcitysballow hazards $urveyjncJuded no shalJowhazards_ have been jd_entified in _seismic .orof(set weJI data. rising!p 10.0 ppg EWM witbil1 to _offset prpduction~ .5ppg. mud weigh.ts to _Seismic_analysjs_ Qf shaJlow gas_z_ol1es Seabedconditipl1 survey (if off-shore) Contact Date 4/4/2005 Appr SFD This exploratory sidetrack is being drilled to the same bottom-hole location as the proposed Ataruq #1 well , as show in the "Shallow Drilling Hazards Evaluation, Kerr-McGee Ataruq #1 and #2 Locations" document contained in well file for Ataruq #2 (PTD 2050390). SFD 4/4/05 Date namelphoneJor_weelsl)' progre$sreports [e1<ploratpry _only] Public Commissioner Date f-5 -ð5- Engineering Commissioner: (ji?I4~I~ Date: Geologic Commissioner . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify fìnding ìnfonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I -C) Sperry..Sun End of Well Report Ataruq#2a Exploration" NWMilne Point I Directional Drilling & MWD/L WD Services I I I I I I I I I I I I I I I I I I I sper-r-aV-5un CAI LLI N G SERVII: E 5 End of Well Report Ataruq #2A Kerr McGee Directional Drillers Ken Harding / Mark Brouillet RECFI\IFD OCT 2 0 Z005 III. k ,'" .. . .0rnmissi0I1 M as a Uh c.,*" Anchorage I I I I I I I I I I I I I I I I I I I Kerr McGee Atamo #2A Operator Kerr McGee Well Ataruq #2A Job Objectives: Aturaq # 2A This well is a sidetrack off Aturaq # 2 exploratory welL Objectives: No Spills, No accidents, No Environmental Violations Evaluation for possible future development in this area Directional Objectives. Efficient cost effective drilling for customer Hit all targets Drill under planned time and AFE budget No tool failures or unplanned Summary of Results: Directional Driller arrived on location for sidetrack. No Directional personnel on location during testing of Ataruq 2. Tools were inventoried and BHA list prepared for kicking off cement plug to begin Aturaq # 2A this well has been assigned a new job # at the request of the client. This means new billing SOA will also be created and even though this well is actually a sidetrack tie in survey will be to surface. With 3rd cement plug set the rig tripped out with the mule shoe. The rig floor was then cleared and cleaned. Rig crew then held a PJSM on picking up BHA # 1. The bit, was torqued to motor, Stabilizer and float sub made up. The MWD directional probe was then picked up and torqued to the string. A rig floor offset was done (275/702 X 360 = 141.43) the remaining MWD components were then made up and data loaded. With data loaded the Non mag flex Drill collars were picked up. A stabilizer was added to the top ofthe flex collars between flex DC's and first stand ofHWDP. The MWD was then shallow pulse tested at 500 gpm with 1,070 psi. The rest of the HWDp and the jars were ran from the derrick. The assembly was then tripped in the hole to 3,080' where it took weight. Tagged cement at that depth. With assembly taking lOK bit wt cement was drilled from 3,080' to 3,330' With a good hard cement plug the Directional Driller made the decision to make 30' of hole at a 70 L toolface. This was not time drilled as it was thought the formation softer than the plug in this area. With 300 feet of cement plug the decision made to drill off the plug with out time drilling was justified if it worked it saved many hours of rig time which is valuable with the limited amount of days left for drilling this exploration welL AIl drilling must be completed by the 25th of ApriL This leaves 7 days to drill from 3,320' to T.D. at 11,318' This means drilling almost 8,000' with two drilling assembly and justifies the gamble of drilling off this cement plug. If unsuccessful there is still ample footage of cement plug for time drilling off the plug in text book fashion. Judging by the wt. indicator it seems as if the assembly kicked off the plug easily. Samples will be checked for cement percentages while circulating for the FIT. The FIT performed trucks that were staged in position for displacing well to new drilling fluid began unloading mud to pits. The mud swap was done while drilling with displaced mud going to vac trucks. Sliding was done from 3,330' to 3,380' before rotation was initiated. A check shot survey at 3,364' survey depth showed inclination to be 43.74 degrees. This confirmed that the assembly was at a higher inclination than the parent wellbores profile at that depth. With this knowledge confirming the assembly was in fact kicked off the cement plug. And with samples only showing 20% cement, rotary drilling was initiated to minimize the dogleg rate from previous slide footage. Total drilling time for kicking off cement plug was .85 hrs. BHA performed well. motor exhibiting consistant 12° dogleg output. Starting to hang up a little but hasn't been a problem yet. Added 2 drums Drill N Slide. Assembly was kept very close to directional proposal line. Largest dogleg for this section was 5.2 this exceeded the planned rate by only 1.2 degrees. Drilled to 4,975' and achieved all directional objectives for this BRA. Rig circulated a sweep around and began tripping assembly out of hole. Assembly is 4' from plan with correct Inclination and Azimuth. Directional proposal now calls for a long tangent from 4,975' to 8,896'. The Geo-Pilot rotary steerable will now be the more suitable assembly for efficient drilling to T.D. Geo-span skid is rigged up and tied into the mudline, will psi test skid on trip in hole with Geo-Pilot BHA. Made up GP BRA, tripped in to top ofHWDP, tested Geo-Span, MWD and Geo-Pilot. Broke in GP seals. Changed GeoSpanjet from 16 to 18. Tripped in and filled pipe at shoe, continued trip in to bottom with out problem. Precautionary reamed 50'. First survey with new MWD showed 3 degrees azimuth change in 50'. Torque very erratic, adding Torq Trim and Drill N Slide. Connection was to be made at 5,390' slips were set but pipe handler would not work. Rig began fixing top drive. Pipe was moved periodically to ensure good hole conditions remained. Flow rate was kept down to 325 gpm while pipe was static to avoid washing out of hole. Several calls from camp were received with explicit instructions frem Co. Man to keep pump rate up. With no hole problems the need to circulate at the drilling flow rate of 600-650 gpm seems that it can cause adverse effects rather than positive ones. Doing as directed by Kerr McGee Company man with no further opinion to be offered by this directional driller! Top drive repair took three hours. Using 23% deflection on Geo-pilot holding a 130 -140 Left toolface is keeping the assembly from building and walking right in the colville formation. ECD's are being closely monitored with pump rate lowered when reaming prior to connections. Swab and surging are also being avoided. ECD's are at 10.5 with a 650 gpm flow rate and penetration rates Alaska Page 3 Sperry-Sun Drilling Services I I I I I I I I I I I I I I I I I I I Kerr McGee Atarua #2A between 175-200 fph. Rotary speed is at 150 rpm. Torque is very errattic but not peeking over 15k. Downlinking has been done without any problems, all downlinking sent has been received and tool has responded. Deflection increases when backreaming prior to connection. With connection made deflection stays at a higher percentage for 15'-20' before it returns to the previous setting. This has not slowed down drilling rates and is to this point not been a problem. MWD has stated that there seems to be some questions concerning the azimuth showing up on the surveys. They have requested that surveys be taken in different toolface setting such as highside, 90 Right, 180, and 270. It should help with IFR on surveys and give a more accurate correction to survey azimuth. Toolface is being changed on goo-pilot just before connections are made in an attempt to comply with this request. At the depth of 6,051' the brake warning light came on the geo-pilot display,housing light and toolface tracking lights also came on. These waming lights did go off at 6,090' IFR / Cassandra corrections have been applied to surveys moving the assembly only one foot trom the previous survey locations. With 12 surveys used for the IFRlCorrections having the adjustment equal only one foot in placement is a relief. This one foot naturally took the assembly trom eleven foot off the line to twelve. But deflection and toolface settings will be downlinked to tool to correct. Morning meeting requests are; maintain 650 GPM, 150 ROP, 170 RPM. Starting to have more touble downlinking, requiring multiple tries for a successful downlink, takes commands off bottom or iflet drill off, MWD showing lots of downhole noise on bottom. John Patton was consulted on our hole cleaning, he suggested 2 ppg over MW be our ECD high limit. Short tripped trom 6992' to 5860', no problems. Drilling rop has slowed down while this is aiding in keeping the ECD's lowered its not doing much good for footage. Geo says we are to expect some pretty tough spots until we clear the bottom of the colville fonnation. Changed the jet in Geo-Skid trom a # 18 to a # 20 in hopes of improving downlinking to tool. Successfully downlinked several times with no problems. This run came to an end when two times the display showed downlinking as unsuccessful. It does not appear however to have helped with the # 20 jet so it was changed to a # 16. Drilling at 7,235' hit a very hard spot picked up and reamed trom ten feet off bottom and when bottom tagged drilled with 10K bit wt. to let assembly work through spot This may of taken extra time but it is far better to conserve bit life by not putting excess wt on bit to get through these hard spots as we still have over 4,000' to go and want to avoid tripping for bit which of course would consume many hrs. of valuable time. Drilling still has a drop dead date of 4-25. Downlinking has not improved and it is still necessary to pick up off bottom to get a successful downlink. Assembly has still been kept close to the line even with downlinking problems. Now downlinking on prior to connection waiting until blocks are bringing stand down trom reaming before connection. This has been working well so far. 8100', wont take commands on or off bottom, tool pointing where it wants to, seeing pressure noise above threshold, tool thinks it is getting commands. Downhole pulse amplitude low, changed jet to 18, raised DL threshold to 276. Added some EZ Glide lube to mud. Downlinking ok now on bottom. Trying to get back toward plan now, 15' off, doesnt want to build with 50-60"/ct deflection over 150'. Increased deflection to 80"/0 at 20L. Started building right away. Dropped deflection to 45% when close to desired inc, started dropping again right away, back to 80% we go. Number 1 pump number blew swab. Swab was changed with top drive service being done while waiting on pump. Drilling ROP is far lower than expected with continuing erratic torque.Lube percentage shows a meager 1.5% with the assembly laid out at this angle and depth this is surprising. Several times request have been made to increase lube percentage. Answer is always yes will increase, yet lube percentage still remains the same 1.5% that was on yesterdays mud report? And torque is still erratic swinging trom 2K to 16K. Possibly mud dilutions are knocking down this lube percentage as i am sure the request for more lubricants is being worked on. Downlinking is once again being difficult to achieve. Tried on bottom to downlink which did not work. Picked up off bottom and stopped rotating and even this did not work. MWD has increased threshhold and did succeed in downlinking to tool. Sweeps are being pumped every 350' with not a very noticable increase in cuttings. ECD's are staying around 10.9 - II with the mud wt. at 10.0 ppg. With downlinking still a problem the jet in the geo-skid was changed ftom a # 18 to a # 20 the first downlink with this bigger jet size was successful. Optimism as to if it will continue to downlink without problems just isnt really in consideration just now. 9,538' cleaning suction screenS in # 1 mudpump. Reamed prior to connection with one pump. Downlink threshold now at 317. Began planned 4°/1 00 drop at 9630' Md. Initialy dropping 3.5°/100 with 40% deflection for 100' then started drop rate started diminishing, increased deflection to 100% over one stand. 110 ROP and 120 RPM requested at 9660' Md for log quality. Seeing over 4°/100 drop now at 9900' Md. Low oil light at 10295' Md. 1530 hrs. Now its off, 1540 Hrs. Geo-Pilot was set at 100% deflection until 10,620' lowered deflection to 70% at this depth as DLS = 5.5 degrees per hundred. Catching the line and do not want to crash through it want to follow it. Drilling sections ofthis area at controlled rate for logging purposes. Geologist is calling when rop can be increased to help get to T.D. before memory dies on batt sonic tool, It will be close! 10,770' with inclination at 28.99 deflection and toolface were reset on Geo-Pilot new deflection is 16% with a 15 left of highs ide toolface. This was done to maintain the inclination at 27 .5 as per plan. The assembly should still drop slightly with this deflection. Once at the desired sail angle deflection will be increased to a percentage that will hold the correct angle. 11,050' under two feet trom target center. Discussion with Geologist and will now drop deflection allowing geo-pilot to drop inclination. Explained to geo there is a bottom hole location that cannot be crossed and ifT.D. is deeper than projected angle needs to be lowered to stay within hardline. Geologist has now called the floor formations are coming in deeper than prognosis. Need to drop angle at least 4 degree per hundred to drill to 11,370' and stay in bottom hole location hardIine! Dropped inclination to 22° in order to stay in hardline at possible deeper ID. ID called early at 11242' MD. Circulated bottoms up once, stood one stand back, circulated two more bottoms up, backreamed out, tight and packing off trom 11030' to 10990'. Continued backreaming out. Logged while backreaming trom 10605' - 10435' at 160'/hr. Backreamed out to 10389' with no problems other than rig SCR kicking off occasionally requiring the use of only one pump. Ran in with no problems to 10860', precautionary reamed to bottom, tight at 11130' - 11137'. The hole was circulated with a hi-vis sweep pumped around. This sweep brought a very minimal increase of cuttings to surface. Backreaming tight hole and packing off trom 6670', losing some mud with hole breathing. Began backreaming with lower flow rate to reduce mud loss, pulling better without packing off now, tried to pull without pump once at 5500', tried to swab a little so continuing to pump out backreaming to shoe. CBU at shoe and flow check.Rig tripped out to shoe. Changed swivel packing in top drive and pumped a dry job. The trip to surface with BRA then bega:n. The Geo-Span skid was rigged down while rig crew changed out swivel. Skid was flushed and power washed along with all piping. The skid was removed trom cellar and is ready for shipping to Sperry's R&M facility. All tools will be shipped back to the shop today as the rig will soon be setting cement plugs for welll abandonment. The assembly was pulled to the ghost reamer at the top ofthe HWDP. This reamer was laid down and the HWDP racked in derrick. A single was picked up before pulling the HWDP, this moved the jars to the top of Alaska Page 4 Sperry-Sun Drilling Services I I I I I I I I I I I I I I I I I I I Kerr McGee Atarua #2A a stand were they could easily be laid down. With the jars laid down and the remaining HWDP racked in the derrick the flex drill collars were then laid down along with the float sub. A PJSM was held and the nuke sources pulled with MWD then being downloaded. The remaining BRA was laid down with the bit being graded a I-l-CT-N-X-I-ER- TD Discussion: BRA Summary: BRA # 1 easily met all objectives set forth. This assembly was very steerable and delivered a good consistant dogleg rate. There were minor wt stacking problems with the assembly hanging up at times. But these instances were few and the problem was in fact only minor at best. The dogleg rate as per proposal was to be 4 degrees per hundred. Max dogleg for this BRA was a 5.2. The BRA kicked off the cement plug in only .85 hrs. and only a 4.1 dogleg rate was delivered trom kicking off the plug. This BRA never strayed farther than 4' trom the proposal line. This gives merit to the consistant dogleg rate and ease of steering as mentioned above. The Hughes GT -I milltooth bit was graded I-I at surface. BRA # 2 The Geo-Pilot rotary steerable BRA drilled the well to T.D. as planned. This assembly also stayed very close to the proposal line. The largest dogleg in this interval was a 5.2 degree. The planned dogleg rate was four degree per hundred. The 5.2 degree dogleg was the first survey taken on the run and this survey showed an azimuth swing of three degrees. This dogleg is most likely the result of the survey tools being changed out ftom previous bha. This BRA drilled 6,267' and never strayed farther than 16' distance to plan. This BRA never got more than 2 degrees away trom proposed inclination and azimuth until directed by geologist to point assembly straight down at end of well. All logging requirements were achieved. SHA Bit Motor Hole Size MOln MOOut TVOln TVO Out Ineln Inc Out Aziln Azi Out Orlg Circ # # Run# (in) (ft) (ft) (ft) (ft) (dell) Ideal Idea) (deal hrs hrs 1 1 1 8.500 3320 4975 3076 3967 42.1 76.3 6 303 16 7 2 2 2 8.500 4975 11242 3967 6134 76.3 21.7 303 302 56 56 Table 1 - BHA Summary Motor Run SUmmary: The 7" Sperrydrill performance motor delivered good horsepower without stalling. No problems were encountered with the motor. This motor is a proven performer and easily handled the formation drilled. Oeo-Pilot rotary steerable tool showed good dogleg rates trom the begining. The tool was reliable throughout the run with minimal housing roll or toolface tracking issues. The low oil light came on but only for a few minutes. Downlinking to the tool was ftustrating at times but the problem was related to downhole noise and erattic torque trom the two ghost reamers ran. The noise and torque seemed to interfere with the signal being correctly read by the tool. These problems were overcome by raising the signal threshold limit and increasing the jet size in the geo-skid trom a # 18 to a # 20. Having drilled 6,267' with this bha this will be considered a great run for this tool. Motor Manufacturer Type Lobe 00 Gauge Bend Adj OLS (Ori) ROP (Ori) ROP (Rot) Run # (inl (in) (dea) 10{100'1 (ftfhr) (ftlhr) 1 SSDS SDerrvDriU 7/8 6.750 8.250 1.50 Y 81 113 2 SSDS Gee-Pilot / 6.750 8.380 0.00 N . 112 124 Table 2 - Motor Run Summary Bit Run Summary: The Hughes GT-I milltooth bit that was used in BRA # I drilled trom 3,320' to 4,975' this was 1,655' total footage with 574' of sliding involved. 16.27 drilling hrs. were accumulated on the bit with an average rop of 102' fph. 25k average bit wt was 25k and the bit came out with a grade ofl-I-WT-A-E-I-ER-BRA. It can defmately be considered a good run for the bit. The Security FSF 2565 PDC bit used with the geo-pilot racked up good footage making the objective of not tripping for bha. The bit started out strong with great penetration rates. These penetration rates did decline but more likely due to the high angle ofthe well than the bit. Alaska Page 5 Sperry-Sun Drilling SeNices I Kerr McGee Atarua #2A I Bit Manufacturer Style 00 Gge len Nozzles TFA Dull Grades Ftge Drlg Rap # (in) (in) (/32's) (in2) 100 lBGO R (ft) hrs (ftlhr) 1 Hughes GT-1 8.500 3x16 0.589 1-1-WT-A -E-I-ER-BHA 1655 16.27 102 2 SDBS FSF2565 8.500 1.200 5x16 0.982 1-1-CT-N -X-I-ER-TD 6267 55.77 112 Table 3 - Bit Run Summary I Rig 27-E: I This rig has improved greatly as it drills each well. When 27-E started doing exploration work for Kerr McGee there were many difficulties associated with the rig as it had been stacked previously. Work in all areas over the last two years have made countless improvements. The latest improvement is to the pipeshed where it was usually very cold. The addition of some duct work and a Tioga air heater now make this one of the warmest pipesheds on the North Slope. Problems moving BHA components in the pipeshed had previously caused problems as the alignment of overhead beams was off. This made it difficult to move components iTom one end ofthe pipeshed to the other. This situation is now fixed and the overhead hoist travels between these beams without problems. Many other improvements have been made to the rig and it is proving itselfto be a good drilling machine! The Toolpushers and rig crews should be congratulated for there continuous improvements and outstanding efforts put forward drilling these exploration wells. These personnel have worked with exceptional effort to maintain high safety standards. Thorough PJSM are held with input iTom all parties involved. These meetings and the pre-tour meetings are taken very seriously and it is very noticeable that all attending are focused on mitigating any safety hazards involved in the tasks at hand. The hands make the rig and Nabors 27-E personnel are continually showing pride in there work and there rig. There efforts are not going unnoticed by the directional personnel involved in these wells I I I I I I I I I I I I I I I Alaska Page 6 Sperry-Sun Drilling Services I Ke" McGee I Hours by Operation Summary I I I I: o i 8- o 72.04 25.17 t 4f·29 21.42 14.33 I Rig Service & Repair Short Trip I I Miscellaneous Other o 50 Total Hours During Job Days vs. Depth I 3000 3500 4000 4500 5000 5500 6000 g 6500 .¡: - 7000 Do CD 0 " e 7500 :::I III IV CD 8000 ::ï: 8500 9000 9500 10000 10500 11000 I I I I I I I I I I 11500 o , \ \ \ \ \ \ \ \ \ \ \ \ \ 2 3 4 6 7 8 9 5 Day I Alaska Hours per BHA Breakdown Ataruq #2A 160 140 ~ IV 120 - ~ ~ 100 0 ø 80 m I!! :::I 60 0 :r S 40 0 I- 20 0 100 II Drilling II Circulating mD Reaming 0 Other 141 1 2 BHA Number Average Rate of Penetration per BHA 't:' .¡: £ Do ~ 120 110 100 90 80 70 60 50 40 30 20 10 o 1 2 BHA Number Footage per BHA :J 7000 6000 =- 5000 " ~ 4000 .¡: 0 CD 3000 CI IV - 0 0 2000 u. 1000 I 0 ISR_d Page 7 6261 --- --- 1655 .-- iii Oriented 1 I I I I -~--~-------~ 2 BHA Number Sperry-Sun Drilling E;ervices - - - - - - Sperry-Sun Drilling Services MD Formation Name Inclination - 0 20 40 60 80 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 0 2 4 6 8 - GT-1 3x16 132's 1.70ftlmin 16.27 hrs FSF2565 5x16/32's 1.87ft1min 55.77 hrs - - Kerr McGee Ataruq #2A 27-E Drilling WOB 26 klbs RPM 98 FLO 614 9pm SPP 1955 psi WOB 17 klbs RPM 120 FLO 644 gpm SPP 2501 psi - 7" SperryDrill 7/8 L 1.50' A8H Geo-Pilot 1 L - - BHA - - - - - - - Kuparuk AK-MJ-0003663832 AK-MJ-0003663832 Exploration KMG 8.250 in @ 2.82 fI Motor revl gal" .33 II Adj. Bend 1.5/1 Planned flow rates 600-650 8.250 in @ 28.69 fI gpm Sensor Oist : Oir = 38.261 OGR" 47.081 EWR = 54.861 8.360 in@180.121t PWD =63.14 8.500 in @ 1093.47 It #1 @ 3319 8.380 in @ 15.35 It 8.380 in @ 32.18f1 8.380 in @ 55.45 It 6.250 in @ 72.45 II 8.500 in@ 1126.89f1 Planned flow rate 600-650 GPM 1/ Rotary 120 - 180 RPM Max bit wt 25 K/I Bit needs to make over 6,000' ABI = 6.5/1 OM = 25.9 II OGR = 34.74 II EWR = 42.52 PWO = 50.80 II SLO = 72.98/1 eTN = 86.82/1 ACAL = 83.34 Batt Sonic = 110.72 #18 Jet in GeoSpan #210064, OL threshold at 180 start. #20 Jet, DL threshold a1317 end. #2 @ 4975 I HAib!~leUI'e!'jjCN Sperry Drilling Services Kerr-McGee Corporation I -4000 Eastings -3000 -2000 -1000 Scale: 1 inch = 1000tl: -5000 I I I I I I 1000 I I 2000 I £. ..... c.. () o 3000 co o :e () > I I 4000 I I ¢:: 5000 o o o ...- I II .J:: o c: ~ 6000 Q) ãi o C/) I I DrillQuest 3.03.06.008 I o Western North Slope, Kerr McGee Ataruq #2A --- Well: Current Well Properties Ataruq #2 Horizontal Coordinates: Ref. Global Coordinates: Ref. 47TFNl, 1834.6' FEl: Ref. Geographical Coordinates: RKB Elevation: 5969528.36 N, 480716.30 E 0.36 N, 0.30 E 70· 19' 40.4852" N, 150· 09' 22.9997" W 102.85ft above Mean Sea level North Reference: Units : True North Feet (US Survey) The "Directional Difficulty Index" for this profile is 6.0 ---- DrillQuesf o I I I I I I ""'11 I '"' I "" 1 I I 14706 I 4000 3000 tJ) c:: :c t::: 2000 ~ 1000 g o ...- II .J:: o c: ...- --- o å) ãi o C/) o 1000 Vertical Section 2000 3000 4000 Section Azimuth: 6.940° (True North) ------------------- 5pe~~V-5un Page: 1 Operator: Kerr McGee Well : Ataruq #2A Exploration KMG Rig: 27·E Field: Kuparuk Location : AK-MJ-0003663832 Job # :AK-MJ-0003663832 North Ref: Mag Declination: ° VS Dir: 6.94° (from Wellhead) WELL BORE SURVEY DRILLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section N/S EIW Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) ("/100') (°/100') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (ftIhr) (#) 3320.00 42.14 5.70 3075.7 707.4 699.7 105.9 0.00 0.00 0.00 1 Tieon Tie in From malnbore 3423.42 44.15 0.15 3151.2 777.9 770.3 109.4 4.15 1.94 -5.37 20 40 525 1400 3330 3380 70L 136 1 3517.97 44.33 355.00 3219.0 842.9 836.1 106.6 3.80 0.19 -5.45 20 80 600 1740 3465 3495 80L 148 1 3612.72 44.82 349.89 3286.5 907.2 902.0 97.9 3.82 0.52 -5.39 20 80 600 1740 3559 3589 70L 137 1 3705.48 44.91 345.18 3352.3 968.9 965.9 83.8 3.58 0.10 -5.08 20 80 620 1900 3653 3683 70L 124 1 3800.95 46.58 340.06 3418.9 1031.2 1031.1 63.3 4.22 1.75 -5.36 20 100 600 1900 3747 3780 60L 155 1 3893.75 49.20 337.67 3481.1 1091.9 1095.3 38.5 3.41 2.82 -2.58 20 110 620 1900 3842 3875 40L 109 1 3989.12 51.83 332.22 3541.8 1154.2 1161.9 7.3 5.20 2.76 -5.71 20 110 620 1950 3935 3975 60L 162 1 4084.04 53.32 328.46 3599.5 1214.7 1227.3 -30.1 3.52 1.57 -3.96 20 110 620 1950 4030 4062 55L 140 1 4179.15 55.98 324.58 3654.5 1273.7 1292.0 -72.9 4.35 2.80 -4.08 20 110 620 1950 4125 4161 50L 130 1 4273.66 59.32 321.27 3705.1 1331.1 1355.6 -121.0 4.61 3.53 -3.50 20 110 620 1950 4221 4257 45L 116 1 4368.10 61.12 317 .43 3752.0 1386.3 1417.8 -174.4 4.01 1.91 -4.07 20 110 620 1950 4314 4346 55L 74 1 4461.00 63.30 314.95 3795.3 1438.3 1477.1 -231.3 3.33 2.35 -2.67 20 110 640 2200 4410 4438 50L 120 1 4556.14 65.97 310.73 3836.1 1488.7 1535.5 -294.4 4.89 2.81 -4.44 20 110 640 2200 4503 4539 50L 98 1 4651.05 68.41 308.81 3872.9 1536.1 1591.4 -361.6 3.18 2.57 -2.02 20 110 640 2150 4598 4630 50L 106 1 4745.29 70.70 304.85 3905.8 1580.1 1644.3 -432.3 4.63 2.43 -4.20 20 110 640 2150 4692 4727 40L 116 1 4840.13 74.57 301.63 3934.1 1620.1 1693.9 -508.0 5.21 4.08 -3.40 20 110 640 2150 4787 4826 25L 82 1 4932.35 76.30 301.06 3957.3 1657.0 1740.3 -584.2 1.97 1.88 -0.62 20 110 640 2150 4882 4904 HS 115 1 4987.24 76.35 303.43 3970.3 1679.8 1768.8 -629.3 4.20 0.09 4.32 10 120 620 1800 132 2 5080.05 76.14 303.14 3992.4 1719.8 1818.3 -704.7 0.38 -0.23 -0.31 12 620 1750 5016 5080 55L 175 2 5173.29 77.07 302.88 4014.0 1759.7 1867.7 -780.7 1.03 1.00 -0.28 12 650 1950 5080 5109 55L 174 2 5109 5173 75L 2 5267.34 77.34 302.46 4034.8 1799.5 1917.2 -857.9 0.52 0.29 -0.45 12 650 1900 5173 5203 75L 122 2 5203 5267 110L 2 5360.54 77.15 301.81 4055.4 1838.2 1965.5 -934.9 0.71 -0.20 -0.70 12 650 1900 5267 5296 110L 162 2 5296 5361 130L 2 5456.84 76.59 300.98 4077.2 1877.0 2014.4 -1014.9 1.02 -0.58 -0.86 12 650 1900 5361 5390 130L 122 2 5390 5457 110L 2 5549.58 76.26 301.24 4099.0 1913.9 2061.0 -1092.1 0.45 -0.36 0.28 15 650 1900 5457 5485 110L 172 2 5485 5550 130L 2 5647.31 75.94 300.54 4122.5 1952.4 2109.7 -1173.5 0.77 -0.33 -0.72 15 650 1900 5550 5576 130L 192 2 ------------------- SpSr'r'v-sun Page: 2 Operator: Kerr McGee Well : Ataruq #2A Exploration KMG Rig: 27-E Field : Kuparuk Location: AK-MJ-0003663832 Job # :AK-MJ-0003663832 North Ref: Mag Declination: 0 VS Dir: 6.940 (from Wellhead) WELL BORE SURVEY DRILLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section NIS EIW Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (ftIhr) (#) 5578 5647 130L 2 5739.02 75.47 300.74 4145.1 1988.1 2155.0 -1250.0 0.55 -0.51 0.22 15 650 1950 5647 5674 130L 197 2 5674 5739 30L 2 5832.00 76.92 301.15 4167.3 2024.9 2201.4 -1327.4 1.62 1.56 0.44 15 650 1950 5739 5769 30L 184 2 5769 5832 140L 2 5926.41 76.87 301.37 4188.7 2062.7 2249.1 -1406.0 0.23 -0.05 0.23 15 650 1950 5832 5861 140L 150 2 5861 5926 140L 2 6021.67 76.45 299.89 4210.7 2100.0 2296.3 -1485.8 1.57 -0.44 -1.55 15 650 2200 5926 5956 140L 150 2 5956 6022 120L 2 6116.76 75.96 299.01 4233.4 2135.3 2341.7 -1566.2 1.04 -0.52 -0.93 15 650 2200 6022 6051 120L 162 2 6051 6117 160L 2 6209.62 76.51 298.54 4255.5 2168.9 2385.2 -1645.3 0.77 0.59 -0.51 15 650 2280 6117 6145 160L 176 2 6145 6210 45L 2 6301.47 77.01 298.67 4276/5 2201.9 2428.0 -1723.8 0.56 0.54 0.14 15 650 2150 6210 6239 45L 158 2 6239 6301 160R 2 6396.84 76.45 298.42 4298.4 2236.1 2472.3 -1805.3 0.64 -0.59 -0.26 15 650 2200 6301 6331 160R 151 2 6331 6397 160R 2 6490.52 76.45 298.87 4320.4 2269.7 2516.0 -1885.2 0.47 0.00 0.48 12 650 2300 6397 6426 160R 138 2 6426 6491 45R 2 6582.82 76.68 300.06 4341.8 2304.1 2560.1 -1963.4 1.28 0.25 1.29 15 650 2350 6491 6520 45R 103 2 6520 6583 65R 2 6676.63 75.96 300.39 4364.0 2340.2 2606.0 -2042.1 0.84 -0.77 0.35 15 650 2350 6583 6612 65R 75 2 6612 6677 HS 2 6771.49 75.41 300.67 4387.4 2377.0 2652.7 -2121.3 0.65 -0.58 0.30 15 650 2350 6677 6706 HS 70 2 6706 6771 20R 2 6867.59 76.24 300.32 4411.0 2414.2 2700.0 -2201.6 0.93 0.86 -0.36 15 650 2350 6771 6801 20R 98 2 6801 6868 20R 2 6963.02 76.58 301.22 4433.4 2451.7 2747.4 -2281.3 0.98 0.36 0.94 15 650 2350 6868 6897 20R 114 2 6897 6963 HS 2 7057.67 76.27 301.03 4455.6 2489.4 2795.0 -2360.1 0.38 -0.33 -0.20 15 650 2350 6963 6992 HS 92 2 6992 7058 20L 2 ------------------- sperarav-sun Page: 3 Operator: Kerr McGee Well: Ataruq #2A Exploration KMG Rig: 27-E Field: Kuparuk Location : AK-MJ-0003663832 Job # : AK-MJ-0003663832 North Ref: Mag Declination: 0 VS Dir: 6.940 (from Wellhead) WELL BORE SURVEY DRILLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section N/S E/W Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (ftlhr) (#) 7153.03 77.81 299.52 4477.0 2526.2 2841.8 -2440.3 2.23 1.61 -1.58 15 650 2350 7058 7087 20L 110 2 7087 7153 20R 2 7247.33 77.22 299.93 4497.4 2561.8 2887.5 -2520.3 0.76 -0.63 0.43 15 650 2350 7153 7182 20R 69 2 7182 7247 140R 2 7341.78 75.62 301.20 4519.6 2598.6 2934.2 -2599.3 2.14 -1.69 1.34 20 650 2400 7247 7276 140R 97 2 7276 7342 140R 2 7435.08 75.81 301.40 4542.6 2635.9 2981.2 -2676.6 0.29 0.20 0.21 20 650 2400 7342 7371 140R 105 2 7371 7435 30R 2 7529.15 77.08 302.23 4564.6 2674.4 3029.4 -2754.3 1.60 1.35 0.88 20 650 2400 7435 7464 30R 107 2 7464 7529 LS 2 7622.54 76.15 301.95 4586.3 2713.0 3077.6 -2831.2 1.04 -1.00 -0.30 20 650 2400 7529 7559 LS 143 2 7559 7623 LS 2 7717.01 75.82 301.95 4609.1 2751.7 3126.1 -2909.0 0.35 -0.35 0.00 20 650 2410 7623 7652 LS 159 2 7652 7717 20L 2 7809.39 76.13 302.72 4631.5 2790.2 3174.1 -2984.7 0.88 0.34 0.83 20 650 2420 7717 7745 20L 176 2 7745 7809 20L 2 7904.35 76.44 302.36 4654.0 2830.0 3223.7 -3062.5 0.49 0.33 -0.38 20 650 2412 7809 7839 20L 139 2 7839 7904 140L 2 7997.65 76.41 302.75 4675.9 2869.2 3272.5 -3139.0 0.41 -0.03 0.42 20 650 2450 7904 7934 140L 111 2 7934 7998 140L 2 8093.60 75.75 302.47 4699.0 2909.6 3322.7 -3217.4 0.74 -0.69 -0.29 20 650 2450 7998 8027 140L 110 2 8027 8094 50L 2 8187.42 75.45 302.63 4722.3 2948.9 3371.6 -3294.0 0.36 -0.32 0.17 15 650 2450 8094 8122 50L 105 2 8122 8187 50L 2 8283.40 75.08 301.59 4746.8 2988.3 3420.9 -3372.6 1.12 -0.39 -1.08 15 650 2500 8187 8218 50L 96 2 8218 8283 40L 2 8378.52 76.17 300.17 4770.4 3025.7 3468.2 -3451.7 1.85 1.15 -1.49 15 650 2550 8283 8312 40L 116 2 8312 8379 20L 2 8474.25 75.86 300.32 4793.5 3062.5 3515.0 -3532.0 0.36 -0.32 0.16 15 650 2600 8379 8408 20L 91 2 8408 8474 10L 2 8569.14 76.61 299.40 4816.1 3098.4 3560.9 -3611.9 1.23 0.79 -0.97 15 650 2600 8474 8503 10L 90 2 ------------------- SPSr'r'\I-sun Page: 4 Operator: Kerr McGee Well: Ataruq #2A Exploration KMG Rig: 27-E Field : Kuparuk Location : AK-MJ-0003663832 Job # : AK-MJ-0003663832 North Ref: Mag Declination: ° VS Dir: 6.94° (from Wellhead) WEllBORE SURVEY DRilLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DlS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section NIS EIW Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (Whr) (#) 8503 8569 20L 2 8663.75 77.97 299.05 4836.9 3133.4 3605.9 -3692.4 1.48 1.44 -0.37 18 650 2650 8569 8598 20L 93 2 8598 8664 10L 2 8758.49 77.33 299.18 4857.2 3168.3 3651.0 -3773.3 0.69 -0.68 0.14 15 650 2600 8664 8693 10L 68 2 8693 8758 20L 2 8851.94 76.90 298.38 4878.0 3202.2 3694.8 -3853.1 0.95 -0.46 -0.86 15 650 2600 8758 8787 20L 120 2 8787 8852 20R 2 8946.77 76.81 298.96 4899.6 3236.4 3739.1 -3934.1 0.60 -0.09 0.61 15 650 2600 8852 8881 20R 112 2 8881 8947 30R 2 9039.83 77.32 299.43 4920.4 3270.7 3783.4 -4013.3 0.74 0.55 0.51 20 650 2600 8947 8976 30R 105 2 8976 9040 30R 2 9135.33 77.98 299.86 4940.8 3306.7 3829.5 -4094.4 0.82 0.69 0.45 20 650 2700 9040 9069 30R 108 2 9069 9135 40R 2 9225.16 76.76 300.62 4960.5 3341.4 3873.7 -4170.1 1.59 -1.36 0.85 20 650 2700 9135 9164 40R 111 2 9164 9225 30R 2 9320.29 75.93 300.85 4982.9 3378.7 3920.9 -4249.6 0.90 -0.87 0.24 20 650 2800 9225 9255 30R 92 2 9255 9320 50R 2 9413.91 75.36 301.80 5006.1 3416.1 3968.0 -4327.1 1.16 -0.61 1.01 20 650 2800 9320 9350 50R 108 2 9350 9414 50R 2 9508.78 75.83 302.44 5029.7 3455.2 4016.9 -4404.9 0.82 0.50 0.67 20 650 2800 9414 9444 50R 111 2 9444 9509 30R 2 9603.90 75.98 302.84 5052.9 3495.2 4066.7 -4482.6 0.44 0.16 0.42 20 650 2800 9509 9538 30R 119 2 9538 9604 20L 2 9699.48 74.17 302.78 5077.5 3535.5 4116.7 -4560.2 1.89 -1.89 -0.06 20 650 2800 9604 9633 20L 110 2 9633 9699 150L 2 9794.22 71.57 302.66 5105.4 3574.9 4165.6 -4636.4 2.75 -2.74 -0.13 15 650 2850 9699 9728 150L 92 2 9728 9794 150L 2 9889.02 67.81 301.07 5138.3 3612.4 4212.6 -4711.8 4.27 -3.97 -1.68 20 650 2800 9794 9823 150L 130 2 9823 9889 150L 2 9982.43 63.46 299.39 5176.9 3646.0 4255.4 -4785.3 4.94 -4.66 -1.80 15 650 2800 9889 9918 150L 87 2 9918 9982 155L 2 ------------------- 5pe~~\I-5un Page: 5 Operator: Kerr McGee Well: Ataruq #2A Exploration KMG Rig: 27-E Field: Kuparuk Location : AK-MJ-0003663832 Job # :AK-MJ-0003663832 North Ref: Mag Declination: ° VS Dir: 6.94° (from Wellhead) WELLBORE SURVEY DRILLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section N/S EIW Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/1 00') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (ftlhr) (#) 10075.49 59.50 299.28 5221.3 3677.2 4295.5 -4856.6 4.26 -4.26 -0.12 20 650 2800 9982 10012 155L 92 2 10012 10075 LS 2 10169.72 55.73 299.13 5271.7 3707.3 4334.3 -4926.0 4.00 -4.00 -0.16 20 650 2800 10075 10106 LS 107 2 10106 10170 LS 2 10265.71 51.54 298.70 5328.6 3736.3 4371.7 -4993.7 4.38 -4.37 -0.45 20 650 2900 10170 10200 LS 108 2 10200 10266 170R 2 10360.17 47.70 298.17 5389.8 3762.6 4405.9 -5056.9 4.09 -4.07 -0.56 20 650 2900 10266 10295 170R 97 2 10295 10360 170R 2 10455.69 43.02 298.67 5456.9 3787.5 4438.3 -5116.7 4.91 -4.90 0.52 20 600 2950 10360 10389 170R 97 2 10389 10441 170R 2 10441 10456 170R 2 10551.30 38.91 299.65 5529.1 3811.2 4468.8 -5171.4 4.35 -4.30 1.02 20 600 2950 10456 10475 170R 131 2 10475 10484 160R 2 10484 10551 160R 2 10646.47 34.71 301.23 5605.3 3833.9 4497.6 -5220.6 4.52 -4.41 1.66 20 600 2950 10551 10580 160R 78 2 10580 10646 160R 2 10740.49 30.22 300.64 5684.6 3854.4 4523.6 -5263.9 4.79 -4.78 -0.63 20 600 2950 10646 10676 160R 113 2 10676 10740 165L 2 10835.76 27.88 300.27 5767.9 3872.9 4547.0 -5303.7 2.46 -2.46 -0.39 20 600 2950 10740 10770 165L 102 2 10770 10836 15L 2 10932.04 27.17 298.64 5853.3 3889.9 4568.9 -5342.5 1.08 -0.74 -1.69 20 600 2950 10836 10865 15L 120 2 10865 10932 30L 2 11026.12 26.92 299.30 5937.0 3905.9 4589.6 -5379.9 0.42 -0.27 0.70 20 600 2950 10932 10961 30L 97 2 10961 11026 HS 2 11026.18 26.92 299.30 5937.1 3906.0 4589.6 -5379.9 0.00 0.00 0.00 20 600 2950 11026 11026 HS 97 2 11120.86 24.00 301.79 6022.6 3922.2 4610.3 -5415.0 3.28 -3.08 2.63 20 620 3400 11026 11056 HS 125 2 11056 11066 LS 2 11066 11121 LS 2 11212.07 21.68 301.86 6106.6 3937.1 4628.9 -5445.1 2.54 -2.54 0.08 20 620 3400 11121 11156 LS 87 2 11156 11212 50L 2 11242.00 21.68 301.86 6134.4 3941.8 4634.8 -5454.5 0.00 0.00 0.00 20 620 3400 11212 11221 50L 87 2 Extrapolated to TD ------------------- 5pe~~V-5un Page: 6 Operator: Kerr McGee Field : Kuparuk Well: Ataruq #2A Exploration KMG Location: AK-MJ-0003663832 ~...~. ~ J_L_.I.~ ~~~. r:::Ü Rig: 27-E Job # :AK-MJ-0003663832 North Ref: Mag Declination: ° VS Dir: 6.94° (from Wellhead) WELLBORE SURVEY DRILLING PARAMETERS Measured Incl Azi Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dir Depth Section N/S EIW Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') ("/100') (°/100') (klbs) (gpm) (psi) (ft) (ft) (deg) (ftIhr) (#) 11221 11242 55L 2 I I I I I I I I I I I I I I I I I I I sper'r'v-sun CRI L.LI N G SERVI c: e 5 Operator: Kerr McGee Well: Ataruq #2A Exploration KMG Field: Kuparuk Location: AK-MJ-0003663832 Rig: 27-E Job #: AK-MJ-0003663832 BHA# 1 BHA Report BHA# 1 : Dateln:4/16/2001: MDln(ft): 3320 TVDln(ft) : 3076 DateOut4/19/2005MDOut(ft): 4975 TVDOut(ft): 3967 BIT DATA Bit # OD (in) MFR Style Serial# Nozzles (/32's) TFA (in2) Dull Condition 1 8.500 Hughes GT-1 5067520 3x16 0.589 1-1-WT-A -E-I-ER-BHA MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum Circ Hrs 1 6.750 SSDS SperryDrill 700025 1.50" 228 23.21 COMPONENT DATA I Item Description Serial 00 10 Gauge Weight Top Con Length Bit - Center # # (in) (in) (in) (Ibslft) (ft) Blade (ft) 1 Hughes GT-1 Milltooth 5067520 8.500 2.750 8.500 173.14 P 4-112" Reg 0.82 2 7" SperryDrill Lobe 7/8 - 6.0 stg 700025 6.750 4.753 8.250 61.48 B 4-1/2" IF 25.15 2.82 3 NM String Stabilizer 62012 6.500 2.813 8.250 91.91 B 4-112" IF 5.66 28.69 4 Non-Mag Float Sub SSDSAK 6.500 2.810 91.95 B 4-1/2" IF 2.30 5 Directional ssds 6.750 1.920 112.09 B 4-112" IF 9.21 6 Gamma / Res / PWD 75233HW 6.750 1.920 112.09 B 4-112" IF 32.45 7 TM - HOC 127422 6.750 1.920 112.09 B 4-1/2" IF 9.97 8 1x Non-Mag Flex Drill collar 10574613 6.500 2.940 89.95 B 4-112" IF 31.06 9 1x Non-Mag Flex Drill collar 2677 6.500 2.813 92.00 B 4-1/2" IF 30.23 10 1x Non-Mag Flex Drill collar 998 6.500 2.880 90.89 B 4-112" IF 30.92 11 Integral Blade Stabilizer 172612 6.500 2.750 8.380 92.85 B 4-112" IF 5.46 180:12 12 15x HWDP NAD 27 5.000 3.000 49.30 B 4-1/2" IF 454.53 13 Drilling Jar - 72.79 hrs 14161562 6.500 2.500 96.36 B 4-1/2" IF 32.58 14 14x HWDP NAD 5.000 3.000 49.30 B 4-1/2" IF 419.93 15 Ghost Reamer 263127 6.500 2.750 8.500 92.85 B 4-1/2" IF 6.41 1093.47 1096.68 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) : 20 40 26 Drilling: 16.27 in Air (Total) 63945 RPM (rpm) : 40 110 98 Reaming: 0.00 in Mud (Total) 54880 Flow (gpm) : 500 640 614 Circ..Qther: 6.94 in Air (Bel Jars) : 39508 Spp (psi) : 1400 2200 1955 Total: 23.21 in Mud (Bel Jars: : 33907 PERFORMANCE In Out Distance(ft) ROP (ftIhr) Build ("/100') Turn ("/100') DLS (°1100') Inclination (deg) 42.14 76.34 Oriented : 574.09 81 Azimuth (deg) 5.70 302.90 Rotated : 1080.91 113 Total: 1655.00 102 2.07 -3.79 3.73 COMMENTS I Motor rev/ gal = .33 1/ Adj. Bend 1.5 1/ Planned flow rates 600-650 gpm Sensor Dist : Dir = 38.26/ DGR = 47.08/ EWR = 54.86 I PWD = 63.14 I I I BHA Report page 2 Operator: Kerr McGee Well : Ataruq #2A Exploration KMG Field: Kuparuk Location: AK-MJ-0003663832 Rig: 27-E Job # : AK-MJ-0003663832 BHA# 1 I 5pe~~V-5un CRILLING SERVIC:ES I OBJECTIVES: I BHA # 1 Objective will be to use the 7" Sperrydrill performance motor with a Hughes GT -1 milltooth bit to kickoff the cement plug and initiate sidetrack off of the Ataruq # 2 parent wellbore. Once off the cement plug this assembly will be used to perform the FIT. With this complete the mud will be displaced for new LSND with lubricants. The assembly shall then build angle while making the azimuth swing from the north east to a northwest direction. Once the directional work has been completed and the assembly has hit the tangent section of the directional plan it will be pulled from the hole for the Goo-pilot rotary steerable system. I RESULTS: I Rig crew then held a PJSM on picking up BHA # 1. The bit, was torqued to motor, Stabilizer and float sOb made up. The MWD directional probe was then picked up and torqued to the string. A rig floor offset was done (2751702 X 360 = 141.43) the remaining MWD components were then made up and data loaded. With data loaded the Non mag flex Drill collars were picked up. A stabilizer was added to the top of the flex collars between flex DC's and first stand of HWDP. The MWD was then shallow pulse tested at 500 gpm with 1,070 psi. The rest of the HWDp and the jars were ran from the derrick. The assembly was then tripped in the hole to 3,080' where it took weight. Tagged cement at that depth. With assembly taking 10K bit wt cement was drilled from 3,080' to 3,330' With a good hard cement plug the Directional Driller made the decision to make 30' of hole at a 70 L toolface. This was not time drilled as it was thought the formation softer than the plug in this area. With 300 feet of cement plug the decision made to drill off the plug with out time drilling was justified if it worked it saved many hours of rig time which is valuable with the limited amount of days left for drilling this exploration well. All drilling must be completed by the 25th of April. This leaves 7 days to drill from 3,320' to T.D. at 11,318' This means drilling almost 8,000' with two drilling assembly and justifies the gamble Of drilling off this cement plug. If unsuccessful there is still ample footage of cement plug for time drilling off the plug in text book fashion. Judging by the wt. indicator it seems as if the assembly kicked off the plug easily. Samples will be checked for cement percentages while circulating for the FIT. The FIT performed trucks that were staged in position for displacing well to new drilling fluid began unloading mud to pits. The mud swap was done while drilling with displaced mud going to "sc trucks. Sliding was done from 3,330' to 3,380' before rotatiOn was initiated. A check shot survey at 3,364' survey depth showed inclination to be 43.74 dGgrees. This confirmed that the assembly was at a higher inclinatiOn than the parent wellbores profile at that depth. With this knowledge oonfirming the assembly was in fact kicked off the cement plug. And with samples only showing 20% cement, rotary drilling was initiated to minimize the dogleg rate from previous slide footage. Total drilling timEt for kicking off cement plug was .85 hrs. BHA performed well. motor exhibiting oonsistant 120 dogleg output. Starting to hang up a little but hasn't been a problem yet. Added 2 drums Drill N Slide. Assembly was kept very close to directiOnal proposal line. Largest dogleg for this sectiOn was 5.2 this exceeded the planned rate by only 1.2 dGgrees. Drilled to 4,975' and achieved all directional objElctives for this BHA. Rig circulated a sweep around and began tripping assembly out of hole. Assembly is 4' from plan with correct InClination and Azimuth. Directional proposal now calls for a long tangent from 4,975' to 8,896'. The Geo.Pilot rotary steerable will now be the more suitable assembly for efficient drilling to T.D. I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I O.D. 8.5" 6.75" 6.5" 6.5" 6.75" 6.75" 6.75" 6.5" 6.5" 6.5" 6.5" 5" 6.5" 5" 6.5" SpE!r'If'"""Y-sun CFfIL-L-INI3 SERVIt:ES Length 0.82' 25.15' 5.66' 2.3' 9.21' 32.45' 9.97' 31.06' 30.23' 30.92' 5.46' 454.53' 32.58' 419.93' 6.41' BHA Schematic Kerr McGee Ataruq #2A BHAID#: 1 8-1/2 Kickoff Assembly BHA Configuration Description Hughes GT-1 Milltooth 7" SperryDrill Lobe 7/8 - 6.0 stg NM String Stabilizer Non-Mag Float Sub Directional Gamma I Res I PWD TM-HOC 1 x Non-Mag Flex Drill collar 1x Non-Mag Flex Drill collar 1 x Non-Mag Flex Drill collar Integral Blade Stabilizer 15x HWDP Drilling Jar -72.79 hrs 14x HWDP Ghost Reamer BHA Discussion Motor revl gal = .33 /I Adj. Bend 1.5/1 Planned flow rates 600- 650 gpm Sensor Dist : Dìr = 38.261 DGR = 47.08 1 EWR = 54.86 I PWD = 63.14 Box 4--¡¡2" iF Ghost Reamer Box 4-1/2" iF 14x HWDP Box 4-1/2" IF Drilling Jar - 72.79 hrs Box 4-1/2" IF 15x HWDP Box 4-1/2" IF Integral Blade Stabilizer Box 4-1/2" IF 1 x Non-Mag Flex Drill collar Box 4-1/2" IF 1 x Non-Mag Flex Drill collar Box 4-1/2" IF 1 x Non-Mag Flex Drill collar Box 4-112" iF TM-HOC Box 4-1/2" IF Gamma 1 Res / PWD 80x 4-112" IF Directional Box 4-1/2" IF Non-Mag Float Sub Box 4-112" IF NM String Stabilizer Box 4-1/2" iF 7" SperryDrill Lobe 7/8 - 6.0 stg Pin £t_1 /?II Rer'! H~gh~~GT ~ 1"" Milltooth I I I I I I I I I I I I I I I I I I I sperar')/-sun CRILLI NG SERVICES Operator: Kerr McGee Well : Ataruq #2A Exploration KMG Field: Kuparuk Location : AK-MJ-0003663832 Rig: 27-E Job # : AK-MJ-0003663832 BHA# 2 BHA Report BHA# 2 : Dateln:4/19/200E MDln(ft): 4975 TVDln(ft) : 3967 DateCur:4/25/2005MDCur(ft): 11242 TVDCur(ft): 6134 BIT DATA Bit# OD (in) MFR Style Serial# Nozzles (/32's) TFA (in2) Dull Condition 2 8.500 SDBS FSF2565 10706063 5x16 0.982 1-1-CT-N -X-I-ER-TD MOTOR DATA Run # OD (in) MFR Model Serial# Bend Nzl (/32's) Avg Dif (psi) Cum Circ Hrs 2 6.750 SSDS Geo-Pilot GP085TL055 0.00· 0 112.11 COMPONENT DATA I Item Description Serial OD ID Gauge Weight Top Con Length Bit - Center # # (in) (in) (in) (Ibs/ft) (ft) Blade (ft) 1 SDBS FSF2565 PDC 10706063 8.500 3.000 8.500 169.30 B 4-112" IF 1.50 2 7600 GeoPilot #55 GP085TL055 6.750 4.490 8.380 68.00 B 4-1/2" IF 20.10 15.35 3 Non-Mag GP Flex DM FL095 6.750 3.250 94.00 B 4-1/2" IF 9.20 4 GP Smart Stab 182081 6.700 1.920 8.380 110.29 B 4-1/2" IF 2.20 32.18 5 6 3/4" RLL 75233HWRG6 6.750 1.920 8.380 112.09 B 4-1/2" IF 30.25 6 6 3/4" Nuke 61881 6.750 1.920 8.250 112.09 B 4-1/2" IF 27.54 7 TM - HOC 127422 6.750 1.920 112.09 B 4-112" IF 9.97 8 6-3/4" MWD Bat Sonic 17579606 6.750 1.920 112.09 B 4-112" IF 21.38 9 Non-Mag Float Sub SSDSAK 6.500 2.810 91.95 B 4-112" IF 2.30 10 1x Non-Mag Flex Drill collar 10574613 6.500 2.940 89.95 B 4-112" IF 31.06 11 1x Non-Mag Flex Drill collar 2677 6.500 2.813 92.00 B 4-1/2" IF 30.23 12 1x Non-Mag Flex Drill collar 998 6.500 2.880 90.89 B 4-1/2" IF 30.92 13 15x HWDP NAD 27 5.000 3.000 49.30 B 4-112" IF 454.53 14 Drilling Jar - 72.79 hrs 14161562 6.500 2.500 96.36 B 4-112" IF 32.58 15 14x HWDP NAD 5.000 3.000 49.30 B 4-112" IF 419.93 16 Ghost Reamer 263127 6.500 2.750 8.500 92.85 B 4-1/2" IF 6.41 1126.89 17 10 Stands 5" Drillpipe 5.000 4.276 22.60 B 4-112" IF 952.98 18 Dailey Ghost Reamer 247876 6.500 2.750 8.500 92.85 B 4-1/2" IF 6.95 2086.58 2090.03 Parameter Min Max Ave Activity Hrs BHA Weight (Ib) Drill String OD(in) Len (ft) WOB (klbs) : 10 20 17 Drilling: 55.77 in Air (Total) 90344 RPM (rpm) : 120 120 120 Reaming: 21.42 in Mud (Total) 76712 Flow (gpm) : 600 650 644 Clrc-Other : 34.92 in Air (Bel Jars) : 43725 SPP (psi) : 1750 3400 2501 Total: 112.11 in Mud (Bel Jars: : 37127 PERFORMANCE In Out Distance(ft) ROP (ftlhr) Build r/100') Turn (°/100') DLS (°/100') Inclination (deg) 76.34 21.68 Oriented : 6226.00 112 Azimuth (deg) 302.90 301.86 Rotated : 41.00 124 Total: 6267.00 112 -0.87 -0.02 0.87 COMMENTS I Planned flow rate 600-650 GPM /I Rotary 120 - 180 RPM Max bit wt 25 K /I Bit needs to make over 6,000' ABI = 6.5/1 DM = 25.9/1 DGR = 34.74/1 EWR = 42.52 PWD = 50.80 /I SLD = 72.98 /I CTN = 86.82 /I ACAL = 83.34 Batt Sonic = 110.72 #18 Jet in GeoSpan #210064, DL threshold at 180 start. #20 Jet, DL threshold at 317 end. I BHA Report page 2 Operator: Kerr McGee Well: Ataruq #2A Exploration KMG Field: Kuparuk Location: AK-MJ-0003663832 Rig: 27-E Job #: AK-MJ-0003663832 BHA# 2 I sper'r'v-sun CRI LoLl N G SERVI c: E 5 I I OBJECTIVES: I BHA #2: Drill 4655' tangent at 76.4° inc at 300.7 Az., drop 4°/100 to 27.5° inc to TO at 11318' Md. RESULTS: I I ~BHA#2: Made up GP BHA, tripped in to top of HWDP, tested Geo-Span, MWD and Geo-Pilot. Broke in GP seals. Changed GeoSpan jet from 16 to 18. Tripped in and filled pipe at shoe, continued trip in to bottom with out problem. Precautionary reamed 50'. First survey with new MWD showed 3 degrees azimuth change in 50'. Torque very erratic, addingTorq Trim and Drill N Slide. Using 23% deflection on Geo-pilot holding a 130 -140 Left toolface is keeping the assembly from building and walking right in the colville formation. ECD's are being closely monitored with pump rate lowered when reaming prior to connections. Swab and surging are also being avoided. ECD's are at 10.5 with a 650 gpm flow rate and penetration rates between 175-200 fph. Rotary speed is at 150 rpm. Torque is very errattic but not peeking over 15k. Morning meeting requests are; maintain 650 GPM, 150 ROP, 170 RPM. Starting to have more touble downlinking, requiring multiple tries for a successful downlink, takes commands off bottom or if let drill off, MWD showing lots of downhole noise on bottom. John Patton was consulted on our hole cleaning, he suggested 2 ppg over MW be our ECD high limit. Short tripped from 6992' to 5860', no problems. Drilling rop has slowed down while this is aiding in keeping the ECD's lowered its not doing much good for footage. Geo says we are to expect some pretty tough spots until we clear the bottom of the colville formation. Changed the jet in Geo-Skid from a # 18 to a # 20 in hopes of improving downlinking to tool. Successfully downlinked several times with no problems. This run came to an end when two times the display showed downlinking as unsuccessful. It does not appear however to have helped with the # 20 jet so it was changed to a # 16. Drilling at 7,235' hit a very hard spot picked up and ream~ from ten feet off bottom and when bottom tagged drilled with 10K bit wt. to let assembly work through spot. This may of taken extra time but it is far better to conserve bit life by not putting excess wt. on bit to get through these hard spots as WEt still have over 4,000' to go and want to avoid tripping for bit which of course would consume many hrs. of valuable time. Drilling still has a drop dead date of 4-25. DOwhlinking has not improved and it is still necessary to pick up off bottom to get a successful downlink. Assembly has still been kept close to the linEt even with downlinking problems. Now downlinking on prior to connection waiting until blocks are bringing stand down from reaming before conn$eìion. This has been working well sO far. 8100', wont take commands on or off bottom, tool pointing where it wants to, seeing pressure noise above threshold, tool thinks it is getting commands. DownhOle pulse amplitude low, changed jEtt to 18, raised Dl threshold to 276. Added some EZ Glide lube to mUd. Downlinking ok now on bottom. Trying to get back toward plan now, 15' off, doesnt want to build with 50-60% deflection over 150'. Increa$ed deftection to 80% at 20L Started building right away. Dropped deflection to 45% when close to desired inc, started dropping again right rNlaY. back to 80% we go. Drilling ROP is far lower than expected with çontinuing Etrrati¢ torque. lube percentage shows a meager 1.5% with the assembly laid out at this angle and depth this is surprising. Several times request have been made to increase lube percentage. Answer is always yes will incre<tse, yet lube percentage still remains the same 1.5% that was on yesterdays mud report? And torque is still erratic swinging from 2K to 16K. Possibly mud dilutions are knocking down this lube percentage as i am sure the request for more lubricants is being worked on. Downlinking is once again being difficult to achieVé. Tried on bottom to downlink whiCh did not work . Picked up off bottom and stopped rotating and even this did not work. MWD has increased threshhold and did succeed in dOwhlinking to tool. SWeeps are being pumped every 350' with not a very noticable increase in cuttings. ECD's are staying around 10.9 -11 with the mud wt. at 10.0 ppg. With downlinklng still a problem the jet in the geo-skid was changed from a # 18 to a '# 20 the first downlink with this bigger jet size was successful. Optimism as to if it will continue to downlink without problems just isnt reðlly in consideration just now. Downlink threshold now at 317 and tool taking commands. Began planned 4°/100 drop at 9630' Md. Initialy dropping 3.5°/100 with 40% defl$eìion for 100' then drop rate started diminishing, increaSed deftection to 100% over one stand. 110 ROP and 120 RPM requested at 9660' Md for log quality. Seeing over 4°/100 drop now at 9900' Md. low oil light at 10295' Md. 1530 hrs. Now its off, 1540 Hrs. Gee·Pilot was set at 100% deflection until 10,620' lowered deflection to 70% at this depth as DlS = 5.5 degrees per hundred. Catching the line and do not want to crash through it want to follow it Drilling sections of this aréia at çontrolled rate for logging purposes. Geologist is calling when rop can be increased to help get to T.D. before memory dies on batt sonic tOOl, It will be close! 10,770' with inclination at 28.99 deflection and toolface were reset on Geo-Pllot new deflection is 16% with a 15 left of highside toolface. This was done to maintain the inclination at 27 .5 as per plan. The assembly should still drop slightly with this defl$eìion. Once at the desired san angle deflection will be increased to a percentage that will hold the correct angle. 11,050' under two feet from target center. Discussion with Geologist and will now drop deflection allowing geo-pilot to drop inclination. Explained to geo there is a bottom hole location that cannot be crossed and if T.O. is deeper than projected angle needs to be lowered to stay within hardline. Geologist has now called the floor formations are coming in deeper than prognosis. Need to drop angle at least 4 degree per hundred to drill to 11,370' and stay In bottom hole location hard line! Dropped inclination to 22° in order to stay in hardlin$ at possible deeper TO. TO called early at 11242' MD. Circulated bottoffi$ up once, stood one stand back, Circulated two more bóttoms up, backreamed out, tight and packing off from 11030' to 10990'. Continued backreaming out. Logged while backreaming from 10605'· 10435' at 160'/hr. Backreamed outto 10390'. Ran in hole with out problem to 10860' were we we bøgan precautionary reaming to b<>itom, had a spot at 11130'-11137' that was real torquey requiring multiple reams. The hole was Circulated with a hi-vis sweep pumped around onCè on bottom. This sweep brought a very minimal increase of cuttings to surface. BHA was backreamed out to 9700' where pipe was pulled without pumping to tight spot at 6670'. Backreamlng tight hole and packing off from 6670', losing some mud with hole breathing. Began backreaming with lower flow rate to reduce mud loss, pulling better without packing off now, tried to pull without pump once at 5500', tried to swab a little so continuing to pump out backreaming to shoe. CBU at shoe and flow check. I I I I I I I I I I I I I SPer"f""lV...5Un C A I L..L..I N E!i 55EAVII::E 55 I BHA Schematic Box 4-1/2" IF Box 4-1/2" IF Dailey Ghost Reamer Kerr McGee I Ataruq #2A Box 4-1/2" IF 1 x Non-Mag Flex Drill collar BHA ID #: 2 I GeoPilot 10 Stands 5" Drillpipe Box 4-1/2" IF BHA Configuration Non-Mag Float Sub I Box 4-1/2" IF O.D. Length Description 8.5" 1.5' SOBS FSF2565 PDC Box 4-1/2" IF 6.75" 20.1' 7600 GeoPilot #55 I 6.75" 9.2' Non-Mag GP Flex OM Ghost Reamer 6-3/4" MWD Bat Sonic 6.7" 2.2' GP Smart Stab 6.75" 30.25' 6 3/4" RLL 6.75" 27.54' 6 3/4" Nuke Box 4-1/2" IF I 6.75" 9.97' TM-HOC 6.75" 21.38' 6-3/4" MWD Bat Sonic Box 4-1/2" IF 6.5" 2.3' Non-Mag Float Sub 6.5" 31.06' 1x Non-Mag Flex Drill collar I 6.5" 30.23' 1 x Non-Mag Flex Drill collar 14x HWDP 6.5" 30.92' 1 x Non-Mag Flex Drill collar TM - HOC 5" 454.53' 15x HWDP 6.5" 32.58' Drilling Jar - 72.79 hrs I 5" 419.93' 14x HWDP 6.5" 6.41' Ghost Reamer Box 4-1/2" IF 5" 952.98' 10 Stands 5" Drillpipe Box 4-1/2" IF 6.5" 6.95' Dailey Ghost Reamer I Drilling Jar BHA Discussion 6 3/4" Nuke I Planned flow rate 600-650 GPM 1/ Rotary 120 - 180 RPM Max bit wt 25 K 1/ Bit needs to make over 6,000' Box 4-1/2" IF Box 4-1/2" IF I ASI = 6.5 II DM = 25.9 II DGR = 34.74 II EWR = 42.52 PWD = 50.80 II SlD = 72.98 II CTN = 86.82 1/ ACAL = 83.34 Batt Sonic = 110.72 #18 Jet in GeoSpan #210064, DL threshold at 180 start. 6 3/4" RLL I #20 Jet, DL threshold at 317 end. 15x HWDP I Box 4-1/2" IF Box 4-1/2" IF GP Smart Stab I Box 4-1/2" IF 1 x Non-Mag Flex Drill collar I Non-Mag GP Flex OM Box 4-1/2" IF Box 4-1/2" IF I 7600 GeoPilot #55 I 1 x Non-Mag Flex Drill collar I Box 4-1/2" IF SOBS FSF2565 PDC I I I I I I I I I I I I I I I I I I I spe..........v-5un CRIL.L.INI3 SERVICES ,. MOTOR PERFORMANCE REPORT·' Motor Serial # : 700025 Directional Driller(s) Mark Brouillet Location AK-MJ-0003663832 Well Ataruq #2A Depth In/Out: 3320 / 4975 ft Application Details : Steerable Drilling MOTOR CONFIGURATION ""'- Lw stab or Pad Sub ......Top Ji1j Pad .....(-) _T... 1234567 1 t I I 1 I I MOTOR RUN DATA Max Dogleg While Rotating Max Dogleg Overpulled In Max Dogleg Pushed Through Hole Azimuth Start I End Interval Oñented I Rot. Jarñng Occured : No Diff Press (psi) 228 400 Avg: Max: PRE-RUN TESTS Motor Tested Pre-Run Dump Sub Operating NIA Flow 1 500 gpm Flow 2 gpm Driveshaft Rotation Observed Beañng Leakage Observèd From Bit (ff) Component 1 2.82 Sleeve Stab/Pad Yes 2 6.74 Bent Housing Yes 3 Housing Tool Used No 4 25.97 Stator Elastomer 5 Bent Sub I 2nd Bent Hsg No 6 28.69 Lower Stñng Stab Yes 7 180.12 Upper String Stab Yes Additional Features Flex Collar : No Brg Cfg (Off/On) 5.20 "/100' 5.20 "/100' 5.20 °/100' 5.70' I 302.90' 574/1081 it Brg Play Pressure 1 Pressure 2 No No Make : Hughes Type: GT-1 Pre Existing Hours From Other Wells: Prey Dñlling Hrs : 0.00 Prey Reaming Hrs : Jet Sizes (132'5) : 3x16 TFA : - .. PERFORMANCE COMMENTS Problem Perceived Performance Motor No Yes Problem Date Tandem Motor Motor delivered strong horsepower without stalling Customer Representative's Signature (optional) : Job# : Operator : Rig: Bit Run # : Date InlOut : f\K-MJ-0003663832 Kerr McGee 27-E BHA # ; 1 4/16/2005 í 4/19/2005 Type Stab: 4 I O' Adjustable: 1.50' bend Stab: 4 0' Stab: 4 I O' Short Brg Pack : No Lobe Cfg : 718 Rtr Noz / Size /32's BHA OD/lO : 6.500/2.813 in Force Force 5000 fuf Inc Start I End Directional Perf Oñ I Rot Motor Stalled : Float Valve : DP Filter: No 42.14' 176.34' I ·/100' ROP Oñented 81 128 mm 1070 psi psi 6141640 Señal #: 5067520 0.00 0.589 No of Runs This Bit : inZ Gage Length: io In Out No Service Interrupt No LlH No .............................................................. Date: M-AK-MJ-0003663832-1 .1 Motor Run #: 1 Hole Size: 8.500 in Diam In/Out (io) 8.250 8.250 8.250 8.250 8.380 8.380 Arr Ret Pick Up Sub Yes Yes Bit Box Protr Yes Yes PreY JoblWell Hrs Dñlling Hrs Circ Hrs Reaming Hrs Total Hrs This Run New Cumulative Hrs (fl/hr) ROP Rotated 113 162 (ftIhr) Wf A ER BHA E Service Interrupt Hrs PPR Ref # ..........................................-.. I I spe.-.f""Iv-sun CRIL-L.INS seRVices JAR PERFORMANCE REPORT I Job # : AK-MJ-0003663832 Operator : Kerr McGee Rig: 27-E Well Type : Deviated Jar Serial #: 14161562 Directional Driller(s): Mark Brouillet Location: AK-MJ-0003663832 Well: Ataruq #2A I Date InlOut : 4/16/200El 4/19/2005 Inc InlOut : 42.14° / 76.34° I I Depth In/Out: 3320 I 4975 ft Mud Wt : Avg Flow Rate: Pressure Drop Below Jar: 9.3 ppg 614 gpm 900 psi Hours Below Rotary: 30.24 I I I I I I I Hrs in 56.51 / Hrs. out = 72.79 I I I I I I J-AK-MJ-O()03663832-1 I ............................................................... Date: ........................................ Customer Representative's Signature (optional) : I Please fax copy of this report to DTDG, Aberdeen: (44) 1224727324. I I spa,.,v-sun CAIL..L..ING SEAVICES JAR PERFORMANCE REPORT I Jar Serial #: 14161562 Directional Driller(s): Mark Brouiliet Location: AK-MJ-0003663832 Well: Ataruq #2/\ Job # : AK-MJ-0003663832 Operator : Kerr McGee Rig: 27-E Well Type : Deviated I Date InlOut : 4/16/200U 4/19/2005 Inc InlOut : 42.14° / 76.34° I I Depth InlOut : 3320 I 4975 ft Mud Wt : Avg Flow Rate: Pressure Drop Below Jar: 9.3 ppg 614 gpm 900 psi Hours Below Rotary: 30.24 I I I I I I I Hrs in 56.51 I Hrs. out = 72.79 I I I I I Customer Representative's Si nature (optional) : ..............................................................' I , Date: ........................................ 1 Û( I q , f , Please fax copy of this report to DTDG, Aberdeen: (44) 1224 727324. I I Date In/Out : 4f19/200et 4/23/2005 Inc In/Out: 76.34° f 21.68° I Spef""lrav-5un DRILLING SERVICES JAR PERFORMANCE REPORT I Jar Serial #: 14'161562 Directional Driller(s): Mark Brouillet, Ken Harding Location: AK-MJ-0003663832 Well: Ataruq #2A Job # : AK-MJ-0003663832 Operator : Kerr McGee Rig: 27-E Well Type : Deviated I I Depth In/Out: 4975 f 11242 ft Mud Wt : Avg Flow Rate: Pressure Drop Below Jar: 9.9 ppg 644 gpm 900 psi Hours Below Rotary: 11 0.02 I BHA Elements Below Jar I BHA Elements Above Jar [Jar], 14x HWDP, Stab, DP (S), Ream I Typical Drag Up Typical Drag Down 60000 Ibf 70000 Ibf I I I I 72.79 hrs at end of BHA # 1 /155.78 hrs from BHA # 2 Jars now have a total of 128.57 drilling hrs. I I I I I Customer Representative's Signature (optional) : ............................................................... Date: ........................................ I Please fax copy of this report to DTDG, Aberdeen: (44) 1224727324. I I Sperry.Sun I I I End of Well Report for I Kerr McGee I Rig: Nabors 27E Well: Ataruq #2A I Field: Exploration I Country: USA Job No: AK-MW-0003663836 I Date: 02-Apr-05 API No: 50-103-20508-01 I I I I I I I I HAlliBURTON I I I I I I I I I I I I I I I I I I I I HALLIBURTON General Information Company: Rig: Well: Field: Country: API Number: Sperry-Sun Job Number: Job start date: Job end date: North reference: Declination: Dip angle: Total magnetic field: Date of magnetic data: Wellhead coordinates N: Wellhead coordinates E: Vertical section direction: MWD Engineers: Company Representatives: Company Geologist: Lease Name: Unit Number: State: County: Kerr McGee Nabors 27E Ataruq #2A Exploration USA 50-1 03-20508-01 AK-MW-0003663836 02-Apr-05 24-Apr-05 True 24.064 deg 80.700 deg 57569.000 nT 02-Apr-05 70 deg. 19 min 40.480 sec North 150 deg. 9 min 23.010 sec West 6.940 deg J. Sack P. Orth G. Goerlich AI Heinrich Exploration 117 Alaska North Slope Borough Sperry-Sun Y. Peltekian W. Burch Job No.: AK-MW-Q003663836 End of Well Report Page 1 Well No.: Ataruq #2A I I I I I I I I I I I I I I I I I I I HALLIBURTON Sperry-Sun Operational Overview Sperry-Sun Drilling Services was called out on April 17, 2005, to perform MWD and LWD services on the exploration well Ataruq #2-A, with API# 50-103-20508-01. MWD Run 400 (6" Dir/GR/Res/PWD): Drilled 8.5" hole out of Ataruq #2 (API # 50-103-20508-00) 9 5/8" casing shoe to TD at 4975' MD 13967' TVD. POOH to pick up GeoPilot. MWD Run 500 (6" Dir/GR/Res/CTN/SLD/BatlPWD/GeoPilot): Drilled 8.5" hole from 4975' MD 1 3967' TVD to TD 11242' MD 16134' TVD. Job No.: AK·MW-0003663836 Wen No.: Ataruq #2A End of wen Report Page Z ------------------- URTON Sperry-Sun Summary of MWD runs Run No. Bit No. MWD Service I Start I Depth I (ft) End Drill/Wipe I Run Start Depth Distance I Date Time (ft) (ft) Run End Date Time i BRT Oper. Circ. ¡Max. Servo Trip for Failure , Hrs. Hrs. Hrs. I Temp. Int. MWD Type i(degF) TOTALS ====> 7923.00 176.10 174.85 124.00 o o Job No.:AK-MW-0003663836 Well No.: Ataruq #2A End of Well Report Page 3 I I I I I I I I I I I I I I I I I I I HALLIBURTON Sperry-Sun Bitrun Summary Run Time Data Drilling Data Mud Data MWD Run: 0400 Start Depth : 3319.00 ft Mud Type: Water Based Rig Bit No: 4 End Depth: 4975.00 ft Weight / Vise: 9.30 ppg/ 42.00 spqt Hole Size: 8.50 in Footage : 1656.00 ft Chlorides: 46000.00 ppm Run Start : 17-Apr-05 21 :00 Avg. Flow Rate: 600.00 gpm PV/YP: 8.00 cp / 15.00 Ihf2 Run End: 19-Apr-05 06:00 Avg. RPM : 100.00 rpm Solids/Sand : 1.9 % / 0.3 % BRT Hrs : 33.00 Avg. WOB : 20.00 klb "IoOil/ O:W : N/A % / 0/92 Circ. Hrs : 18.00 Avg. ROP : 0.00 fph pH/Fluid Loss: 9.20 pH / 1.00 mptm Oper. Hrs : 32.00 Avg. SPP : 2000.00 psig Max. Temp. : 105.00 degF MWD Schematics BHA Schematics I Component Length O.D. I.D. (7) œ (14) (ft) (in) (in) (13) 41 (6) (12) I 7. TM SN: 191771 (11 ) I (5) 14. Drill Pipe (E) 1500.00 5.000 4.276 6. 8 DGWD 650 System (10) I 13. 3-Point String Reamer 6.41 6.500 2.750 SN: (4) œ 0.00 ft From Bit (9) . 12. HWDP 419.93 5.000 3.000 5. HCIM (8) I 11. Drilling Jars 32.58 6.200 2.500 SN: 191771 10. HWDP 454.53 5.000 3.000 (3) 4. PWD (7) I 09. Integral Blade Stabilizer 5.46 6.500 2.750 SN: 152681 08. Flex Collar 30.92 6.500 2.880 63.14 ft From Bit (6) 3. EWR-P4 07. Flex Collar 30.23 6.500 2.823 (2) SN: 151524 (5) 06. Flex Collar 31.06 6.500 2.940 54.86 ft From Bit 05. MWD 51.63 6.750 1.920 2. DGR SN: 53519 (4) 04. Float Sub 2.30 6.500 2.813 (1 ) 47.08 ft From Bit (3) 03. Integral Blade Stabilizer 5.66 6.500 2.813 1. DM (2) SN: 505081 02. Mud Motor 25.15 6.750 4.750 38.26 ft From Bit (1 ) . 01. Tricone 0.82 8.500 2.750 Comments drilled 8.5" Open Hole from 3319' MD to 4975' MD /3967' TVD HCIM Amps used = 0.39 MWD Performance Tool OD / Type: 6.75 in / MPT MWD Real-time%: 99.25 % MWD Recorded%: 100.00 % Min. Inc. : 42.14 deg/ 3320.00 ft Max. Inc. : 76.30 deg/ 4932.35 ft Final Az. : 301 .06 deg Max Op. Press. : 1917.00 psig Job No.: AK-MW-0003663836 Well No.: Ataruq #2A End of Well Report Page 4 I, 1 HALLIBURTDN Sperry-Sun Bitrun Summary 1 Run Time Data Drilling Data Mud Data MWD Run: 0500 Start Depth: 4975.00 ft Mud Type: KCL Mud I Rig Bit No: 5 End Depth: 11242.00 ft Weight / Vise: 11.30 ppg/ 45.00 spqt Hole Size: 8.50 in Footage : 6267.00 ft Chlorides: 50000.00 ppm Run Start : 19-Apr-0508:54 Avg. Flow Rate: 630.00 gpm PV/YP: 17.00 cp / 13.00 Ihf2 I Run End: 25-Apr-05 08:00 Avg. RPM : 170.00 rpm Solids/Sand : 7.7 % / 0.5 % BRT Hrs : 143.10 Avg. WOB : 15.00 klb %Oil/O:W : N/A % / N/N87 Circ. Hrs : 106.00 Avg. Rap: 112.40 fph pH/Fluid Loss: 8.20 pH / 0.60 mptm I Oper. Hrs : 142.85 Avg. SPP : 3400.00 psig Max. Temp. : 159.80 degF MWD Schematics BHA Schematics I Component Length 0.0. 1.0. (11 ) (15) I (ft) (in) (in) I (10) (14) · (13) I' 11. BAT (9) SN: 175796 I 110.72 It From Bit (12) · 10. MK VIII Positive Pulser (11 ) I 15. Drill Pipe (E) 3000.00 5.000 4.276 SN: 8385 (8) 14. 3-Point String Reamer 6.95 6.500 2.750 9. TM I SN: 191771 (10) I 13. Drill Pipe (E) 952.58 5.000 4.276 (7) 0.00 It From Bit 8. CTN 12. 3-Point String Reamer 6.41 6.500 2.750 SN: 173970 (9) I I (6) 86.82 It From Bit 11. HWDP 419.93 5.000 3.000 7. SLD SN: 71412 (8) I 10. Drilling Jars 32.58 6.200 2.500 (5) 72.98 It From Bit 6. HCIM 09. HWDP 454.53 5.000 3.000 I SN: 191771 (7) I (4) 5. PWD 08. Flex Collar 30.92 6.500 2.880 SN: 152681 07. Flex Collar SO.80 It From Bn (6) I 30.23 6.500 2.823 I 4. EWR-P4 06. Flex Collar 31.06 6.500 2.940 (3) SN: 151524 42.52 It From Bit (5) 05. Float Sub 2.30 6.500 2.813 3. DGR (4) · SN: 53519 I (2) 34.74 It From Bit (3) I 04. Integral Blade Stabilizer 2.20 6.500 2.813 2. DM SN: 505073 03. Flex Collar 9.20 6.750 3.250 (1 ) 25.90 It From Bit (2) I I 1. GeoPilot 02. MWD 91.14 6.750 1.920 SN: 179535 6.50 It From Bn (1 ) .. 01. PDC 1.50 8.500 3.000 I Comments MWD Performance Drilled to TO @ 11242' MD, 6134' TVD Tool aD/Type: 6.75 in / PFE HCIM Amps used = 4.35 MWD Real-time%: 97.00 % I MWD Recorded%: 100.00 % Min. Inc. : 21.68 deg/ 11212.07 ft Max. Inc. : 77.98 deg/ 9135.33 ft I Final Az. : 301.86 deg Max Op. Press. : 3630.00 psig I Job No.: AK-MW-0003663836 Well No.: Ataruq #2A End of Well Report Page 5 I Halliburton Global EI I I E I c;òmþai)y: KettMêGee Date: 5/2/2005 Time: 13:13:48 Page: I Fiêld: Atåruq CÚ"Úrdináti\(NE) Rêfetertce: Well: At<!rlfq#2, True North Site: Alåruq Vertical('fVD)Reference: Ata ru~#2:1 02.6 Well: Ataruq #2 Section(VS) Refere¡jce: Weli..(D.OON;O.00E:,310.36Azi) WéllpatÞ: Alaruq #2A SÍlrveyCálcUlätiÚn Meth(¡d: Mirtimum CUr\lalure Db: Orable Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: Ataruq Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: Ataruq Site Position: Northing: 5969528.36 ft Latitude: 70 19 40.485 N From: Map Easting: 480716.30 ft Longitude: 150 9 23.000 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.15 deg Well: Ataruq #2 Slot Name: Well Position: +N/-S 0.00 ft Northing: 5969528.36 ft Latitude: 70 19 40.485 N +E/-W 0.00 ft Easting : 480716.30 ft Longitude: 150 9 23.000 W Position Uncertainty: 0.00 ft Wellpath: Ataruq #2A Drilled From: Ataruq #2 501032050801 Tie-on Depth: 3280.35 ft Current Datnm: Ataruq#2: Height 102.62 ft Above System Datum: Mean Sea Level Magnetic Data: 4/16/2005 Declination: 24.06 deg Field Strength: 57569 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.42 0.00 0.00 310.36 Survey Program for Definitive Well path Date: 5/2/2005 Validated: Yes Version: 1 Actual From To Survey Toolcode Tool Name ft ft 146.15 3280.35 Ataruq #2 (146.15-7330.84) (0) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ see 3320.00 11212.07 Ataruq #2A (3320.00-11212.07) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ see Survey MD IncI Azim TVD Sys TVD N/S E/W M:tpN MapE TMI ft dég deg ft ft ft ft ft ft 30.42 0.00 0.00 30.42 -72.20 0.00 0.00 5969528.36 480716.30 TIE LINE 146.15 0.71 218.66 146.15 43.53 -0.56 -0.45 5969527.80 480715.85 MWD+IFR-AK-CAZ-Se 239.04 0.67 226.67 239.03 136.41 -1.38 -1.20 5969526.98 480715.09 MWD+IFR-AK-CAZ-Se 333.82 0.57 226.04 333.80 231.18 -2.09 -1.94 5969526.28 480714.35 MWD+IFR-AK-CAZ-Se 422.06 0.71 216.14 422.04 319.42 -2.84 -2.58 5969525.53 480713.71 MWD+I FR-AK-CAZ-Se 514.99 0.84 219.97 514.96 412.34 -3.82 -3.36 5969524.55 480712.93 MWD+IFR-AK-CAZ-Se 601.09 0.82 218.11 601.05 498.43 -4.79 -4.15 5969523.58 480712.14 MWD+IFR-AK-CAZ-Se 692.39 0.79 224.71 692.34 589.72 -5.75 -4.99 5969522.62 480711.29 MWD+IFR-AK-CAZ-Se 782.96 0.76 222.52 782.90 680.28 -6.64 -5.84 5969521.74 480710.45 MWD+IFR-AK-CAZ-Se 874.53 1.05 218.98 874.46 771.84 -7.74 -6.78 5969520.64 480709.51 MWD+IFR-AK-eAZ-SC 960.01 1.25 227.98 959.93 857.31 -8.97 -7.96 5969519.41 480708.32 MWD+IFR-AK-CAZ-SC 1052.85 1.31 230.94 1052.74 950.12 -10.32 -9.54 5969518.07 480706.74 MWD+IFR-AK-eAZ-Se 1148.98 1.59 226.51 1148.84 1046.22 -11.93 -11.36 5969516.46 480704.91 MWD+IFR-AK-CAZ-SC 1242.78 1.79 225.50 1242.60 1139.98 -13.85 -13.35 5969514.54 480702.92 MWD+I FR-AK-CAZ-SC 1336.85 1.54 215.21 1336.63 1234.01 -15.91 -15.12 5969512.49 480701 .14 MWD+IFR-AK-CAZ-Se 1432.68 2.07 230.01 1432.41 1329.79 -18.08 -17.19 5969510.33 480699.06 MWD+IFR-AK-CAZ-SC 1526.01 2.15 228.27 1525.68 1423.06 -20.33 -19.79 5969508.09 480696.46 MWD+IFR-AK-CAZ-SC 1623.58 2.30 228.58 1623.18 1520.56 -22.84 -22.62 5969505.58 480693.62 MWD+IFR-AK-CAZ-SC I I I I I I I I I I I I I I I I I I Halliburton Global I C)rnþany: Kerr McGee Date: 5/2/2005 Hrne: 13: 13:48 Page: 2 Field: Ataruq Co-ordinate(NE) Reference: Well: Ataruq #2, True North Site: Ataruq Verticàl(TVD) Rèference: Atàruq#2: 102,6 Well: Ataruq #2 SectiOn (VS) Rèference: Wèll (O.00N,0.00E,310,36Azi) Well path: Ataruq#2A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Ine! AZim TVD Sys TVD N/S EIW M;tpN MapE Tool ft deg dèg ft ft ft ft ft ft 1717.97 2.22 226.51 1717.49 1614.87 -25.35 -25.37 5969503.08 480690.87 MWD+IFR-AK-CAZ-SC 1812.84 1.97 338.01 1812.33 1709.71 -25.10 -27.32 5969503.33 480688.92 MWD+IFR-AK-CAZ-SC 1906.46 7.53 7.49 1905.60 1802.98 -17.52 -27.12 5969510.91 480689.14 MWD+IFR-AK-CAZ-SC 1999.86 11.39 7.85 1997.71 1895.09 -2.31 -25.06 5969526.11 480691.24 MWD+IFR-AK-CAZ-SC 2094.43 14.30 10.37 2089.91 1987.29 18.43 -21.68 5969546.84 480694.67 MWD+IFR-AK-CAZ-SC 2186.87 17.37 12.54 2178.83 2076.21 43.14 -16.63 5969571.53 480699.78 MWD+IFR-AK-CAZ-SC 2281.99 20.98 13.42 2268.66 2166.04 73.57 -9.59 5969601.95 480706.90 MWD+IFR-AK-CAZ-SC 2375.23 24.25 15.03 2354.72 2252.10 108.31 -0.75 5969636.66 480715.83 MWD+IFR-AK-CAZ-SC 2470.04 29.20 15.70 2439.37 2336.75 149.40 10.56 5969677.72 480727.25 MWD+I FR-AK-CAZ-SC 2565.28 33.53 14.18 2520.68 2418.06 197.29 23.30 5969725.57 480740.11 MWD+IFR-AK-CAZ-SC 2659.74 37.99 11.91 2597.31 2494.69 251.06 35.70 5969779.30 480752.64 MWD+IFR-AK-CAZ-SC 2755.83 42.17 11.13 2670.82 2568.20 311.67 48.03 5969839.88 480765.13 MWD+I FR-AK-CAZ-SC 2849.43 45.63 10.99 2738.25 2635.63 375.36 60.48 5969903.53 480777.74 MWD+I FR-AK-CAZ-SC 2944.67 45.33 9.47 2805.03 2702.41 442.18 72.54 5969970.31 480789.97 MWD+IFR-AK-CAZ-SC 3036.21 45.15 7.77 2869.49 2766.87 506.44 82.28 5970034.54 480799.88 MWD+IFR-AK-CAZ-SC 3132.07 44.16 7.62 2937.68 2835.06 573.21 91.31 5970101.28 480809.07 MWD+IFR-AK-CAZ-SC 3227.17 42.34 6.67 3006.95 2904.33 637.86 99.42 5970165.90 480817.35 MWD+I FR-AK-CAZ-SC 3280.35 42.13 5.85 3046.32 2943.70 673.39 103.32 5970201.42 480821.34 MWD+IFR-AK-CAZ-SC 3320.00 42.14 5.70 3075.73 2973.11 699.86 105.99 5970227.87 480824.08 MWD+IFR-AK-CAZ-SC 3423.42 44.15 0.15 3151.21 3048.59 770.43 109.54 5970298.43 480827.80 MWD+IFR-AK-CAZ-SC 3517.97 44.33 355.00 3218.97 3116.35 836.29 106.74 5970364.29 480825.18 MWD+IFR-AK-CAZ-SC 3612.72 44.82 349.89 3286.48 3183.86 902.17 97.99 5970430.18 480816.60 MWD+IFR-AK-CAZ-SC 3705.48 44.91 345.18 3352.25 3249.63 966.02 83.87 5970494.07 480802.65 MWD+I FR-AK-CAZ-SC 3800.95 46.58 340.06 3418.89 3316.27 1031.22 63.42 5970559.31 480782.36 MWD+IFR-AK-CAZ-SC 3893.75 49.20 337.67 3481.12 3378.50 1095.41 38.58 5970623.56 480757.69 MWD+IFR-AK-CAZ-SC 3989.12 51.83 332.22 3541.78 3439.16 1162.01 7.37 5970690.23 480726.65 MWD+IFR-AK-CAZ-SC 4084.04 53.32 328.46 3599.48 3496.86 1227.48 -29.94 5970755.79 480689.52 MWD+IFR-AK-CAZ-SC 4179.15 55.98 324.58 3654.52 3551.90 1292.14 -72.75 5970820.55 480646.87 MWD+IFR-AK-CAZ-SC 4273.66 59.32 321.27 3705.09 3602.47 1355.79 -120.90 5970884.32 480598.89 MWD+IFR-AK-CAZ-SC 4368.10 61.12 317.43 3752.01 3649.39 1417.94 -174.30 5970946.60 480545.66 MWD+IFR-AK-CAZ-SC 4461.00 63.30 314.95 3795.32 3692.70 1477.23 -231.20 5971006.03 480488.92 MWD+IFR-AK-CAZ-SC 4556.14 65.97 310.73 3836.09 3733.47 1535.63 -294.24 5971064.59 480426.04 MWD+IFR-AK-CAZ-SC 4651.06 68.41 308.81 3872.89 3770.27 1591.59 -361.49 5971120.71 480358.94 MWD+IFR-AK-CAZ-SC 4745.29 70.70 304.85 3905.81 3803.19 1644.48 -432.15 5971173.78 480288.42 MWD+I FR-AK-CAZ-SC 4840.13 74.57 301.63 3934.12 3831.50 1694.06 -507.85 5971223.55 480212.86 MWD+IFR-AK-CAZ-SC 4932.35 76.30 301.06 3957.31 3854.69 1740.48 -584.07 5971270.17 480136.76 MWD+IFR-AK-CAZ-SC 4987.24 76.35 303.43 3970.29 3867.67 1768.94 -629.18 5971298.73 480091.73 MWD+IFR-AK-CAZ-SC 5080.05 76.14 303.14 3992.36 3889.74 1818.41 -704.54 5971348.39 480016.51 MWD+IFR-AK-CAZ-SC 5173.29 77.07 302.88 4013.96 3911.34 1867.82 -780.60 5971398.00 479940.58 MWD+I FR-AK-CAZ-SC 5267.34 77.34 302.46 4034.79 3932.17 1917.33 -857.80 5971447.70 479863.51 MWD+I FR-AK-CAZ-SC 5360.54 77.15 301.81 4055.36 3952.74 1965.68 -934.78 5971496.24 479786.67 MWD+IFR-AK-CAZ-SC 5456.84 76.59 300.98 4077 .24 3974.62 2014.54 -1014.83 5971545.30 479706.75 MWD+IFR-AK-CAZ-SC 5549.58 76.26 301.24 4099.01 3996.39 2061.11 -1092.01 5971592.07 479629.70 MWD+I FR-AK-CAZ-SC 5647.31 75.94 300.54 4122.48 4019.86 2109.82 -1173.42 5971640.98 479548.42 MWD+IFR-AK-CAZ-SC 5739.02 75.47 300.74 4145.13 4042.51 2155.11 -1249.88 5971686.46 479472.08 MWD+IFR-AK-CAZ-SC 5832.00 76.92 301.15 4167.32 4064.70 2201.54 -1327.32 5971733.09 479394.77 MWD+IFR-AK-CAZ-SC 5926.41 76.87 301.37 4188.72 4086.10 2249.26 -1405.93 5971781.00 479316.30 MWD+IFR-AK-CAZ-SC 6021.67 76.45 299.89 4210.70 4108.08 2296.48 -1485.68 5971828.42 479236.68 MWD+IFR-AK-CAZ-SC 6116.76 75.96 299.01 4233.38 4130.76 2341.88 -1566.09 5971874.03 479156.39 MWD+I FR-AK-CAZ-SC 6209.62 76.51 298.54 4255.47 4152.85 2385.30 -1645.15 5971917.64 479077 .45 MWD+IFR-AK-CAZ-SC 6301.47 77.01 298.67 4276.51 4173.89 2428.11 -1723.64 5971960.65 478999.07 MWD+I FR-AK-CAZ-SC 6396.84 76.45 298.42 4298.40 4195.78 2472.46 -1805.18 5972005.21 478917.66 MWD+IFR-AK-CAZ-SC I I I I I I I I I I I I I I I I I I I Halliburton Global I gøJj¡pany: KêrrMtGee Date: 51212005 Time: 13: 13:48 Page: 3 Field: At<1ruq Co-ordinåte(NE) Reference: Well: Ataruq #2, True North Site: Ataruq Vertical (TVD)Reference: Ataruq#2: 102.6 We!l: Atarùq#2 Section (VS) Reference: Wêll (O.OON,0.00E,310.36Azi) I WeIlpath: Ataruq #2A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S EIW MapN MapE Tool ft deg deg ft ft ft ft ft ft 6490.52 76.45 298.87 4320.35 4217.73 2516.12 -1885.11 5972049.07 478837.85 MWD+IFR-AK-CAZ-SC 6582.82 76.68 300.06 4341.79 4239.17 2560.28 -1963.27 5972093.42 478759.81 MWD+I FR-AK-CAZ-SC 6676.63 75.96 300.39 4363.98 4261.36 2606.16 -2042.03 5972139.50 478681.18 MWD+I FR-AK-CAZ-SC 6771.49 75.41 300.67 4387.43 4284.81 2652.85 -2121.20 5972186.39 478602.14 MWD+I FR-AK-CAZ-SC 6867.59 76.24 300.32 4410.97 4308.35 2700.13 -2201.48 5972233.87 478521.98 MWD+I FR-AK-CAZ-SC I 6963.02 76.58 301.22 4433.39 4330.77 2747.59 -2281.18 5972281.53 478442.41 MWD+IFR-AK-CAZ-SC I 7057.67 76.27 301.03 4455.61 4352.99 2795.15 -2359.94 5972329.28 478363.78 MWD+IFR-AK-CAZ-SC 7153.03 77.81 299.52 4476.99 4374.37 2841.99 -2440.20 5972376.33 478283.66 MWD+IFR-AK-CAZ-SC 7247.33 77.22 299.93 4497.38 4394.76 2887.64 -2520.15 5972422.18 478203.83 MWD+I FR-AK-CAZ-SC 7341.78 75.62 301.20 4519.56 4416.94 2934.32 -2599.20 5972469.06 478124.91 MWD+I FR-AK-CAZ-SC 7435.08 75.81 301.40 4542.58 4439.96 2981.30 -2676.46 5972516.23 478047.78 MWD+IFR-AK-CAZ-SC 7529.15 77.08 302.23 4564.63 4462.01 3029.51 -2754.16 5972564.63 477970.21 MWD+IFR-AK-CAZ-SC 7622.54 76.15 301.95 4586.25 4483.63 3077.77 -2831.13 5972613.09 477893.37 MWD+IFR-AK-CAZ-SC 7717.01 75.82 301.95 4609.12 4506.50 3126.28 -2908.91 5972661.79 477815.73 MWD+I FR-AK-CAZ-SC 7809.39 76.13 302.72 4631.51 4528.89 3174.21 -2984.63 5972709.92 477740.13 MWD+IFR-AK-CAZ-SC 7904.35 76.44 302.36 4654.03 4551.41 3223.84 -3062.40 5972759.73 477662.50 MWD+IFR-AK-CAZ-SC 7997.65 76.41 302.75 4675.93 4573.31 3272.64 -3138.85 5972808.73 477586.19 MWD+IFR-AK-CAZ-SC 8093.60 75.75 302.4 7 4699.01 4596.39 3322.83 -3217.30 5972859.12 477507.87 MWD+IFR-AK-CAZ-SC 8187.41 75.45 302.63 4722.34 4619.72 3371.72 -3293.89 5972908.19 477431.42 MWD+I FR-AK-CAZ-SC 8283.45 75.08 301.59 4746.77 4644.15 3421.09 -3372.56 5972957.76 477352.88 MWD+IFR-AK-CAZ-SC 8378.52 76.17 300.17 4770.37 4667.75 3468.35 -3451.60 5973005.22 477273.97 MWD+IFR-AK-CAZ-SC 8474.23 75.86 300.32 4793.50 4690.88 3515.13 -3531.83 5973052.20 477193.87 MWD+I FR-AK-CAZ-SC 8569.14 76.61 299.40 4816.08 4713.46 3561.02 -3611.77 5973098.30 477114.05 MWD+IFR-AK-CAZ-SC 8663.75 77.97 299.05 4836.90 4734.28 3606.08 -3692.31 5973143.56 477033.63 MWD+I FR-AK-CAZ-SC 8758.49 77.33 299.18 4857.16 4754.54 3651.11 -3773.17 5973188.79 476952.90 MWD+I FR-AK-CAZ-SC 8851.55 76.90 298.38 4877.91 4775.29 3694.79 -3852.68 5973232.67 476873.51 MWD+I FR-AK-CAZ-SC 8946.35 76.81 298.96 4899.47 4796.85 3739.08 -3933.67 5973277.16 476792.64 MWD+I FR-AK-CAZ-SC 9039.83 77.32 299.43 4920.40 4817.78 3783.52 -4013.21 5973321.80 476713.23 MWD+IFR-AK-CAZ-SC 9135.33 77.98 299.86 4940.82 4838.20 3829.66 -4094.29 5973368.15 476632.28 MWD+IFR-AK-CAZ-SC 9225.16 76.76 300.62 4960.47 4857.85 3873.80 -4170.01 5973412.48 476556.67 MWD+I FR-AK-CAZ-SC 9320.29 75.93 300.85 4982.92 4880.30 3921.05 -4249.47 5973459.93 476477.34 MWD+IFR-AK-CAZ-SC 9413.91 75.36 301.80 5006.13 4903.51 3968.20 -4326.94 5973507.27 476400.00 MWD+I FR-AK-CAZ-SC 9508.78 75.83 302.44 5029.74 4927.12 4017.05 -4404.77 5973556.32 476322.31 MWD+IFR-AK-CAZ-SC 9603.90 75.98 302.84 5052.90 4950.28 4066.81 -4482.45 5973606.28 476244.76 MWD+IFR-AK-CAZ-SC 9699.48 74.17 302.78 5077.52 4974.90 4116.86 -4560.07 5973656.51 476167.28 MWD+IFR-AK-CAZ-SC 9794.22 71.57 302.66 5105.42 5002.80 4165.79 -4636.24 5973705.64 476091.25 MWD+IFR-AK-CAZ-SC 9889.02 67.81 301.07 5138.32 5035.70 4212.73 -4711.72 5973752.76 476015.89 MWD+I FR-AK-CAZ-SC 9982.43 63.46 299.39 5176.85 5074.23 4255.57 -4785.21 5973795.80 475942.52 MWD+IFR-AK-CAZ-SC 10075.49 59.50 299.28 5221.27 5118.65 4295.63 -4856.47 5973836.03 475871.37 MWD+IFR-AK-CAZ-SC 10169.72 55.73 299.13 5271.73 5169.11 4334.45 -4925.92 5973875.02 475802.03 MWD+I FR-AK-CAZ-SC 10265.71 51.54 298.70 5328.64 5226.02 4371.82 -4993.56 5973912.56 475734.49 MWD+I FR-AK-CAZ-SC 10360.17 47.70 298.16 5389.82 5287.20 4406.08 -5056.82 5973946.98 475671.32 MWD+I FR-AK-CAZ-SC 10455.69 43.02 298.67 5456.92 5354.30 4438.40 -5116.59 5973979.46 475611.64 MWD+I FR-AK-CAZ-SC 10551.30 38.91 299.65 5529.10 5426.48 4468.92 -5171.32 5974010.11 475556.99 MWD+IFR-AK-CAZ-SC 10646.54 34.71 301.23 5605.34 5502.72 4497.79 -5220.53 5974039.10 475507.87 MWD+I FR-AK-CAZ-SC 10740.50 30.22 300.64 5684.59 5581.97 4523.72 -5263.77 5974065.14 475464.70 MWD+IFR-AK-CAZ.SC 10835.71 27.88 300.27 5767.82 5665.20 4547.16 -5303.62 5974088.68 475424.92 MWD+IFR-AK-CAZ-SC 10932.04 27.17 298.64 5853.25 5750.63 4569.05 -5342.37 5974110.67 475386.22 MWD+I FR-AK-CAZ-SC 11026.12 26.92 299.30 5937.04 5834.42 4589.77 -5379.80 5974131.48 475348.85 MWD+IFR-AK-CAZ-SC 11120.86 24.00 301.79 6022.57 5919.95 4610.42 -5414.88 5974152.22 475313.82 MWD+IFR-AK-CAZ-SC 11212.07 21.68 301.86 6106.63 6004.01 4629.09 -5444.96 5974170.97 475283.79 MWD+IFR-AK-CAZ-SC 11242.00 21.68 301.86 6134.44 6031.82 4634.92 -5454.36 5974176.83 475274.42 PROJECTED to TO I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I t .~~"" HALLIB:U"RTDN Sperry-Sun MWD/L WD After Action Review Employee Name: Orth, Sack, Peltekian, Burch Date: 4/24/2005 Well: Ataruq #2-A Hole Section: 8.5" ¡ ;..iít, :~ What went as, or better than, planned? Geopilot was able to get us to TO before BAT Sonic memory filled up, despite a number pump/rig problems. What experienced difficulty? Detection was challenging towards TO due to pump problems. Recommendations? The pumps need to be repaired prior to picking up tools. .¡ Were there any innovations and/or cost savings realized on this well? The ACAL tool and SAT Sonic tool were read in the pipe shed. This saved approx. 3 hrs of rig time. Sperry-Sun Confidential I I I I I I I I I I I I I I I I I I I HALLIBURTON Sperry-Sun Directional Drilling After Action Review Employee Name: Harding / Brouillet Date: 4/24/2005 Well: Aturaq #2A Hole Section: 8-1/2 What went as, or better than, planned: BHA #1: Kicked off the cement plug in less than 1 hr. As the plug was hard this was very easily accomplished. The build section done with the 7" performance motor went very well with consistent dogleg rates given. The assembly stayed very close to the proposal line throughout this 8-1/2 sidetrack. BHA #2: GeoPilot produced required dogleg and hit both targets. 8-1/2 sidetrack was drilled with two BHA runs as planned Difficulties experienced: Some difficulties associated to erratic torque. Problems downlinking to Geo-pilot tool occurred often. This downlinking did cause minor problems keeping the tool steering in the correct direction. Recommendations: Consider kicking off a good plug with Geo-Pilot assembly and avoid a trip for BHA. Lubrication percentage never reached 3% which is usually a minimum. At the high angle of this well lubricants should have been more of a priority. Innovations and/or cost savings: Efficient drilling with preplanning done that resulted in additional rig time savings! Sperry-Sun Confidential I I I I I I I I I I I I I I I I I I I HALLIBURTON Sperry-Sun Job No.: AK-MW-0003663836 Well No.: Ataruq #2A End of WeU Report Page 10 HALLIBURTON Sperry-Sun Surface Data Logging END OF WELL REPORT Kerr McGee Oil and Gas Corp. AT ARUQ #2A ,{O('lU-<" Ci I I I I I I I I I I I I I I I I I I I sper-r-v-sun C R I L..L..I N G 5 E A V I c: E 5 Surface Data Logging END OF WELL REPORT Kerr McGee Oil and Gas Corp. AT ARUQ #2A ,{o(".o><. I I I I TABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Formation Tops I 4. Morning Reports I 5. Bit Record 6. Mud Reports I 7. Show Reports I 8. Survey Report 9. Days vs. Depth I 10. Formation Evaluation logs I 11. Engineering log I I I I I sperl'-"v-sun I I:IRI'-'-INI::Þ Se:Fi\JIc:e:5 I I I I I' I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date (TD): North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: SDl Engineers: Company Geologist: SSDS Unit Number: Kerr McGee Corporation Nabors N27E Ataruq #2 A Kuparuk North Slope Alaska United States 50-103-20508-01 AK-AM-0003663836 18th April 2005 2ih April 2005 True 24.064 deg 80.70 deg 57569 NT April 02, 2005 North 70 deg 19 min 40.482 see East 150 deg 09 min 23.008 see Doug Wilson Tom Mansfield Mark Lindloff Steve Greene T. Hillegeist A. Heinrich 117 spe.....l.....y- sun t:JRIt-t-1 N I::i liiief"il\llc:e5 I I I I I I I I I I I I I I I I I I I Ataruq #2 A - Diary of Events 18th April 2005 Kickoff Ataruq #2 A sidetrack at 0129 hrs 04/18/05 at 3319' MD ( 3075' TVD) out of base of9 5/8" casing set to 3319' MD from original Ataruq #2 well. Directionally drilled 8 1/2" hole with bit #1, Hughes GT -1, TF A=0.589 , 3x16 jets, to build angle from 42.14° and turn from 5.70° azimuth. Continued to drill 8 W' hole from 3319' to 4964' MD at 600 gpm, 80-100 RPM and average ROP of 102 fi/hr. IIFR corrected MWD survey at 4932.35' MD was 76.30° inclination and 301.06° azimuth with TVD of 3957.31'. Lithology was comprised primarily of siltstone with minor interbedded sandstones and claystones of the Colville formation. Maximum gas was 167 units at 4949' MD. Gas consisted of methane with minor ethane showing at 4065' MD. Mud weight was 9.3 ppg with viscosity 42 (waterbased KCL polymer). 19th April 2005 Drilled from 4964' MD to 4975' MD , 3967' TVD. Circulated bottoms up and tripped out of hole to pickup Geopilot PDC assembly, Nuke and BAT sonic tools. Maximum gas was 155 units at 4975' MD. Bit # 1 statistics = 1656 feet, 16.3 hours, 246 k revolutions with average ROP of 102 fi/hr. Pickup Bit # 2 and BHA ( 8 W' Security FSF2565 PDC , TFA=0.982, 5x16 jets). Ran in hole and shallow tested MWD and Geopilot downlink. 20th April 2005 Directionally drilled ahead with Geopilot from 4975' to 6994' MD, 4441' TVD while alternately pumping hi-vis and weighted sweeps every 400' to keep hole clean. Maintained approximately 76.5° inclination at 300° azimuth. At 6994', circulated the hole clean and short tripped to 5950' with no drag. Short trip gas was 1656 units. Continued to drill ahead through Coleville from 6992' MD to 7435' MD while to alternating sweeps. Began seeing minor connection gas peaks starting at 7182' MD with 9.6 ppg mud weight. 21st April 2005 Directionally drilled from 6994' MD to 9215' MD, 4958' TVD with connection gases dieing out as the mud weight built from 9.6 to 9.9 ppg. Dropped carbide to confirm lag washout factor. Results indicated 10.15" average hole size. Maximum drilled gas readings through sands in the lower part of the Colville peaked at 4963 units from 7675' MD, 4599' TVD, with only minor spotty fluorescence reported. The top of the Tam formation was breeched at 8245' MD (4738' TVD). 22nd April 2005 Directionally drilled from 9215' MD to 10702' MD (5652' TVD). Began dropping inclination around 9400' MD (5000' TVD). Encountered the Lower Tam formation at 9577' MD (5047' TVD), and the Moraine formation at 10432' MD (5441' TVD). Continued alternating hi vis and weighted sweeps every 400 feet. The maximum gas through this interval was 899 units at 9215' MD (4958' TVD). I I I I I I I I I I I I I I I I I I I 23rd April 2005 Drilled from 10702' MD to 11242' MD (6135' TVD) and TD well. The HRZ was encountered at 10679' MD (5632' TVD), where the background gas increased to as much as 1680 units. The Kalubik was encountered at 10882' MD (5813' TVD) and the Kuparuk Cat 11041' MD (5955' TVD). Sand in the Kuparuk C was poorly developed. The Miluveach was at 11128' MD (6034' TVD). Drilling was then completed at 11242'. Three bottoms up were circulated before back reaming 10 stands out. Running back in the hole, last 5 stands were reamed to bottom. A hi-vis sweep was pumped and short trip gas was 475 units. Bottoms up was circulated three more times before pumping out of the hole to the shoe. 24th April 2005 Backreamed out to 9728' and pulled to 6670'. Tight hole, washed and back -reamed from 6670' to 4449'. Pulled into 9 5/8" casing shoe to 3314' and circulated bottoms up. Pumped a dry job. Pulled out of hole to 2090'. Ran back in hole to shoe, broke circulation. Ran in hole to 7182'. Circulated and conditioned mud system. Pumped a Hi-Vis sweep. Backreamed and pumped out of hole. 25th April 2005 Backreamed and pumped out of hole to casing shoe. Circulated bottoms up at the shoe while changing out swivel packing. Pumped dry job. Continued to pull out of hole and lay down BHA. Tested BOP'S. Picked up clean out BHA. 26th April 2005 Tripped in hole - tagged bridge at 5480'. Washed and reamed from 5480' to 5670'. Tight spots at 6400', 10829'. Reamed from 10829' to 1113' - trip gas peaked at 4064 units. Circulated and conditioned mud. Added new mud to system. A number of gas peaks were observed while conditioning hole near bottom. Gas peaks ranged from 1490 to 2650 units with background gas ranging from 400 to 600 units. 27th April 2005 Pulled out of hole to casing shoe. Slipped and cut drilling line. Continued pulling out hole. Ran in hole for MBTs. 28th April 2005 I I I I GEOLOGIST FORMATION TOPS MD TVD TVD SS I BASE PERMAFROST 1490 1490 1387.4 I SCHRADER BLUFF 1730 1730 1627.4 1852 1748.4 SCHRADER OA 1851 I T ABASCO 3130 2937 2834.4 I COLVILLE 3202 2988 2885.4 TARN 8245 4738 4875.4 I LOWER TARN 9577 5047 5044.4 I MORAINE 10432 5441 5438.4 HRZ TOP 10679 5632 5629.4 I HRZ BASE 10882 5813 5810.4 TOP KALUBIK I KUP ARUK "C" 11041 5955 5952.4 I LCU/KUP ARUK "A" 11089 5998 5995.4 MILUVEACH 11128 6034 6031.4 I I I I I I I I I I I I I I I I I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: Kerr MeGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: sper'r'v-sun DRI LL.I N G SERVI c:: ES -.....--.-.....-..--.----...........--..-.....--..-.--......-....-.............-..-.-..-.. Mudlogger's Morning Report 1 4/17/2005 3319 o RIH Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr 0 fUhr ( 0 ftIhr @ 0 Pump 1 50 spm Flow rate 463 gpm Gas* 0 units unit~ ( units @ Pump 2 52 7.717 gps - Temp Out 65 Deg F ( deg F @ Pump Liner 6.5" x 12 in. SPP 1685 Mud Wt In Mud Wt Out 10.10 ppg 10.10 ppg -- Vise 42 sees APlfilt 10.1 ml HTHP 0.0 mMud Wtat Max Gas PV 9 eP YP 11 Ibs/100ft2 Gels 2 \ 13 \ 17 PH 11.2 Sd ppg 0.1 % GT-1 o x 0 o x TFA: 0.5890 -- Footage for Bit Run Bit Size: Hrs. On Bit: 81/2 Jets: 3 x 16 -- Total Revs on Bit: 4 Type: RPM: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 15000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: I 1 I Feet of Fill on Bottom: 0 ft 0 % Sltst 0 % Sh 0 % elyst 0 % Sst % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units ppg ppg ppg Drilling Breaks Drill Rate during Depth Gas during after before before after to to to to units units units % Lithology Sltst Sst Ls Cly ppg ppg ppg I I I I I I I I I I I sper'r'V- sun CRIL..L..ING SERVICES -.....---.......---..-............-......-......---......-...-.--....--...--.....- Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 2 4/18/2005 4964 1645 Drill ahead Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data 90 fUhr 101 ftlhr ( 193 fUhr @ 4906 Pump 1 60 spm Flow rate 603 148 units 121 unit~ ( 167 units @ 4949 Pump 2 65 10.05 - 65 Deg F ( deg F @ Pump Liner 6.5" x 12 SPP 1891 0.0 m Mud Wt at Max Gas 4 \ 8 \ 15 PH Mud Wt In Mud Wt Out Vise PV 42 sees API filt 5.6 ml HTHP 8 eP YP 15 Ibs/100ft2 Gels -- 9.30 ppg 9.30 ppg 4 GT-1 Bit Size: Hrs. On Bit: Type: RPM: 9.2 Sd ppg 0.3 % 81/2 16.1 o x 0 243 x TFA: 0.5890 -- Footage for Bit Run 1645 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft Jets: 3 x 16 Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 15000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: 1 1 I Feet of Fill on Bottom: 0 ft Current Lithology: 100 % Sltst 0 % Sh 0 % clyst 0 % Sst % ft ft ft units units units ppg ppg ppg Depth Drill Rate during before to to to to Drilling Breaks after Gas during after before units ppg units ppg units ppg Sltst % Lithology Sst Ls Cly I I I I I I I I I I I I I I I I I I I spe....,....,v- sun DRIL..L.INIli seRVIc:es _.__.._....__.____...._.___....____.__m__..___ Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 3 4/19/2005 5732 768 Drill ahead Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data 201 fUhr 160 fUhr ( 259 fUhr @ 5691 Pump 1 67 spm Flow rate 628 - 215 units 161 unih( 227 units @ 5669 Pump 2 60 10.47 65 Deg F ( deg F @ Pump Liner 6.5" x 12 SPP 2141 Mud Wt In Mud Wt Out ppg ppg Vise 45 sees PV 12 eP API filt 5.8 ml HTHP 0.0 m Mud Wt at Max Gas YP 15 Ibs/100ft2 Gels 3 \ 8 \ 14 PH 9.30 ppg 9.2 Sd 0.5 % 9.30 9.30 2 Type: RPM: FSF2565 Bit Size: Hrs. On Bit: -- 81/2 4.8 o x 0 105 x TFA: 0.9820 -- Footage for Bit Run 756 Jets: 5 x 16 -- Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 15000 ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: 1 I Feet of Fill on Bottom: 0 ft 80 % Sltst 0 % Sh 20 % elyst 0 % Sst % ft ft ft units units units ppg ppg ppg Depth Drill Rate during before to to to to Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft Drilling Breaks after Gas during after before units units units % Lithology Sltst Sst Ls Cly ppg ppg ppg I I I I I I I I I I I I I I I I I I I sper'r'v-sun I:J RILL I N G 5 E R V IE:: E 5 Customer: Well: Area: Lease: Rig: Job No.: --..-....-.....-...-.-..-......--.....-.-..-...---..-...---..--............---.....- Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 4 4/20/2005 7435 1703 Drill ahead Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data 153 ftlhr 112 ftlhr ( 219 ftlhr @ 7467 Pump 1 65 spm Flow rate 639 gpm - 695 units 502 unit~ ( 805 units @ 7446 Pump 2 60 10.65 gps 65 Deg F ( deg F @ Pump Liner 6.5" x 12 in. SPP 2379 Mud Wt In Mud Wt Out Vise 45 sees PV 12 eP API filt 5.8 ml HTHP 0.0 m Mud Wt at Max Gas YP 15 Ibs/100ft2 Gels 3 \ 8 \ 14 PH ~ppg 9.2 Sd 0.5 % 9.65 ppg 9.65 ppg FSF2565 96 Bit Size: Hrs. On Bit: 2 Type: 32.00 RPM: -- 81/2 18.4 o x 0 406 x TFA: 0.9820 -- Footage for Bit Run 2459 Jets: 5 x 16 -- Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: 15000 ppm Short Trip Depth 6994 ft Short Trip Gas: 1656 Mud Cut: 9.3 ppg Short Trip CI: 50000 ppm Tight Spots: I 1 I Feet of Fill on Bottom: 0 ft 0 Sltst 80 % Sh 0 % elyst 0 % Sst % 7182 ft 641 units ~ppg 7276 ft 471 units ~ppg 7370 ft 583 units 9.6 ppg Depth Drill Rate during before to to to to Connection Gas and Mud Cut 7463 ft 1768 units ~ ppg ft units ppg ft units ppg ft ft ft Drilling Breaks after Gas during after before units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly Current 24 hr Avg 24 hr Max Pump and Flow Data 107 fUhr 112 fUhr ( 227 ftlhr @ 8870 Pump 1 65 spm Flow rate 639 246 units 862 unih( 3810 units @ 7823 Pump 2 60 10.65 65 Deg F ( deg F @ Pump Liner 6.5" x 12 SPP 2789 I I I I I I I I I I I I I I I I I I I sper'r'v-sun DRILLING SERVICES Customer: Well: Area: Lease: Rig: Job No.: -.....----....-.--..-.-----.---.--....-...-.....-...-..-..-..-.--.--- Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 4/21/2005 9215 1780 Drill ahead Gary/Mike Mud Wt In Mud Wt Out 9.90 ppg 9.90 ppg Visc 47 secs PV 17 cp API filt 5.0 ml HTHP 0.0 m Mud Wt at Max Gas YP 15 Ibs/100ft2 Gels 5 \ 15 \ 19 PH 9.90 ppg 9.2 Sd 0.5 % FSF2565 181 Bit Size: Hrs. On Bit: 2 Type: 28.00 RPM: 7558 ft 2933 units ~ ppg 7651 ft 3194 units ~ppg 7745 ft 2094 units 9.7 ppg Depth Drill Rate during before to to to to -- 81/2 35.9 o x 0 756 x TFA: 0.9820 -- Footage for Bit Run 4239 Jets: 5 x 16 -- Total Revs on Bit: Connection Gas and Mud Cut 7838 ft 5444 units ~ ppg 7932 ft 3750 units ~ ppg 8027 ft 2286 units 9.8 ppg ft ft ft Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: / / Feet of Fill on Bottom: 0 ft 70 % Sltst 20 % Sh 0 % clyst 10 % Sst % Drilling Breaks after Gas during after before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of filings: very fine filings 24 hr Recap: Directionall drill ahead. * 2 Sample catchers on Location: Bobby, Steve Jenkins Daily cost: Full Mudlogging + 2 Sample Catchers ($275.00/ man/day) + Pit Monitor-3 extra pits+Geo Comp Daily cost: = $3025.00 + $550.00 + $60 + $100= $ 3735.00 Logging Engineer: Tom Mansfield / Steve Greene units units units % Lithology Sltst Sst Ls Cly ppg ppg ppg I I I I I I I I I I I I I I I I I I I spe....,....,v- sun [J RILL IN G 5 e R v I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 6 4/22/2005 10702 1487 Drill ahead Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data 144 ft/hr 102 ft/hr ( 268 ft/hr @ 10702 Pump 1 60 spm Flow rate 614 536 units 355 unit~ ( 899 units @ 9215 Pump 2 60 10.23 - 65 Deg F ( deg F @ Pump Liner 6.5" x 12 SPP 3502 ft ft ft units units units ppg ppg ppg ---.....-......-......-..........--.....-.....--.--......-.-.--..-...-...-...--.....-...........- Mudlogger's Morning Report Mud Wt In Mud Wt Out Visc 47 secs PV 17 cp API filt 5.0 ml HTHP 0.0 m Mud Wt at Max Gas YP 15 Ibs/100ft2 Gels 4 \ 18 \ 26 PH 9.90 ppg 8.2 Sd 0.5 % 11.30 ppg 11.30 ppg 2 Type: 28.00 RPM: FSF2565 195 Bit Size: Hrs. On Bit: -- 81/2 50.6 o x 0 1,073 x TFA: 0.9820 -- Footage for Bit Run 5726 Jets: 5 x 16 -- Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: I / Feet of Fill on Bottom: 0 ft 55 % Sltst 25 % Sh 0 % clyst 20 % Sst % Depth Drill Rate during Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft before to to to to Drilling Breaks after Gas during after before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of filings: very fine filings 24 hr Recap: Directionall drill ahead. * 2 Sample catchers on Location: Bobby, Steve Jenkins Daily cost: Full Mudlogging + 2 Sample Catchers ($275.00 / man/day) + Pit Monitor-3 extra pits+Geo Comp Daily cost: = $3025.00 + $550.00 + $60 + $100= $ 3735.00 Logging Engineer: Tom Mansfield / Steve Greene units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly Current 24 hr Avg 24 hr Max Pump and Flow Data 0 fUhr 102 fUhr ( 212 fUhr @ 11 068 Pump 1 60 spm Flow rate 614 gpm - 145 units 854 unit~ ( 1652 units @ 10888 Pump 2 60 10.23 gps 65 Deg F ( deg F @ Pump Liner 6.5" x 12 in. SPP 3502 I I I I I I I I I I I I I I I I I I I spe...,...,v-sun CRIL..L.ING SERVICES _....___.__.w__.._......____.....__...__._.....__.._...___.....__ Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 7 4/23/2005 11242 540 POOH Gary/Mike Mud Wt In Mud Wt Out Visc 44 secs PV 15 cp API filt 4.8 ml HTHP 9.4 m Mud Wt at Max Gas YP 10 Ibs/100ft2 Gels 6 \ 18 \ 0 PH 11.30 ppg 8.2 Sd 0.5 % 11.30 ppg 11.30 ppg 2 Type: 28.00 RPM: FSF2565 195 Bit Size: Hrs. On Bit: Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: / I 85 % Sltst 10 % Current Lithology: ft ft ft units units units ppg ppg ppg Depth Drill Rate during before to to to to -- ppm ppm o ft units units units % Lithology Sltst Sst Ls Cly 81/2 55.8 o x 0 1,073 x TFA: 0.9820 -- Footage for Bit Run 6266 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of filings: very fine filings Jets: 5 x 16 -- Total Revs on Bit: Mud Cut: Mud Cut: ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Sh o % clyst % Sst % ppg ppg ppg 5 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft 24 hr Recap: Directionall drill ahead. TD 11242ft MD. Short trip 10 stds, run back to bottom. Start to POOH. * 2 Sample catchers on Location: Bobby, Steve Jenkins Daily cost: Full Mudlogging + 2 Sample Catchers ($275.00 / man/day) + Pit Monitor-3 extra pits+Geo Comp Daily cost: = $3025.00 + $550.00 + $60 + $100= $ 3735.00 Logging Engineer: Tom Mansfield / Steve Greene Drilling Breaks after Gas during after * 10000 units = 100% Gas In Air before oz. I I I I I I I I I I I I I I I I I I I spe....,....,v- sun CRILLING seRVices Customer: Well: Area: Lease: Rig: Job No.: ---..-.....-.-.-............................----..--.-..---...-......--.-....-..--.- Mudlogger's Morning Report Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 8 4/24/2005 11242 o POOH Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. fUhr ftIhr ( ftIhr @ Pump 1 spm Flow rate gpm Gas* 145 units 120 unit~ ( 1020 units @ Pump 2 0 gps - Temp Out Deg F ( deg F @ Pump Liner 6.5" x 12 in. SPP Mud Wt In Mud Wt Out Vise 44 sees PV 15 eP API filt 4.8 ml HTHP 9.4 m Mud Wt at Max Gas YP 10 Ibs/100ft2 Gels 6 \ 18 \ 0 PH 11.30 ppg 8.2 Sd 0.5 % 11.30 ppg 11.30 ppg FSF2565 195 Bit Size: Hrs. On Bit: 2 Type: 28.00 RPM: -- 81/2 55.8 o x 0 1,073 x TFA: 0.9820 -- Footage for Bit Run 6266 Jets: 5 x 16 -- Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: I 1 1 Feet of Fill on Bottom: 0 ft y: % Sltst % Sh % clyst % Sst % ft ft ft units units units ppg ppg ppg Depth Drill Rate during before to to to to Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft Drilling Breaks after Gas during after before units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly I I I I Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: spe....,....,v- sun CRIL...L...ING SERVICES _M__.._.....__.._......._.._........____._.....__._.__.._....__.._......_.._..__ Mudlogger's Morning Report 9 4/25/2005 11242 o Make up BHA Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data RO.P. ft/hr ftIhr ( ft/hr @ Pump 1 spm Flow rate gpm Gas* units unit~ ( units @ Pump 2 0 gps Temp Out Deg F ( deg F @ Pump Liner 6.5" x 12 in. SPP I I I I I I I I I I I I I I I API filt 4.8 ml HTHP 9.4 m Mud Wt at Max Gas YP 10 Ibs/100ft2 Gels 6 \ 18 \ 0 PH Mud Wt In Mud Wt Out 11.30 ppg 11.30 ppg Vise 44 sees PV 15 eP -- 11.30 ppg 8.2 Sd 0.5 % Bit Size: Hrs. On Bit: Jets: x x 0 x 0 -- Total Revs on Bit: x TFA: -- Footage for Bit Run Type: RPM: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: I / Feet of Fill on Bottom: 0 ft Current Lithology: % Sltst % Sh % elyst % Sst % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units ppg ppg ppg Drilling Breaks Gas during Depth Drill Rate during after before before after to to to to units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly I I I I I I I I I I I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: sper'r'v-sun CRIL..L.ING seRVices -..--.-.-.--..--..-...........----..........-.....-.....-- Mudlogger's Morning Report 10 4/26/2005 11242 o POOH Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data ft/hr ft/hr ( ft/hr @ Pump 1 60 spm Flow rate 600 units 400 unit~ ( 4064 units @ TG Pump 2 60 10 - Deg F ( deg F @ Pump Liner 6.5" x 12 SPP 2400 Mud Wt In Mud Wt Out 11.30 ppg 11.30 ppg Visc 53 secs PV 15 cp API filt 6.6 ml HTHP 12.4 m Mud Wt at Max Gas - - YP 13 Ibs/100ft2 Gels 10 \ 24 \ 0 PH -- 11.30 ppg 7.8 Sd 0.25 % HTC MXC1 Bit Size: Hrs. On Bit: o x 0 x TF A: 1.8040 -- Footage for Bit Run 0 Type: RPM: 81/2 REAM Jets: 3 x 28 -- Total Revs on Bit: Trip Depth: 11242 ft Trip Gas: 4064 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: 5480 I 5670 / 6400 I 10829 - 11113 Feet of Fill on Bottom: 0 ft nt Lithology: % Sltst % Sh % clyst % Sst % 24 hr Recap: RIH - ta brid eat 5480'. Wash & ream from 5480 to 5670'. Ti ht spots at 6400',10829' & ream from 10829 to 1113' - TG 4064 units. Circulate & condition mud & add new mud to s stem. Note: Gas peaks while reaming near bottom @ 10:40 hrs=2018 units; 11 :11 hrs=2646 units; 15:10 hrs=2168 units; 17:29 hrs=1486 units. * 1 Sample catchers on Location: Steve Jenkins Daily cost: Full Mudlogging + 1 Sample Catcher ($275.00 / man/day) + Pit Monitor-3 extra pits Daily cost: = $3025.00 + $275.00 + $60 = $ 3360.00 Logging Engineer: Tom Mansfield / Wayne Hermanson Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units ft ft ft ppg ppg ppg Drilling Breaks Drill Rate during Depth Gas during before after before after to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of filings: * 10000 units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly units = 100% Gas In Air I I I I I I I I I I I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Ataruq #2 A North Slope Kuparuk Nabors 27E AK-AM-3637543 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: spe...,...,v-sun I:J RILL I N Gi 5 e R v I c: e 5 -.....--.--.-.-..--..-.----.---......--..-..............................----.....-- Mudlogger's Morning Report 11 4/27/2005 11242 o Run MDT Log Gary/Mike Current 24 hr Avg 24 hr Max Pump and Flow Data ft/hr ft/hr ( ft/hr @ Pump 1 spm Flow rate units unit~ ( 2216 units @ 9860 Pump 2 Deg F ( deg F @ Pump Liner 6.5" x SPP API filt 6.5 ml HTHP 13.0 m Mud Wt at Max Gas YP 16 Ibs/100ft2 Gels 7 \ 22 \ PH Mud Wt In Mud Wt Out 11.30 ppg 11.30 ppg Visc 47 secs PV 15 cp -- 11.30 ppg 7.7 Sd 0.1 % Type: RPM: x x TFA: -- Footage for Bit Run o Bit Size: Hrs. On Bit: Jets: x -- Total Revs on Bit: Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: I / I Feet of Fill on Bottom: ft % Sltst % Sh % clyst % Sst % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft ft ft ft units units units ppg ppg ppg Drilling Breaks Drill Rate during Depth Gas during before after before after to to to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of filings: oz. units units units ppg ppg ppg % Lithology Sltst Sst Ls Cly 24 hr Recap: POOH & stand back DC's. Pick u Schlumber er 10 in tools. RIH with MBT tools on drill pi e to shoe. Establish circulation. RIH & circ eve 5 stands to 9040'. Make up side door ent sub. Run wireline down pipe and latch onto tool. Circulate at 9860' - max gas 2216 units. Run multiple MBT test with Sclumberger. * 1 Sample catchers on Location: Steve Jenkins Daily cost: Full Mudlogging + 1 Sample Catcher ($275.00 / man/day) + Pit Monitor-3 extra pits Daily cost: = $3025.00 + $275.00 + $60 = $ 3360.00 Logging Engineer: Tom Mansfield / Wayne Hermanson - - - - - - - - - - - - - - - - - - - sper"'r"'v-sun DRILLING SERVICES WELL NAME: OPERATOR: CONTRACTOR: Ataruq #2 A Kerr McGee Corp Nabors 27E LOCATION: AREA: STATE: Kuparuk North Slope Alaska BIT RECORD BIT Bit Bit Depth Depth Footage Bit TFA AVG WOB RPM PUMP PUMP Bit Bit HHP Krevs Bit Grade Remarks # Type Size IN OUT Hours Rap Press GPM Psi Drop fils HHP I in2 1 HTCGT-1 8.5' 3319.0 4975.0 1656.0 16.3 0.5890 101.6 15 100 2100 600 891 327 5.50 246 1-1-WT-A-E-I-ER-TD PULL FOR Geopilot Assy 2 SEC FSF2565 8.5' 4975.0 11242.0 6267.0 55.8 0.9820 112.3 15-20 135 3400 650 462 212 14.40 1183 1-1-CT-N-X-I-ER-TD PULLED AT T.D. ------------- ------ ~errv-Sun Casing Record Company: Kerr McGee Corporation Lease Drilling Services Well Ataruq # 2 A Area North Slope - Alaska 13 3/S" CSG 106.62 ft MD Rig Nabors 27E Job No: AK-AM-0003663836 95/S" 3319 ft MD Water-based Mud Record Mud Co Baroid Spud Date 1S Apr 2005 7" Liner N/A TD Date: 23 Apr 2005 Date Depth Wt Vis PV YP Gels Filt R600/300 Cake Solids Water Sd Pm pH MBT Pf/Mf Chlor Hard LGS Remarks ft-MD ppg see Ib/100 1b/100ft" m/30m 200/100/6/3 32nds % % % ppm(k) Ca++ %blvol 18-Apr 4918 9.30 42 8 15 4/8/15 5.6 31/23118/1314/3 2 1.9 92.0 0.3 0.40 9.2 1.0 0.15/1.20 50 400 0.3 Drill 8.5" 19-Apr 5620 9.30 45 12 15 3/8/14 5.8 39/27/22/15/413 1 1.9 92.0 0.5 0.30 9.2 3.0 0.10/1.60 50 400 0.3 Drill 8.5" 20-Apr 7371 9.50 47 17 15 5/15/19 5.0 49/35125/17/413 1 5.1 90.0 0.5 0.80 9.2 7.5 0.20/1.20 49 280 5.1 Drill 8.5" 21-Apr 9190 9.90 45 17 13 4/18/26 6.4 47/30122/14/413 2 7.7 87.0 0.5 0.40 8.2 10.5 0.05/1.00 50 480 7.1 Drill 8.5" 22-Apr 10680 11.00 40 13 9 5/18/- 6.8 35122/16/11/4/3 2 11.8 83.0 0.5 0.20 8.7 8.0 0.10/0.80 51 320 7.0 Drill 8.5" 23-Apr 11242 11.30 44 15 10 6/18/- 4.8 40/25/19/12/4/3 2 13.5 81.0 0.5 0.10 8.2 10.0 0.05/1.20 49 480 7.9 POOH 24-Apr 11242 11.30 50 15 15 1 0/26/- 7.6 45130/25/16/8/7 2 14.6 80.0 0.5 0.10 8.2 11.0 -/1.20 48 400 10.0 POOH 25-Apr 11242 11.30 46 12 16 16/30/- 8.8 40128/2311719/8 2 14.5 80.0 0.5 0.10 7.6 11.0 -/2.40 49 680 10.0 RIH 26-Apr 11242 11.30 53 15 13 10/24/- 6.6 43/28/21/14/5/4 2 13.6 81.0 0.3 0.20 7.8 5.0 -/1.20 48 560 4.9 RIH & ream 27 -Apr 11242 11.30 53 14 12 9/24/- 6.8 40/28/21/14/5/4 2 13.7 81.0 0.1 7.7 5 -/1.00 46 560 8.2 Run MBT 100 I I I I I I sperry-sun DRILLING SERVICES Show Report Well Name: Location: Depth (MD) (TVD) DatelTime: (ppm) - Depth ppm ppm ppm (Steam Still PPM's in 100Q's) Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 ppm ppm ppm (Steam Still PPM's in 1000's) 1000.0 NPH ------~~~_..~~- 100.0 (ppm) " Gas Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 10.0 Oil NPH 1.0 Hydrocarbon Ratios ppm ppm ppm (Steam Still PPM's in 1000's) C1 '" C2 '" C3 '" C4 '" Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 1000.0 NPH .. .' ... 100.0 Non-Producible Hydrocarbons Gas " _.-- ' ----- _......- ppm ppm ppm (Steam Stili PPM's in 1000's) C1 C2 C3 C4 C5 Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 '" '" '" '" '" 10.0 Oil >"-'-~-.~ NPH 1.0 I I I I I I I I I I I I I I I I I I I I Halliburton Global Start Date: Engineer: Tied-to: I Field: , Map System:US State Plane Coordinate System 1927 I Geo Datum: NAD27 (Clarke 1866) , Sys Datum: Mean Sea Level Ataruq Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 Site: Ataruq Site Position: Northing: 5969528.36 ft Latitude: 70 19 40.485 N From: Map Easting: 480716.30 ft Longitude: 150 9 23.000 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: -0.15 deg ¡Well: Ataruq #2 Slot Name: I Well Position: +N/-S 0.00 ft Northing: 5969528.36 ft Latitude: 70 19 40.485 N +E/-W 0.00 ft Easting : 480716.30 ft Longitude: 150 9 23.000 W Position Uncertainty: 0.00 ft Wellpath: Ataruq #2A Drilled From: Ataruq #2 501032050801 Tie-on Depth: 3280.35 ft Current Datum: Ataruq#2: Height 102.62 ft Above System Datum: Mean Sea Level Magnetic Data: 4/16/2005 Declination: 24.06 deg Field Strength: 57569 nT Mag Dip Angle: 80.70 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.42 0.00 0.00 310.36 I I I I 1 ~ ~ -~-~-_.- I Survey Program for Definitive Wellpath Date: 5/2/2005 Validated: Yes Actual From To Survey ft ft 146.15 3280.35 3320.00 11212.07 Version: Toolcode Tool Name MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Ataruq #2 (146.15-7330.84) (0) Ataruq #2A (3320.00-11212.07) Survey MD lncl Azim TVD ft deg deg ft ft 30.42 0.00 0.00 30.42 -72.20 0.00 0.00 5969528.36 480716.30 TIE LINE 146.15 0.71 218.66 146.15 43.53 -0.56 -0.45 5969527.80 480715.85 MWD+IFR-AK-CAZ-SC 239.04 0.67 226.67 239.03 136.41 -1.38 -1.20 5969526.98 480715.09 MWD+IFR-AK-CAZ-SC 333.82 0.57 226.04 333.80 231.18 -2.09 -1.94 5969526.28 480714.35 MWD+IFR-AK-CAZ-SC 422.06 0.71 216.14 422.04 319.42 -2.84 -2.58 5969525.53 480713.71 MWD+IFR-AK-CAZ-SC 514.99 0.84 219.97 514.96 412.34 -3.82 -3.36 5969524.55 480712.93 MWD+IFR-AK-CAZ-SC 601.09 0.82 218.11 601.05 498.43 -4.79 -4.15 5969523.58 480712.14 MWD+ IFR-AK-CAZ -SC 692.39 0.79 224.71 692.34 589.72 -5.75 -4.99 5969522.62 480711.29 MWD+IFR-AK-CAZ-SC 782.96 0.76 222.52 782.90 680.28 -6.64 -5.84 5969521.74 480710.45 MWD+IFR-AK-CAZ-SC 874.53 1.05 218.98 874.46 771.84 -7.74 -6.78 5969520.64 480709.51 MWD+IFR-AK-CAZ-SC 960.01 1.25 227.98 959.93 857.31 -8.97 -7.96 5969519.41 480708.32 MWD+IFR-AK-CAZ-SC 1052.85 1.31 230.94 1052.74 950.12 -10.32 -9.54 5969518.07 480706.74 MWD+IFR-AK-CAZ-SC 1148.98 1.59 226.51 1148.84 1046.22 -11.93 -11.36 5969516.46 480704.91 MWD+IFR-AK-CAZ-SC 1242.78 1.79 225.50 1242.60 1139.98 -13.85 -13.35 5969514.54 480702.92 MWD+IFR-AK-CAZ-SC 1336.85 1.54 215.21 1336.63 1234.01 -15.91 -15.12 5969512.49 480701.14 MWD+IFR-AK-CAZ-SC 1432.68 2.07 230.01 1432.41 1329.79 -18.08 -17.19 5969510.33 480699.06 MWD+IFR-AK-CAZ-SC 1526.01 2.15 228.27 1525.68 1423.06 -20.33 -19.79 5969508.09 480696.46 MWD+IFR-AK-CAZ-SC 1623.58 2.30 228.58 1623.18 1520.56 -22.84 -22.62 5969505.58 480693.62 MWD+IFR-AK-CAZ-SC I Halliburton I Global I Well: N¥¢llpath: I Survey loci Azim TVD deg deg ft 1717.97 2.22 226.51 1717.49 1614.87 -25.35 -25.37 5969503.08 480690.87 MWD+IFR-AK-CAZ-SC I 1812.84 1.97 338.01 1812.33 1709.71 -25.10 -27.32 5969503.33 480688.92 MWD+IFR-AK-CAZ-SC 1906.46 7.53 7.49 1905.60 1802.98 -17.52 -27.12 5969510.91 480689.14 MWD+IFR-AK-CAZ -SC 1999.86 11.39 7.85 1997.71 1895.09 -2.31 -25.06 5969526.11 480691.24 MWD+IFR-AK-CAZ-SC 2094.43 14.30 10.37 2089.91 1987.29 18.43 -21.68 5969546.84 480694.67 MWD+IFR-AK-CAZ-SC I 2186.87 17.37 12.54 2178.83 2076.21 43.14 -16.63 5969571.53 480699.78 MWD+IFR-AK-CÄZ-SC 2281.99 20.98 13.42 2268.66 2166.04 73.57 -9.59 5969601.95 480706.90 MWD+IFR-AK-CAZ-SC 2375.23 24.25 15.03 2354.72 2252.10 108.31 -0.75 5969636.66 480715.83 MWD+IFR-AK-CAZ-SC I 2470.04 29.20 15.70 2439.37 2336.75 149.40 10.56 5969677.72 480727.25 MWD+IFR-AK-CAZ-SC 2565.28 33.53 14.18 2520.68 2418.06 197.29 23.30 5969725.57 480740.11 MWD+IFR-AK-CAZ-SC 2659.74 37.99 11.91 2597.31 2494.69 251.06 35.70 5969779.30 480752.64 MWD+IFR-AK-CAZ-SC 2755.83 42.17 1113 2670.82 2568.20 311.67 48.03 5969839.88 480765.13 MWD+IFR-AK-CAZ-SC I 2849.43 45.63 10.99 2738.25 2635.63 375.36 60.48 5969903.53 480777.74 MWD+IFR-AK-CAZ-SC 2944.67 45.33 9.47 2805.03 2702.41 442.18 72.54 5969970.31 480789.97 MWD+IFR-AK-CAZ -SC 3036.21 45.15 7.77 2869.49 2766.87 506.44 82.28 5970034.54 480799.88 MWD+IFR-AK-CAZ-SC 3132.07 44.16 7.62 2937.68 2835.06 573.21 91.31 5970101.28 480809.07 MWD+IFR-AK-CAZ-SC 3227.17 42.34 6.67 3006.95 2904.33 637.86 99.42 5970165.90 480817.35 MWD+IFR-AK-CAZ-SC I 3280.35 42.13 5.85 3046.32 2943.70 673.39 103.32 5970201.42 480821.34 MWD+IFR-AK-CAZ-SC 3320.00 42.14 5.70 3075.73 2973.11 699.86 105.99 5970227.87 480824.08 MWD+IFR-AK-CAZ-SC 3423.42 44.15 0.15 3151.21 3048.59 770.43 109.54 5970298.43 480827.80 MWD+IFR-AK-CAZ -SC 3517.97 44.33 355.00 3218.97 3116.35 836.29 106.74 5970364.29 480825.18 MWD+IFR-AK-CAZ-SC I 3612.72 44.82 349.89 3286.48 3183.86 902.17 97.99 5970430.18 480816.60 MWD+IFR-AK-CAZ -SC 3705.48 44.91 345.18 3352.25 3249.63 966.02 83.87 5970494.07 480802.65 MWD+IFR-AK-CAZ -SC 3800.95 46.58 340.06 3418.89 3316.27 1031.22 63.42 5970559.31 480782.36 MWD+IFR-AK-CAZ-SC I 3893.75 49.20 337.67 3481.12 3378.50 1095.41 38.58 5970623.56 480757.69 MWD+IFR-AK-CAZ-SC 3989.12 51.83 332.22 3541.78 3439.16 1162.01 7.37 5970690.23 480726.65 MWD+IFR-AK-CAZ-SC 4084.04 53.32 328.46 3599.48 3496.86 1227.48 -29.94 5970755.79 480689.52 MWD+IFR-AK-CAZ-SC 4179.15 55.98 324.58 3654.52 3551.90 1292.14 -72.75 5970820.55 480646.87 MWD+IFR-AK-CAZ-SC I 4273.66 59.32 321 .27 3705.09 3602.4 7 1355.79 -120.90 5970884.32 480598.89 MWD+IFR-AK-CAZ-SC 4368.10 61.12 317.43 3752.01 3649.39 1417.94 -174.30 5970946.60 480545.66 MWD+IFR-AK-CAZ-SC 4461.00 63.30 314.95 3795.32 3692.70 1477.23 -231.20 5971006.03 480488.92 MWD+IFR-AK-CAZ-SC 4556.14 65.97 310.73 3836.09 3733.4 7 1535.63 -294.24 5971064.59 480426.04 MWD+IFR-AK-CAZ-SC I 4651.06 68.41 308.81 3872.89 3770.27 1591.59 -361.49 5971120.71 480358.94 MWD+IFR-AK-CAZ-SC 4745.29 70.70 304.85 3905.81 3803.19 1644.48 -432.15 5971173.78 480288.42 MWD+IFR-AK-CAZ-SC 4840.13 74.57 301.63 3934.12 3831.50 1694.06 -507.85 5971223.55 480212.86 MWD+IFR-AK-CAZ-SC 4932.35 76.30 301.06 3957.31 3854.69 1740.48 -584.07 5971270.17 480136.76 MWD+IFR-AK-CAZ-SC I 4987.24 76.35 303.43 3970.29 3867.67 1768.94 -629.18 5971298.73 480091.73 MWD+IFR-AK-CAZ-SC 5080.05 76.14 303.14 3992.36 3889.74 1818.41 -704.54 5971348.39 480016.51 MWD+IFR-AK-CAZ -SC 5173.29 77.07 302.88 4013.96 3911.34 1867.82 -780.60 5971398.00 479940.58 MWD+IFR-AK-CAZ -SC 5267.34 77.34 302.46 4034.79 3932.17 1917.33 -857.80 5971447.70 479863.51 MWD+IFR-AK-CAZ-SC I 5360.54 77.15 301.81 4055.36 3952.74 1965.68 -934.78 5971496.24 479786.67 MWD+IFR-AK-CAZ-SC 5456.84 76.59 300.98 4077.24 3974.62 2014.54 -1014.83 5971545.30 479706.75 MWD+IFR-AK-CAZ-SC 5549.58 76.26 301.24 4099.01 3996.39 2061.11 -1092.01 5971592.07 479629.70 MWD+IFR-AK-CAZ-SC 5647.31 75.94 300.54 4122.48 4019.86 2109.82 -1173.42 5971640.98 479548.42 MWD+IFR-AK-CAZ -SC I 5739.02 75.47 300.74 4145.13 4042.51 2155.11 -1249.88 5971686.46 479472.08 MWD+IFR-AK-CAZ-SC 5832.00 76.92 301.15 4167.32 4064.70 2201.54 -1327.32 5971733.09 479394.77 MWD+IFR-AK-CAZ-SC 5926.41 76.87 301.37 4188.72 4086.10 2249.26 -1405.93 5971781.00 479316.30 MWD+IFR-AK-CAZ-SC I 6021.67 76.45 299.89 4210.70 4108.08 2296.48 -1485.68 5971828.42 479236.68 MWD+IFR-AK-CAZ-SC 6116.76 75.96 299.01 4233.38 4130.76 2341.88 -1566.09 5971874.03 479156.39 MWD+IFR-AK-CAZ-SC 6209.62 76.51 298.54 4255.4 7 4152.85 2385.30 -1645.15 5971917.64 479077.45 MWD+IFR-AK-CAZ-SC 6301.47 77.01 298.67 4276.51 4173.89 2428.11 -1723.64 5971960.65 478999.07 MWD+IFR-AK-CAZ-SC 6396.84 76.45 298.42 4298.40 4195.78 2472.46 -1805.18 5972005.21 478917.66 MWD+IFR-AK-CAZ-SC I I I Halliburton I Global I I Survey luel deg ft 6490.52 76.45 298.87 4320.35 4217.73 2516.12 -1885.11 5972049.07 478837.85 MWD+IFR-AK-CAZ-SC I 6582.82 76.68 300.06 4341.79 4239.17 2560.28 -1963.27 5972093.42 478759.81 MWD+IFR-AK-CAZ-SC 6676.63 75.96 300.39 4363.98 4261.36 2606.16 -2042.03 5972139.50 478681.18 MWD+IFR-AK-CAZ-SC 6771.49 75.41 300.67 4387.43 4284.81 2652.85 -2121.20 5972186.39 478602.14 MWD+IFR-AK-CAZ-SC 686759 76.24 300.32 4410.97 4308.35 2700.13 -2201.48 5972233.87 478521.98 MWD+IFR-AK-CAZ-SC I 6963.02 76.58 301.22 4433.39 4330.77 2747.59 -2281.18 5972281.53 478442.41 MWD+IFR-AK-CAZ-SC 7057.67 76.27 301.03 4455.61 4352.99 2795.15 -2359.94 5972329.28 478363.78 MWD+IFR-AK-CAZ-SC 7153.03 77.81 299.52 4476.99 4374.37 2841.99 -2440.20 5972376.33 478283.66 MWD+IFR-AK-CAZ-SC 7247.33 77.22 299.93 4497.38 4394.76 2887.64 -2520.15 5972422.18 478203.83 MWD+IFR-AK-CAZ-SC I 7341.78 75.62 301.20 4519.56 4416.94 2934.32 -2599.20 5972469.06 478124.91 MWD+IFR-AK-CAZ-SC 7435.08 75.81 301.40 4542.58 4439.96 2981.30 -2676.46 5972516.23 478047.78 MWD+IFR-AK-CAZ-SC 7529.15 77.08 302.23 4564.63 4462.01 3029.51 -2754.16 5972564.63 477970.21 MWD+IFR-AK-CAZ-SC 7622.54 76.15 301.95 4586.25 4483.63 3077.77 -2831.13 5972613.09 477893.37 MWD+IFR-AK-CAZ-SC I 7717.01 75.82 301.95 4609.12 4506.50 3126.28 -2908.91 5972661.79 477815.73 MWD+IFR-AK-CAZ-SC 7809.39 76.13 302.72 4631.51 4528.89 3174.21 -2984.63 5972709.92 477740.13 MWD+IFR-AK-CAZ-SC 7904.35 76.44 302.36 4654.03 4551.41 3223.84 -3062.40 5972759.73 477662.50 MWD+IFR-AK-CAZ-SC 7997.65 76.41 302.75 4675.93 4573.31 3272.64 -3138.85 5972808.73 477586.19 MWD+IFR-AK-CAZ-SC I 8093.60 75.75 302.47 4699.01 4596.39 3322.83 -3217.30 5972859.12 477507.87 MWD+IFR-AK-CAZ-SC 8187.41 75.45 302.63 4722.34 4619.72 3371.72 -3293.89 5972908.19 477431.42 MWD+IFR-AK-CAZ-SC 8283.45 75.08 301.59 4746.77 4644.15 3421.09 -3372.56 5972957.76 477352.88 MWD+IFR-AK-CAZ-SC 8378.52 76.17 300.17 4770.37 4667.75 3468.35 -3451.60 5973005.22 477273.97 MWD+IFR-AK-CAZ-SC I 8474.23 75.86 300.32 4793.50 4690.88 3515.13 -3531.83 5973052.20 477193.87 MWD+IFR-AK-CAZ-SC 8569.14 76.61 299.40 4816.08 4713.46 3561.02 -3611.77 5973098.30 477114.05 MWD+IFR-AK-CAZ-SC 8663.75 77.97 299.05 4836.90 4734.28 3606.08 -3692.31 5973143.56 477033.63 MWD+IFR-AK-CAZ-SC 8758.49 77.33 299.18 4857.16 4754.54 3651.11 -3773.17 5973188.79 476952.90 MWD+IFR-AK-CAZ-SC I 8851.55 76.90 298.38 4877.91 4775.29 3694.79 -3852.68 5973232.67 476873.51 MWD+IFR-AK-CAZ-SC 8946.35 76.81 298.96 4899.4 7 4796.85 3739.08 -3933.67 5973277 .16 476792.64 MWD+IFR-AK-CAZ-SC 9039.83 77.32 299.43 4920.40 4817.78 3783.52 -4013.21 5973321.80 476713.23 MWD+IFR-AK-CAZ-SC 9135.33 77.98 299.86 4940.82 4838.20 3829.66 -4094.29 5973368.15 476632.28 MWD+IFR-AK-CAZ-SC I 9225.16 76.76 300.62 4960.47 4857.85 3873.80 -4170.01 5973412.48 476556.67 MWD+IFR-AK-CAZ-SC 9320.29 75.93 300.85 4982.92 4880.30 3921.05 -4249.4 7 5973459.93 476477.34 MWD+IFR-AK-CAZ-SC 9413.91 75.36 301.80 5006.13 4903.51 3968.20 -4326.94 5973507.27 476400.00 MWD+IFR-AK-CAZ-SC 9508.78 75.83 302.44 5029.74 4927.12 4017.05 -4404.77 5973556.32 476322.31 MWD+IFR-AK-CAZ-SC I 9603.90 75.98 302.84 5052.90 4950.28 4066.81 -4482.45 5973606.28 476244.76 MWD+IFR-AK-CAZ-SC 9699.48 74.17 302.78 5077.52 4974.90 4116.86 -4560.07 5973656.51 476167.28 MWD+IFR-AK-CAZ-SC 979422 71.57 302.66 5105.42 5002.80 4165.79 -4636.24 5973705.64 476091.25 MWD+IFR-AK-CAZ-SC I 9889.02 67.81 301.07 5138.32 5035.70 4212.73 -4711.72 5973752.76 476015.89 MWD+IFR-AK-CAZ-SC 9982.43 63.46 299.39 5176.85 5074.23 4255.57 -478521 5973795.80 475942.52 MWD+IFR-AK-CAZ-SC 10075.49 59.50 299.28 5221.27 5118.65 4295.63 -4856.47 5973836.03 475871.37 MWD+IFR-AK-CAZ-SC 10169.72 55.73 299.13 5271.73 5169.11 4334.45 -4925.92 5973875.02 475802.03 MWD+IFR-AK-CAZ-SC I 10265.71 51.54 298.70 5328.64 5226.02 4371.82 -4993.56 5973912.56 475734.49 MWD+IFR-AK-CAZ-SC 10360.17 47.70 298.16 5389.82 5287.20 4406.08 -5056.82 5973946.98 475671.32 MWD+IFR-AK-CAZ-SC 10455.69 43.02 298.67 5456.92 5354.30 4438.40 -5116.59 5973979.46 475611.64 MWD+IFR-AK-CAZ-SC 10551.30 38.91 299.65 5529.10 5426.48 4468.92 -5171.32 5974010.11 475556.99 MWD+IFR-AK-CAZ-SC 10646.54 34.71 301.23 5605.34 5502.72 4497.79 -5220.53 5974039.10 475507.87 MWD+IFR-AK-CAZ-SC I 10740.50 30.22 300.64 5684.59 5581.97 4523.72 -5263.77 5974065.14 475464.70 MWD+IFR-AK-CAZ-SC 10835.71 27.88 300.27 5767.82 5665.20 4547.16 -5303.62 5974088.68 475424.92 MWD+IFR-AK-CAZ-SC 10932.04 27.17 298.64 5853.25 5750.63 4569.05 -5342.37 5974110.67 475386.22 MWD+IFR-AK-CAZ-SC I 11026.12 26.92 299.30 5937.04 5834.42 4589.77 -5379.80 5974131.48 475348.85 MWD+IFR-AK-CAZ-SC 11120.86 24.00 301.79 6022.57 5919.95 4610.42 -5414.88 5974152.22 475313.82 MWD+IFR-AK-CAZ-SC 11212.07 21.68 301.86 6106.63 6004.01 4629.09 -5444.96 5974170.97 475283.79 MWD+IFR-AK-CAZ-SC 11242.00 21.68 301.86 6134.44 6031.82 4634.92 -5454.36 5974176.83 475274.42 PROJECTED to TD I I I I I 1000 2000 I J: +-' c.. (!) o 3000 ro u 1:: (!) > I I 4000 I ¢: 5000 0 0 0 .,- II ..c (.) .5 .,- (¡) 6000 1š en OrmQuest 3.03.06.008 Services Scale: 1 inch:::: 1000ft -5000 Eastings -3000 -2000 o -4000 -1 000 o Well: Current Well Properties Ataruq #2 Horizontal Coordinates: Ref. Global Coordinates: Ref. 477' FNL, 1 í;34,6' FI':L : Ref. Geographical Coordinates: RKB Elevation: 5969528.36 N, 480716.30 E 0.36 N, 0.30 E 70' 19' 40.4852" N, 150' 09' 22.9997" W 102.85ft above Mean Sea Level North Reference : Units: True North Feet (US Survey) The "Directional Difficulty Index" for this profile is 6.0 o 1000 Vertical Section 2000 3000 4000 Section Azimuth: 6.940" (True North) 4000 3000 I I I ~-