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204-260
THE STATE °fALASKA July 24, 2019 GOVERNOR MIKE DUNLEAVY Ms. Lindsay Wright SEQ Specialist and Land Technician ENI US Operating Co Inc 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503-5818 Re: Location Clearance Rock Flour #2 (PTD 2061660) Rock Flour #3 (PTD 2070050) Maggiore #1 (PTD 2070060) Nikaitchuq #1 (PTD 2040180) Nikaitchuq #2 (PTD 2040380) Nikaitchuq #3 (PTD 2042600) Nikaitchuq #4 (PTD 2050010) Dear Ms. Wright: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.aloska.gov Eni US Operating Company Inc. (Eni) has requested guidance regarding the final site clearances for seven exploration wells located on its leases. The seven referenced wells are listed above. All seven wells have been plugged and abandoned in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) regulations and the approved sundry applications. The AOGCC approves the location clearances for these seven wells. The Maggiore #1, Rock Flour 42 and Rock Flour #3 well sites were initially inspected by the AOGCC on July 12, 2007. Due to debris left at the sites, final location clearances were not issued at that time. The sites were subsequently cleaned by Eni between August 1, 2010 and August 3, 2010. Photographs of these three well locations taken during the inspections and a closeout report were provided to AOGCC on October 1, 2010 and October 11, 2010, respectively. After a thorough review, these onshore well sites were found to be in compliance with location clearance requirements as stated in 20 AAC 25.170. By email dated July 2, 2008, the AOGCC responded to requests from the prior operator (Kerr- McGee) and the State of Alaska Department of Environmental Conservation concerning the status of the four offshore Nikaitchuq wells. The AOGCC responded that the wells were plugged and abandoned as required by AOGCC regulation 20 AAC 25.112 and offshore location clearance requirements as stated in 20 AAC 25.172. The AOGCC requires no further work on the subject wells or locations at this time. However, Eni remains liable if any problems occur with these wells in the future. Sincerely, '?"AtZ"'dL� Jessie L. Chmielowski Commissioner 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 6 ~-" ~~ D ~.. _.... _ ~.. _ ~. _. _. n, r , 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 Laurie, et aE, As requested, l 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 204-018 204-038 204-249 205-025 204- 205-001 205-039 205-056 Nikaitchuq #1 Nikaitchuq #2 Tuvaag State #1 Kigun #1 (redrill of Tuvaaq State #1) Nikaitchuq #4 Nikaitchuq #3 Ataruq #2' Ataruq #2A (redrill of Ataruq #2) ~~P~Ep JUL ~ 2008 Based. on the file 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 (welt 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: iaurie.silfven@alaska.gov 7/2/2008 ~ l M-~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2042600 MD 7577 / Well Name/No. NIKAITCHUQ 4 Operator KERR-MCGEE OIL & GAS CORP TVD 4186 /' Completion Date 4/21/2005 Completion Status P&A REQUIRED INFORMATION Mud Log Yes Samples No DATA INFORMATION Types Electric or Other Logs Run: See 10-407 Well Log Information: Log/ Data Digital Typy'Me_d/Frmt ~ C Pds ~. .fi; ~g C Dls ...log (ÁOg vLog .Æog iLoy Log / )..sJg ...rOg :r i Log Log Electr Dataset Number Name - 13092 Induction/Resistivity Log Log Scale Media Run No 1 13205 Induction/Resistivity Density 5 Col 13092 Induction/Resistivity 13092 Induction/Resistivity 2 Blu 5 Blu 13092 Induction/Resistivity 5 Blu 13092 Cement Evaluation 5 Blu 4 Mud Log 2 Col 13102 Mud Log 5 Col 13102 Mud Log 2 Col 13102 Mud Log 5 Col 13102 Mud Log 5 Col 13102 Mud Log 2 Col 13102 Mud Log 2 Col Current Status P&A S.f~ J.. r=J J.-0..ö ç- API No. 50-629-23241-00-00 UIC N --~ Directional surve~ (data taken from Logs Portion of Master Well Data Maint Interval Start Stop 2448 4294 215 7577 4850 7503 2448 4294 2448 4294 2448 4294 300 2430 215 4308 3910 4180 200 4300 4700 5000 5200 7560 200 7560 200 7600 e OH/ CH Received Comments Open 3/30/2005 RESISTIVITY/GRlSP/GR/S I ONICITWAlCALlPER/DEN I SITY/NEUTRON/CBLNDL- GRlGRAPHIC IMAGES ROP, DGR EWR CNP ALD Open 7/22/2005 Open 7/22/2005 Open 3/30/2005 Open 3/30/2005 Open 3/30/2005 Case 3/30/2005 Open 4/27/2005 Open 4/27/2005 Open 4/27/2005 Open 4/27/2005 Open 4/27/2005 Open 4/27/2005 Open 4/27/2005 ALD Image Dipsite Processing RESISTIVITY/GRlSP RESISTIVITY/GRlSONIC/R WAlCALlPER RESISTIVITYIDENSITY/N EUTRON/GRlSP/CALlPER I CEMENT BOND LOGNDL- : GR MD COMBINATION MUDLOG-PB1 MD COMBINATION SHOWLOG-PB 1/MWD MD ENGINEERING LOG- PB 1/ROP/LlTH MD COMBINATION SHOWLOG/MWD MD COMBINATION SHOWLOG/MWD MD COMBINATION SHOWLOG/MWD ENGINEERING LOG- MD/MWD -- DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2042600 Well Name/No. NIKAITCHUQ 4 Operator KERR-MCGEE OIL & GAS CORP API No. 50-629-23241-00-00 ~ 7577 TVD 4186 Completion Date 4/21/2005 Completion Status P&A Current Status P&A UIC N - 13102 Report: Final Well R 0 0 Open 4/27/2005 END OF WELL REPORT-4 ~C & 4PB1 Asc 13102 Report: Final Well R 0 0 Open 4/27/2005 END OF WELL REPORT-4 & 4PB1 ø 13125 See Notes 0 0 Open 6/27/2005 Core Analysis Data Final ~ Report by CoreLab 13125 See Notes 0 0 Case 6/27/2005 Core Analysis Data Final Report by CoreLab e L.p~r 13124 I nd uction/Resistivity 5 Blu 1-3 215 4310 Open 5/28/2005 ROP, DGR, EWR, MRIL~i$ , /' WD, TEMP {/(og 13124 Induction/Resistivity M L)þ ì) 2 Blu 1-3 215 7577 Open 5/28/2005 ROP, DGR, EWR, MRIL- WD VLog 13124 I nd uction/Resistivity {Yf Djrvb 5 Blu 1-3 215 7577 Open 5/28/2005 ROP, DGR, EWR, MRIL- WD ~"C Las 13124 I nd uction/Resistivity PI:? ( 1-3 215 7577 Open 5/28/2005 ROP, DGR, EWR, MRIL- WD ~ Report: Final Well R 0 0 Open 6/1/2005 End of Well Report Nikaitchuq 4 & 4 PB1. ..ßð C Wrd Report: Final Well R 0 0 Open 6/1/2005 End of Well Report Nikaitchuq 4 & 4 PB1. U69 13142 See Notes 2 Col 200 4300 Open 6/1/2005 Engineering Log PB 1 (Y69 13142 See Notes 2 Col 200 7577 Open 6/1/2005 Engineering Log 'JP9 13142 See Notes 5 Blu 1-3 215 4310 Open 6/1/2005 Combination Showlog f() f cJ..og 13142 Mud Log 2 Blu 1-3 215 4310 Open 6/1/2005 combination mud log ¡!J n ( e -I:og 13142 Mud Log 2 Blu 1-3 215 4310 Open 6/1/2005 combination mud log P¡)' ~6g 13142 See Notes 5 Blu 1-3 215 7577 Open 6/1/2005 Combination Showlog .,.k6g M.D i./J?r I nd uction/Resistivity 2 Col 215 ~ Open 7/22/2005 ROP DGR EWR CNP ALD ì Ìí f') >î ...cog I nd uction/Resistivity 2 Col 215 JMfr Open 7/22/2005 ROP DGR EWR CNP ALD i~g Induction/Resistivity 5 Col TVb 215 7577 Open 7/22/2005 ROP DGR EWR CNP ALD .fLog I nd u ction/Resistivity 5 Col (}À..t) 215 7577 Open 7/22/2005 ROP DGR EWR CNP ALD it D Asc Directional Survey 2842 7577 Open 9/26/2005 IIFR Directional Survey 2842 7577 Open 9/26/2005 IIFR ¿Z. D Asc Directional Survey 30 4310 Open 9/26/2005 PB 1 IIFR Directional Survey 30 4310 Open 9/26/2005 PB 1 IIFR Permit to Drill 2042600 DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Well Name/No. NIKAITCHUQ 4 MD 7577 TVD 4186 Well Cores/Samples Information: Name i-----~ttingS i L__~~ ADDITIONAL INFORM!'"9", N Well Cored? ~ Chips Received? ~ ~ Analysis Received? Comments: ~._~--,_..._----_.~._.._-._- ~~._--,-------- Compliance Reviewed By: ~~______ Completion Date 4/21/2005 ~ Interval Start Stop ----- 2900 7577 Operator KERR-MCGEE OIL & GAS CORP Completion Status P&A Sent Received Daily History Received? Formation Tops -~----_._-- API No. 50-629-23241-00-00 Current Status P&A UIC N Sample Set Number Comments 1150 Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 1/20/2005. cy.N @N - Date: ;)7- ~Å)Ð7 - · ~ 21-Sep-05 Alaska Oil & Gas Conservation Commission 333 W. th Ave., Suite 100 Anchorage, AK 99510 DEFINITIVE Re: Distribution of Survey Data for Nikaitchuq #4 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: 2,842.58 I MD 2,863.00 'MD (if applicable) 7,577.00 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 Â~¥~~\ ~ rdl J Signed (Jþ1 Please call me at 273-354 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager /-Ot(-Â6d . . 21-Sep-05 Alaska Oil & Gas Conservation Commission 333 W. ih Ave., Suite 100 Anchorage, AK 99510 DEFINITIVE Re: Distribution of Survey Data for Nikaitchuq #4PB1 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: 30.06 I MD N/A 'MD (if applicable) 4,310.00 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. :;:h0;:Z~,~ /1/ ~ II/I / Signed ~{)f.JtvJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager 'Â~ ~,v ~ (vJ . . WELL LOG TRANSMITTAL To: Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian July 22, 2005 RE: MWD Formation Evaluation Logs - Kerr-McGee Nikaitchuq #4 AK-MW-0003523133 API #: 50-629-23241-00-00 Nikaitchuq #4: 2" MD Triple Combo Logs: o 2 Color Prints 5" MD Triple Combo Logs: 2 Color Prints ;)."""b vv'(1ì S ~ò"e~~~L 2" TVD Triple Combo Logs: 2 Color Prints 5" TVD Triple Combo Logs: 2 Color Prints 2"/5" MD ALD Image & Dip Pick Logs: 2 Color Prints CD ROM Disk with graphic images of above logs, and LAS/DLIS LWD data 1 Disk # J J Àt);- "¡.c~'7·'- ?ï 11 )1)~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATIACHED COPIES OF THE TRANSMTITAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Fax: (907) 273-3535 Date: I ~.~ \- 1/ n 'ìj J () Signed: ti~- O)Jv~ ') G~-À~lJ r: l-t --~ STATE OF ALASKA;t i\/E D ALA~IL AND GAS CONSERVATION COM ON ,. . " ' ,', WELL COMPLETION OR RECOMPLETION R "PORT AND ¡'t~('Ø7 Z005 OilD GasD Plugged 0 AbandonedLj SuspendedD WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ExploratórÝŒJ No. of Completions Other Service 0 Stratigraphic TéstËl 5. Date Comp., Susp., or ,12. Permit to Drill Number: Kerr McGee Oil & Gas Corporation Aband.: 4/2~005 204-260 3. Address: 6. Date Spudded: 13. API Number: 3900 C Street, Suite 744, Anchorage, AK 99503 2/2/05 / 50-629-23241-00 4a. Location of Well (Governmental Section): 6fIJ :1' 7. Date TD Reached: 14. Well Name and Number: Surface: 350' FSL & 1460' FWL, See 16, T14N,~, UM ,... ... 2/19/05 NIKAITCHUQ #4 Top of Productive Horizon: @ 4648'MD, 4107' TVD ~ 8)<8 Elevation (ft): 15. Field/Pool(s): x::: 518924 Y:::6055522 in Schraeder OA Sand lV rþ 31.26 ft Total Depth: 7,577' MD; 4,185' TVD in Schraeder Interval. ft~ J .~tt 9. ,P,IU9 Back D epth(MD+ TVD): Exploration X::: 517398; Y::: 6054833 in SChraede~lnterv ,\I'" V ,!:J/A 4b. Location of Well (State Base Plane Coordinates): J~1d~!jI,.D~ (MD + TVD):, 16. Property Designation: Surface: x- 519,642 E - y- 6,054,828 ' Zone- r1~D /4,186' TVD ADL 388582 & 388583 TPI: 4103'TVD x- 518856 E y- 6055584 N ~~ OA Horiz. 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 517398 Ey- 6057999 N B'- OA Horiz. n/a 18. Directional Survey: Yes 0 No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 1710' MD /1710' TVD Surface hole: MWD Directional/Cassandra Surveys; LWD Gr/Res. Intermediate Hole: MWD Directional/Cassandra Surveys; LWD Triple Combo. Production Hole: MWD Directional Cassandra Surveys; LWD Triple Combo. ; Original Hole E-Line. Run #1 Triple Combo on Wireline. Run # 2 FMIICBUDSI. Run #3 CBLNDL. ... 1a. Well Status: GINJD WINJD WDSPLD 2. Operator Name: 21. Logs Run: 22. CASING, LINER AND CEMENTING RECORD 'NT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 68# L-80 31' MD 133' MD 31' TVD 133' TVD Drive Pipe n/a 9-5/8" 40# L-80 31' MD 2,457' MD 31' TVD 2,457' TVD 12-1/4" 520 sx Permafrost L (385 bbl) 0' & 300 sx G (60 bbl) 7" 26# L-80 31' MD 4851' MD 31' TVD 4,145' TVD 8-1/2" 59.8 Bbls Cement @15.8ppg with 290 sxs "G" cement. 3-1/2" 9.2# L-80 4,672 MD 7,567' TVD 4145' TVD 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): SHORT TERM PRODUCTION TEST WITH SLOTTED LINER RUN IN OPEN HOLE AND ESP RUN ON TUBING 4186' TVD 24. 6/1/2002 SLOTTED LINER/NO CEMEN- TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 4500' SIZE 2-7/8" 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED nla 26. Date First Production: PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Oil-Bbl: 3/11/2005 24 Test Period", 660 Flow Tubing Casing Press: Calculated Oil-Bbl: Press. 89# 89# 24-Hour Rate ... 660 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". Well was whole cored from 4120' MD to 4180' MD with 58 feet of recovery. SEE GEOLOGICAL REPORT FOR DETAILS ON LITHOLOGY. Gas-MCF: 60 Gas-MCF: 60 Water-Bbl: Choke Size: I Gas-Oil Ratio: n/a 91 Oil Gravity - API (corr): 17 o Water-Bbl: nla .',!6·".·,.·_''''':---··~1 J sr.¡'"",'\¡;n! ¡;::>rWifl \ f ,....f{<;J'·'c....LI.><.·d.. t DATE ~, ~ µL~?.51 ". "'-'rn,' \ \~"..,."." .. ! ¡.,-,) ,."..-." .~ t:::.= . _ '::~.=:.:'::J 11 ¡: BFl JUN 072005 rc..1I1I 10-407 R6v;"êd 12/2'003 OOr~TINU[D ON RCV[R~[ NAME GEOLOGIC MARKE. TVD 29. FORMATION TESTS Include and briefly su.ze test results. List intervals tested, and attach detailed supporting da. _ necessary. If no tests were conducted, state "None". ~8~ Base Permafrost BI Prince Creek T/ UGNU wp1 TI Schraeder Bluff TI Schraeder OA Base Lower OA Sand 1703' 2037' 3367' 4081' 4870' 5275' 1702' 2036' 3356' 3896'] 4155' 4165' THE SCHRAEDER OA SAND WAS TESTED WITH AN ESP. THE WELL TESTED AT A RATE OF 660 BOPD of 17 API OIL, Tr WTR, 60 MCFPD. PUMP WAS PULLED AND THE WELL ABANDONED. 30. List of Attachments: Final Well bore Diagram, Final Survey Report, Operations Daily Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: S. Coyner, 339-6269 Printed Name: Stuart Boggan Signature:¿ fJ ~ Title: Drilling Manager I Kerr McGee Oil & Gas Corp. Phone: (907) 339-6370 Date: 4/29/2005 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 / 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 Corrected Locations / 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 ?-- fJ '-/- Á~ò 1 of 1 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' "rAT,! Bï OK I 'Pï . ŒSmPlIa< ¡REV DAlE I BY lei APP I DESCRIPTION ....... .. ...........~..~n^'.~.._^M^^"~^^"^^"___~_^^^M.~"__~·_.··.. ........ _........".~..^~,_.-,......~^....,.,..-.............. ...... .. . ..... ..-........_"~^....^^<-"...¥~.........,~.......... ........ ... .m..... ....... ~_...~.~^......~....M·,,^...~^..~ ::0::0 CX>t!) rrtrrt 13 18 , , . . , , sPy ISLAND) 17 ! 16 I 15 Nikaitchuq-3 Nil<aitchuq-1 14 ::0::0 t!)-" rrtO rrt . . . _......._."u^;.M_~·_'^·~ 18 ~ mm ,....,. mm_m C;;'(\Om'¿~ o(\ò ~{o(\ \51 11.~ , ". m 24 ~;¡ø'f. .........._._..~_.............,..~- 21 Ni, aitchuq-2 ¡ ~ . 23 24 19 NIKAITCIiUQ #4 . '.. ....... .............. . ........ ...... '"' .....,..... ..y......~....."6~.Õ54:'82ã:-3Er~----"........ . .-..,,~" .". ."_n~._.~...."........._..... .... X = 519,64~.99 LAT = 70· ~3' 39.464" LONG = 14S· 50' 19.911" 351' F.S.L., h460' F.W.L. ~ PROTRACTED SECTION 16. ' T14N, R9E. UMIAT MERIDIAN i ,'.."" ""m mm 'm ,m---mrop-ormeONt5:m;;;'[3"',mmm_mmmm! (Lowest flohge on wellheadþ TOP OF ICE ,PAD = 1.2' ' 31 32 ,.·.=,.._,..".',,·..·._A~,',...'~"··_.... ........ .......... ........."..........".".,'""....-.. 25 27 ¡ SCALE: 11" = 1 Mile 25 30 28 26 .. .-........... ...... ............... ........... ...m.'''_.._·..-.M_M~'_''_,~'........ ..' ..----.-......_"...._....._..~ 36 NOTE: SHAPE AND CONFIGURATION OF SPY ISLAND IS FROM OLD MAPPING AND HAS BEEN ADJUSTED TO FIT THE LOCATION OF EXPLORATORY WEllS. THE ACTUAL CONFIGURATION OF THE ISLAND MAY VARY GREATLY FROM THAT SHOWN ON THIS DRAWING. 31 T14N T13N 4 3 2 o~ S 6 \ , Xl DEW rUNE .mm~' ~mm '"., -SIT[ r' --{ , '<'- 12 0 ~ .M....'._............_..n........ SURVEYOR'S CERTlFICA TE I HEREBY CERTlFY THA T I AM PROPERL Y REGISTERED AND LICENSED TO PRACTlCE LAND SURVEYING IN THE STA TE OF ALASKA AND THA T THIS PLA T REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THA T ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 25, 2005. ~"""""" ~~ C OF ..... ."ti ~ ~ ........... _... ,I ~ \ :........ ······t . 0 .... ...... t... . ... .. ~ :~! 49th ~~* , " . . ~ If .....:..... I ... I'" .... .... .··~····.I . ~ 1,........ ... .. ..... ........~ II":?:!~ :Q-iI , ~ \. L J. ROOKUS / ~: ,~ ú>. ....~-8;5 ....#.~ - \I> «}. " S.. .- '9: '~ I. (J.. ... ~ ' . .~... .' ~\) ,.- ..... F'£SSION/>.L \. ~.., ....,"',..~ NOTES: 1. Basis of Location: Mon. 3R South-2, by LH.D. & Assoc. 2. Coordinates Shown are A.S.P.. Zone 4. NAD 27. 3. Geographic Coordinates are NAD 27. 4. Elevations ore B.P.M.S.L. Datum. 5. Horizontal & Vertical Location Determined with Leica 500 Series GPS Units. using Geoid 96. 6. Dote of Survey: 2/25/05. F.B. L05-04, pp 52-53. ØJ, LOUNSBURY Ie ASSOCIATES. INC. SURVEYORS ENGINEERS PLANNERS ~ (I{'ID)KERR-UCGEE CORPORATION CADD FILE NO. LK601D597 I DRAWING NO: 2/25/05 NIKAITCHUQ #4 EXPLORATORY WELL CONDUCTOR AS-BUILT LOCATION NSK 6.01-d597 PART: 1 OF 1 REV: 0 - Surf Cut off casing below mudline - 500' 7" EZSV at 120' MD - 1000' Down-Squeeze the 7" Casing & "OA" Lateral - 1500' - 2000' Down-Squeezed 9-5/8" x 7" Annulus - 2500' 9~5/8", 40#, BTC-M 2457' MD / TVD - 3000' - 3500' Nikaitchuq #4 (Plugged and Abandoned) - 4000' ---------------------------. I - _.._.._........,... - - - - - - - _.._ _... - __I - 4500' OBM TMD A ND S Coyner 4/5/05 . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NIKAITCHUQ #4 NIKAITCHUQ #4 (ALASKA) DRILLING NORDIC NORDIC Start: 1/25/2005 Rig Release: Rig Number: 3 Spud Date: 2/112005 End: Group: 1/25/2005 06:00 - 06:00 24.00 01 MIRU THIS IS THE FIRST REPORT FOR NIKAITCHUQ #4 AND COVERS FROM 1/24/05 TO 1/26/05.133/8 CONDUCTOR STARTED MORNING OF 1/24 AND WAS SET @ 102' WITH A FINAL BLOW COUNT OF 86 PER FOOT. NIKAITCHUQ #3 WAS DIVEN TO A DEPTH OF 100' WITH A FINAL COUNT OF 66 BLOWS PER FOOT ON 1/25. NORDIC'S CAMPS WERE MOVED IN 1/25 SET AND BERMED IN. NORDIC'S RIG #3 BEGAN MOVING FROM 1Q PAD TOWARDS STAGING AREA AT ICE ROAD @ 02001/26, WHERE CELLAR DOORS AND PHILLIPS 66 SIGNS WILL BE REMOVED. ROWAN CAMP IS SCHEDULED TO DEPART DEAD HORSE @ 1000 AM & AND SHOULD TAKE ABOUT 8-10 HOURS TO ARRIVE. MATS WILL BE LAYED TWO DEEP WHLE WAITING ON ROWAN CAMP,IN PREPARITION FOR THE RIG. 'NORDIC CALISTA IS NOT IN THE VENDOR COLUMN AS IT DOES NOT APPEAR IN THE PICKLlST 1/26/2005 06:00 - 23:00 17.00 01 MIRU COMPLETE RIG MOVE TO STAGING PAD. REMOVE CELLAR WINDWALLS & PHILLIPS 66 SIGNS PROIR TO STARTING MOVE ON TO ICE ROAD. LAY ALL AVAIABLE MATS AND START DOWN ICE ROAD @ 23:00 23:00 - 06:00 7.00 01 MIRU MOVE DOWN ICE ROAD & SHUFFLE RIG MATS AS RIG PROGRESSES 1/27/2005 06:00 - 06:00 24.00 01 MIRU CONTINUE RIG MOVE ON ICE ROAD WITH MAT. EXPECT RIG ON LOCATION AT 0600. MOBILIZE MATERIAL TO LOCATION WHILE MOVING RIG. ROWAN 50 MAN CAMP IN ROUTE. 1/28/2005 06:00 - 06:00 24.00 01 MIRU CONT. MOVE RIG ON ICE ROAD WITH NO PROBLEMS. CLEAR AND PREP AREA AROUND WELL FOR RIG ARRIVAL. MOVE LIGHT LOADS ON APRON AROUND RIG AND STAGE @ PAD. CONTACT ALL VENDORS FOR PLANNED ARRIVAL OF DRILLING MATERIALS. VG STARTING INSTALLED ON CONDUCTOR & TESTED T/1000 PSI 1/29/2005 06:00 - 06:00 24.00 01 MIRU CONTINUED TO MOVE RIG ON DOUBLE MATS. PREPARED BERM ED AREAS FOR LIQUID MUD PRODUCTS AND EVALUATED ROAD CONDITIONS FOR CAMP MOVEMENT. PLACED HERCULlTE FOR RIG MATS. AIC MAINTAINED ICE ROAD WITH BLADE AND SNOW BLOWER DURING PHASE 2 CONDITIONS. 1/30/2005 06:00 - 18:00 12.00 01 MIRU COMPLETE RIG MOVE. ORIENT RIG AND MOVE OVER WELLHEAD. HUNG BOP AND BEGAN N/U DIVERTER SPOOL. BERMED RIG AND SPOTTED MUD LOGGERS SHACK AND MWD UNITS. COMPLETED ROWAN 50 MAN CAMP MOVE. SPOTTED CAMP ON LOCATION AND BERMED AROUND CAMP EQUIPMENT. STARTED WARMUP OF CAMP. SPOTTED MEDIC CLINIC AND CONTINUED RIGGING UP COMMUNICATIONS. MOVE MISC. EQUIPMENT TO LOCATION. 18:00 - 00:00 6.00 01 MIRU NIPPLED UP DIVERTER STACK AND REMOVED DIVERTER LINES FROM STANDS. HUNG CELLAR WALLS. CUT SILLS FOR BERMING DIVERTER DISCHARGE PIT. RU TIOGA HEATERS AND MOVED IN VARIOUS DUNNAGE AND SMALL EQUIPMENT LEFT ON QPAD. 00:00 - 06:00 6.00 01 MIRU CONTINUED HANGING CELLAR WIND WALLS. LAID OUT SILLS AND DIVERTER LINE. NOTIFIED JEFF JONES WITH AOGCC AT 10:00 PM THAT WE WILL BE READY TO FUNCTION TEST DIVERTER AND KNIFE VALVE TODAY. Printed: 4/25/2005 11:10:09 AM . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 I Sub Code 1/31/2005 06:00 - 12:00 6.00 01 MIRU COMPLETE RIG UP DIVERTER BAG AND FLOW NIPPLE. CONTINUE RIG UP MWD AND ML. STARTED HEATING UP AREA ABOVE CELLAR. 12:00 - 22:00 10.00 01 MIRU LOADED DRILL PIPE AND BHA COMPONENTS INTO PIPE SHED. STRAPPED DRILL STRING AND BHA COMPONENETS. BEGAN STEAMING OUT EACH JOINT AND WARMING UP PIPE. SET MUD ENGINEERS LAB AND BEGAN WARMING UP SAME. 22:00 - 00:00 2.00 01 MIRU BEGAN PICKING UP AND STANDING BACK DRILL PIPE. RECEIVED DIVERTER ADAPTER SPOOL FROM WELDERS AT 00:00. ACCEPTED RIG AT 00:00 ON 1/31/05 00:00 - 01 MIRU INSTALLED KNIFE VALVE ON DIVERTER SPOOL AND CONTINUE PICKING UP DRILL PIPE 2/1/2005 06:00 - 15:30 9.50 01 MIRU PICK UP 25 STANDS OF DRILL PIPE THAW SNOW PACK OUT OF DP. M/U DIVERTER FLOW LINE AND DRIP BERM. CONTINUE RIU MUD LOGGERS. BEGIN TO TAKE ON 9.0 PPG KCUPHPA MUD. 15:30 - 19:00 3.50 01 MIRU LOAD HWDP AND DC'S TO PIPE SHED. BEGIN THAWING SAME. RIGGED UP CEMENT STANDPIPE LINES. CONTINUED RIGGING UP TOTCO AND SPERRY SUN MUD LOGGING. 19:00 - 19:30 0.50 01 MIRU HOOKED UP EXTENSIONS TO KNIFE VALVE CONTROL LINES. , FUNCTIONED DIVERTER. 19:30 - 22:00 2.50 01 MIRU I THAWED HEAVY WEIGHT DRILL PIPE. STRAPPED AND I CALlPERED BHA AND PREPARED TO FUNCTION TEST DIVERTER FOR STATE MAN. 22:00 - 00:00 2.00 01 MIRU INSPECTED GAS DETECTORS, FLO SHOWS, PVT'S, DIVERTER LINE, AND DIVERTER FUNCTION WITH AOGCC. 00:00 - 06:00 6.00 01 MIRU PICKED UP HWDP AND DC'S. SWAPPED OUT CUTTINGS BOX AND LAID BERMS AROUND BIGGER CUTTINGS BOX. OFFLOADED SECOND LOAD OF LIQUID MUD. 2/2/2005 '06:00 - 06:30 0.50 27 A DRLSUR PRE JOB SAFETY MEETING FOR SURFACE HOLE DRILLING OPERATIONS 06:30 - 09:00 2.50 02 A DRLSUR PU BHA. 12.25 BIT, MUD MOTOR, XO, XO, HWDP 09:00 - 09:30 0.50 26 DRLSUR RIH. TAG ICE AT 40 FT. WASH TO 80 FT. 09:30 - 10:30 1.00 05 A DRLSUR CIRCULATE AND SHEAR FRESH KCLlPOL YMER MUD. 10:30 - 11 :00 0.50 02 A DRLSUR DRILL TO 135' AT REDUCED FLOW RATE OF 300 GPM DUE TO SCREEN BLINDING 11 :00 - 12:00 1.00 05 A DRLSUR CIRCULATE AND CONDITION MUD. # 3 SHAKER DOWN FOR REPLACEMENT OF SHEARED MOTOR MOUNTING BOLT. PHASE 2 DRIVING CONDITIONS. WIND 20 MPH -20 DEG. TEMPERATURE. BIGIN TWO VEHICLE CONVOYS FOR ALL TRAFIC. 12:00 - 13:00 1.00 02 A DRLSUR CONTROL DRILL AT REDUCED FLOW OF 300 GPM TO 215 FT. 13:00 -13:15 0.25 48 DRLSUR CIRCULATE BOTTOMS UP FOR HOLE CLEANING. SHAKER #3 BACK ON LINE. 13:15 - 14:00 0.75 06 D DRLSUR BLOW DOWN TOP DRIVE AND STAND PIPE. POOH FOR MWD TOOLS. PHASE 3 DRIVING CONDITIONS. WIND 30 MPH. 14:00 - 18:00 4.00 06 D DRLSUR PU MWD TOOLS AND UPLOAD SAME 18:00 - 01 :00 7.00 02 DRLSUR DRILLED FROM 215' TO 641'. 01 :00 - 02:30 1.50 06 DRLSUR MADE SHORT TRIP TO SHOE OF CONDUCTOR WHILE WAITING ION SUPER SUCKER TRUCKS. PHASE 3 WEATHER CONDITIONS DELAYED VACUUM AND WATER TRUCKS. Printed: 4/25/2005 11:10:09 AM . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 I From - To 2/2/2005 02:30 - 06:00 3.50 02 DRLSUR DRILL FROM 641' TO 818. 2/3/2005 06:00 - 00:30 18.50 02 A DRLSUR DRILLING AND SURVEYING FROM 818 TO 2464'. 00:30 - 02:00 1.50 05 A DRLSUR CIRCULATE, SWEEP HOLE AND PREPARE TO POOH 02:00 - 03:30 1.50 06 B DRLSUR PULL OUT OF HOLE TO HWDP. HOLE PULLED TIGHT AT 2190' 03:30 - 05:30 2.00 06 B DRLSUR CLEAN FLOOR AND RUN IN HOLE. TOOK WEIGHT AT 2190' ON TIH 05:30 - 06:00 0.50 05 A DRLSUR CIRCULATE 2/4/2005 06:00 - 08:30 2.50 05 A DRLSUR CIRCULATE AND SWEEP WITH HIGH VIS SWEEP. PUMP CARBIDE SWEEP FOR LAG. 08:30 - 11 :30 3.00 06 H DRLSUR POOH FOR CASING. HOLE CONDITION GOOD. 11 :30 - 13:00 1.50 06 H DRLSUR LD BHA. 13:00 - 15:00 2.00 06 H DRLSUR DOWNLOAD MWD DATA AND LAY DOWN TOOLS. 15:00 - 16:00 1.00 12 B CSGSUR RIG DOWN FLOOR AND PICK UP CASING TOOLS 16:00 - 17:30 1.50 12 A CSGSUR MAKE UP FO SHIFTING TOOLS AND LD SAME 17:30 - 18:30 1.00 12 A CSGSUR PICK UP CASING ELEVATOR AND FRANKS FILL UP TOOLS. SET SPIDER ON ROTARY AND REMOVE FLOOR MATS AND ROTARY BUSHINGS. PICKED UP MANDREL HANGER AND MADE DUMMY RUN WITH CASING HANGER MANDREL. 18:30 - 20:30 2.00 12 A CSGSUR PICK UP AND MAKE UP 9-5/8" FO TOOL ON TWO PUP JOINTS. LAID DOWN SAME. 20:30 - 04:00 7.50 12 A CSGSUR PICKED UP AND RAN 58 JOINTS OF 9-5/8", 40#, L-80, BTC SURFACE CASING WITH WEATHERFORD FLOAT SHOE AT 2456', WEATHERFORD FOAT COLLAR AT 2371', HALLIBURTON FO TOOL AT 102' AND VETCO MANDREL HANGER AT 30'. INSTALLED SIX EACH STRAIGHT BLADE CENTRALIZERS AND TURBOLATORS ON JOINTS 1 THROUGH 11 AS PER PROGRAM. VERIFIED FLOATS AND RIH WITH CASING. BROKE CIRCULATION AT 1600' AND CONTINUED IN HOLE WITH CASING. MAKE UP TORQUE AVERAGE 7500 Ft#'S. PICKED UP LANDING JOINT AND BROKE CIRCULATION. WORKED MANDREL HANGER THROUGH STACK. HANGER HUNG UP ON EVERY RAM. TAGGED UP WITH MANDREL HANGER WHILE CIRCULATING. PICKED UP 1 FOOT AND CIRCULATED AT 40 SPM WITH 300 PSI. 04:00 - 06:00 2.00 12 CSGSUR PUMPED OUT CELLAR AND RIGGED UP TO TAKE CEMENT RETURNS TO VAC TRUCKS FROM CELLAR OUTLETS. RIGGED UP HALLIBURTON WHILE RUNNING CASING. CIRCULATED AT 50 SPM WITH 200 PSI. CONDITIONED MUD FOR CEMENTING. 2/5/2005 06:00-11:15 5.25 05 A CSGSUR CIRCULATE TO CONDITION MUD. HANGER MANDREL HANGING UP IN BOP SO NOT RECRIPROCATED. STRING WEIGHT 80 K. TOTAL BLOCK WEIGHT 105K. MUD WT 9.4 PPG, VIS 39. 11:15 -12:30 1.25 12 B CSGSUR LAND CASING. SO = 105K. LD CIRCULATING TOOL. BLOW DOWN TOP DRIVE AND NU CEMENTING HEAD. PU CASING AND RESUME CIRCULATION. PU WT. = 105 K. 12:30 -12:45 0.25 27 A CSGSUR PJSM FOR CEMENTING CASING. CIRCULATE AT 5.2 BPM WITH 200 PSI AND FULL RETURNS. 12:45 - 13:30 0.75 12 C CSGSUR RU EXTERNAL CEMENT LINES. CHARGE LINES AND TEST TO 3000PSI. 13:30 - 17:00 3.50 12 C CSGSUR CEMENTED 9 5/8" L-80 BTC CASING WITH 315 BBL PERMAFROST L AT 10.7 PPG AND 40 BBL PREMIUM G W/2% CACL AT 15.8 PPG. PUMPED 20 BBL H20 AND 50 BBL NSCI SPACER AT 10.0 PPG. AT 5 Printed: 4/25/2005 11 :10:09 AM . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 2/5/2005 13:30 - 17:00 3.50 12 C CSGSUR BPM. DROPPED PLUG AND BEGAN LEAD AT 5 BPM AT 50 PSI WITH FULL RETURNS. NOTED PARTIAL LOSS OF RETURNS AT 139 BBL PUMPED (SPACER AT SHOE) REDUCED RATE TO 3 BPM AND HAD TOTOAL LOSS OF RETURNS AT 175 BBL PUMPED. PICKED UP AND RECRIPROCATED AT 2 BPM AND 70 PSI. PU = 105K. ATTEMPTED FULL JOINT RECRIPROCATlON. MANDRELL HANGING UP IN BOP. WORK BACK OUT OF BOP WITH IMPROVED RETURNS. CEMENT AT 3 BPM AND RECRIPROCATE 3 FOOT STROKES WITH MANDREL IN DIVERTER SPOOL. CONTINUE CEMENTING WITH PARTIAL TO FULL RETURNS. FINISHED LEAD WITH 160 PSI AND FULL RETURMS AT 3 BPM. PUMPED 40 BBL TAIL AT 3 BPM AND 180 PSI WITH VARYING RETURNS WHILE RECRIPROCATING PIPE. DROPPED BOTTOM PLUG AND PUMPED 20 BBL H20. SWITCH TO RIG PUMP AND LAND CASING. SO = 105 K. DISPLACE WITH MUD AT 3 BPM. LOST PARTIAL RETURNS. PU CASING AT 105 K AND RECRIPROCATED. REGAIN RETURNS. DISPLACED AT 3 BPM AND 580 PSI FINAL PRESSURE. FULL RETURNS WHILE RECRIPROCATING. LANDED CASING AT 125 BBL WHEN CEMENT RETURNED. CONTINUE DISPLACING WITH FULL RETURNS. PUMPED CALCULATED DISPLACEMENT OF 183 BBL. DID NOT BUMP PLUG. PUMPED 3 BBL ADDITIONAL WITH NO BUMP. FLOATS WERE HOLDING. BLEED BACK 1/2 BBL. ESTIMATED 60 BBL CEMENT RETURNED. FLUID BALANCE AFTER CEMENTING INDICATED 1 BBL CUMULATIVE LOSS. 17:00 - 18:00 1.00 12 B CSGSUR RID CMT HEAD & LID LANDING JOINT 18:00 - 20:30 2.50 12 B CSGSUR C/O BALES M/U SHIFTING TOOL, RIH OPEN FO TOOL,POOH 20:30 - 22:00 1.50 12 B CSGSUR M/U FRANK'S TOOL,RIH DISPLACE CMT IN 133/8 X 9 5/8 ANNULUS F/100' T/ SURFACE & FREEZE PROTECT SAME W/9.3 PPG KCL 22:00 - 00:00 2.00 12 B CSGSUR P/U SHIFTING TOOL RIH ON DRILL COLLARS & CLOSE FO TOOL. SIB D.C.'S BREAK & LID SHIFTING TOOL 00:00 - 00:30 0.50 26 CSGSUR LID SPERRY TOOLS FROM PIPE SHED 00:30 - 06:00 5.50 14 CSGSUR N/D DIVERTER SYSTEM & BOP 2/6/2005 06:00 - 07:00 1.00 28 A DRLSUR NO DIVERTER 07:00 - 14:00 7.00 14 DRLlN1 NU BOP. PICK UP BOP AND REMOVE DIVERTER SPOOL. INSTALL MULTI BOWL CASING HEAD. TEST SEAL. SET DOWN AND NU BOP. 14:00 - 17:30 3.50 14 DRLlN1 CONT NU BOP 17:30 - 22:30 5.00 15 DRLlN1 TEST BOP,CHOKE MANIFOLD, FLOOR VALVES, TOP DRIVE IBOP. 250 LOW 5000 HIGH,ANNULAR 250/3500 5 MIN EA. WITNESS BY CHUCK SCHEVE AOGCC 22:30 - 23:30 1.00 26 DRLlN1 PULL TEST PLUG SET WEAR BUSHING 23:30 - 01 :30 2.00 14 DRLlN1 NU BELL NIPPLE ADAPTER 01 :30 - 04:30 3.00 20 DRLlN1 M/U & RIH W/ BHA #2 UPLOAD MWD 04:30 - 05:00 0.50 06 DRLlN1 RIH W/ HWDP F/ DERRICK T/815' 05:00 - 05:30 0.50 20 DRLlN1 PULSE TEST MWD BLOW DOWN TOP DRIVE 05:30 - 06:00 0.50 DRLlN1 SINGLE IN 4" DP 2/7/2005 06:00 - 08:00 2.00 06 0 DRLlN1 SINGLE IN HOLE TO 2310'. 08:00 - 09:00 1.00 25 DRLlN1 PRECAUTIONARY WASH TO 2335' AND TAG SOFT CEMENT. DRILL SOFT CEMENT TO FC AT 2371' 09:00 - 10:00 1.00 05 DRLlN1 CIRCULATE OUT CONTAMINATED MUD. BLOW DOWN TOP DRIVE. Printed: 4/25/2005 11:10:09AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NIKAITCHUQ #4 NIKAITCHUQ #4 (ALASKA) DRILLING NORDIC NORDIC Code 2/7/2005 09:00 - 10:00 1.00 05 DRLlN1 10:00 - 11 :00 1.00 25 DRLlN1 11 :00 - 12:30 1.50 25 DRLlN1 12:30 - 14:00 1.50 25 DRLlN1 14:00 - 16:00 2.00 26 DRLlN1 16:00 - 06:00 14.00 02 DRLlN1 2/8/2005 06:00 - 11 :00 5.00 02 A DRLlN1 11:00 -12:00 1.00 05 A DRLlN1 12:00 - 14:00 2.00 06 B DRLlN1 14:00 - 15:00 1.00 06 B DRLlN1 15:00 - 16:00 1.00 05 A DRLlN1 16:00 - 20:30 4.50 06 D DRLlN1 20:30 - 21 :00 0.50 26 DRLlN1 21 :00 - 01 :00 4.00 06 D DRLlN1 01 :00 - 03:30 2.50 06 D DRLlN1 03:30 - 06:00 2.50 03 A DRLlN1 2/9/2005 06:00 - 07:00 1.00 03 A 07:00 - 14:00 7.00,04 14:00 - 14:30 0.50 04 14:30 - 18:00 3.50, 04 18:00 - 19:00 1.00 04 19:00 - 22:00 3.00 04 22:00 - 23:00 1.00 04 23:00 - 02:00 3.00 04 02:00 - 04:00 2.00 04 04:00 - 05:00 1.00 04 05:00 - 06:00 1.00 26 2/10/2005 06:00 - 06:30 0.50 07 06:30 - 12:30 6.00 20 12:30 - 13:30 1.00 06 13:30 - 14:00 0.50 06 14:00 - 15:00 1.00 06 Start: 1/25/2005 Rig Release: Rig Number: 3 Spud Date: 2/112005 End: Group: RU FOR CASING TEST TEST CASING TO 2500 PSI FOR 30 MIN. GOOD TEST. DRILL FC, GOOD CEMENT, FS AND RATHOLE TO 2464'. DRILL 20' OF NEW HOLE 2484'. CIRCULATE AND CONDITION MUD TO 9.3 PPG FOR LOT. PJSM, RIU & PERFORM LOT T/14.4 PPGT EMW LEAK OFF @ 655 PSI WITH 1.3 BBL. CONT. T/ PUMP T/ EST INJECTION RATE OF 630 PSI @ .1 BPM. TOTAL PUMPED 3.7 BBL. SHUT IN FOR 33 MIN. STABILIZED SHUT IN PRESSURE = 310 PSI @ 2484 MD DRILLING F/2484 T/ 3820 P/U WT 76K S/O WT 90K RT/WT 65K PSI ON 1900 PSI OFF 1800 TQ ON 2800 TQ OFF 1800 80 RPM DRILLING F/3820 T/ CORE POINT PER GEOLOGIST DIRECTION AT 4121 FT. P/U WT 92K S/O WT 76K RT/WT85K. PSI ON 1900 PSI OFF 1800 TQ ON 2800 TQ OFF 180080 RPM. WOB 18K CIRCULATE AND CONDITION FOR CORING. SHORT TRIP FROM 4121' TO CASING SHOE AT 2357' HOLE CONDITION GOOD. NO EXCESS DRAG. RIH TO TD. NO DRAG OR LEDGES. CBU & CONDITION MUD FOR CORING SPOT HI VIS PILL POOH CLEAN FLOOR & PJSM W/ CORE PERSONNEL,HSE REP M/U CORE ASSY RIH T/2464 BREAK CIRCULATION, CO NT RIH T/3794. TAKING WEIGHT MU TOP DRIVE WASH & REAM F/3794 T/4120 34 SPM 180 PSI 50 RPM PU WT 82K SO WT 75K RT/WT 80K STRING WAS TORQUEING UP & STALLING TOP DRIVE @ 15K FT/ LBS PRE SET VALUE CONTINUED TO BOTTOM WITH NO OTHER SIGNIFICANT PROBLEMS CONTINUED T/ WASH & REAM T/4120 SPACED OUT FOR CORE PT MU BALL DROP ASSY CORE F/4120 T/4171 65 RPM 1100 FT/LBS TQ 200 GPM 460 PSI PU/WT 91K SO/WT 92K RT/WT 91K CONT CORING F/4171 T/4180 TD 67 SPM 480 PSI91K UP 92K DN 91K RT/WTTQ 1100 FT/LBS BLOW DOWN TOP DRIVE POOH W/ CORES 7 STDS @ 7 MIN PER STD- 7STD @ 6 MIN PER STD WAIT 1 HR PER CORE PROGRAM CO NT POOH 14 STDS @ 9.5 FT PER MINUTE AS DIRECTED WAIT 1 HR PER PROGRAM CO NT POOH 3 FT/MIN PER PROGRAM TO CORE ASSY PJSM W/ BAKER & CORELAB HANDS BREAK OFF BIT & BOTTOM SUBS. PULL INNER CORE BARRELS & UD SAME 58' CORE RECOVERED BREAK & UD OUTER CORE BARREL ASSY & UD SAMEBEGIN PACKING CORES W/ DRY ICE ASIST CORELAB HANDS IN PIPE SHED CLEAR RIG FLOOR SERVICE RIG C/O SAVER SUB PJSM MU MRIL-WD BHA & UPLOAD RIH W/7 STD HWDP F/ DRK & PULSE TEST MWD PU 21 JTS DP FROM SHED RIH RIH T 2400 FROM DERRICK CONT RIH T/4120 Printed: 4/25/2005 11 :10:09 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: NIKAITCHUQ #4 NIKAITCHUQ #4 (ALASKA) DRILLING NORDIC NORDIC Start: 1/25/2005 Rig Release: Rig Number: 3 Spud Date: 2/112005 End: Group: 2/10/2005 15:00 - 15:30 0.50 03 A REAM CORE SECTION F/4120 T/4180 15:30 - 19:00 3.50 02 A DRILL F/4180 T/4310 P/U 100 S/O 100 RT 100 19:00 - 20:00 1.00 05 A CBU 2X 100 SPM 2380 PSI WORK PIPE 20:00 - 00:00 4.00 06 D POOH T HWDP 5K MAX DRAG 00:00 - 03:00 3.00 06 D DOWN LOAD MWD TOOLS SET BACK BHA 03:00 - 05:00 2.00 11 A PJSM RlU WIRELlN LOGS LOAD NUKES IN NUETRON DENSITY TOOL 05:00 - 06:00 1.00 11 A RIH WITH WIRE LINE 2/11/2005 06:00 - 11 :00 5.00 39 B EVAL POH W/HRLA (Iateralog), lay down tool. 11:00 -12:00 1.00 39 B EVAL P/U HALS 12:00 - 13:30 1.50 39 B EVAL RIH & LOG, POH 13:30 - 14:00 0.50 39 B EVAL P/U FMIICBL 14:00 - 16:00 2.00 39 B EVAL CONT RU DSI-FMI 16:00 - 19:00 3.00 39 B EVAL RIH W/ DSI-FMI LOG INTERVAL POOH RlU CBL-VDL 19:00 - 21:00 2.00 39 B EVAL RIH W/ CBL-VDL PERFORM BOND LOG POOH 21 :00 - 22:00 1.00 39 B EVAL RID WIRELlNERS 22:00 - 00:30 2.50 06 OTHER RIH OPEN ENDED 00:30 - 04:00 3.50 05 OTHER CIRC ANDCONDITION MUD (WAIT ON CEMENTERS) 04:00 - 05:00 1.00 12 D OTHER RlU AND SPOT CEMENTERS 05:00 - 06:00 1.00 12 D OTHER PJSM PUMP & SPOT 700 FOOT CMT PLUG FROM 4300 3600 1st STAGE 2/12/2005 06:00 - 12:00 6.00 17 OTHER FINISH PLUGGING BACK F/431 0-2900', POH 12:00 - 14:00 2.00 15 OTHER RlU & TEST BOPE 14:00 - 17:00 3.00 15 OTHER TEST CHOKE MANIFOLD FLOOR VALVES TOP DRIVE IBOP'S STACK 250 LOW 5000 HI5 MIN EA. ANNULAR PREVENTER 250 LOW 3500 HI 5 MIN 17:00 -17:30 0.50 15 OTHER PULL TEST PLUG SET WEAR BUSHING 17:30 - 20:30 3.00 20 OTHER PJSM MU BHA #5 UPLOAD MWD & PULSE TEST SAME 350GPM 750 PSI BLOW DOWN TOP DRIVE 20:30 - 22:00 1.50 06 OTHER RIH HW & 4" DP T/2200 22:00 - 22:30 0.50 07 OTHER SERVICE RIG 22:30 - 00:00 1.50 06 OTHER CONT RIH T/2863 TO.C. EST CIRCULATION 62 SPM 340 PSI P/U 83K S/O 80K RT 80K 00:00 - 02:30 2.50 20 OTHER TIME DRILLING F/2863-2895' 02:30 - 06:00 3.50 02 A OTHER DRLD F/2895-3150' (3032' TVD) 2/13/2005 06:00 - 14:00 8.00 02 DRLlN2 DRILL & SLIDE F/3150 T/3770 PU 85K S/O 85K RT 85K TQ 3400 FT/LBS PSI 1570 ON 1480 OFF 14:00 - 06:00 16.00 02 DRLlN2 DRILL & SLID F/3770 T/ 4735' P/U 87K S/O 85K RT/ 85K TQ ON 4K TQ OFF 3K SPR@ 4610 MD 4099 TVD 9.3 MW #1 & #230 SPM 150 PSI 40 SPM 185 PSI 2/14/2005 06:00 - 08:00 2.00 02 A DRLlN1 CONTINUE TO DRILL F/4735-4861, Printed: 4/2512005 11:10:09AM \ ' . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 2/14/2005 08:00 - 10:30 2.50 05 A DRLlN1 CIRCULATE & CONDITION MUD, PUMP SWEEP & CIRCULATE 3 BTMS UP, MONITOR HOLE. 10:30 - 12:00 1.50 06 B DRLlN1 WIPER TRIP TO SHOE 12:00 - 13:00 1.00 06 B DRLlN1 RIH F/2426-4861, HOLE IN GOOD CONDITION. 13:00 - 15:00 2.00 05 A DRLlN1 CIRCULATE AND CONDITION MUD. 15:00 - 19:00 4.00 12 A DRLlN1 POH TO RUN CSG, SLM NO CORRECTION. 19:00 - 20:30 1.50 06 D CSGIN1 LAY DOWN BHA, DOWNLOAD MWD. 20:30 - 21 :30 1.00 28 A CSGIN1 PULL WEAR BUSHING AND DUMMY RUN HANGER. 21 :30 - 23:30 2.00 15 CSGIN1 C/O RAMS, SET TEST PLUG, TEST DOOR SEALS TO 1500 PSI, 23:30 - 02:00 2.50 12 B CSGIN1 RlU TO RUN 7" CASING. 02:00 - 06:00 4.00 12 A CSGIN1 PJSM P/U & RIH W/ SHOE TRACK BRK CIRCULATION CK FLOATS OK CONT RIH INSTALL STRAIGHT BLADE & RH CENTRALIZERS PER PLAN T/2017 INSTALL E S CEMENTER 2/15/2005 06:00 - 07:30 1.50 12 A CSGIN1 CONT RIH T/2960 BRK CIRC @ 9 5/8 SHOE CIRC 1 PIPE VOLUME STEPPING UP RATE T/5 BBUMIN 400 PSI 07:30 - 10:00 2.50 12 A CSGIN1 RIH T/4818 P/U HGR & LNDNG JT & LAND @ 4851 10:00 - 12:00 2.00 05 A CSGIN1 TAG BTM SPACE OUT LAND HGR CIRC 2X BTMS UP CONDTlON FOR CMT 12:00 - 15:00 3.00 05 A CSGIN1 M/U CMT HEAD CONT CIRC & CONDITION RlU CEMENTERS 15:00 - 17:00 2.00 12 C CSGIN1 PUMP 10 BBL H20 TEST LINES T/2500 PSI DROP BYPASS PLUG PUMP 30 BBL SPACER, 59.8 BBL CMT DROP BTM SHUT OFF PLUG, PUMP 73 BBL MOBM W/ LlL' RED SVCS CHASE W/108.3 BBL H20 BASE MUD W/ RIG BUMP PLUG. CHECK FLOATS 17:00 - 18:00 1.00 12 CSGIN1 PRESS UP OPEN E S CEMENTER CIRC OUT EXCESS CMT F/ ABOVE E S CEMENTER 120 BBLS 18:00 - 19:30 1.50 12 CSGIN1 'DROP CLOSING PLUG & PUMP 108.2 BBL MOBM W/ LlL' RED. PRESS UP & CLOSE E S CEMENTER 19:30 - 00:00 4.50 12 B CSGIN1 RI CMT HEAD SET 9 5/8 X 7 PACK OFF TEST VOID T/5000 PSI 5 MIN (OK) PUMP PLASTI PAC SEAL INTO VOID TEST SAME T/5000 PSI 15 MIN (OK) RID CASING EQUIPMENT 00:00 - 04:00 4.00 15 OTHER SET TEST PLUG C/O OUT 7" T/4" RAMS BODY TEST T/1500 PSI 10 MIN INSTALL WEAR RING C/O RIG TONGS P/U & S/412 JT HWDP 04:00 - 06:00 2.00 20 INT3 P/U & RIH BHA #6 2/16/2005 06:00 - 10:00 4.00 20 DRLPRO ORGAIZE PIPE SHED P/U BHA # 6 10:00 - 12:00 2.00 20 DRLPRO PJSM LOAD NUKES RIH W/ NMDC & HWDP P/U 2 SGLS PULSE TEST MWD 12:00 - 13:00 1.00 09 DRLPRO CUT DRLG LINE 13:00 - 14:00 1.00 07 DRLPRO COMPLETE RIG SVC 14:00 - 17:00 3.00 06 DRLPRO CO NT SGL IN DP T/2833 17:00 - 18:30 1.50 25 DRLPRO DRILL OUT E S CEMENTER 18:30 - 20:30 2.00 06 DRLPRO RIH T/4761 TOP OF BAFFLE 20:30 - 22:00 1.50 26 DRLPRO TEST 7" CSG T/2500 PSI 30 MIN 22:00 - 23:00 1.00 05 DRLPRO CIRC WHILE SCREEN DOWN SHAKERS 23:00 - 01 :30 2.50 25 DRLPRO DRILL OUT BAFFLE & SHOE TRACK 01 :30 - 03:00 1.50 25 DRLPRO RlU & PERFORM FIT 12.5 PPG EMW 627 PSI RID 03:00 - 06:00 3.00 02 B DRLPRO SLIDE F/4880 T/4970 P/U 76K S/O 76K SPM 100 PSI 2275 2/17/2005 06:00 - 06:00 24.00 02 DRLPRO DRILL & SLIDE F/4970 T/6304' CONTROLLED DRILLING AS PER GEO AND DIRECTIONAL DRILLER. PERIODIC SWEEPS TO ASSIST Printed: 4/25/2005 11:10:09 AM . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 Description of Op 2/17/2005 06:00 - 06:00 24.00 02 DRLPRO IN HOLE CLEANING. 2/18/2005 06:00 - 06:00 24.00 02 DRLPRO DRILL & SLIDE F/6304 T/7468 CONTROLLED DRILLING PER GEOLOGIST & DD PUMP SUCTION CHAMBERS PACKED OFF REDUCING PSI RUN ON 1 PUMP WHILE CLEANING 2/19/2005 06:00 - 09:00 3.00 02 DRLPRO DRLG F/7468 T17577 TO 09:00 - 11 :00 2.00 05 A DRLPRO PUMP SWEEP CBU 3X 11:00 -14:00 3.00 06 B DRLPRO PUMP OUT OF HOLE T/4851 7" SHOE 14:00 - 14:30 0.50 07 DRLPRO SERVICE TOP DRIVE SWIVEL CK SAVER SUB 14:30 - 16:00 1.50 06 B DRLPRO RIH T/7577 16:00 - 19:30 3.50 05 A DRLPRO PUMP SWEEP CBU 3X SPOT 110 BBL NEW MOBM 19:30 - 05:00 9.50 06 H DRLPRO MONITOR WELL POOH ON TRIP TANK HOLE TAKING PROPER FILL CONT. POOH 05:00 - 06:00 1.00 20 DRLPRO PUMP BASE OIL THROUGH MWD & MUD MOTOR TO FLUSH; UD BHA 2/20/2005 06:00 - 09:30 3.50 06 DRLPRO UD BHA DOWN LOAD MWD REMOVE NUKES 09:30 - 10:30 1.00 15 OTHER PULL WEAR RING SET TEST PLUG 10:30 - 15:00 4.50 15 OTHER TEST CHOKE MANIFOLD ALL RAMS FLOOR VALVES T.D. IBOP VALVES HCR'S 250 LOW 5000 HIGH. ANNULAR PREVENTER T/250 LOW 3500 HIGH TEST WITNESS BY JOHN SPAULDING AOGCC 15:00 - 18:30 3.50 33 POST PULL TEST PLUG INSTALL WEAR RING R/U TO RUN LINER 118:30 - 19:00 ORGANIZE PIPE SHED 0.50 33 POST PJSM RUNNING LINER 19:00 - 00:00 5.00 33 POST RIH W/3.5 9.2 # IBT L-80 SLOTTED LINER 00:00 - 06:00 6.00 06 POST P/U PKR M/U SAME & RIH W/ DC'S HWDP & 4' DP T/ (DRIFT PIPE FROM DERRICK) FLUID COMING OUT OVER TOP OF PIPE 30-40 FOOT UP RIH 2-3 MIN PER STO 2/21/2005 06:00 - 09:00 3.00 33 B COMRNC CONT RIH T/7567 09:00 - 10:00 1.00 33 B COMRNC DROP DART PUMP DOWN SET HGR & PKR TEST T/2500 PSI UNSTING PULL UP 30' TOL SET @ 4672 110:00 -12:00 2.00 05 B COMRNC MIX SPACERS FLUSH ALL SURFACE LINES CLEAN RIG FLOOR 12:00 - 13:00 1.00 05 B i COMRNC PUMP SPACERS, DISPLACE WELL T/9.3 PPG KCL BRINE BLOW ! DOWN T.D 13:00 - 13:30 0.50 07 COMRNC SERVICE RIG 13:30 - 16:30 3.00 06 D COMRNC POOH BALANCING WEIGHT IN DERRICK FOR RIG MOVE 16:30 - 19:30 3.00 33 C COMRNC PULL WEAR RING RIU TBG EQUIP ESP SHEAVES SET JEWELRY IN ORDER IN PIPE SHED 19:30 - 20:00 0.50 33 C COMRNC PJSM ON ESP PROCEDURE; SUCK OUT STACK 20:00 - 00:00 4.00 33 C COMRNC P/U ESP HALLIBURTON GAUGE CARRIER BACK FILL W/ OIL BLEED OUT AIR INSTALL ESP CABLE INSTALL CLAMP RIH 00:00 - 00:30 0.50 33 C COMRNC PJSM @ CREW CHANGE 00:30 - 06:00 5.50 33 C COMRNC RUN ESP IN HOLE ON 2 7/8 6.5 # EUE TBG INSTALLING CHECK VALVE, DRAIN VALVE, XN NIPPLE, & GLM. CLAMP INSTALLED ON EA JT FOR FIRST 34 EVERY OTHER ONE ON NEXT 85. CO NT RIH. 2/22/2005 06:00 - 09:30 3.50 33 C COMRRC CONT RIH T/ JT #121 CABLE FAILS MEGGER TEST 09:30 - 12:30 3.00 33 C COMRRC POOH T/ JT #99 (CABLE SPLICE) CUT CABLE & MEGGER TEST FAILED 12:30 - 15:30 3.00 33 C COMRRC RESPLlCE CABLE 15:30 - 21 :30 6.00 33 C COMRRC CO NT POOH STANDING BACK TBG T/ DRAIN VALVE 21 :30 - 23:30 2.00 33 C COMRRC RELIEVE PRESSURE F/ DRAIN PLUG BETWEEN RXN PLUG & CHECK VALVE. PULL RXN PLUG UD & UD DRAIN VALVE & PUP JTS 23:30 - 01 :00 1.50 33 C COMRRC CO NT POOH T/ PUMP MOTOR Printed: 4/25/2005 11:10:09 AM .' . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: DRILLING Start: 1/25/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 From - Hours Code Sub Phase Code 2/22/2005 01 :00 - 05:00 4.00 33 C COMRRC MOTOR LEAD KINKED & WORN THROUGH AT SPLICE POINT REBOOT & RELOAD DOWN HOLE SENSOR GAUGES (HALLIBURTON) RESPLlCE MOTOR LEAD & ESP CABLE 05:00 - 06:00 1.00 33 C COMRRC REINSTALL GAUGES IN CARRIER PLUG IN MOTOR LEAD. WHILE SLACKING OFF TO RESEVICE MOTOR SEALS LINE TENSIONED UP & MOTOR LEAD PARTED 2/23/2005 06:00 - 09:30 3.50 33 C COMRNC CONT.SPLlCE MOTOR LEAD ON ESP CABLE 09:30 - 10:00 0.50 26 COMRNC PJSM DISCUSSING ALL ASPECTS OF UPCOMING OPERATION 10:00 - 18:00 8.00 33 C COMRNC RIH W/ ESP ON STDS F/ DERRICK (117 JTS 6.5 # 27/8 EUE TBG) 18:00 - 20:00 2.00 33 C COMRNC SGL IN F/ PIPE SHED T/4000' P/U TRSSV MAKE UP CONTROL LINE & TEST T/5000 PSI (JTS #118- 126) 20:00 - 21 :30 1.50 33 C COMRNC CONT SGL IN F/ PIPE SHED (JTS # 127- 138) PROPER FILL ON TRIPS IN & OUT OF HOLE (9.3 PPG MOBM F/7568 T/4672 TOll 9.3 PPG KCL BRINE F/4672 T/120' DIESEL T/ SURFACE 21 :30 - 00:30 3.00 33 C COMRNC P/U HGR & LANDING JT & TERMINATE ESP CABLE & CONTROL LINE 00:30 - 01 :30 1.00 33 C COMRNC LAND HGR, RILDS, TEST T/5000 PSI (OK) GAUGE CARRIER SET @ 4500' 01 :30 - 02:30 1.00 33 C COMRNC PUMP 4 BBLS DIESEL DOW BACK SIDE FREEZE PROTECT 2 7/8 X 7 ANNULUS T/ +/- 120' 02:30 - 03:00 0.50 33 C COMRNC PRESSURE TEST TBG T/1000 PSI 03:00 - 03:30 0.50 33 COMRNC LID LANDING JT INSTALL 2 WAY CHECK & TEST T/1000 PSI 03:30 - 06:00 2.50 14 COMRNC N/D BOPE 2/24/2005 06:00 - 09:00 3.00 COMRNC N/D AND SET BACK BOP 09:00 - 12:00 3.00 COMRNC N/U PRODUCTION TREE. TEST HANGER SEAL VOID AND TREE TO 5000 PSI. PULL TWO WAY CHECK VALVE AND RUN BPV. FUNCTION TEST SSCV. RELEASE RIG FOR MOVE AT 12:002/23/05 Printed: 4/25/2005 11 :10:09 AM . . NIKAITCHUQ #4 OPERATIONAL TIME LOG WITH BHP GAUGE SAMPLING FREQUENCY 2/22/2005 9:09:30 Start Gauge Clocks. Start TIH with ESP and completion string 2/22/200521:10:00 2/22/2005 21 :30:00 Space Out & Terminate Lines at Hanger 2/23/2005 0:30:00 Land Hanger & Test. Pump Diesel down annulus to freeze protect. Test tbg 1000 psi. 2/23/2005 3:00:00 NO BOP's 2/23/2005 i::ndôf 1 minSarnpling Rate Gauge Set#l; Begir14$eç SamplingRäte 2/23/2005 9:00:00 NU Tree and Test 2/23/2005 2/23/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/24/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/25/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/26/2005 2/27/2005 2/27/2005 12:00:00 Release Rig to Nik #3 and begin demob 21 :00:00 Rig Demob. StaJÍ~U Surface lines for well test 9:30:00 Pressure te~a~ lines 10:50:00 PIP reading!1923 psi, 87 degrees F 11 :08:00 Start ESP abd ¡yWent down on drive failure. Determine BPV still in well. 14:15:00 Remove BP\í SITP 3 psi, PIP 1869 psi. Open well to separator on 14/64th chk and start ESP at 35 Hz, PIP 1859 14:30:00 psi 15:38:00 Open to 16/64th chk, PIP 1779 psi 16:30:00 Open to 22/64th chk, PIP 1601 psi. Motor temp starts to decrease indicating fluid from formation 18:45:00 Rock choke to remove plugging 19:40:00 Cut back to 20/64th chk 21 :00:00 Oil to surface after producing 125 bbl of load water, PIP 1618 psi 22:40:00 Open to 24/64th chk, PIP 1640 psi. Last water produced after total of 130 bbl. 23:30:00 Set choke at 22/64th, PIP 1628 psi 3:00:00 Open to 32/64th chk, PIP 1584 psi 9:00:00 Open to 40/64th chk, PIP 1572 psi 9:30:00 Open to 48/64th chk, PIP 1504 psi 14:00:00 Open to 64/64th chk, PIIP 1493 psi 16:35:00 Oilphase Collect Surface Samples (PIP 1486, TP 71, 680 bopd, 0 bwpd, 30 mcfd) 18:00:00 Decrease choke to 48/64th, PIP 1481 psi 18:10:00 Decrease choke to 32/64th 18:20:00 Decrease choke to 16/64th 18:30:00 Shut down ESP, Close in at choke, monitor PIP (Cums: 516 bo, 130 blw, 16 mct) 18:35:00 RU Halliburton slickline 19:30:00 Pressure test Lubricator. PIP 1585 psi 20:00:00 Pull Lubricator, reset clocks on samplers 20:30:00 Pressure test Lubricator. PIP 1610 psi 21 :00:00 RIH with samplers on slickline to 1300' 22:30:00 POOH to reset clocks on samplers. Slow to fall in heavy oil. 23:00:00 RIH with samplers to 4012' SLM. PIP 1644 psi 1: 10:00 End of 2 sec$ªrnpling Rate for Gauge Set #1 ; Begin 5 sec S¡;¡mPliriggäte 4:40:00 POOH with samplers, PIP 1681 psi 5:15:00 Pump diesel through lubricator for flush 6:00:00 Closed master valve on slickline wire and dropped toolstring 7:30:00 Open wing on tree to the line heater. PIP 1683 psi.- -- 8:45:00 Bleed casing pressure from 143 psi to 30 psi. 9:30:00 Kick off ESP on 128/64th choke in attempt to flow / push toolstring to surface 10:30:00 Decrease choke to 64/64th and check tree for fish. 15:30:00 Wide open choke 128/64th, 35 Hz, PIP 1454 psi 9:45:00 Bleed casing pressure from 60 psi to 44 psi Increase frequency from 36 Hz to 38 Hz. PIP 1383 psi, TP 119, 800 bopd, 0 bw, 30 mcfd, Mtr temp 11 :00:00 95.5, Mtr Amps 112, Intake Temp 88.3 (Increase of 5 HP) 2/27/2005 2/28/2005 2/28/2005 2/28/2005 3/3/2005 3/5/2005 3/6/2005 3/7/2005 3/8/2005 3/8/2005 3/8/2005 3/8/2005 3/8/2005 3/10/2005 3/11/2005 3/12/2005 3/12/2005 3/12/2005 3/12/2005 3/12/2005 . . Increase frequency from 38 Hz to 41.7 Hz. Rates Prior to frequency change are as follows: PIP 1328 psi, TP 101, 680 bopd, 0 bw, 60 mcfd, Mtr temp 96.5, Mtr Amps 118, Intake Temp 88.3 (Increase of 15 19:00:00 HP) Increase frequency from 41.7 Hz to 45.7 Hz. Rates Prior to frequency change are as follows: PIP 1248, TP 158, 800 bopd, 0 bw, 60 mcfd, Mtr temp 98.5, Mtr Amps 127, Intake Temp 88.3 (Increase of 15.8 5:15:00 HP) 7:00:00 Backpressure problem in Separator. Make surface changes between Gas Scrubber and LP Sep. Increase frequency from 45.7 Hz to 50.2 Hz. Rates Prior to frequency change are as follows: PIP 1147, 16:00:00 TP 116, 960 bopd, 0 bw, 80 mcfd, Mtr temp 101.6, Mtr Amps 140, Intake Temp 88.2 Decrease freqency from 50.2 Hz to 46.7 Hz in order to stabilize declining PIP. Rates Prior to frequency change are as follows: PIP 918, TP 146, 880 bopd, .3 bwpd, 30 mcfd, Mtr temp 108.9, Mtr Amps 149, 17:00:00 Intake Temp 87.8. Shutdöwn ESPfor BHPBuildup.Monitor PIP. R psi. ,1.5ÞWþd,150rncfd, Mtrtem 18:00:00 Pro i ,134.7bw,484mcf) RUHallib ine.TlHtoA001'SLM =4036'.rndWith 6:00:00 tötalof7s runsindependelltlyto get 6 six samples. 20: 15:00. Finish runningsamples,RDHallibUrton. sl ickline.PIP. 1362 psi. 5:00:00 PIP reading 1380 psi. > PIP reading 1393 psi, CP 100,TPA7.9.0perlwèll 13:00:00 choke to 128/64th over period of45 minutes. Increase frequency from 35 Hz to 40 Hz. Rates Prior to frequency change are as follows: PIP 1362 14:00:00 psi, TP 78, 200 bopd Increase frequency from 40 Hz to 45 Hz. Rates Prior to frequency change are as follows: PIP 1320, 15:00:00 TP 93,560 bopd, 1.4 bwpd, 40 mcfd, Mtr Temp 100, Mtr Amps 105, Intake Temp 86.6 Increase frequency from 45 Hz to 50.2 Hz. Rates Prior to frequency change are as follows: PIP 1170, 17:30:00 TP 112, 840 0 80 mcfd, Mtr 101, Mtr 136, Intake 87.6 Prior to shutting in are as follows: PIP 971 ~ 3, Mtr Amps 134, Intake Temp 87.5. (Cum fish. Decrease frequency from 50.2 Hz to 46.7 Hz. Rates Prior to frequency change are as follows: PIP 6:30:00 899, TP 108, 880 bopd, 0 bwpd, 60 mcfd, Mtr Temp 110.6, Mtr Amps 144, Intake Temp 87.3 ShllfÐOwrlESP.FihaIRate. priorto shut down: PI P 955, TP 89,.6 pd,Obwpd,60mcfd,Mtr Temp 103, Mtr Amps 135, Intake Temp 87.2. Cum Production from 11:8857 bo,13Tbw,654.5 mcf Open Well to stock tank to see if it would flow. SITP 140 psi. Open well and gas head blew off 6:00:00 immediately. Monitor well for 1 hr to see if it would flow. It would not. PIP 1312 psi 7:00:00 SI well and start RU Halliburton Slickline. Test Lubricator and TIH with Lead Impression Block. Tag up at 4180 SLM = 4125' MD. Attmpt to beat 8:30:00 down to get an impression. Out of hole & had impression of cut wire top looking up. Decided to go in with split skirt. TIH. Could 15:00:00 not work past GLM. POOH 19:45:00 Out of hole. MU and TIH with 2" kickover tool to pull dummy from GLM. Could not latch. POOH 3/13/2005 0:15:00 Out of hole. MU and TIH with 21/2" kickover tool to pull dummy from GLM. Could not latch. POOH 3/13/2005 7:00:00 Out of hole. No recovery. RU Hot Oiler to pressure test tubing. Establish Injection Rate with hot diesel @ 1 bpm / 500 psi. Pump total of 15 bbl. SD & RU 1 1/2" hose 3/13/2005 8:30:00 to swab valve for more rate. Pump total of 50 bbl of 180 degree diesel down tubing @ 2.5 bpm /450 psi, 3 bpm / 600 psi. SD ISIP 3/13/2005 9:30:00 250 psi. 3/13/2005 10:00:00 RD Hot Oiler. RU Slickline. 3/13/2005 11 :00:00 Open well (on vac). TIH with 2" kickover tool, latch dummy and pull. POOH. Recovered dummy. 3/13/2005 12:25:00 MU split skirt overshot. TIH. Work over fishing neck. POOH with lost fish and - 4" of wire. RD Halliburton Slickline. RU Hot Oiler. Reverse circulate the hole by pumping 345 bbl of 180 degree 3/13/2005 13:45:00 diesel down annulus and taking returns up tubing at 2.5 bpm / 500 psi. Finish pumping diesel cleanup job. Secure well. RD surface equipment. SD and wait on rig to mobilize 3/13/2005 17:00:00 and pull BHP bombs from well. . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: PLUG & ABANDON Start: 4/15/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 Sub Code 4/18/2005 16:30 - 17:30 1.00 01 RDMO PREPARE RIG FOR MOVE. 17:30 - 20:30 3.00 01 RDMO MOVE RIG. 20:30 - 21 :30 1.00 01 RDMO SPOT & LEVEL RIG BERM UP, SPOT CUTTINGS & BLOW DOWN BOXES. 21 :30 - 22:00 0.50 14 RDMO CHECK WELL FOR PRESSURE, TBG & ANNULUS ON VACUUM 22:00 - 23:00 1.00 14 RDMO N/D TREE 23:00 - 04:00 5.00 14 RDMO N/U BOPE 04:00 - 05:00 1.00 14 RDMO C/O LOWER RAMS TO 2-7/8 05:00 - 06:00 1.00 14 RDMO PULL BPV, SET TWO WAY CHECK, RIU TO TEST EQUIPMENT. 4/19/2005 06:00 - 13:00 7.00 15 P&A TEST ALL RAMS, CHOKE MANIFOLD VALVES, FLOOR VALVES, TOP DRIVE IBOP'S 250 PSI LOW,5000 PSI HIGH. TEST ANNULAR PREVENTER TO 250 LOW 3500 HIGH. PERFORM ACCUMULATOR TEST. WITNESS OF TEST WAIVED BY LOU GRIMALDI AOGCC FIELD INSPECTOR. 13:00 - 14:00 1.00 49 P&A PULL HANGER TO FLOOR DISCONNECT ESP CABLE, & SSSV CONTROL LINE. LID HGR FILL HOLE WITH 70 BBLS SEAWATER 14:00 - 23:00 9.00 49 P&A POOH LAYING DOWN 2 7/8 TBG TO ESP ASSY 23:00 - 01 :30 2.50 49 P&A LID SUBMERSIBLE PUMPS & HALLIBURTON GAUGE CARRIERS 01:30 - 02:30 1.00 26 P&A CLEAR FLOOR ROUND UP TOOLS FOR EZSV 02:30 - 03:30 1.00 49 P&A PU EZSV & SINGLE IN TO 120' SET & TEST TO 1000 PSI 03:30 - 04:00 0.50 49 P&A STING BACK IN TO EZSV & ESTABLISH INJECTION RATE @5 BBLlMIN 370 PSI. RIU HALLIBURTON 04:00 - 05:15 1.25 49 P&A PUMP 5 BBL WATER, TEST LINES TO 3000 PSI, PUMP 116 BBL 13.2 PPG LEAD FOLLOWED BY 73 BBL 10.7 PPG TAIL UNSTING FROM EZSV & PUMP 2 BBL. CEMENT ON TOP OF PLUG 05:15 - 06:00 0.75 49 P&A PUMP THROUGH DRILL PIPE TO CLEAR CEMENTPOOH LID 4 JT DP. MAKE SERVICE BREAKS & LID EZSV RUNJNING TOOL 4/20/2005 06:00 - 07:00 1.00 12 P&A TEST CMT RETAINER TO 1000 PSI 30 MIN. CEMENT PLUGS & TEST WITNESSED BY JOHN CRISP AOGCC FIELD INSPECTOR 07:00 - 09:30 2.50 19 P&A BRING UP CASING CUTTERS & C/O BLADES. BEGIN REMOVING BOLTS ON STACK 09:30 - 10:00 0.50 19 P&A PULL 7" PACK OFF 10:00 -11:00 1.00 19 P&A M/U 7" CUTTING ASSY & CUT 7" @ 65' 11 :00 - 12:00 1.00 19 P&A LID CSG CUTTER & P/U SPEAR ASSY. PULL 7" CSG 7 LID SAME WITH HANGER 12:00 - 13:30 1.50 19 P&A MU 95/8 CUTTING ASSY & MAKE CUT @ 60' POOHM, BL. DN. TOP DRIVE 13:30 - 15:30 2.00 26 P&A LOAD OUT ESP SPOOL & CABLE & VAC SYSTEM WITH CRANE 15:30 - 21 :00 5.50 14 P&A REMOVE ALL RAMS,SPLlT STACK ND BOPE, 21 :00 - 22:00 1.00 14 P&A REMOVE MULTI BOWL & HGR ASSY 22:00 - 23:00 1.00 19 P&A MU 95/8 SPEAR ASSY, SPEAR INTO & LID 9 5/8 CUT JOINT 23:00 - 00:00 1.00 19 P&A LID SPEAR ASSY & MU 133/8 CUTTER ASSY 00:00 - 01 :00 1.00 19 P&A CUT 13 3/8 CSG @ 50' POOH WITH SPEAR 01 :00 - 02:00 1.00 19 P&A ATTEMPT TO PULL VG STARTING HEAD & 133/8 CUT JOINT CUT JT. WITH SLING & BLOCKS. NO GO 02:00 - 06:00 4.00 19 P&A MU 133/8 SPEAR ASSY & ATTEMPT TO WORK FREE (ORDERED SURFACE JARS & ACCELERATOR, & BUMPER SUB FROM BAKER) CO NT WORK PIPE WHILE WAIT ON TOOLS PULLED 250K OVER & RAISED NO MORE THAN 18" 4/21/2005 06:00 - 07:30 1.50 19 P&A POOH W/ SPEAR & M/U JARS & BUMPER SUB Printed: 4/2512005 11 :20:52 AM . . Legal Well Name: NIKAITCHUQ #4 Common Well Name: NIKAITCHUQ #4 (ALASKA) Spud Date: 2/1/2005 Event Name: PLUG & ABANDON Start: 4/15/2005 End: Contractor Name: NORDIC Rig Release: Group: Rig Name: NORDIC Rig Number: 3 From- To Hours Code Sub Phase iþtiún of Code 4/21/2005 07:30 - 08:00 0.50 19 P&A JAR ON 133/8 CONDUCTOR UNTIL JARS GIVE OUT. MOVED PIPE 3' JARRING WITH 250K. JARS FAILED AFTER 25 BLOWS. 08:00 - 09:00 1.00 26 P&A PUT STEAM HOSE IN CONDUCTOR IN HOPE OF THAWING OUT GROUND BETWEEN PIPE WHILE CHASING REPLACEMENT JARS. 09:00 - 16:30 7.50 19 P&A SPEAR BACK INTO PIPE & PULL 335K (310K OVER) & HOLD TENSION. WORK TENSION FROM OK TO 335 K SEVERAL TIMES. PIPE BEGAN MOVING SLOWLY. WORKED TENSION 315 TO 335k AND WORK PIPE UP TO ROTARY BEAMS PULLING 160K AT END OF STROKE. UNSPEAR & CUT OFF AT GROUND LEVEL AND LAY OUT VG STARTING HEAD AND 23' STUB FROM CELLAR. CONT PULLING PIPE IN WORKABLE INCREMENTS, CUTTING OFF WITH TORCH AND LAYING OUT FROM FLOOR LEVEL. 50 k OVERPULL AT 60' PULLED AND 50K OP AT 80'. ENTIRE 133/8 CONDUCTOR RECOVERED. CASING CUTTER DID NOT PERFORM AS EXPECTED. PIPE WAS PARTIALLY CUT BUT NOT PENETRATED ON OPOSITE SIDES WITH 1 CUT 3 FT ABOVE THE OTHER. 16:30 - 19:00 2.50 12 P&A RlU TO CEMENT RIH TO 55' TAG TOP OF CEMENT ON RETAINER, PUMP 15 BBL 15.6 PPG CLASS G PERMAFROST CEMENT. TOC AT 5' BELOW MUD LINE WASH UP RID CEMENT HEAD & UD 2 JTS DP 19:00 - 00:00 5.00 26 P&A CLEAR FLOOR OF FISHING TOOLS ALL CUT JTS PIPE. MOVE STARTING HEAD OUT OF CELLAR & CLEAN SAME. 00:00 - 06:00 6.00 26 P&A CLEAN RIG IN PREPARATION FOR MOVE, WAIT ON DECISION FROM TOWN AS TO WETHER RIG WILL DECOMPLETE NIK # 3 4/22/2005 Printed: 4/25/2005 11 :20:52 AM . . Halliburton Global Survey: Start Date: Company: Engineer: Tool: Tied-to: Field: NW Milne Point Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Modet: Alaska, Zone 4 Well Centre bggm2004 Site: Spy Island Site Position: Northing: 6054881.08 ft Latitude: 70 33 39.985 N From: Map Easting: 519518.28 ft Longitude: 149 50 23.590 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.15 deg Well: Nikaitchuq #4 Slot Name: Well Position: +N/-S -53.03 ft Northing: 6054828.38 ft Latitude: 70 33 39.464 N +E/-W 124.58 ft Easting : 519642.99 ft Longitude: 149 50 19.911 W Position Uncertainty: 0.00 ft --~-- Wellpath: Nikaitchuq #4 506292324100 Current Datum: Nik#4: Magnetic Data: 1/31/2005 Field Strength: 57594 nT Vertical Section: Depth From (TVD) ft 30.06 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 ------- Nikaitchuq #4PB1 2842.58 ft Mean Sea Level ,/ 24.43 deg 80.89 deg Direction deg 324.15 ~---~_. Height 31.26 ft ~-'------ -'-- -~---. Survey Program for Definitive Wellpath Date: 3/23/2005 Validated: No Actual From To Survey ft ft 204.13 2842.58 2863.00 7577.00 Version: 2 Toolcode Tool Name Nikaitchuq #4PB1 (204.13-4310.00) (1) Nikaitchuq #4 (2863.00-7577.00) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey .-~--_.~".. Iuel Azim TVD Sys TVD N/S E/W MapN MapE dég deg ft ft ft ft ft ft .-------- 30.06 0.00 0.00 30.06 -1.20 0.00 0.00 6054828.38 519642.99 TIE LINE 204.13 2.81 82.61 204.06 172.80 0.56 4.32 6054828.95 519647.31 MWD+IFR-AK-CAZ-SC 294.31 2.30 74.73 294.15 262.89 1.32 8.26 6054829.72 519651.25 MWD+IFR-AK-CAZ-SC 386.47 1.24 69.66 386.26 355.00 2.16 10.98 6054830.56 519653.96 MWD+IFR-AK-CAZ-SC 477.59 1.41 75.96 477.36 446.10 2.77 12.99 6054831.18 519655.97 MWD+IFR-AK-CAZ-SC 568.76 1.06 89.85 568.51 537.25 3.04 14.93 6054831.46 519657.91 MWD+IFR-AK-CAZ-SC 660.79 1.63 83.70 660.51 629.25 3.19 17.08 6054831.62 519660.06 MWD+IFR-AK-CAZ-SC 754.38 1.60 64.75 754.07 722.81 3.89 19.58 6054832.33 519662.56 MWD+IFR-AK-CAZ-SC 849.15 1.85 55.12 848.79 817.53 5.33 22.03 6054833.77 519665.01 MWD+IFR-AK-CAZ-SC 943.44 2.05 61.74 943.03 911.77 7.00 24.77 6054835.45 519667.74 MWD+IFR-AK-CAZ-SC 1039.73 1.24 68.30 1039.28 1008.02 8.20 27.25 6054836.65 519670.22 MWD+IFR-AK-CAZ-SC 1134.68 1.30 78.64 1134.21 1102.95 8.79 29.26 6054837.25 519672.23 MWD+IFR-AK-CAZ-SC 1228.46 1.36 92.64 1227.96 1196.70 8.95 31.42 6054837.42 519674.38 MWD+IFR-AK-CAZ-SC 1324.18 1.47 103.37 1323.65 1292.39 8.62 33.75 6054837.09 519676.71 MWD+IFR-AK-CAZ-SC 1418.77 1.38 110.56 1418.21 1386.95 7.94 35.99 6054836.41 519678.96 MWD+IFR-AK-CAZ-SC 1513.81 1.42 111.83 1513.22 1481.96 7.10 38.16 6054835.58 519681.13 MWD+IFR-AK-CAZ-SC 1608.98 1.41 115.25 1608.36 1577.10 6.16 40.31 6054834.64 519683.28 MWD+IFR-AK-CAZ-SC 1704.65 1.63 109.84 1704.00 1672.74 5.19 42.66 6054833.69 519685.63 MWD+IFR-AK-CAZ-SC -'-_..- . . Halliburton Global Date: Co-ordinat Verti~ª'( S¢~tion (VS $*rveyÇal~,ulation 1\fet\îód: Survey TVD N/S ft ft 1798.11 1.77 114.05 1797.42 1766.16 4.15 45.23 6054832.65 519688.20 MWD+IFR-AK-CAZ-SC 1894.41 1.72 107.72 1893.68 1862.42 3.11 47.96 6054831.62 519690.94 MWD+IFR-AK-CAZ-SC 1989.13 1.59 106.24 1988.36 1957.10 2.31 50.58 6054830.82 519693.55 MWD+IFR-AK-CAZ-SC 2084.30 1.60 110.18 2083.49 2052.23 1.48 53.09 6054830.00 519696.07 MWD+IFR-AK-CAZ-SC 2179.53 1.63 102.66 2178.68 2147.42 0.73 55.66 6054829.25 519698.64 MWD+IFR-AK-CAZ-SC 2274.24 1.46 104.19 2273.36 2242.10 0.13 58.14 6054828.67 519701.13 MWD+IFR-AK-CAZ-SC 2369.41 1.48 106.06 2368.50 2337.24 -0.50 60.50 6054828.04 519703.49 MWD+IFR-AK-CAZ-SC 2463.52 1.64 103.97 2462.57 2431.31 -1.16 62.98 6054827.38 519705.96 MWD+IFR-AK-CAZ-SC 2557.62 1.47 107.42 2556.64 2525.38 -1.85 65.43 6054826.70 519708.42 MWD+IFR-AK-CAZ-SC 2652.42 1.34 106.38 2651.41 2620.15 -2.53 67.66 6054826.03 519710.65 MWD+IFR-AK-CAZ-SC 2747.56 1.10 87.06 2746.53 2715.27 -2.79 69.64 6054825.77 519712.63 MWD+IFR-AK-CAZ-SC 2842.58 1.43 84.79 2841.52 2810.26 -2.64 71.73 6054825.93 519714.72 MWD+IFR-AK-CAZ-SC 2863.00 1.39 86.32 2861.94 2830.68 -2.60 72.23 6054825.97 519715.22 MWD+IFR-AK-CAZ-SC 2937.44 1.44 322.11 2936.37 2905.11 -1.80 72.56 6054826.77 519715.54 MWD+IFR-AK-CAZ-SC 3032.66 5.13 323.79 3031.41 3000.15 2.58 69.31 6054831.14 519712.28 MWD+IFR-AK-CAZ-SC 3127.98 9.49 326.59 3125.94 3094.68 12.58 62.46 6054841.12 519705.41 MWD+IFR-AK-CAZ-SC 3223.17 14.31 322.16 3219.05 3187.79 28.43 50.91 6054856.94 519693.82 MWD+IFR-AK-CAZ-SC 3318.79 18.95 316.46 3310.66 3279.40 49.03 32.96 6054877 .49 519675.81 MWD+IFR-AK-CAZ-SC 3413.84 23.35 310.10 3399.29 3368.03 72.36 7.90 6054900.76 519650.70 MWD+IFR-AK-CAZ-SC 3508.95 28.44 308.91 3484.83 3453.57 98.75 -24.16 6054927.05 519618.57 MWD+IFR-AK-CAZ-SC 3604.54 33.88 311.00 3566.60 3535.34 130.55 -62.01 6054958.75 519580.64 MWD+IFR-AK-CAZ-SC 3697.87 39.38 312.76 3641.47 3610.21 167.75 -103.41 6054995.83 519539.14 MWD+IFR-AK-CAZ-SC 3793.61 43.66 311.69 3713.13 3681.87 210.37 -150.41 6055038.33 519492.03 MWD+IFR-AK-CAZ-SC 3887.04 47.79 310.32 3778.35 3747.09 254.23 -200.90 6055082.05 519441.44 MWD+IFR-AK-CAZ-SC 3984.16 52.98 309.42 3840.25 3808.99 302.15 -258.32 6055129.82 519383.90 MWD+IFR-AK-CAZ-SC 4078.31 57.19 309.61 3894.13 3862.87 351.27 -317.86 6055178.77 519324.23 MWD+IFR-AK-CAZ-SC 4173.49 62.35 309.77 3942.03 3910.77 403.77 -381.12 6055231.10 519260.84 MWD+IFR-AK-CAZ-SC 4268.85 65.62 310.64 3983.85 3952.59 459.09 -446.55 6055286.24 519195.27 MWD+IFR-AK-CAZ-SC 4363.02 69.24 310.25 4019.99 3988.73 515.49 -512.72 6055342.46 519128.95 MWD+IFR-AK-CAZ-SC 4458.12 72.06 311.69 4051.50 4020.24 574.32 -580.46 6055401.10 519061.07 MWD+IFR-AK-CAZ-SC 4552.91 71.66 311.77 4081.01 404\H5 634.28 -647.68 6055460.87 518993.69 MWD+IFR-AK-CAZ-SC 4648.88 75.77 312.01 4107.92 4076.66 695.77 -716.24 6055522.18 518924.98 MWD+IFR-AK-CAZ-SC 4743.72 77.49 312.83 4129.85 4098.59 758.01 -784.35 6055584.24 518856.71 MWD+IFR-AK-CAZ-SC 4801.70 77.69 313.34 4142.31 4111.05 796.69 -825.71 6055622.80 518815.26 MWD+IFR-AK-CAZ-SC 4899.23 82.88 315.61 4158.76 4127.50 864.03 -894.26 6055689.95 518746.53 MWD+IFR-AK-CAZ-SC 4944.03 88.02 318.39 4162.31 4131.05 896.68 -924.70 6055722.51 518716.00 MWD+IFR-AK-CAZ-SC 4993.44 88.64 324.70 4163.76 4132.50 935.33 -955.40 6055761.08 518685.20 MWD+IFR-AK-CAZ-SC 5039.61 89.51 326.86 4164.50 4133.24 973.50 -981.36 6055799.18 518659.15 MWD+IFR-AK-CAZ-SC 5099.28 89.01 329.19 4165.27 4134.01 1024.11 -1012.96 6055849.70 518627.42 MWD+IFR-AK-CAZ-SC 5134.14 89.45 330.08 4165.74 4134.48 1054.19 -1030.58 6055879.72 518609.72 MWD+IFR-AK-CAZ-SC 5179.09 90.80 330.97 4165.64 4134.38 1093.32 -1052.69 6055918.79 518587.51 MWD+IFR-AK-CAZ-SC 5229.13 89.57 329.97 4165.48 4134.22 1136.85 -1077.36 6055962.26 518562.73 MWD+IFR-AK-CAZ-SC 5278.45 93.09 330.76 4164.34 4133.08 1179.70 -1101.73 6056005.04 518538.24 MWD+IFR-AK-CAZ-SC 5323.22 91.05 330.55 4162.72 4131.46 1218.70 -1123.66 6056043.98 518516.22 MWD+IFR-AK-CAZ-SC 5373.00 87.96 329.99 4163.15 4131.89 1261.92 -1148.34 6056087.13 518491.42 MWD+IFR-AK-CAZ-SC 5418.59 89.20 331.05 4164.28 4133.02 1301.60 -1170.77 6056126.74 518468.89 MWD+IFR-AK-CAZ-SC 5464.03 92.22 331.56 4163.72 4132.46 1341.45 -1192.58 6056166.53 518446.97 MWD+IFR-AK-CAZ-SC 5513.96 90.86 331.44 4162.37 4131.11 1385.31 -1216.40 6056210.32 518423.04 MWD+IFR-AK-CAZ-SC 5558.88 89.20 331.28 4162.35 4131.09 1424.73 -1237.93 6056249.68 518401.41 MWD+IFR-AK-CAZ-SC 5608.70 89.01 330.84 4163.13 4131.87 1468.33 -1262.03 6056293.21 518377.19 MWD+IFR-AK-CAZ-SC 5660.58 89.94 330.54 4163.60 4132.34 1513.56 -1287.43 6056338.37 518351.68 MWD+IFR-AK-CAZ-SC 5706.12 90.00 330.49 4163.63 4132.37 1553.20 -1309.84 6056377.95 518329.16 MWD+IFR-AK-CAZ-SC . . Halliburton Global Survey SysTVD N/S ft ft 5749.96 89.26 330.36 4163.91 4132.65 1591.33 -1331.48 6056416.02 518307.43 MWD+IFR-AK-CAZ-SC 5801.31 88.70 330.51 4164.83 4133.57 1635.99 -1356.81 6056460.60 518281.98 MWD+IFR-AK-CAZ-SC 5851.41 88.58 330.45 4166.01 4134.75 1679.57 -1381.49 6056504.12 518257.19 MWD+IFR-AK-CAZ-SC 5896.40 89.44 330.90 4166.79 4135.53 1718.79 -1403.52 6056543.27 518235.06 MWD+IFR-AK-CAZ-SC 5948.19 89.38 330.49 4167.33 4136.07 1763.95 -1428.87 6056588.36 518209.59 MWD+IFR-AK-CAZ-SC 5991.26 90.25 330.58 4167.46 4136.20 1801.45 -1450.05 6056625.80 518188.31 MWD+IFR-AK-CAZ-SC 6041.68 90.06 330.07 4167.33 4136.07 1845.26 -1475.02 6056669.53 518163.23 MWD+IFR-AK-CAZ-SC 6086.06 89.07 328.58 4167.66 4136.40 1883.42 -1497.66 6056707.64 518140.49 MWD+IFR-AK-CAZ-SC 6140.41 88.40 327.79 4168.86 4137.60 1929.60 -1526.30 6056753.73 518111.73 MWD+IFR-AK-CAZ-SC 6181.68 90.25 327.99 4169.35 4138.09 1964.55 -1548.23 6056788.62 518089.70 MWD+IFR-AK-CAZ-SC 6234.41 89.75 327.58 4169.35 4138.09 2009.16 -1576.35 6056833.15 518061.48 MWD+IFR-AK-CAZ-SC 6277 .34 89.26 327.74 4169.72 4138.46 2045.43 -1599.31 6056869.36 518038.42 MWD+IFR-AK-CAZ-SC 6326.07 88.52 328.09 4170.67 4139.41 2086.71 -1625.19 6056910.56 518012.44 MWD+IFR-AK-CAZ-SC 6373.02 87.59 327.64 4172.26 4141.00 2126.44 -1650.15 6056950.23 517987.37 MWD+IFR-AK-CAZ-SC 6420.47 89.81 329.80 4173.34 4142.08 2166.98 -1674.77 6056990.70 517962.64 MWD+IFR-AK-CAZ-SC 6467.73 89.44 330.39 4173.64 4142.38 2207.95 -1698.34 6057031.60 517938.97 MWD+IFR-AK-CAZ-SC 6515.29 88.83 330.04 4174.36 4143.10 2249.22 -1721.96 6057072.80 517915.24 MWD+IFR-AK-CAZ-SC 6562.61 87.35 329.06 4175.94 4144.68 2289.99 -1745.93 6057113.50 517891.17 MWD+IFR-AK-CAZ-SC 6608.25 90.12 329.70 4176.95 4145.69 2329.25 -1769.16 6057152.70 517867.83 MWD+IFR-AK-CAZ-SC 6657.62 88.83 329.97 4177.40 4146.14 2371.93 -1793.97 6057195.31 517842.92 MWD+IFR-AK-CAZ-SC 6706.23 91.48 331.01 4177.27 4146.01 2414.23 -1817.91 6057237.54 517818.86 MWD+IFR-AK-CAZ-SC 6751.83 89.14 330.24 4177.02 4145.76 2453.97 -1840.28 6057277.21 517796.40 MWD+IFR-AK-CAZ-SC 6813.37 87.78 329.90 4178.68 4147.42 2507.28 -1870.97 6057330.44 517765.56 MWD+IFR-AK-CAZ-SC 6848.17 87.59 329.94 4180.08 4148.82 2537.37 -1888.40 6057360.48 517748.06 MWD+IFR-AK-CAZ-SC 6896.20 87.90 330.93 4181.97 4150.71 2579.11 -1912.08 6057402.15 517724.27 MWD+IFR-AK-CAZ-SC 6942.18 91.36 331.12 4182.27 4151.01 2619.33 -1934.35 6057442.31 517701.90 MWD+IFR-AK-CAZ-SC 6992.03 91.67 331.87 4180.95 4149.69 2663.12 -1958.13 6057486.03 517678.00 MWD+IFR-AK-CAZ-SC 7036.49 90.49 332.24 4180.11 4148.85 2702.39 -1978.96 6057525.24 517657.07 MWD+IFR-AK-CAZ-SC 7084.36 89.38 331.70 4180.17 4148.91 2744.64 -2001.46 6057567.43 517634.46 MWD+IFR-AK-CAZ-SC 7132.16 88.46 331.69 4181.07 4149.81 2786.72 -2024.12 6057609.44 517611.69 MWD+IFR-AK-CAZ-SC 7180.29 88.64 331.78 4182.29 4151.03 2829.10 -2046.90 6057651.76 517588.80 MWD+IFR-AK-CAZ-SC 7226.83 88.46 330.50 4183.46 4152.20 2869.84 -2069.36 6057692.44 517566.24 MWD+IFR-AK-CAZ-SC 7272.86 90.25 332.65 4183.98 4152.72 2910.32 -2091.26 6057732.85 517544.22 MWD+IFR-AK-CAZ-SC 7322.64 89.38 332.12 4184.14 4152.88 2954.42 -2114.34 6057776.89 517521.04 MWD+IFR-AK-CAZ-SC 7372.19 89.32 332.41 4184.70 4153.44 2998.28 -2137.40 6057820.68 517497.86 MWD+IFR-AK-CAZ-SC 7417.40 90.31 331.62 4184.85 4153.59 3038.20 -2158.61 6057860.54 517476.55 MWD+IFR-AK-CAZ-SC 7468.08 89.14 332.09 4185.09 4153.83 3082.89 -2182.52 6057905.16 517452.52 MWD+IFR-AK-CAZ-SC 7511.90 90.19 329.88 4185.35 4154.09 3121.20 -2203.77 6057943.42 517431.17 MWD+IFR-AK-CAZ-SC J 7577.00 90.19 329.88 4185.13 4153.87 3177.51 -2236.44 6057999.64 517398.36 MWD+IFR-AK-CAZ-SC _~__n___'__..____ . Halliburton Global .EFI ITI E . -- Company: Field: Site: Well: Wellpath: Field: Kerr McGee NW Milne Point Spy Island Nikaitchuq #4 Nikaitchuc¡#4PB 1 NW Milne Point Date: 9/21/2005 Time: 15:33:16 Page: Co"ordinate(NE) Reference: Wèlt: Nikaitchuq#4, True North Vertical (TVD) Reference: Nik#4: 31.3 Section (VS) Reference: Welt (0.QON,0.00E,324.15Azi) Survey Calculation Method: Minimum Curvature Db: O~"~~ -I ----~ I I Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Welt Centre bggm2004 Well: Nikaitchuq #4 Slot Name: Well Position: +N/-S -53.03 ft Northing: 6054828.38 ft Latitude: +E/-W 124.58 ft Easting: 519642.99 ft Longitude: Position Uncertainty: 0.00 ft 70 33 39.464 N 149 50 19.911 W +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Welt Ref. Point 30.06 ft Mean Sea Level 24.43 deg 80.89 deg Direction deg 324.15 Wellpath: Nikaitchuq #4PB1 50629232417000 Current Datum: Nik#4: Magnetic Data: 1/31/2005 Field Strength: 57594 nT Vertical Section: Depth From (TVD) ft 30.06 Height 31 .26 ft Survey Program for Definitive Wellpath Date: 3/23/2005 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft -- 204.13 4246.84 Nikaitchuq #4PB1 (204.13-4246.84) MWD+IFR-AK-CAZ-SCMWD+IFR AK CAZ SCC -- Survey MD Incl Azim TVD Sys TVD N/S EIW MapN MapE TóOl ft dèg deg ft ft ft ft ft ft 30.06 0.00 0.00 30.06 -1.20 0.00 0.00 6054828.38 519642.99 TIE LINE 204.13 2.81 82.61 204.06 172.80 0.55 4.23 6054828.94 519647.22 MWD+IFR-AK-CAZ-SC 294.31 2.30 74.73 294.15 262.89 1.31 8.17 6054829.71 519651.16 MWD+IFR-AK-CAZ-SC 386.47 1.24 69.66 386.27 355.01 2.14 10.89 6054830.55 519653.87 MWD+IFR-AK-CAZ-SC 477.59 1.41 75.96 477.36 446.10 2.76 12.90 6054831.17 519655.88 MWD+I FR-AK-CAZ-SC 568.76 1.06 89.85 568.51 537.25 3.03 14.83 6054831.45 519657.81 MWD+I FR-AK-CAZ-SC 660.79 1.63 83.70 660.51 629.25 3.18 16.98 6054831.60 519659.96 MWD+IFR-AK-CAZ-SC 754.38 1.60 64.75 754.07 722.81 3.88 19.49 6054832.31 519662.47 MWD+IFR-AK-CAZ-SC 849.15 1.85 55.12 848.79 817.53 5.32 21.94 6054833.76 519664.91 MWD+I FR-AK-CAZ -SC 943.44 2.05 61.74 943.03 911.77 6.99 24.68 6054835.43 519667.64 MWD+I FR-AK-CAZ-SC 1039.73 1.24 68.30 1039.28 1008.02 8.19 27.16 6054836.64 519670.13 MWD+IFR-AK-CAZ-SC 1134.68 1.30 78.64 1134.21 1102.95 8.78 29.17 6054837.24 519672.13 MWD+IFR-AK-CAZ-SC 1228.46 1.36 92.64 1227.96 1196.70 8.94 31.33 6054837.40 519674.29 MWD+IFR-AK-CAZ-SC 1324.18 1.47 103.37 1323.65 1292.39 8.60 33.65 6054837.07 519676.62 MWD+IFR-AK-CAZ-SC 1418.77 1.38 110.56 1418.21 1386.95 7.92 35.90 6054836.40 519678.87 MWD+IFR-AK-CAZ-SC 1513.81 1.42 111.83 1513.23 1481.97 7.08 38.07 6054835.56 519681.03 MWD+IFR-AK-CAZ-SC 1608.98 1.41 115.25 1608.37 1577.11 6.15 40.22 6054834.63 519683.19 MWD+I FR-AK-CAZ-SC 1704.65 1.63 109.84 1704.00 1672.74 5.18 42.56 6054833.67 519685.54 MWD+IFR-AK-CAZ-SC 1798.11 1.77 114.05 1797.42 1766.16 4.14 45.13 6054832.64 519688.11 MWD+IFR-AK-CAZ-SC 1894.41 1.72 107.72 1893.68 1862.42 3.10 47.87 6054831.60 519690.84 MWD+IFR-AK-CAZ-SC 1989.13 1.59 106.24 1988.36 1957.10 2.30 50.48 6054830.81 519693.46 MWD+IFR-AK-CAZ-SC 2084.30 1.60 110.18 2083.49 2052.23 1.47 53.00 6054829.99 519695.98 MWD+I FR-AK-CAZ-SC 2179.53 1.63 102.66 2178.68 2147.42 0.71 55.57 6054829.24 519698.55 MWD+IFR-AK-CAZ-SC 2274.24 1.46 104.19 2273.36 2242.10 0.12 58.05 6054828.66 519701.04 MWD+IFR-AK-CAZ-SC 2369.41 1.48 106.06 2368.50 2337.24 -0.51 60.41 6054828.03 519703.39 MWD+IFR-AK-CAZ-SC 2463.52 1.64 103.97 2462.57 2431.31 -1.18 62.88 6054827.37 519705.87 MWD+I FR-AK-CAZ-SC 2557.62 1.47 107.42 2556.64 2525.38 -1.86 65.34 6054826.69 519708.33 MWD+I FR-AK-CAZ-SC 2652.42 1.34 106.38 2651.41 2620.15 -2.54 67.56 6054826.02 519710.55 MWD+IFR-AK-CAZ-SC 2747.56 1.10 87.06 2746.53 2715.27 -2.81 69.54 6054825.76 519712.53 MWD+I FR-AK-CAZ-SC 2842.58 1.43 84.79 2841.52 2810.26 -2.65 71.64 6054825.92 519714.63 MWD+ FR-AK-CAZ-SC --~..- _____L ().ß tf---~ ~ð # . Halliburton . Global CQmpany: KerrMcGee Date: 9/21/2005 Time: 15:33:16 Page: 2 Field: NWMilne Point CQ-Qrdinate(NE) Reference: Well: Nikaitchuq #4, True North Site: Spy Island Vertical (TVD) Reference: Nik#4: 31.3 Well: Nikaitchuq #4 Section (VS) Referençe: Well (0.00N,0,00E,324.15Azi) Wellpath: Nikaitchuq #4PB1 Survey Calculation MethQd: Minimum Curvature Db: Oracle --- Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE TQQI ft deg deg ft ft ft ft ft ft 2937.80 1.27 92.64 2936.72 2905.46 -2.59 73.87 6054825.98 519716.86 MWD+I FR-AK-CAZ-SC 3032.57 1.23 86.90 3031.47 3000.21 -2.59 75.94 6054826.00 519718.93 MWD+IFR-AK-CAZ-SC 3128.01 1.47 74.79 3126.88 3095.62 -2.21 78.14 6054826.38 519721.13 MWD+I FR-AK-CAZ-SC 3223.00 1.30 76.02 3221.84 3190.58 -1.63 80.36 6054826.96 519723.35 MWD+IFR-AK-CAZ-SC 3317.74 1.44 75.10 3316.55 3285.29 -1.06 82.56 6054827.54 519725.54 MWD+IFR-AK-CAZ-SC 3413.53 1.27 84.57 3412.32 3381.06 -0.65 84.78 6054827.95 519727.76 MWD+I FR-AK-CAZ-SC 3508.64 1.19 82.22 3507.41 3476.15 -0.42 86.80 6054828.19 519729.79 MWD+I FR-AK-CAZ-SC 3603.20 1.10 92.14 3601.95 3570.69 -0.32 88.68 6054828.29 519731.67 MWD+IFR-AK-CAZ-SC 3698.56 1.02 85.67 3697.29 3666.03 -0.29 90.45 6054828.33 519733.43 MWD+I FR-AK-CAZ-SC 3792.50 0.98 99.38 3791.22 3759.96 -0.36 92.07 6054828.27 519735.05 MWD+I FR-AK-CAZ-SC 3888.81 1.22 95.55 3887.51 3856.25 -0.59 93.90 6054828.04 519736.89 MWD+I FR-AK-CAZ-SC 3983.27 1.39 91.45 3981.94 3950.68 -0.72 96.05 6054827.92 519739.03 MWD+I FR-AK-CAZ-SC 4058.93 1.27 88.60 4057.58 4026.32 -0.72 97.81 6054827.92 519740.79 MWD+IFR-AK-CAZ-SC 4115.93 1.34 87.42 4114.57 4083.31 -0.68 99.10 6054827.97 519742.09 MWD+IFR-AK-CAZ-SC 4211.39 1.13 95.63 4210.01 4178.75 -0.72 101.16 6054827.93 519744.14 MWD+IFR-AK-CAZ-SC 4246.84 1.14 98.49 4245.45 4214.19 -0.80 101.85 6054827.85 519744.83 MWD+IFR-AK-CAZ-SC 4310.00 1.14 98.49 4308.60 4277.34 -0.99 103.10 6054827.66 519746.08 PROJECTED to TD April 2i\ 2005 . , Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No. 12 4/15/05 4/16105 4/17/05 4/18/05 4/19105 4/20105 4/21/05 7.577' MD I 4.186' TVD Shut in. W/O P & A. 7.577' MD 14.1 86' TVD Shut in. W/O P & A. 7.577' MD I 4.186' TVD Moved in Nordic 3. Well on vacuum. Set BPV. Filled the tubing and annulus with brine. NID Tree. NIU BOPE. Pulled BPV. Set TWC. 7.577' MD 14.186' TVD TestedBOPE., :LID the tubing and ,ESP assembly. RIH and set EZSV at 120' MD~ Tested,EZSV to 1000 psi. Down-squeezed Nikaitchuq #4 with 191 bblof cement as per program. Dumped the last 2 bbl of cement on top ofthe EZWSV. 7.577'MD I 4.186' TVD Tested EZSV to 1000 psi. Pull 7" packoff. Cut 7" casing at 65' MD. Speared and LID 7" stub. Cut 9-5/8" casing at 60' MD. N/D BOP's. NID wellhead. Speared and LID the 9-5/8" stub. Cut the 13-3/8" casing at 50' MD. Speared and attempted to pull the 13-3/8" stub: negative. W/O jars. 7.577' MD I 4.186' TVD Jarred 13-3/8" conductor out: the cut was not completed. Laid down the 13-3/8" conductor. RIH to 55' MD with 4" DP. Tagged cement at 55' MD. Spotted 15.bbl of 15.6 ppg Permafrost C cement from 55' up to the mud line. LDDP. 7.577' MD I 4.186' TVD Cleared the floor. Cleaned pits, etc. Released the rig. P & A. Final Report. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 MC 25.230 ?T-Þ ~() i-( ~.~ lc CY Name of Operator: Kerr-McGee Oil & Gas Corp. 1. Well No. 2. API No. 50-XXX-XXXXX-XX-XX 3. Type (see instruct. ) Field and Pool: Exploration 4. Field & 5. Method Pool Code (see instruct.) 6. Days in Oper. 7. Tubing PSIG IMonth and Year: DAILY AVG. PRODUCTION 8. OIL 9. WATER 10. GAS (BBL) (BBL) (MCF) Mar-05 TOTAL MONTHLY PRODUCTION 11. OIL 12. WATER 13. GAS (BBL) (BBL) (MCF) 4 50-629-23241-00-X01 388582 7.2 70 853.61 0.97 65.69 6146 7 473 .1 Note: Test Production, Exploratory Well (Nikaitchuq #4) I I . I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Printed Name: Ricky D Gravesmill Title: Staff Accountant ~ ~ .. Signature: r:f) .V~~ Form 10-405 Rev. 1 /2003 Date: 4/18/2005 INSTRUCTIONS ON REVERSE SIDE TOTAL 6146 7 473 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 12. Facility Name Disposition 3. Field Exploration Volume MCF 14. Operator 15. MonthlYear of Disposition Kerr-McGee Oil & Gas Corp. Mar-05 20. For production from multiple pools, list contribution of each pool as a percent of Tota/ Volume. 6. Sold o Pool Name Pool Code Percent 7. Reinjected o 8. Flared or vented 1 hour or less o . 9. Flared or vented more than 1 hour (see instr.) 473 10. Pilot and Purge o 11. Used for lease operations (specify in Remarks) o 12. Other (see instructions) o Lease Use MCF MCF MCF MCF Date . Authorization >1 hr: Safety 13. TOTAL VOLUME (ITEMS 6-12) 473 14. NGL Gas Equivalent Conservation 15. Purchased gas Waste: 16. Transferred from: Commissioner 17. Transferred to: (Express as a negative #) 18. Remarks: Note: Test Production, Exploratory Well I hereby certify that the foregoing is true and correct to the best of my knowledge. Sigoatme ~ <Í>. ~ Printed Name Ricky D Gravesmill Phone (281) 673 6542 Date 4/18/2005 Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 600 F. Authority 20 AAC25.235. Title Staff Accountant Form 10-422 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate . . Kerr-McGee Oil & Gas Corp. Excess Flare Report March 2005 Production Support of Form 10-422 Field Exploration Gas Flared 473 # Hours Produced 173 Start Date 3/1/2005 End Date 3/11/2005 All gas flared during well test of Nikaitchuq #4 as approved by Explanation state. . . Kerr-McGee Oil & Gas Corp. Well Day Report March 2005 Production Well # 4 API # 50-629-23241-00-X01 # Hours Produced 173 Well Days 7.2 April 15th, 2005 . Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No. 11 4/08/05 4/09/05 4/10105 4/11/05 4/12/05 4/13/05 4/14/05 7,577' MD I 4,186' TVD Shut in. 7,577' MD I 4,186' TVD Shut in 7,577' MD I 4,186' TVD RID Halliburton. Tied into 7" x 9-5/8" annulus. SICP = 225 psi. Established injection rate: 3 bbl/min at 310 psi. Down-squeezed the annulus with 78 sx (58 bbl) of Penna frost L followed by 91 sx (15.5 bbl) ofPennaftost C. Down- squeezed at 3 bbl/min and 250 to 560 psi. Displaced with 1.5 bbl of diesel. Shut down and trapped 400 psi on the annulus. RID Halliburton. wac. 7,577' MD I 4,186' TVD WOC. Tied in test pump to 7" x 9-5/8" annulus. SICP = 300 psi. Tested Down- Squeeze" to 1550 psi for 30 minutes: good test. AOGCC field inspector waived witnessing the MIT. 7,577' MD 14,186' TVD Shut in. W/O P & A. 7,577' MD I 4,186' TVD Shut in. WIO P & A 7,577' MD I 4,186' TVD Shut in. W/O P & A with Nordic 3. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P. I. Supervisor . K<é?f1 "5 ( ( 01 0') DATE: April 19, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Permanent Abandonment Cement Plug Kerr-McGee Nikaitchug #4 PTD 204-260 April 19, 2005: I traveled to Kerr-McGee's Exploratory well Nikaitchuq #4 to witness a cement job for permanent abandonment. Nordic Rig 3 is performing work for Kerr-McGee on this well. The Rig was filling hole wI 8.5 PPG Seawater ( after POOH wI tubing & ESP) when I arrived on Rig Floor. Estimated 10 BPH to keep the hole full. I witnessed a Halliburton EZSV bridge plug RIH in the 7" casing to a measured depth of 120'. BP was set & tested to 1000 psi. After PT of BP the Rig established an !r.jsction rate of 5 BPM 370 psi. 114 bbls 13.2 ppg class G lead cement was pumped thru EZSV at a rate of 4.5 bpm 325 psi. Lead was followed by 77 bbl's 10.7 type L tail cement @ 4.5 bpm 200 psi. 2 bb! of tail cement was left on top of BP after the Drill Pipe & stinger was POOH. Post cement job pressure test of the Bridge Plug was performed with blind rams closed after POOH. PT was witnessed to 1000 psi. for 30 minutes. No problems witnessed. Summary: I witnessed a permanent abandonment cement job on Kerr-McGee's Exploratory well Nikaitchuq #4. Attachments: None Confidential Cement Job Nikaitchuq #404-19-05 JC.doc · ¡-;;::¡ î ¡ I!=! ! ¡ i :j ;k.,j I. ~oi-;l/bcJ ¡ ¡ I FRANK H. MURKOWSKI, GOVERNOR ~ .,.\..fi11iA. OIL AND GAS CONSERVATION COMMISSION j I J , ! 333 W. 7'" AVENUE, SUITE 100 l ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Todd Durkee Drilling Manager Kerr McGee Oil & Gas Corporation 3900 C Street, Suite 744 Anchorage, AK 99503 Re: Nikaitchuq #4 Sundry Number: 305-083 Dear Mr. Durkee: 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 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Daniel T. Seamount, Jr. Commissioner DATED this II day of April, 2005 Encl. . @J KE1JR.Ml:6EE CIJRPORATIOI . April 5th, 2005 RECEIVED APR ~" 5 Z005 AI..h all & Oil Con.. Cørnmic.ion Anchareg_ Commissioner Alaska Oil and Gas Conservation Commission 333 W ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq #4: APD 204-260 Kerr McGee Oil & Gas Corporation Application for Sundry Approval: Plug & Abandonment /,..?1 '~O ç -0 <0 ~ The Application for Sundry Approval to "Re-Configure" the completion is hereby cancelled. Attached for your review is a new Application for Sundry Approval. Form 10-403. This new Application for Sundry Approval is to plug and abandon the well using Nordic 3. It is planned to carry out this operation immediately after Nordic 3 completes Nikaitchuq #3. One additional Application for Sundry Approval was verbally approved and then formally submitted on April 4th, 2005. That Application for Sundry Approval was for a down-squeeze of the 9-5/8" x 7" casing annulus. This new Application assumes that the down-squeeze will have already been done. Sincerely, ~yn~ ASRC Energy Services Project Drilling Supt. Attachments: Nikaitchuq #4 Plug and Abandon ProcedureCurrent Nikaitchuq #4 Wellbore Schematic Nikaitchuq #4 Proposed Wellbore Schematic 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 l\ i-\ L. (907)-339-6370 a STATE OF AlASKA .~ REC~IVË6k A~ Oil AND GAS CONSERVATION CO~ION ¡. APPLICATION FOR SUNDRY APPROVAL APR - 5 Z005 &1, '3 Perforate U Alaska aQi~~ Cons. Co'W~~~tJ Stimulate D Time Extensio~hOrage Re-enter Suspended Well D 5. Permit to Drill Number: Abandon LJ Alter casing D Change approved program D 2. Operator Name: Kerr McGee Oil & Gas Corporation 1. Type of Request: Suspend U Repair well D Pull Tubing 0 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): 7,577 ft Casing Structural Conductor Surface Intermediate Production Slotted Liner Perforation Depth MD (ft): N/A, Slotted Liner Packers and SSSV Type: 31.5 ft (corrected) ADL: 388582 & ADL: 388583 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development Stratigraphic D D Service Exploratory 0 D 204-260 6. API Number: 50-629-23241-00 9. Well Name and Number: Nikaitchuq #4 10. Field/Pools(s): Exploration ITotal Depth rvD (ft): 4,186 ft Length PRESENT WELL CONDITION SUMMARY EffeCtiVe Depth MD (ft): IEffective Depth TVD (ft): Size MD TVD IJUnk (measured): N/A Collapse 102 ft 2426 ft 13-3/8" 9-5/8" 4818 ft 7" N/A 2,895 ft 3-1/2" perfOration Depth TVD (ft): N/A, Slotted Liner HES WellStar TRSSV 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Todd Durke~ Title Drilling Manager Signature I~QCJ_~ ~Phone 907-339-6370 Date 4/12/2005 Date: Plugs (measured): N/A Burst 133 ft 2457 ft 4851 ft 5020 psi 5750 psi 7240 psi 2260 psi 3090 psi 5410 psi 133 ft 2457 ft 4154 ft 7567 ft 4186 ft ITubing Size: ITubing Grade: 2-7/8" L-80 Packers and SSSV MD (ft): N/A, Slotted Liner N/A, Slotted Liner ITubing MD (ft): 4,500 ft 432' MD 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D D Service D lJi'V-J! ~ Abandoned D WDSPL o D Plugged WINJ Skip Coyner: 907-339-6269 a0 ~Q~ L.1::ú-:;- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness SUndry Number: ..::'~'?S-- c2:3 Plug Integrity .~ BOP Test "Ø. Mechanical Integrity Test D Location Clearance ~ QIh,c <: C,,\.u~\- !:~\ro,~, ~ ,\ "6"" 0. '-, \> \ ~""~ . Subsequent Form Required: L..\ tJ ~ Approved by: OrIginal Signed By DAN SEAMOUNT Form 10-403 Revised 11/2004 RBDMS Bfl APR 11 2005 COMMISSIONER APPROVED BY THE COMMISSION L. Date: '1/ It J 66 (~ \.)1 ¡ Submit in Duplicate . . f.-) KEII MCGEE , t1 'I 1/011 Nikaitchuq #4 Plug and Abandon Drilling Rig: Nordic 3 1 Plug and Abandon Surface Location: 350' FSL & 1460' FWL of Section 16, T14N, R9E UM X = 519,643' Y = 6,054,828' Start Operations: 14/12/05 1 [ Operating Rig days: 12 I TMD: 17,577' TVD: 14,186' 1 BHP: 11694 psi I DF: 131.5 ft I I Objectives: Pull ESP completion. Plug and Abandon Casing - Actual: Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD I TVD MD I TVD N/A 13-5/8" 68# L-80 BTC 102' 31' 133' / 133' 12-1/4" 9-5/8" 40# L-80 BTC 2,426' 31' 2,457' / 2,457' 8-1/2" 7" 26# L-80 BTC 4,820' 31' 4,851' /4,154' 6-1/8" 3-1/2" 9.2# Slotted LNR 2,895' 4,672' 7,567' / 4,186' Producing Reservoir Schrader Bluff, OA sand MD (ft) 4,145/7,577' TVD 4,145 BHP 1,694 KWM Sea Water Overview: · The current ESP completion will be pulled. Then the well will be plugged and abandoned as per AOGCC regulations. · The 7" x 9-5/8" annulus will be down-squeezed before the rig moves on the well. · All three (3) casing strings will be cut off below the mud line. Mosley / Coyner 4/5/2005 . ABANDONMENT PROCEDURE . Lay Down the ESP Completion: The 7" casing and the 2-7/8" tubing are currently loaded with diesel. 1. Circulate (or bullhead) the well with heated seawater at 8.5 ppg. Close the SSSV. Install a BPV. MI & RU Nordic 3. N/D the tree. N/U BOPE. Test BOPE. NOTIFY AOGCC 24 HOURS BEFORE RURT & BOP TEST 2. RlU Cable spooler. LID the tubing and the ESP. Spool up the cable, and recover the gages. Keep the hole full with seawater. Down-Squeeze the OA lateral and 7" Casina: 3. Set a 7" EZSV on tubing at 2:120' RKB and test same to 1000 psi. NOTIFY THE AOGCC WITH 24 HOURS NOTICE THAT THE P&A OF THE PRODUCTION ZONE AND TUBING WILL BE CONDUCTED AS FOLLOWS. 4. Rig up Halliburton and establish injection rate. Test lines to 3000 psi. Mix and pump cement through the EZSV: Plug #2: Down-squeeze the 7 casing and OA Lateral 7" Casing Shoe: 4,851' MD 1 4,154' TVD End of 2-7/8" Tubing (EZSV): 120' MD Top of 3-1/2" slotted liner: 4,672' MD 6-1/8" open hole Fill: 100 ft Excess in Open Hole: 100% Base Permafrost: 2,010' MD 1 TVD Top of Tail Slurry: 70' MD Lead Slurry, Premium + Gel: Lead Slurry Volume: Tail Slurry, Permafrost C: Tail Slurry Volume: Density (ppg) Yield (cu ft 1 sk) Thickening Time Hr: min. 5,001' to 2,010' MD 345 sx /116 bbls 2,010' to 70' RKB 102 sx / 75.4 bbls Lead/G + Gel 13.2 1.89 +1-3:00 Tail 1 TVlJe L 10.7 4.15 6:00+ 5. Pull out of the EZSV. Dump the last 2 bbl of cement on the EZSV. Pull up to 70' RKB and reverse out with seawater. Test the plug to 1000 psi. RID Halliburton. Mosley I Coyner 4/512005 . . Cut Off the Casina Strinas: 6. Retrieve the 7" packoff. RIH with a casing cutter on 4" drill pipe. Cut the 7" casing at +65' RKB. LID the casing cutter. Spear the 7" cut off. LID the 7" cut off. 7. RIH with a casing cutter on 4" drill pipe. Cut the 9-5/8" casing at ±60' RKB. LID the casing cutter. 8. N/D the BOPE and the VETCO Multi-Bowl. 9. Spear the 9-5/8" cut off. LID the 9-5/8" cut off. 10. N/D the VETCO casing head. 11. RIH with a casing cutter on 4" drill pipe. Cut the 13-3/8" casing at ±55' RKB. LID the casing cutter. Spear the 13-3/8" cut off. LID the 13-3/8" cut off. 12. RIH to spot surface plug: Plug #3 (Surface Abandonment) Tail Slurry, Permafrost C: Tail Slurry Volume: 70' to 40' RKB 88 sx 115 bbls Density (ppg) Yield (cu ft I sk) Thickening Time Hr: min. Compressive Strength - PSI Tvøe C Permafrost 15.6 0.95 2:30 13. Clean the location and scrape the ice as directed. Notify AOGCC 1 DNR 1 DEC to inspect the location and issue site clearance certificate or letter. Mosley I Coyner 4/5/2005 - Surf - 500' - 1000' - 1500' -- 2000' - 2500' -- 3000' -- 3500' -- 4000' - 4500' KOP :::: 3000' BUR ~ 6°/100' Pad Elev = 1.0 ft GL to RKB = 30.5 ft Rig RKB = 31.5 ft 2-7/8"" WellStar TRSSV at ± 432' 2-7/8",6.5#, L-80, EUE-M 9-5/8",40#, L-80, BTC-M 2457' MD I TVD LOT = 14.4 ppg EMW 7" H-ES Cementer at 2,834' Tubing Deployed ESP with gauge carriers, in Tangent section at 72° Nikaitchuq #4 (Current ESP Completion) -----------------------------. 3-1/2",9.3#, l-SQ, EUE Slotted Liner: 4672' -7,567' MD I .... ...... - ._..- - _. - - - ...... - - . 6-1/8" 7,577' TMP 4,186' TVD Pilot Hole 4,300' MD 7", 26#, L-80, BTC-Mod 4,851' MD J 4,145' TVD S Coyner 4/10/05 - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' - 4500' KOP ::: 3000' BUR.:: 6°/100' -----------------------------, 3-1/2",9.3#, loBO, EUE Slotted Liner: 4672' - I -------______1 7,577' TMD 4,186' TVD Pad Elev:: 1.0 ft GL to RKB:: 30.5 ft Rig RKB:: 31.5 ft 2-7/8.... WellStar TRSSV at.:!: 432' 2-7/8", 6.5#, L-80, EUE-M Down-Squeeze the 9-5/8" x 7" Annulus 9-5/8", 40#, L-80, BTC-M 2457' MD ! TVD LOT = 14.4 ppg EMW 7" H-ES Cementer at 2,834' Tubing Deployed ESP with gauge carriers, in Tangent section at 72° 4,300' MD Nikaitchuq #4 (After Down-Squeeze) S Coyner 4/10/05 - Surf Cut off casing below mudline - 500' 7" EZSVat 120' MO - 1000' Down-Squeeze the 7" Casing & "OA" lateral - 1500' - 2000' Down-Squeezed 9-5/8" .x 7" Annulus - 2500' 9-5/8", 40#, L-SO, BTC-M 2457' MD I TVD - 3000' - 3500' Nikaitchuq #4 (Plugged and Abandoned) - 4000' ---------------------~----, I ------.--- - 4500' Piiot Hole 4,300' MD ,26#, L-80, 4,851' MOl 6-1/8" ----------______1 OBM TMD 4,186' TVO S Coyner 4/5/05 . . . ~ :g :8 -^r- -L. L 7 ~ ~ ~ ? 6 ~ Þ .~ ,~ -..:::=: -..... ~~ !~ 1:1 ~g~ ~ CI 0 ,..¡ :.ö: &: £ ø w > ~ u~ ...I !iiìi ""t'J ~ . ..... . ..... w EJ ~J. z '":" ::¡ .., ...I ...I ¡¡¡: ~ ... !¡ I: e? ~-5 I~ ~..m II :::r U ¡¡¡ U Ii =æ ~ . -ºdWb. 3-%" EUE §JIØG D51 CI Menufaetur"r Model P"'.<;Run:! Rating ~ ~ ~. Y. If: IBOP 5 000 DBI -(I) !w MsnrJfsctufer Model Pressure Raring ( )~ ~ S·y. IF LowerK.,l1v a.OOO DSI ...Ie => Manufadur9r MedeJ Pff1S8Uffl Rating a:; CI TESC.ø I HI~I. 3-% FH_D~AI 81i1l1 5.000 œl Manufacturer MOdel Pres51Jfe Rallng a:: a:: ~~ Hvdrll GK 5.00D osl ;ÞW Msnufaelurgr Modsl P/'f1#l~re Rating z~ za:: <t1L, 5 w ....::IE .fit!!!r!! "SL· Manual Lø¡;k" 5.000 081 ~~ ManlJfar;turor Modøl Pressure Razing 0 C:JImArðn 3.118- FC S.UBO DSI Manufadurer Mode/ / Size Pressure ~sring Cameron s.1~" FC. HCR 5.000 Elfl Ma"ufSC1urer Modef / Size PrP.Rllure Rating CHOKE LINE VALVES 4 Þ :Ii ~ .J L ~ .ibIffI[ ~ !i 000 ..I c:I ManufaCTurer Mode/ PfflS8UrfI Rl'lting 3 z ¡¡¡ 2 .. 1! \ ~ KEY: 1. Lltndlr'lI Ril 'g. on coflduclor cøslng. 2. Well H..d. on surfaott casing, 3.. Adapter Spool or Flange, as needeð. 4. Single Ram BOP, with pipe rlilrTIS 5. Drilling Spool, 5000 psi. w/2 Side Outtets 6. Double Ram BOP, with pipe rams on top and blind rams on Bottom 7. Annu"r BOP. Hydrll GK 8. Choke Line Valve, Manual Opel'lllion. 3-1/S" x 5,000 psi 9. Choke Une Valve. Hydraulically Operated. 3-118.... x 5.000 p! 1 10. Kill Line Valve. Maflusl Operation, 3-118" x 5.000 psi 11. Kill Line Valve. Manual Operetion. 3-118" x 5.ooQ psi Nordic Rig #3 13·5/8" X 5,000 psi BOP Schematic April st\ 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No.9 4/01/05 7,577' MD 14,1S6' TVD Shut in. 4/02/05 7,577' MD 14,186' TVD Shut in 4/03/05 7,577' MD 14,186' TVD Shut in. W 10 annulus down-squeeze. 4/04/05 7,577' MD 14,186' TVD Shut in. WIO annulus down-squeeze. 4/05105 7,577' MD 14,186' TVD Shut in. W 10 annulus down-squeeze. 4/06/05 7,577' MD 14,186' TVD Shut in. W 10 annulus down-squeeze. 4/07/05 7,577' MD 14,186' TVD Shut in. WIO annulus down-squeeze. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 . (907)-339-6370 [Fwd: FW: Alleged Spill on Nordic 3 at Spy Island that was initially... . . Subject: [Fwd: FW: Alleged Spill on Nordic 3 at Spy Island that was initially Reported to BP] From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Fri, 08 Apr 2005 13:30:27 -0800 To: Jim Regg <jim Jegg@admin.state.ak.us> Jim, Enclosed is a report from KM regarding a "spill" of hydraulic fluid at the Nordic 3 during a BOP test. It makes for interesting reading. Appears there may be a disgruntled employee involved here as well. The report mentions Chuck as being there for the BOP test. I talked to him and he said a DEC person "Amanda" asked him about it on the plane on Wednesday. He said he did not see anything of spill when he was there. His assessment is as mine that the event as described likely happened during the NU when lines were being energized prior to actual testing. I did forward Chuck a copy of the report. Just so you are aware. I don't believe there will be any issue with this, but you never know. Tom -------- Original Message -------- FW: Alleged Spill on Nordic 3 Fri, 08 Apr 2005 14:21:23 -0500 Durkee, Todd <TDURKEE@!(¡"IG. com> tom maunder@aàmin. state. ak. us ,. at Spy Island that was initially Reported to BP Subject: Date: From: To: Thanks for all of your support. :ìÜL\- d-~D Here it is. Regards, */Todd Durkee/* *----------------------------------------------------------* /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: * Durkee, Todd *Sent: * Monday, April 04, 2005 6:34 PM *1'0: * 'Gary Evans@dec.state.ak.us'; 'Ed Meggert@dec.state.ak.us'; 'Lydia Miner@dec.state.ak.us' *Cc: * Stockinger, Michael P.; Wittenbach, Stuart; Guidry, Chad E; Boggan, Stuart *Subject: * Alleged Spill on Nordic 3 at Spy Island that was initially Reported to BP All, Attached is a summary of the investigate carried out on the report of an alleged spill occurring on Nordic 3 at Spy Island. Included with the summary is back up documentation maintained on location as well as written statements from individuals that were onsite at the time of the alleged spill. As you will find in the conclusion of the summary, I believe it is appropriate to consider this issue closed out. If you have any questions or comments with respect to the attached summary or require additional information, please contact me on 907-339-6370. «Summary of alleged spill on Nordic 3.pdf» Regards, */Todd Durkee/* *----------------------------------------------------------* /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**** 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. of alleged spill on Nordic Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/15/20052:22 PM . . ~o l-\ ,'- d-"4> 0 Below is a summary of events and facts associated with the Alleged Spill that was reported to BP (Mark Merrill) on March 30, 2005, March 30. 2005 I received a phone call from Mark Merrill (BP's EH&S Manager, Anchorage) on March 3D, 2005 at approximately 1645 hrs. Mark informed me that he had received an unsolicited call from an anonymous caller about a spill occurring on Nordic 3. Mark said that the caller said he had witnessed a spill of hydraulic fluids resulting from a hydraulic line break on a BOP control line during a BOP test. The caller said the spill was 20 to 25 gallons and was outside of the rig floor structure and on the ice. The caller said he reported this spill to the Driller and the Driller said don't worry about it, it's too small. The caller said the Driller's name was Hal or AI and that two other crew members witnessed the incident and their names were Snow and Steve. The caller also said a Peak truck driver was involved with the dean up with truck 3. When questioned, the caller said the event occurred three to four weeks ago (from the date ofthe call to Mark Merrill on March 30, 2005). The caller informed Mark that he no longer worked for Nordic and currently works for Nabors Drilling. Mark. stated that the individual wanted to remain anonymous and therefore did not provide any information to me on the individual making the call. Mark and I traded phones numbers. Mark said that he would call the individual back and provide him my contact information and encourage him to call me. The call ended. I received a second call from Mark. on March 30, 2005 at approximately 1700 hrs. Mark informed me he had attempted to call the individual back to give him my name and contact information, but was only able to leave a voice message. Mark and I discussed the timing of contacting DEC and NRC. I reviewed the Nordic 3 drilling reports looking for BOP tests. I found BOP tests on March 02, 2005 and March 13, 2005 that fit the caller's time frame. I reviewed documentation to help understand if a spill of any type had been noted. I discussed the situation with Skip Coyner and Jim Mosley to understand if they were aware of an incident. Skip contacted Noel Therrien (Nordic's Superintendent) to discuss the situation. Noel informed Skip he was not aware of any such incident. Noel said he would dig into the information and try to understand who the individual could be. At approximately 1730 hrs I contacted Mike Stockinger (KMG VP-Drilling) and informed him of the alleged spill situation. Mike and I discussed the details (or lack of) and elected not to make DEC and NRC notification at this point due to not having the details pulled together yet. We discussed advising DEC the next day after facts were gathered and the interviews of the Nordic personnel were conducted. At approximately 1800 hrs I contacted Andy Stewart (KMG Comp Engr) on Nordic 3. I asked Andy to interview the Toolpusher and the three individuals the caller identified. The individuals the caller identified as Hal or AI, Snow and Steve were understood to be AI Hansen, Jeff Snow and, Steve Cocchiarella. Andy informed me that the three individuals were not currently on the rig and on their days off. Andy did interview the Toolpusher (Shane McGahan) and he said he had no knowledge of any such incident as described above. March 31. 2005 At 0700 hrs I contacted Noel Therrien (Nordic's Superintendent) and discussed the details of the situation. I asked Noel to come to my office. Noel informed me that he suspected the caller might be Ralph Hernandez. At this point Noel informed me that Ralph Hernandez was terminated by Nordic on 02114/05. I asked Noel to contact the three crew members the caller identified and arrange for interviews (in person or by phone) this afternoon. . . At 0800 hrs I discussed this situation with John McCoy (ASRC-onsite EH&S specialist). John said he was completely unaware of an incident as described above ever occurring on Nordic 3. At 0900 hrs, while discussing other business with Gal)l Evans (DEC), I discussed the situation with Gal)l. I told Gal)l of my plans to interview the crew members the caller identified. Gal)l thought I was taking the proper measures and said he would advise his Supervisor (Lydia Miner) of the situation and would provide feedback if needed. At 0945 hrs, I received an email from Gal)l Evans (DEC). Gal)l suggested that I conduct the interviews and gather additional facts and then advise Ed Meggert with DEC in Fairbanks. At 1130 hrs I received a voice message on my cell from Mark Merrill stating that he had been contacted by the anonymous caller and Mark had provided him my contact information. The caller said he would call me. At 1145 hrs I received a call from Noel Therrien advising me that AI Hansen and Jeff Snow would be available around 1400 hrs at Nordic's office for interviews and that Steve Cocchiarella would be available for a phone interview at 1500 hrs. At 1215 hrs, when I return to the office, Sharon St Charles (ASRC - Admin Asst) informed me that someone had called and wanted to speak with me about a spill. Sharon informed the caller I was out of the office and attempted to transfer the call to Skip Coyner (ASRC - Dr1g Supt). The individual promptly hung the phone up. At 1345 hrs I called Mark Merrill to advise him the individual had attempted to make contact, but the call was missed and that I was going to Nordic's office to interview the individuals the caller identified. At 1350 hrs I went to Nordic's office At 1400 hrs I interviewed AI Hansen (Nordic 3 Driller) - AI Hansen (Driller) stated he had no knowledge of a spill of any kind outside the containment of the rig. He did note that during a BOP test on 02/05/05 that one of the hydraulic control lines to the BOP leaked when they pressured up the Koomey unit. The Koomey unit was shut down and an o-ring on the quick connect connection was replaced. AI estimates the volume of hydraulic fluid sprayed on the BOP and inside the cellar compartment of the rig was 1 pint. None of the hydraulic fluid was on the ice. All hydraulic fluid was cleaned up using sorbent pads. AI showed me on the IADC report where the BOP test was witnessed by AOGCC field inspector Chuch Scheve. I asked AI if this spill had been recorded or documented anywhere. AI said no because of the small volume and it was contained within the rig. During this interview there was a lot of discussion with regards to Ralph Hernandez's employment histol)l. Nordic advised that they were having an ongoing discrimination dispute with this individual and that a hearing is set for April 13. AI stated that he demoted Ralph Hernandez to roustabout due to poor performance and he was terminated on 2/14/05 after missing a mandatol)l meeting with Noel Therrien. At the end of the interview AI provided a written statement stating at no time was he informed of a 20 - 30 gallon hydraulic oil spill. At 1430 hrs I interviewed Jeff Snow (Nordic 3 Floorhand) - Jeff stated that he had no knowledge of a spill of any kind outside the containment of the rig. Jeff confirmed he was aware of the small leak associated with the failed o-ring on the quick-connect and commented it was less than a quart and was cleaned up with pads. I asked if there was any way any of the hydraulic fluid could have got outside the containment and on the ice and Jeffs answer was "absolutely not". At the end of the interview Jeff provided a written statement stating that there have not been any spills outside containment associated with BOP testing during any of his hitches while at Spy Island. . . At 1500 hrs I interviewed Steve Cocchiarella (Nordic 3 Floorhand) by telephone - Steve stated that he had no knowledge of a spill of any kind outside the containment of the rig. steve confinned he was aware of the small leak associated with the failed o-ring on the quick-connect and commented it was about a pint and was cleaned up with pads. Steve said he was the one that initially notified AI of the leak. Steve stated that the spray of the Hydraulic fluid did get on his clothing. I asked if there were any other incidents he could recall and he said no. No written statement was made due to this being a phone interview. At 1530 hrs I call Ed Meggert (DEC - Fairbanks) and left a brief message about the alleged incident and asked him to call me back. At 1800 hrs left office. No call received from the individual that made the anonymous report to BP. April 1. 2005 At 0900 hrs Called Gary Evans and provided an update on the interviews held the day before. At 1000 hrs started to draft a summary of events. At 1450 hrs I received a call from Ed Meggert (DEC - Fairbanks). I advise Ed ofthe situation and said that I had not heard from the individual yet but was anticipating a call this aftemoon. I advised Ed that I would send him the summary I was preparing. At 1545 hrs I received a call from the anonymous caller. He did not identify himself. I asked him to explain the situation to me. He said that a hydraulic hose broke off of the BOP and spilled hydraulic oil in the conduit ofthe well. He said he reported the spill to the driller. He said the spill was 20-25 gallons. He gave me the impression he was not in the area when the hose broke, but was nearby. I asked him to explain what the conduit was. He said the thing that connects the BOP to the well. I asked him if he was referring to the cellar, conductor pipe or wellhead. He said "oh yea the conductor". I asked him to explain how the hydraulic fluid got in the conductor pipe. He said "you know it just that big open area right next to the ice". I asked if he was referring to the cellar. I believe at this point he was a little confused. I asked him if anyone else witnessed the incident. He said AI (driller), Snow and steve. He said I should talk to them, they saw everything. He said a Peak truck driver helped by pumping out the cellar. I asked if he knew the name of the truck driver or the number on the truck. He said he did not know the driver's name, but he thought the truck number had a 3 in it. I asked when this incident occurred, he replied a month and three weeks ago. I asked, "about seven weeks ago". He said yes. I asked why he initially made the report to BP. He said he did not know anyone at Kerr-McGee and that he knows people at BP. He kept waiting to end the conversation and I would try to extend it for more infonnation. I asked him to provide his name and phone number so I could contact him again and he refused to provide the requested infonnation. He said if he gave me his name, he would never work in the oilfield again. Several times during the conversation I had to ask him to repeat himself due to a poor phone connection or background noise. I asked him why he was just now reporting this incident and he ended the call. At 1900 hrs I called John McCoy on Nordic 3 and asked him to review all manifests on or about February 5, 2005. A BOP test was performed on February 5, 2005 and according to the Driller (AI) and the other crew members, a leak associated with a failed o-ring on a quick connect did occur. April 2. 2005 At 0915 hrs I received a call from John McCoy. John informed me that he had reviewed all manifests and logs from the date of Feb 5, 2005 +/- 2 days. John said that 140 bbls of seawater . . had been removed from the cellar on Feb 07, 2005 via a Peak vacuum truck and was hauled to CPF-1 water recycle. No other water removal from the cellar had been manifested. John said that 10 bags of oily waste were generated on the date in question. Hydraulic oil was noted as one of the substances as well as grease, oil and pipe dope. The 43 bags noted on the log with the same date were bags that were stock piled on location until the oily waste dumpster was delivered to the location. Once the dumpster was in place on location, the bags were placed inside and the bags were logged in on the log. There were no indications from the log that hydraulic oil was in any of the 43 bags. John received a message from Larry Woodke (Peak truck driver) that he was not aware of any oil associated with the water he removed from the cellar. Conclusion Based on all of the information collected and interviews performed, it is my belief that the date in question is actually February 05, 2005 at approximately 1730 hrs. The operations on the rig at this date and time were just finished nippling up the BOP and starting to test the BOP. All parties have stated that a hydraulic fluid leak did occur on one of the BOP control lines during the BOP test on February 5, 2005. The anonymous caller claimed that the hydraulic hose broke (i.e. burst failure). The Nordic crew members (AI Hansen, Jeff Snow and steve Cocchiarella) all said an 0- ring failed on quick connect connection on the hose was the cause of the leak and that the hose itself did not fail or rupture. The o-ring was replace and the hose pressured up with no further problems. Upon visual inspection of the current hydraulic hoses by John McCoy there is no evidence that a new hose has been installed recently. All of the current hoses appear to be of the same vintage. A review of Nordic's material requisitions does not reflect that a new hose was ordered to replace the alleged failed hose. The anonymous caller claimed a volume of 20 to 25 gallons was spilled into the cellar. The Nordic crew members estimated less than 1 quart. The log of oily waste does not suggest a volume of 20 to 25 gallons was cleaned up with sorbent pads. The Peak truck driver stated that only water was recovered from the cellar when he pumped (sucked) out 140 bbls. An AOGCC field inspector was on location during the BOP test. Based on my conversation with the anonymous caller, he did not seem to have a general understanding of equipment and/or concepts. Forexamp/e, when we talked about the cellar, I got the impression that he did not understand the cellar provides containment for this type of incident and that the cellar is actually a piece of equipment. I believe the caller was under the impression the cellar was just a hole on the ice. In conclusion, an incident did occur on Feb 5, 2005 where hydraulic fluid was release from a BOP hydraulic control hose. This incident did occur about the time a BOP test was taking place. An AOGCC field inspector was on location during the BOP test. The volume of hydraulic fluid released was less than 1 gallon. None of the hydraulic fluid made it beyond the rig's containment (no hydraulic fluid on the ice). The hydraulic fluid was cleaned from the surfaces of the BOP, walls and floor with sorbent pads. No hydraulic fluid was noted in the cellar. The oily waste was properly disposed. Todd Durkee KERR-McGEE OIL & GAS CORPORA TION Drilling & Completions Operations Manager Well Name: NIKAITCHUQ #4 Event Name: DRILLING Rig Name: NORDIC Rig Super: LEWIS/DURKIN Wellsite Eng: V.COYNER Daily Cost: 127.019 From-To Houl'$ Code 06:00 - 07:00 1.00 28 07:00 -14:00 7.00 14 14:00 - 17:30 3.50 14 17:30 - 22:30 5.00 15 22:30 - 23:30 1.00 26 23:30 - 01:30 2.00 14 01 :30 - 04:30 3.00 20 04:30 - 05:00 0.50 06 05:00 - 05:30 0.50 20 05:30 - 06:00 0.50 . . KERR-MCGEE CORPORATION Page 1 of 4 Daily Drilling Report Date: 2/612005 Report: 13 DFS: 5.00 Start: 1/2512005 End: DOL: 12.00 TMD: 2,464.0 (ft) TVD: 2,464.0 (It) Progress: Rot. Houl'$: AV ROP: Hole Size: 12250 (in) Last Casing: 9.625 (in) Shoe TMD: 2,464.0 (ft) Shoe TVD: 2.464.0 (ft) Cum Cost: 2.965,366 Operations Summary Sub Code Phase Description of Operations A P )RLSUR ND DIVERTER P )RLlN1 NU BOP. PICK UP BOP AND REMOVE DIVERTER SPOOL INSTALL MULTI BOWL CASING HEAD. TEST SEAL. SET DOWN AND NU BOP. P )RLlN1 CaNT NU BOP P )RLlN1 TEST BOP.CHOKE MANIFOLD. FLOOR VALVES. TOP DRIVE IBOP. 250 LOW 5000 HIGH,ANNULAR 250/3500 5 MIN EA. WITNESS BY CHUCK SCHEVE AOGCC P )RLlN1 PULL TEST PLUG SET WEAR BUSHING P )RLlN1 NU BELL NIPPLE ADAPTER P )RLlN1 MIU & RIH W/ BHA t/:2 UPLOAD MWD P )RLIN1 RIH WI HWDP FI DERRICK TI 815' P )RLIN1 PULSE TEST MWD BLOW DOWN TOP DRIVE DRLIN1 SINGLE IN 4" DP Current Status: PU DRILL PIPE FI PI[pE SHED 24hrSummary:NU & TEST BOP MU BHAin PU DP 24hr Forecast: CONT PU DP TEST COO DRILL OUT SHOE TRACK PERFORM LOT Prin1I!d: 21612005 6:31:21 AM · . KERR-MCGEE CORPORATION Page 4 of 4 Daily Drilling Report Well Name: NIKAlTCHUQ #4 Event Name: DRILLING Date: 2/612005 Report: 13 DFS: 5.00 Start: 1/25/2005 End: DOL: 12.00 Remarks PIONEER CAMP MOBILIZED, BOP TEST 1MTNESS BY CHUCK SCHEVE AOGCC. TEST BOP,CHOKE MANIFOLD, FLOOR VALVES, TOP DRIVE IBOP. 250 LOW 5000 HIGH,ANNULAR 25013500 5 MIN EA. GOOD TEST. Pmœd: 21612005 6:31:21 AM ((ù 97',...', '. '~'j\\\ 'i. i,' P, I' ;S 'llJ " ,- 't:,! . '." ¡"...... , "¡ æJ u l.f'"ü U L6 . ¡0n i rr j'¡\ n m" ì rru ry7 I'^' I Ui, II? ,,',fj\ Ie ß\" ~ ¡ ~"'¡, '\ , ~\, 6 J .FU L:::J uu cQ) Uü!Jï"J · ;?otj-2~() AI,.\....1iA OIL AlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Todd Durkee Drilling Manager Kerr McGee Oil & Gas Corporation 3900 C Street, Suite 744 Anchorage, Alaska 99503 Re: Nikaitchuq #4 Sundry Number: 305-081 Dear Mr. Durkee: 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 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this~ day of April, 2005 Encl. Abandon U Alter casing D Change approved program D 2. Operator Name: Kerr McGee Oil & Gas Corporation 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 7. KB Elevation (ft): 1. Type of Request: (]¡I; 4-?--O{ _ STATE OF ALASKA RECEIVED ~ K''- A~ Oil AND GAS CONSERVATION COM. ION , ' f<t'l¡ APPLICATION FOR SUNDRY APPROVAL APR -4 2005 -l/IA 20 MC 25.280 A/aska Oi/ & Gas C n C .'. ~ Operational shutdown U Perforate U A'fi'êWår~' ðnltl"SSIQßher~1 Plug Perforations D Stimulate D Time ExtensioJ~ Down-Squeeze the· Perforate New Pool D Re-enter Suspended Well D 'i-S/8- x 7- Annulus 4. Current Well Class: 5. Permit to Drill Number: Suspend U Repair well D Pull Tubing D Development Stratigraphic D D 6. API Number: 50-629-23241-00 Exploratory 0 D 204-260 Service 9. Well Name and Number: 31.5 ft (corrected) Nikaitchuq #4 8. Property Designation: ADL: 388582 & ADL: 388583 11. Total Depth MD (ft): 7,577 ft Casing Structural Conductor Surface Intermediate Production Slotted Liner Perforation Depth MD (ft): N/A, Slotted Liner Packers and SSSV Type: 10. Field/Pools(s): Exploration ITotal Depth TVD (ft): 4,186 ft Length PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): IEffeCtiVe Depth TVD (ft): Size MD TVD IPlugs (measured): N/A Burst IJUnk (measured): N/A Collapse 102 ft 13-3/8" 2426 ft 9-5/8" 4818 ft 7" N/A 2,895 ft 3-1/2" IperfOration Depth TVD (ft): N/A, Slotted Liner 133 ft 2457 ft 4154ft 5020 psi 5750 psi 7240 psi 2260 psi 3090 psi 5410 psi 133 ft 2457 ft 4851 ft 7567ft 4186ft ITubing Size: Tubing Grade: 2-7/8" L-80 Packers and SSSV MD (ft): N/A, Slotted Liner N/A, Slotted Liner ITubing MD (ft): 4,500 ft HES WellStar TRSSV 432' MD 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for 16. Verbal Approval: t~ 4/2/2005 Commission Representative: fAr {Tot Maunder 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name _ . Todd DU~~ Title Drilling Manager Signature / ~ \ .IJ.2.3hone 907-339-6370 Date Commencing Operations: t1/tjJ~s 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Abandoned WDSPL D D Service D D D D 1/3/20OG - Plugged WINJ Contact Skip Coyner: 907-339-6269 OÖA.?R ~ COMMISSION USE ONLY SUndry Number: Plug Integrity 'Ø.. BOP Test D Mechanical Integrity Test D Location Clearance D Oth.c ~\\-¡T"">\,~c-~'~\CP~~A.I \0 ~A~~ ~~\""f""\' C~~~\ ~~":>S~~ ~.\CA5·-.-~~,,~èJ~ Subsequent Form Required: \....\0 ~ <:..t.. -\-Q:.~Ot-'-"Je.ll Conditions of approval: Notify Commission so that a representative may witness 30~ofr / Appco"",, by, ~ COMMISSIONER APPROVED BY 1;45 THE COMMISSION , Date: 4-, ~ , RBDMS BFl APR 2005 I\L Form 10-403 Revised 11/2004 Submit in Duplicate · . (..1 KERR-MCBEE JJ¡ Nikaitchuq #4 Down-Squeeze the 9-5/8" x 7" Annulus I Drilling Rig: 1 Plug and Abandon Suñace Location: 350' FSL & 1460' FWL of Section 16, T14N, R9E UM X = 519,643' Y = 6,054,828' I Start Operations: 141Q1¿ I05 1 I TMD: 17,577' I TVD: 14,186' 1 I Operating Rig days: I nla I BHP: 11694 psi I I DF: 131.5 ft I I Objectives: Down-Squeeze the 9-5/8" x 7" Annulus Casing - Actual: Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD I TVD MD I TVD N/A 13-5/8" 68# L-80 BTC 102' 31' 133' 1133' 12-1/4" 9-518" 40# L-80 BTC 2,426' 31' 2,457' 12,457' 8-1/2" 7" 26# L-80 BTC 4,820' 31' 4,851' 14,154' 6-1/8" 3-1/2" 9.2# Slotted LNR 2,895' 4,672' 7,567' 1 4,186' Producing Reservoir Schrader Bluff, OA sand MD (ft) 4,145/7,577' TVD 4,145 BHP 1,694 KWM Sea Water Overview: The current ESP completion will be cemented in the hole. The well will be plugged and abandoned as per AOGCC regulations using rig-less techniques. The 7" x 9-5/8" annulus will be down-squeezed and pressure tested before continuing with the remaining plug and abandonment operations. Mosley I Coyner 4/112005 . . ABANDONMENT PROCEDURE Down-Squeeze the 9-5/8" x 7" Annulus: The 9-5/8" x 7" annulus was displaced with diesel and currently has 200 psi SICP. 1. R/U Halliburton, test lines and establish injection parameters: :t 4 bpm at ~ 1200 psi. NOTIFY THE STATE AOGCC THAT THE P&A CEMENT FOR THIS ANNULUS WILL BE PUMPED. GIVE THE STATE 24 HOURS NOTICE! VERBAL APPROVAL FROM TOM MAUNDER 4/2/05. 2. The objective is to fill the annulus with cement above the shoe of the 9-5/8" casing AND a minimum of 200 feet of open hole annulus below the 9-5/8" shoe. Calculated volumes are as per the Halliburton program as follows: Plug #1: Down-squeeze the 9-5/8" 40#/ft x 7 casing annulus. 9-5/8" Casing Shoe: 2,457' MD Hole size below 9-5/8" shoe: 8-1/2" Base of Permafrost: 2,010' MD Open Hole by 7" Casing Fill: 200' % Excess in Open Hole: 25% Top of Plug: 80' MD Lead Slurry, Permafrost L: Lead Slurry Volume: 2,657' to 625' MD 78 sx / 57.3 bbls Tail Slurry, Permafrost C: Tail Slurry Volume: 625' to 80' MD 91 sx /15.4 bbls Density (ppg) Yield (cu ft / sk) Thickening Time Hr: min. Lead - Tvpe L 10.7 4.15 6:00+ Tail - Tvpe C 15.6 .99 +/- 2:30 3. Mix and Pump the cement down the 9-5/8" x 7" annulus and displace same to 80' RKB with :t1.5 bbls (+Iine volume) of diesel. Hold pressure on annulus for at least 1 hour and then release pressure. Do not allow the diesel to bleed back. Hold pressure longer if necessary until bleed back is zero. 4. Wait on cement at least 12 hours. Test the 9-5/8" x 7" annulus to 2500 psi or 500 psi over the final injection pressure to confirm that a seal exists between the 9-5/8" casing and the 7" casing. Hold pressure for 30 minutes and make a chart of the pressure test for submittal to the AOGCC with the P&A documents. Mosley I Coyner 4/112005 - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' ...... 4500' KOP := 3000' BUR::: 6°/100' Pad Elev = 1.0 ft GL to RKB = 30.5 ft Rig RKB = 31.5 ft 2-7/8'''' WellStar TRSSV at::!:: 432' 2-7/8",6.5#, l-80, EUE-M 9-5/8", 40#, l-80, BTC-M 2457' MD I TVD LOT = 14.4 ppg EMW 7" H-ES Cementer at 2,834' Deployed ESP with gauge carriers, in Tangent section at 72° Nikaitchuq #4 (Current ESP Completion) ~~----~----------------------, 3-1/2", EUE Slotted Liner: 4672' -7,567'I\IID I ~--------------~------------- 6-1/8" Hole, OSM 4,186' ND S Coyner 4/10/05 - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' -- 4000' - 4500' KOP = 3000' BUR ~ 6°/100' Pad Elev = 1.0 ft GL to RKB = 30.5 ft Rig RKB = 31.5 ft 2-7/8'''' WellStar TRSSV at:± 432' Nikaitchuq #4 (After Down-Squeeze) 2-7/8", 6.5#, l-80, 9-5/8", 40#, l-80, BTC-M 2457' MD I TVD LOT = 14.4 ppg EMW 7" H-ES Cementer at 2,834' Tubing Deployed ESP with gauge in Tangent section at 72° of Gage Carrier at 4500' Nil) 1IIIIIiIIIO.........._illllllli-iWI!IIII______ .... ...-.- --. - -- --.-------..., I --:----...- S Coyner 4/10/05 - _I Nikaitchuq #4 / Down-Squeeze the Annulus . . Subjèct: Nikaitchuq #4 / Down-Squeeze the Annulus / From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Sat, 02 Apr 200509:38:23 -0900 To: "dri1l30@kmg.com" <dri1l30@kmg.com> CC: "andystewart@kmg.com" <andystewart@kmg.com>, "tdurkee@kmg.com" <tdurkee@kmg.com>, "tom _ maunder@admin.state.ak.us" <tom _ maunder@admin.state.ak.us>, "mark.wedman@halliburton.com" <mark.wedman@halliburton.com> Tom Maunder and I discussed the annular down-squeeze this morning and we have verbal approval to proceed with the stipulation that we limit the injection pressure to the pressure we had when we pumped the diesel on February 17th: Little Red recorded 1200 psi at 4 bpm. Therefore, your maximum injection pressure is 1200 psi. See attached program SkJp Coyner 907-339-62690fc 907-748-3689 cell Content-Description: Plug and Abandon Program.doc and Abandon Program. doc Content-Type: application/msword Content-Encoding: base64 I of 1 4/4/2005 1 :36 PM . . Durkee, Todd I From: Sent: To: Subject: McCoy, John Uohn.mccoy@asct.asrc.com] Saturday, April 02, 2005 4:20 PM Durkee, Todd 02-07-05 manifest and oily waste log -m Red Book Manifest and Oily Was... Todd, Here is the manifest and oily waste log, The log starts on the 6th of Feduary, that is the day the oily waste dumpster arrived. The large amounts of oily waste bags is what had accumulated from the rig-ups and wad stored prior to the oily waste dumpster being dropped of on loaction. I've called Peak dispatch and asked the whereabouts of Larry Woodke. Peak dispatch called back and said all he can remember is just loading on sea water from the cellar, he did not see any oil floating on top of the cellar water. He also said that he would not mix a load because of the problems involved with mixing liquids and the trouble he or Peak would get into for not following proper procedure with class 1 or class 2 fluids. Thats all I can find for now. John McCoy 1 '-. -- -- -e---· -- - "'_''''_U__·.n --- ,,---_..._,-...... -..--. -........ '~. ! Faciity " I Source{ weD Nc( ., 12. GENERATING ACTIVITY OR PROC~ . Ti~, ~ ~':.- . ¡ ,BNA DPM Cost CodeIAF~", .Ij- í::: , --¿= T }.::~~i~~ ~ ~~"~''l:.: ~ c~ i'T~'\ -::7-..;:> ~'~';,\ \f''";~:~-~ -....'-:.(>.\.._,!'~-...~._ ~ 1.-.'_.. J-'~ ;~ 3. VOLUME (Eslima1O) / i..1 )3.sb1 o Gal DCllyd 4. DESCRIPTION (CompostIIon must equal 100% - use whole numbers) Crude Oil ProcIuced Water DrillinO Mud Cuttlng& , Cemønt/COntamfnate DieSel MeUIaIIoI OTHER (De&cribe) % Fres.hWater %'Søa~J8rinel1<CI % Söiiiœ Water % ReservelFlalelRelief Plr Water % Snow % GravellSand % 00n1estic ~ater Check one: 0 Usted in Waste Dispœal & Reuse Guide OR o Approved by (Name/Date) 5. WIJ,.L MATEmAL BE REUSED OR RECYCLED in a manner 8pPtØVed In ihe Wests DIspossIlUJd Reuse Guide? ~S Select methcd at light and go to PART 8 ~ Water Recycle/EOR _ Hydrocæbon Recyd!I , OND Go to PART 6 _ 0Ihar BeneficIal Reuse (Describe) 6. ClASS ø DISPOSAL: Were the fluids brought to the surface or otherwise approved for Class " disposal? o YES Go to PART 7 if Class I facility will be IJSØd OR PART 8 if Class II facilty wlJl be used o IfQ Go to PART 7 or confa<:t EnvironmenlBl 7. CLASS t DISPOSAL: fluids Injected In s ClasS I well are either non-haZarcfOus or exempt from regulation as a hazardous waste P4!! 40 CFR 261.4. Is the waste approved or Identified as RCRA exempt or non-hazardOus in the Waste Disposal MId ~ Guide? ,)!íyES IndIcaIa exemption or ONE Class I Waste Stream q RCRA exempt (specify) 0 Noo-exempt. Non-Hazardous , at fi9ht and go to PART 8 . >~. E&P o NO Contact ElWironmømal fOt case-by-case Emply ....-.......ne approval Of' further In$1JUCtiOns - .............. r 8. DESTiNATION (Name of Facility) Greater Prudhoe Bay 0 Pad 3 Waste Facllty KuperuJc 0 CPF-1 Hydrocarbon Recycle o 1R-18 Class It Wen % Glycol %Açid % . Fraç Sand % DlesellWater Gel % Scale/Corrosion Inhibitor % BÒiIer BIowdown % Used Oil % % % ';;';-;:'{) % % % % % % WASTE STREAM CODE: (IICm ìnIIrUcIIct1_. onatm'-¡ o Grind & In 4lcl FacllllY á.CPF-' WàtèrRecyde '0 l-H Oily Waste Storage o Other (describe below) o CPF-1 OIly WaaIe l",êCtIOn [J OIf1er (deSCribe beJoW) ; Other Asset/SpeC1f1c Facility 9. TEST DATA IF REQUIRED BY RECEIVING FACILITY Flash point Organic ctIIorkIes (ppm) . '~ ~~~~ :10. GENERATOR I~~"---r~-':-/, - ,,'./ F '-" i :." Certification: This oonsIgnment, to the besf 01 my fmowiødge and bfHief. ~ratefy døscríbsd aboVe and I have sppIi8d the ptOVislon$ of the Waste Disposaf SlId Reuse Guide in making decisions conœming the reu!U/ or dlspcsal of this matørlaL ~PORTER := L' ~= No: /(, 306 Name (Print) Volume ReteìWd: % SolIds ' , % Water Signawre- . .......~_..j7'~-y__.-, Date .' , ,;;::1- j _or ) } f:.~- ={:" Signatura , .,>0., T-3£3 Date F c:-h Signature 7 f- oS 12. RECEIVER 0ffI0aded at: [J BbI OGaI Date OCu yd : COMMENTS MARCH 2002 ORIGINAL· ReceiVing Fadlty COPIES· Follow site-specific filing insttuotions /J \.'~ ""\ ,...,': .-.--.,,- \ i--- OWl18r ¡. )MPSTER'L~G OILY WA{ WPM .of O~1y Wastèa be:¡ 1.<.-) "~~.'\+- ~ () ,/Y' <".,I'¡'~... /- Z,' 71; lLAJ~"""..2:-,hé".,:<"C' -'IlL ' ,. I '" l'l h<-...."..4:Þ, h 11l:.Q.~::¡. Â;(~:2t!. ( 3 . P,A- D:-j~';t.) í.i)l.,~ v', \ l t1~.(p"..J <, ,. l ,,"~~t~. ....:"h (.,..~ <. -¡,)" ."<..... /((! ~:,.J .'(...) n: flõ , ,>:Ã' .~\o-;(t . , .f/j¡:;"": ¡rCc' CM;Ÿ '-' - ~¡!J'.~t!.JMJt. ~~ ~;JtJo".6<1.. ¿ IF-tC/¡.tfw.¡.A' '''~rþ.·,,¡' , .- ;- <Y.. /...(. ,^, .;. <'tv'" ~ ,/'" .. t t ' . ~ ~:oJ J .... ;.... ,.'¡ .~, ,,'" '~c.' ,·e ;.r ~ ..;..~ ~'r \i. .~(..., , ',' ~ . ',:,;IIi'1 .At:.."w f.;" I pi f'i.! t lc ¡IJ-..b1."7 {J¿)(<!. (.,,~ ...··.l.V\)K G:..../!·;,'{(1.. ,6~I.../.A\""',; 'fkl,/Ill.""')" J'í';' ~J , ~ \~Il.Jt}rc('(Clb\. \. M,,),L(,..q'.}.'~ 0.'1.,. ,.;;¡,,~.-f.J';' /,.::..~tq'e '< :.: f.~' j ...,> /, ' .:t 7'" I ' 'I .,1.., '. l ' . .J' 0, ... >, I ø "Wh, 1.7 é IVÞìb.tt]J . .<2. 7 ./ ,-,i.,'~. _ hk¡C, 1 ~j /lr..o4. 7 '.-þJ '} , . ¡'\,~â1:' ,'.~ .~..{., 1:.......- . _. , .;. (..i.'tli'(j)I7("'/I~fdr'~I.t ".....l It~4·.1 ')..7£ ~¡)'~'jt;:/, <,..;.,.·..d-·!¡ , Oily (.(.'J'!..!.n: ß,;t,:,.:;.·.. N cRt) I c:,# ). .,.., V (,¡: "1' A'it~ ~ ¡e,~",ZC>CL:· .:>ti.yuutST(. . ,NORDiC'#:3 ~'¡,)AtA<~J~ .;z. II '1. o¡t.y sOlCc1jJl:S fVO~OiC'¡;...1 (8f(.r., "'1'7C AI ~ 0... /. I D I 't' )«. { <. v /V 1 "'7 5 t2 ¡.^ ~ ~;¡.~ Comments l)c~¡'« ,&" yyJ 'f k::; <-{ ,I ! Owner ApprovB Traoklngll 41 0' Bags Origin of Oily W~~bt8 ~ 1!S.f\laJx)ô .., I .__ Supervisor & Departmont . . .,1' Dllte Generator '2---&;V:" . ~1 C'''' '··¡1,·(f ¡~ ()<~ I~ 1<:. 7;~(~~ Cf ;''''' ..~ LJ3 '- ) ,¡.: 'J.l!,,ea;c ,~3 Z-(r(!;; . 'J" , il("'bië-·f£.~éf€J + --+""fS~(J . v\ f) i If) 'W '--:2 _/ ;0 -' , :){,-(7;- ., r j. (:.~. (0';, ( 7 4-l.'$' .2 7 £' -"7 ~li'·,._'C< ~ _7 ç .... ""';0 I C. '¿ '((.of)- 276' .~ -f r 'Q,:;'ì\l~' n'5 t.- . f ............. ;)yf:. / i' ~1 . Do¡)h/~ ßQj:Jf.l:> ..¡.. ';-/P66f&J_: .(41'1. 'Déúbk g Cj .;35. ,.,d -+ NI;. , 7~Jl" Oo·bi.i B.,~~.: :+ .",¡:. , TA.:Ie '...- btll10le ~r'~~·;'ó. ~ í.....r~'ìecl. ,. . Oily Waste Dumpster Log '-I.. l' 3J Sf'1l~. ~~ 'It;" /<¡''''t ~ JJL I<,'¡"'t¡ 9t't G-/'tl''-' ;\(?.. ~1K..·{¡"I"w..;.:¡:zz; ¿; i /7 ~..... Æ.;c.-, 5ff(:/\f.>4..T ...-- ·-!.r;:;t.1 2:J )-,h yj¡'~t.J.'ç.. .( 2ftff Î_? (' ~t" __f,' "..J._ ..., I ..... It -f¡ . ,.- .,. J. Ã:j"'.{Y ~·H( ) ¥ J/~,"j/¡t.i~, 7l$ ¥/¡ßr ÎJD£(,)JCTt.3 ;;045' I~NDRi)¡(4i~ ";../Jsþ1' ND~D (..:t;~ ,j.h~·f JÁlhtt1'Úe ij¡''c¡þ., k~1( fa "'Il )Ai' f fJv,1iI.;·~ (;¡.t.f ; . . Durkee, Todd From: Sent: To: Subject: McCoy, John Oohn.mccoy@asct.asrc.com] Monday, April 04, 200510:00 AM Durkee, Todd statement from Larry Woodky am Todd, Here is the statement you asked for. Larry did not see any hyd, oil in the cella~. Larry Woodky.pdf (157 KB) Talk to you later, John McCoy 1 --. . .. ç~ 7 ('00' /}/J f, ìJly~, '~) I Þ 0", lA, I~~ e{ ~ ~ ìti-6 . ~ JJ ~ ~ Â~~, ~ wlm1/4 -L.-1/11 ..2 7.JI/W t; ~ ~ . Ù1JJ~.-(f.'1 z, èfN5 RF / ....- 1. Get a 72 in OD x 8 ft culvert from Culfabco 2. Cut a 72 in OD disc from 1/4" plate steel and cut a14 in OD hole in the center of the disc. 3. Weld the 16 in OD x 14.5 in ID x 5 ft riser to the disc as shown (use 16" drive pipe). 4. Weld the 72" OD culvert to the disc. 5. Cut 4 lift eyes in the top ofthe 72" culvert. _L__.~~...~ .-.,-.-.-.- & 8ft The critical issue is that the riser must have an ID between 14.5 in and 14.0 in Nikaitchuq #3, Cellar and Nikaitchuq #4, Cellar 72" OD x 8 ft Deep ~ 0 ______ C Corrugated Culvert ~" .-------72 in ;:.7 ~ ...._ _'fII1O ~ o -------0 . r "'""" '-'Ã'-'-'~ . ,....--", 5ft ~ 16" OD, 14.5" ID Steel Riser x 5 ft ~14.5 in-þ ID . 72" OD x 1/4" Plate Steel Disc . . ~!J!J~lli~~" ¡~jtët1j!}.;;¡~§~ _ 'Ür.M.t¡r~n~ Kerr-McGee tests Schrader Bluff oil By OGJ editors HOUSTON, Mar. 15 - Kerr-McGee Oil & Gas Corp. has tested as much as 1,200 bId of 16°-17° gravity oil from the Schrader Bluff reservoir in its Nikaitchuq-4 horizontal appraisal well on Alaska's North Slope. \--.,. J-04 - ;}.f.O Kerr-McGee operates the Nikaitchuq prospect and holds a 70% interest. Armstrong Alaska Inc. holds a 30% stake. ~ ~O '-\ _ ~ '-\ " Kerr-McGee encountered the same Schrader Bluff interval in its Tuvaaq exploration well, 3 miles west of Nikaitchuq-4. It is drilling the Kigun sidetrack to ---. ò).O 5 -O;:}.S- earn additional acreage. After completion. Kerr-McGee will operate the well with a 55% working interest. dO~-a~)s~ Kerr-McGee has increased its stake to 82% in and become operator of Tuvaaq by acquiring an additional 40% working interest from Pioneer Natural Resources. ~ JC:)\.\...(:) \ '6 r-" J. 0 S -CO \ Also during the 2005 Alaskan drilling season, Kerr-McGee is drilling the Nikaitchuq-3 horizontal appraisal well to test the Sag River formation. In 2004, the Nikaitchuq-1 vertical well tested more than 960 bId of 38° gravity oil from the Sag River, and Nikaitchuq-2, drilled 9,000 ft southeast of the discovery well, extended the discovery downdip (OGJ, Sept. 20. 2004, p. 34). Earlier this year, Kerr-McGee acquired a 50% working interest and will operate the Ataruq prospect in Alaska, where it will drill an initial exploration well following the appraisal drilling at Nikaitchuq. lof2 3/17/2005 10:41 AM . . '2r 3/- 0 S ~ J ft L If /j !\Js-e tV 191" ¡UO i-/~e Wìts ¿¡:>u ¡:oC?.JV\€. c;( ðf It d.O -)0 6ðl lý'1 þ, ð¡' { ~ P/'Ir X/0 fite. Ce((+tl /1-/z.«1f oR õN 1-k'« .rl:~ (JJuf ~/J~ ð F ..¡.~ «, '3 .j) ufl/ I\J~ f't ß . o. P. e T-<=s--r /} l ~ p¡ f 5LitAJD . :f..Q.-ff S N Q vJ 3.: D Ö r"" I. ¡JOT A Witte€. ON ÆAlY /-(/+eH beeN 11-"- spy.:r c¿; I.-~ ¡-) d . Or ON . 0'ls/IOf> ÆAly' sfJ I'LL S w ho...-f 6"0 ever wi,; If!. -I-es -110':; ß. ô. P s- /' (/ ~ Nordic report . . Page 1 of 1 Durkee, Todd From: Evans, Gary IGary_Evans@dec.state.ak.us] Sent: Thursday, March 31,200512:48 PM To: Durkee, Todd Subject: Nordic report Todd Lydia suggested you wait until your interviews are completed and then give Ed Meggert a call and brief him of the whole deal. You can tell Ed you briefed us and Lydia told you to wait to report it until your investigation was complete since there were so many holes in the guys story. Please let us know how that turned out too. 04/0212005 . . Page 1 of 1 Durkee, Todd From: Stewart, Andy Sent: Wednesday, March 30, 2005 11 :24 PM To: Durkee, Todd Subject: Alleged Incident Todd, Hansen, Snow and Cocchiarcella are all scheduled back to the rig next Monday according to Shane. I can see them then or you can speak to them before they leave. Just let me know. Shane and I agreed to keep everything confidential. I did not tell him what the allegation was or who it came from but just said we wanted to talk to them about what they remembered about that BOP test. He volunteered to me that there had been some animosity within that crew that he knew about but did not elaborate. Andy 04/02/2005 . . r:XD ct- ~ (b 0 [Fwd: Annular Disposal of Produced Fluids] , . Subject: [Fwd: Annular Disposal of Produced Fluids] From: John Norman <john_norman@admin.state.akus> Date: Tue, 29 Mar 2005 12:16:16 -0900 To: jody_colo Jody-please be sure a copy of this got into the file. Thanx -------- Original Message -------- Subject:Annular Disposal of Produced Fluids Date: Thu, 13 Jan 2005 15:33:51 -0900 From:Thomas Maunder <tom maunder@admin.state.akus> Organization:State of Alaska To:Todd Durkee <TDURKEE@KMG.com>, Skip Coyner <Ski p. Coyner@asrcenergy.com>, Stu Gustafson <stu@armstrongoilandgas.com> CC:John D Hartz <jack hartz@admin.state.akus>, Steve Davies <steve davies@admin.state.akus>, Jim Regg <jim regg@admin.state.ak.us> Gentlemen: '')05 "tJb ( / 11ll.::¿J;0 '~ ("jMC") ptfu,ary plan for handling oil obtained through production testing of the propos . 3 and #4 wells is transportation to one of ConocoPhillips Alaska, Inc.' s ("CP AI") production facilities in the Kuparuk River Field. However, if "emergency conditions" such as inclement weather or CPAI's refusal to accept the oil occur, KMC proposes to inject and dispose of the oil in an approved annulus or Class II well. This is not an acceptable option. The Commission is charged with preventing physical waste of hydrocarbons. Injecting oil obtained through production testing into an annulus, a Class II well, or into any formation other than a producing formation would constitute waste. As an alternative, KMC could provide sufficient storage for the production test oil, and re-inject the oil into the producing formation. The Commission strongly encourages KMC establish an agreement with CP AI or BP Exploration (Alaska) Inc. ("BPXA") to allow transfer of the produced oil to a production facility. According to information provided in KMC's meeting with Commission staff on January 11,2004 and the estimated well times in your applications, the earliest date testing is likely to occur is February 13,2004. The Commission remains interested in the matter. IfKMC is not successful in negotiating a satisfactory agreement with CPAI or BPXA by February 4,2004, please contact either myself (907-793-1250), Jack Hartz (907-793-1232) or Steve Davies (907-793-1224). Please be aware, I will be out of state January 15-19. Tom Maunder, PE Alaska Oil and Gas Conservation Commission lof2 3/30/2005 4:23 PM [Fwd: Annular Disposal of Produced Fluids] . . John K. Nonnan <John Nonnan(G}admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 3/30/2005 4:23 PM March 25th, 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No.8 3/18/05 7,577' MD / 4,186' TVD Shut in. 3/20/05 7,577' MD / 4,186' TVD Shut in 3/21/05 7,577' MD / 4,186' TVD Shut in. 3/22/05 7,577' MD / 4,186' TVD Shut in. 3/23/05 7,577' MD / 4,186' TVD Shut in. 3/24/05 7,577' MD / 4,186' TVD Shut in. 3/25/05 7,577' MD / 4,186' TVD Shut in. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 e (907)-339-6370 . . ;)0 Jj - "(PO Kerr-McGee Oil & Gas Corp. Well Day Report February 2005 Production Well # 4 API # 50-629-23241-00-X01 # Hours Produced 102 Well Days 4.3 )~~.¡G¥j)M ~ Uh{) I -. ~ fP r:ltïi4 ~ .. · · --tuJ: evno ~ ~ðYl~~· - -+ SAs J)~po~~~ RßDP1S ~ í\l\.c0\{túuo ;¿ f /ì}ti-VrÁ). ðOS- STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 RECEIVED MAt< 2 1 Z005 Name of Operator: Kerr-McGee Oil & Gas Corp. 1. Well No. 2. API No. 50-XXX-XXXXX-XX-XX 3. Type (see instruct.) Field and Pool: Exploration 4. Field & 5. Method Pool Code (see instruct.) 6. Days in Oper. 7. Tubing PSIG IMonth and Year: , O'l & G s Cons. Commission Ataska a Feb-05 DAILY AVG. PRODUCTION M~~'~"HHL Y PRODUCTION 8. OIL 9. WATER 10. GAS 11. OIL 12. WATER 13. GAS (BBL) (BBL) (MCF) (BBL) (BBL) (MCF) 4 50-629-23241-0Q-X01 388582 4.25 80 637.88 30.59 42.82 2711 130 182 .. Note: Test Production, Exploratory Well (Nikaitchuq #4) . I hereby certify that the foregoing is true and correct to the best of my knowledge. 14. Printed Name: Larry A. Johnson Sig",""" ~ C\--O~~ Fo~ 10-405 Re' 1212003 {( .--- - Title: Accounting Supervisor Date: 3/17/2005 INSTRUCTIONS ON REVERSE SIDE TOTAL 2711 130 182 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION 1. Facility Number 12. Facility Name Disposition 3. Field Exploration Volume MCF 6. Sold 7. Reinjected .. Flared or vented 1 hour or less 9. Flared or vented more than 1 hour (see instr.) 10. Pilot and Purge 11. Used for lease operations (specify in Remarks) 12. Other (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 14. NGL Gas Equivalent 15. Purchased gas .16. Transferred from: 17. Transferred to: (Express as a negative #) 18. Remarks: 14. Operator 15. MonthlYear of Disposition Kerr-McGee Oil & Gas Corp. Feb-05 20. For production from multiple pools, list contribution of each pool as a percent of Total Volume. o Pool Name Pool Code Percent o o 182 o o o 182 Authorization >1 hr: MCF Safety MCF Lease Use MCF Conservation Waste: MCF Commissioner Date Note: Test Production, Exploratory Well I hereby certify that the foregoing is true and correct to the best of my knowledge. S;,,,,,'" ~ ~ .. nle Acoo"t;" S'pe~;'m Printed Name Larry A. Johnson Phone (281) 673 6542 Date 3/17/2005 Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 600 F. Authority 20 AAC25.235. Form 10-422 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate e e March 18t\ 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weeklv Operations Report No.7 3/11/05 3/12/05 3/13/05 3/14/05 3/15/05 3/16/05 3/17/05 7,577' MD /4,186' TVD Shut in. 7,577' MD / 4,186' TVD Shut in 7,577' MD / 4,186' TVD Circulated hot oil through dump sub. RIU SLU. Fished sampler. Shut in. 7,577' MD / 4,186' TVD Shut in. 7,577' MD /4,186' TVD Shut in. 7,577' MD / 4,186' TVD Shut in. 7,577' MD / 4,186' TVD Shut in. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 ~~~~r-' ~., HlJUð~f,¡!Þ ù 'ª I ¡ ''-- WI U ¡...;;;;:;¡ . 111 t~ r;:¡ r T 'fù -~., j fi"\ ll. I i '/8 \ 11,1 b \,~< i ¡ ( ¡'ß \ ,~¡ LrÙ~JU0UÙJU · c4tJ r/~ ;l.,fe() AI/A~IiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. ]T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Stuart Boggan Drilling Manager Kerr McGee Oil & Gas Corporation 3900 C Street, Suite 744 Anchorage, Alaska 99503 Re: Nikaitchuq #4 Sundry Number: 305-068 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 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been d ~ requeste . .;#'" ,/"'::;' /S~nceE~lYs,e¿~".,,::;,;,;:~:~::::,,~Ø7 //' ".,'" ,', /,' ,..,..,. ',/,'/'''' r---', / /<lj2'.,J~/:.:"'// /,,/,'"'''''' / _ /,,/7' "16hn K. NoriÍ1anj/ -" Chairman //",." DATED thiS~ day of March, 2005 Encl. . . . @ KERR-MCBEE CORPORATION . March 8th, 2005 RECEIVED MAR 1 0 2005 Alaska Oil & G as Cons C . Anchorage' °mmtssion Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq #4: APD 204-260 Kerr McGee Oil & Gas Corporation Application for Sundry Approval: Re-configure the completion Attached for your review is our Application for Sundry Approval. Form 10-403 is attached. After completing Nikaitchuq #3, we intend to move Nordic 3 back to Nikaitchuq #4 and re-configure the completion. This re-configuration includes laying down the ESP, and running a packer [7" EZSV] on the 2-7/8" tubing. As such, the well will be properly configured to dispose of oil produced during the Nikaitchuq #3 well test into the Schrader Bluff"OA" sand. It will also be strategically configured for a rig-less P & A. Sincerely, I1t2rr ASRC Energy Services Project Drilling Supt. Attachments: Nikaitchuq #4 Current Wellbore Schematic Nikaitchuq #4 Proposed Wellbore Schematic Nikaitchuq #4 Re-configuration Program Nordic 3 BOP Diagram 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 . o ,. r'", ILJ ~ 1. Type of Request: STATE OF ALASKA 1)ì5 3/tS¡(sRECE'VED t~~/ A OILAND GAS CONSERVATION CO.ION IA.~ "7 A.CATION FOR SUNDRY APPROVAL MAR 1 02005 0i . 20 MC 25.280 r: gons. Commission Operational shutdown U Perforate U Alaska O~\Ié' Other LJ Plug Perforations 0 Stimulate 0 Time ExtensiM ' rag9Re_COmfigUre Perforate New Pool 0 Re-enter Suspended Well 0 Wellbore 4. Current Well Class: 5. Permit to Drill Number: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Kerr McGee Oil & Gas Corporation Suspend U Repair well 0 Pull Tubing 0 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): 7,577 ft Casing Structural Conductor Surface Intermediate Production Slotted Liner Perforation Depth MD (ft): NI A, Slotted Liner Packers and SSSV Type: 31.5 ft (corrected) ADL: 388582 & ADL: 388583 Development Stratigraphic o o Exploratory 0 o 6. API Number: 50-629-23241-00 204-260 Service 9. Well Name and Number: Nikaitchuq #4 10. Field/Pools(s): Exploration ITotal Depth TVD (ft): 4,186 ft Length PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): EffeCtiVe Depth TVD (ft): Size MD TVD IPlugs (measured): NIA Burst JUnk (measured): NIA Collapse 3/16/2005 Date: OriginAl p~ '" DAN SEAMOUNT Form 10-403 Revised 11/2004 . 1 02 ft 13-3/8" 133 ft 133 ft 5020 psi 2260 psi 2426 ft 9-518" 2457 ft 2457 ft 5750 psi 3090 psi 4818 ft 7" 4851 ft 4154 ft 7240 psi 5410 psi N/A 2,895 ft 3-1/2" IperfOration Depth TVD (ft): N/A, Slotted Liner HES WellStar TRSSV 7567 ft 4186 ft ITubing Size: ITubing Grade: 2-7/8" L-80 Packers and SSSV MD (ft): N/A, Slotted Liner NIA, Slotted Liner ITubing MD (ft): 4,500 ft 432' MD 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name S~aJ B09¥~ Title Drilling Manager Signature ~ t( A..-___ Phone 907-339-6370 '-'(f7' COMMISSION USE ONLY Coo,""" of appro,,"~ Notify Co",m;"~" 00 that a copre"""'ti,. may wün." ~ I" Is,",,>, N,mOO" _ : ~ ~~ct c..\-o r BOP Test K Mechanical Integrity Test ~ Location Clearance 0 Othe, "''' ,,::u'»; \' ,,~'>\:>~ Ç> ~ \,\,,~ \'~~'>.;),~'> ~ \2) '* Me ':',\0 ~ <PI\-\'t ~\ì ~~\\Cè\>~~~'\"~\ \-C*G.\.~~\~~fèV>J~~ Mvs~b«: ~~\-\c.¿) , Subsequent Form Required: l..\'\)"\. Q q:~ ()~ ~ \ \ Commencing Operations: 16. Verbal Approval: Commission Representative: Plug ,. Approved by: 13. Well Class after proposed work: Exploratory ~I¡ , ~elopment D 15. Well St;u~ %îl~d'work: Oil 51 Gas D Plugged D Abandoned ~D WAG D GINJ ~""~~ D WDSPL 'It.'. ~ of produced oil from Nikaitchuq #3 well tes. ''1~~ Contact Skip Coyner: 907-339-6269 j (;..../ Service D Date Id~ fPlo".J.- of) Jt:'-5 - ó6~ COMMISSIONER APPROVED BY THE COMMISSION ~ 3/I~Ç Date: OR1C, L RBDMS BFL MAR 1 7 Z005 . Submit in Duplicate ~ \ÌI - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' - 4500' KOP :::: 3000' BUR:E 6"/100' Pad Elev == 1.0 ft GL to RKB == 30.5 ft Rig RKB == 31.5 ft 2-7/8"" WellStar TRSSV at ± 432' 2-7/8", l-80, EUE-M 9-5/8",40#, l-80, BTC-M 2457' MD I TVD LOT:::: 14.4 ppg EMW 7" H-ES Cementer at 2,834' Tubing Deployed ESP with gauge carriers, in Tangent section at 72,0 Nikaitchuq #4 (Current ESP Completion) -----------------------------, ,9.3#, EUE Slotted Liner: 4672' -7,567' MD I _....... _.. - - - - - - - - -- -- - ... _.. .... -., OBM TMD 4,186' TVD ----- BTC-Mod 4,145' S Coyner 3/10/05 - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' Pad Elev = 1 ft GL to RKB = 30.5 ft Rig RKB = 31.5 ft - 2-7/8"" WellStar TRSSV at ± 80' 2-7/8",6.5#, 9-5/8", 40#, BTC-M 2457' MD I TVD TOC :: 2834' MDITVD GlM, SSD or ES Cmtr 2,950' MD Nikaitchuq #4 (Proposed Re-Configuration) --------------------------- -...-... - - -.- Coyner 3/10/2005 . . (..1 KE1JR..MCSEE ""'- ß Nikaitchuq #4 Re-Configure Program I Drilling Rig: Nordic 3 I Re-Configure the Completion Suñace Location: 350' FSL & 1460' FWL of Section 16, T14N, R9E UM X = 519,643' Y = 6,054,828' I Start Operations: 13/16/05 I I Operating Rig days: 12 I TMD: 17,577' TVD: 14,186' I I BHP: 11694 psi I DF: 131.5 ft I I Objectives: Pull ESP completion. Run tubing & packer [EZSV] Casing - Actual: Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD I TVD MD I TVD N/A 13-5/8" 68# L-80 BTC 102' 31' 133' 1 133' 12-1/4" 9-518" 40# L-80 BTC 2,426' 31' 2,457' 1 2,457' 8-1/2" 7" 26# L-80 BTC 4,820' 31' 4,851' 14,154' 6-1/8" 3-1/2" 9.2# Slotted LNR 2,895' 4,672' 7,567' 14,186' Producing Reservoir MD (ft) TVD BHP KWM Schrader Bluff, OA sand 4,145/7,577' 4,145 1,694 Sea Water Well Control: The BHP as recorded on Halliburton's gages is 1694 psi at 4145' TVD. That equates to a gradient of 7.86 psi/ft. The 13-5/8" BOP stack will be N/U on the 13-5/8" (5M) Vetco Gray wellhead and 2-7/8" rams will be installed. Because the BHP is only 1694 psi, Test the rams, valves and manifold to 250 psi low I 2500 psi high. Test the annular tested to 250 psi low I 2500 psi high. Maximum Suñace Pressure = 1694 psi - (4145 ft x 0.11 psi/ft) = 1238 psi S Coyner . . 3/10/2005 . . ,. Disposal of Waste: · 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 / Prudhoe Bay / North Slope Borough where it will be treated and injected. H2S: · H2S was not detected during the extensive test of the Schrader Bluff in this well As a precaution, however, H2S monitors will be used at all times in accordance with State Regulations. RE-CONFIGURATION PROCEDURE Pre-Rig Work: 1. RlU SLU. Pull the gage/dummy GL V from the GL Vat 4000' MD. RID SLU. 2. Displace the well [circulate] with hot diesel to clean up the casing & tubing. 3. Kill the well with heated sea water [circulate] then bullhead 20-30 bbl into the lateral. 4. Close the TRSSV and install a BPV. 5. Blow down and disconnect the flow lines. Rig Operations: 1. MIRU Nordic 3. RlU the ESP cable spooler. 2. Flow check. N/D the tree. N/U Nordics' 13-5/8" BOP stack on the. Test the BOP stack to the approved pressure with the AOGCC field supervisor present to witness the test. 3. POOH with the 2-7/8" EUE tubing. Spool up the ESP cable. UD the ESP. Keep the hole full using warm seawater. 4. M/U a 7" EZSVand RIH on 2-7/8" tubing. Run a GLM/SSD or H-ES cementer at ±2950' MD depending on availability. Re-Run the TRSSV at ±80' MD. 5. Set the EZSV at ±4500' MD. Test the annulus to 2500 psi. .~ ~,,'~~~cr 6. Space out the tubing. M/U the tubing hanger. Shift the EZSV to the open position and land the hanger. Pump through the EZSV to confirm that it is open. RILD's. Close the TRSSV. 7. Install a BPV. N/D the BOP's. N/U and test the tree. 8. RD & MO Nordic 3. 9. Rig up the flow line as an injection line. 10. Retrieve the BPV. S Coyner . . 3/1012005 · March 11 t\ 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No.6 3/03/05 3/04/05 3/05/05 3/06/05 3/07/05 3/08/05 3/09/05 3/10/05 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. Slowed the ESP from 50.2 Hz to 46.7 Hz. Oil Rate dropped from 800 BOPD to 715 BOPD. 60 MCFD. PIP increased from 935 psi. to 985 psi. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP at 46.7 Hz. 679 BOPD, 150 MCFD. PIP = 971 psi. SD the ESP at 18:00 hrs for samples and BHP. 7,577' MD / 4,186' TVD RID SLU. RIH with LIB: no sign offish or sand. POOH. RIH with sampler. Made 3 sampler runs. 7,577' MD / 4,186' TVD Continued down-hole fluid sampling with SLU. RID SLU. Shut in for BHP. 7,577' MD / 4,186' TVD Shut in for BHP build up. Hauling oil. Tanks empty. 7,577' MD / 4,186' TVD Shut in for BHP build up. Re-started the ESP. Phase II/III. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. Phase II. 7,577' MD / 4,186' TVD At midnight 3/10/05, shut in for BHP build up. Phase I/II. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 . ~ C? fA' IT ~ rñìo re ® 0 fM ~J, ~ lR,\ cY) w L~ i-j ~ LW J lfîJ Lb iFU æJ u ù UìJ . /} ~f) t.f / Z& 0 AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Todd Durkee Drilling Manager Kerr McGee Oil & Gas Corporation 3900 C Street, Ste 744 Anchorage, Alaska 99503 Re: Nikaitchuq #4 Sundry Number: 305-053 Dear Mr. Durkee The Commission denies the enclosed Application for Sundry Approval relating to the above- referenced well. This denial is based on a comparison of the Equivalent Mud Weights ("EMW s") detennined necessary to allow pumping into the fonnations exposed below the surface casing shoe. After setting the surface casing, it was possible to pump-in to the exposed fonnations at 14.2 EMW. After setting the production casing, all subsequent pumping operations have required EMWs in excess of 14.7 ppg. Based on the submitted pressure infonnation, it is not possible to meet the requirements of 20 AAC 25.080(e)(2) [downhole disposal pressure may not exceed that initially detennined, unless the Commission finds that ... waste will not migrate above the confining zone]. As provided in AS 31.05.080(a), 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 day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. person may not appeal a Commission decision to Superior Court unless rehearin ee re sted. ~ DATED this L day of March, 2005 . Note to File . Nikaitchuq #4 (204-260...305-053) Exploration Kerr-McGee Oil and Gas Corporation Kerr-McGee has made application for annular disposal for the subject well. This document examines the pertinent information for the well and recommends the request be denied. --Surface casing was cemented surface. Some lost circulation was experienced, however returns were regained and lead cement was circulated. Additional cement was circulated via the Fa circulating tool installed at 60' md. No top job was performed. --The surface casing was successfully pressure tested to 2500 psi with no pressure loss reported. --On the initial leak off test, the pressure slope changed at 14.4 EMW and "broke" at 14.7 EMW. Steady pump in occurs at about 14.2 EMW. The pressure declined slowly during the observation period to about 11.7 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --No major problems are reported while drilling, coring or plugging back the intermediate pilot hole. The wellbore was successfully sidetracked off the abandonment plug and landed in the target zone. The 7" casing was run and successfully cemented. The casing was reciprocated. An ES cementer was installed at 2834' md (-400' below 9-5/8" shoe) and after the primary cement job the annulus was circulated to assure the intervals below the shoe would be clear for possible annular disposal. --An injectivity test down 13-3/8" x 9-5/8" annulus was conducted. Pressure steadily increases until the break at 15.2 EMW. The EMW is calculated to be greater than the originally determined. Pumping continued to freeze protect the well with the pumping pressure not declining. After SO, the pressure declined 60 psi in 2 minutes and then essentially held through the remainder of the observation period. Throughout the next day, the pressure declined another 400 psi. Since diesel was pumped, having positive pressure is not unusual however the slow decline is not a common observation. Kerr-McGee requested to pump an additional diesel volume in an attempt to "clean/get past" possible formation damage. Their request was approved based on the initial LOT and in consideration that no fresh water is present in the area. Kerr-McGee provided independent log interpretations to support this claim. During this most recent pumping event, an additional 100 bbls of diesel was pumped with steady pump occurring at 16.3 EMW. No "clean up" is evidenced while the pumping proceeds. The reported pumping rates of 3 - 4 bpm are in excess of those originally pumped. When pumping was stopped, the pressure declined to 650 psi in 38 minutes and was still declining. This pressure behavior is different than has been seen on other annular disposal pumping tests. While it is possible to pump into the formations exposed below the surface casing shoe, the pressures necessary to do so are again in excess of those determined by the initial leak off test. While there is no fresh water to protect, it is a regulatory requirement that any disposed waste is to be confined in the formations below the surface casing shoe. The pressure behavior demonstrated does not allow such a conclusion to be made. G:\common\tommaunder\Well Information\By Subject\Annular Disposal\050228--Nik_ 4.doc -- Nikaitchuq #4 is the af 3 wells to be drilled in the immee vicinity. Nikaitchuq #3 will be drilled in the near future and will about 250' away from Nikaitchuq #4. Nikaitchuq #2 was drilled and abandoned in the immediate vicinity last year. Although Kerr-McGee has designed the cementing program of the #3 well to provide isolation through the potential annular disposal interval, past experience has shown that it is possible to communicate when wellbores are so proximate. --Based on examination of the submitted information, I recommend that Kerr-McGee's annular disposal request for the subject well is denied. 621~ Sr. Petroleum Engineer February 28, 2005 G:\common\tommaunder\Well Information\By Subject\Annular Disposal\050228--Nik _ 4.doc ~ KERR-:'CORPORATIfIN · February 21th, 2005 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq #4: APD 204-260 Kerr McGee Oil & Gas Corporation Application for Sundry Approval for Annular Injection of Drilling Waste Attached for your review is our Application for Sundry Approval for annular disposal pursuant to 20AAC 25.080 (a). Form 10-403AD is attached. In accordance with 20 AAC 25.1)80 (b): 1. The annulus to be used for disposal is between the 9-5/8" surface casing and the 7" intermediate casing in Nikaitchuq #4 (see attached wellbore schematic). 2. Independent analysis ofE-Line logs and LWD logs have determined that no fresh water sands are present (see attachments: Schlumberger & Sperry-Sun). The Prince Creek sand is behind pipe. The base of the Permafrost in this well is at 1703' MD/TVD. 3. The Ugnu sands below the 9-5/8" casing shoe: 2490' to 2834'. 4. Nikaitchuq #1,204-018,50-629-23193-00 (see attached plat & diagrams). Nikaitchuq #3, 205-001,50-629-23242-00 5. Water-based,KCLlPolymer drilling mud & cuttings: 9.0 - 11.0 ppg, 17,500 bbl Mineral-oil-based drilling mud~9.0 - 10.0 ppg, 500 bbl Completion brines, KCL-based: 9.0 - 9.8 ppg, 2500 bbl Freeze protect fluid (diesel, etc.): 6.9 ppg, 2000 bbl Rig & cementing wash water, boiler & camp water: 8.4 - 8.5 ppg, 2500 bbl 6. Freeze protection fluids (diesel/ crude oil) and produced water. 7. The anticipated maximum pressure at the 9-5/8" casing shoe is 1840 psi: Injection test dated 2/06/05: 650 psi + (9.3 ppg x .052 x 2457') = 1840 psi 8. L WD GR/RES log is attached showing BlPermafrost and the formations exposed to the annulus which is the subject of this application. Likewise, cementing records and a CBL are attached. 9. The outer casing string set at 2457' MD/TVD is 9-5/8", 40#, L-80, BTC: Pc = 3090 psi, Pi = 5750 psi. The outer casing string set at 2457' MD/TVD is 7", 26#, L-80, BTC: Pc = 5410 psi, Pi = 7240 psi. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 · . ~ KERJl..MCSEE ctJRPORATItJII 10. The injection pressure at the 9-5/8" shoe obtained while freeze protecting the annulus (after cementing the 7" casing) was 1880 psi. 1000 psi + (6.9 ppg x .052 x 2457') = 1840 psi 11. There are no hydrocarbon bearing zones exposed to the 7" x 9-5/8" annulus. 12. The disposal operation must conclude prior to March 31, 2005::S 40 days. 13. This is the first application for annular disposal for this well/project. 14. Drilling waste from Nikaitchuq #3 will be disposed of into the 7" x 9-5/8" annulus on Nikaitchuq #4 (drilled first). Also with AOGCC approval, drilling waste from Tuvaaq State #1 (3-1/2 miles away) will be disposed of into the 7" x 9-5/8" annulus on Nikaitchuq #4. All of these wells are part of Kerr McGee's exploratory drilling program, and whereas they are not all on the same pad, they are all part ofthe same project. 15. Kerr McGee plans to fully comply with 20 AAC 25.080 (d) except that Kerr McGee requests permission to dispose of drilling waste generated at Tuvaaq State #1 into the 7" x 9-5/8" annulus in Nikaitchuq #4. These wells are not on the same pad. No permanent pad exists for either well. Sincerely, s&~~ -------- ASRC Energy Services Project Drilling Supt. Attachments: Nikaitchuq #4 Wellbore Schematic Nikaitchuq #3 Wellbore Schematic Nikaitchuq #1 Wellbore Schematic Nikaitchuq #4 LOT below the 9-5/8" Shoe (previously submitted) Nikaitchuq #4 Injection Test in 7" x 9-5/8" annulus L WD GR/RES log CBL run on the 9-5/8" shoe on 2/10/05 ScWumberger's E-Line log analysis ofNikaitchuq #1 Sperry-Sun's LWD log analysis ofNikaitchuq #1 Sim-Ops Plan 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 1. Operator Name: . .. STATE OF ALASKA Auw. OIL AND GAS CONSERVATION COM.ION ANNULAR DISPOSAL APPLlCAì'rON 20 AAC 25.080 3. Permit to Drill No: ~ ~.';.,,,,-<.'" Kerr McGee Oil & Gas Corporation 204-260 4. API Number: 50- 629-23241-00 2. Address: 5. Well Name: Nikaitchuq #4 3900 C Street, Ste 744 Anchorage, Alaska 99503 6. Field: Exploration 7. Publicly recorded wells a) All wells within one- quarter mile: Nikaitchuq #1, 204-018, 50-629-23193-00 Nikaitchuq #3, 205-001, 50-629-23242-00 8. Stratigraphic description: a) Interval exposed to open annulus: b) Waste receiving zone: c) Confinement: \ Ugnu san s 2490' to 2885' MD I TVD a) 9-5/8" asing at 2457' MD I TVD b) 7" ing with TOC at ±2850' MD / TVD b) water wells within one mile: none Conditions of approval: B/Permafrost = 1703' MD /1702' TVD 10. Hydrocarbon zones above waste receiving zone: / none 13' 'a""ì!'\ at)~ "."ore at ,hoe f\.... 1\ ~ 1840 psi Q \ (I ·don Test 216105) 9. Depth to base of permafrost: 11. Previous volume disposed in annulus and date: none 14. Estimated volume to be disposed with this request: Not to exceed 35,000 bbl including freeze protect fluid(s) February 24$1, 2005 CUPolymer drilling mud L VT20 based drilling mud Ri sh water, boiler water, rig camp waste water d) ompletion brines [KCL / NaCL] e) ementing wash/waste water f) roduced water subject to 20 AAC 25.080(h)(3) reeze protect fluid: diesel or oil subject to 20 AAC 25.080(h)(3) 16. Estimated start date: 17. Attachments: Well Schematic (Include MD and ty Cement Bond Log (if required) [I] FIT Records w/ LOT Graph [I] Surf. Casing Cementing Data Other [J LWD GRlRes log across the watse receiving zone Signature: /, Title: Drilling Manager, Kerr McGee Oil & Gas Corporation Printed Name: Phone 907-339-6370 Number: Commission Use Only LOT review and approval: Date: 2/;;'1/6"' Approval number: JOrs- - t7 Ç;3 ~ ~~~~~~'~'ON Date i~/.,.(' {3t)'r~ RBDMS BFL MAR 08 2005 COMMISSIONER Form 10-403AD Rev.6/2004 INSTRUCTIONS ON REVERSE Submit in Duplicate - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' - 4500' I Rig RKB = 35 ft I 12-1/4" Hole , 40#, l-80, BTC-M 2457' MD / TVD H-ES Cementer at 2,834' Annular Disposal KOP::: 3130' BUR ~ 6°/100' Pilot Hole 4,310' MD Nikaitchuq #4 (Schrader Bluff Horizontal) . 9-5/8" Casing cemented with 315 bbllead cement followed by 40 bbl of Tail cement. Circulated ± 60 bbl of cement to surface. . Drilled 8-1/2" pilot hole. Cored S.B. sand. Drilled rat hole to 4310'. Logged. Plugged back in two (2) stages: 304 sx (62 bbl) each. · 7" Casing cemented with 60 bbl of Premium cement. Opened the cementer at 2834' and C8U from 2834'. Closed the Tool. · Freeze protected the 7" x 9-5/8" annulus with 100 bbl diesel at 4 bpm. ISDp::: 650 psi. -----------------------------, 3-1/2", 9.3#, l-SO, EUE Slotted Liner I ------------------------------, 6-1/8" Hole,OBM 7,880' MD S Coyner 2/14/05 -- Surf -- 1000' -- 2000' -- 3000' -- 4000' -- 5000' -- 6000' -- 7000' -- SOOO' -- 9000' 7" Whipstock at 9235' MD (At the T/Sag River Silty zone) I Rig RKB '" 35 ft I 12-114" Hole TOL = 4200' 9-5/S", 40#, L-SO, BTC ?: 4350' MD 1 TVD 7", 26#, L-SO, BTC-Mod Drift ID:::: 6.151" ........ S-1/2" Pilot Hole KOP = 7330' +- BUR:::: 4°/100' :::: 9200' S9° Nikaitchuq #3 Drilling Phase · 80 ft of 13-3/8" Drive · 12-1/4" Drill Hole to 1: 4350' MDITVD · & cement to · 8-1/2" intermediate pilot hole through the · KOP is 7330'. Build to 60° and hold to Pilot hole TD · Set and cement 7" intermediate Liner · Set a whipstock & Mill a window at River. · Build to 89° in the 6-1/8" · Hold angle at + 89° for the entire 3000' · Drill the 6-1/8" OBM · Run a slotted liner with Hyd'l HGR & PKR · Run an ESP completion 6-1/S" Hole with OBM S9° ~--------------------------------- 3-1/2",9.3#,1...-80, EUE Slotted Liner ] a _____________________________________J 7",26#, l-SO, BTC-Mod 9600' MD /S99S' TVD Revised: 12/21/04, SC -':~ -i:.-·-·-·f-·-·- Mud - --"'- 26ft, 21 ft - -,. 42' MD Nikaitchuq #1 Plug & Abandon t (Sundry No.: 304-088) 1. Displaced the tubing and lower liner from 5800' perforations with 1 ppg mud. an 10,380' MD. Tagged & tested the to 1500 Dumped of cement on top. :::: 1 MD. sx of Premium cement via tubing, through the 5860' -70', had returns to surface. Displaced with 10 bbl water and allowed the well to U-tube: leaving the TOC at MD. . 3-1/2" Tubing cut & at 68' MD cut & at 63' MD 1 cut & retrieved at 50' MD Covered the casing stubs and back filled conductor hole with yd3 Ready Mix I I I I I I I I I I I + I I I I I I TOL at 5556' MD TVD) (Tested to 3500 psi) 9-5/8" at 5708' MD (4688' Punch Holes: MD Sliding Sleeve at 5878' MD (could not pump through , 9.2#, L-80, IBT -Mod Tubing ,17#, Upper liner PBR: 9450'-74' MD EZSV at 10380' wi 26' of"G" cement. TOC "" 10354' MD (Tagged & tested to 1500 psi. ) Perforations: 10408' to 10472' MD 8716' to 8778' TVD PBTD"" 10,750' MD (CTU 11,CHO' TMD (9307' TVD) CASING AND PRESSURE INTEGRITY TEST Date: Pump used: #2 Mud Pump .. Pumping down annulus and DP. Weil Name: Drilling Supervisor: Rig: ., Hole Size: USE PICK LIST RKB-CHF: Ft Casing Size and Description: Cas!nf , T~,~t Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight (Pumps off BiockslTop Drive Weight: Casing Shoe Depth ppg Lb/100 Ft2 Pressure Mud Weight: Mud 10 min Gel: Rotating Weight (Pumps off): BiockslT op Drive Weight: Desired PIT EMW: psi Lbs Lbs 1.7 bbls . EMW :::: leak-off Pressure -I- Mud Weight :::: 0.052 x TVD 0.052 x 2457 -I- 9.3 EMWat 2451 Ft-MD (2451 Ft-TVD):::: 14.4 ppg 3000 2000 w a:: ;:) tJ) 1500 tJ) W a:: Q. ;;. 'It n ppg Lb/100 Ft2 Lbs Lbs ppg bbls r;"l PIT 15 Second Shut-in 615 Lost 1 00 psi during test, 96.1 % of test pressure. i .........CASING TEST _LEAK-OFF TEST 5 0 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point Barrels Comments: Input ... Volume Pumped 2.0 Bbls Volume Bled Back Bbls Volume/Stroke i Bbls/Strk ... Pump Rate: Strk/min ... Pressure Integrity Test Pumping Shut-in Strks psi Min psi o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4.5 5 5.5 6 6.5 7 7.5 8 8.5 9 9.5 10 Volume Pum Jed 3.1 Bbls CasÌlig Test Pumpin¡:;¡ Shut-in Strks psi Min psi o 1 2 3 4 5 6 7 8 9 10 15 20 25 30 Volume Bled Back Bbls CASING TEST and FORMATION INTEGRITY TEST Well Name: NIKAITCHUQ#4 Date: 2/17/2005 Supervisor: DURKIN/SPRINGER o initial Casing Shoe Test Reason(s) for test: Formation Adequancy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" 26# L80 BTC CSG 2,459' TMD TVD Hole Depth: 2,833' TVD Mud Weight: 6.9 ppg Length of Open Hole: EMW= 1 ,000 psi 0.052 x TVD = 1,000 0.052 x + Mud Weight + 6.9 ppg Pump output = 0.3000 bps Fluid Pumped = BLED BACK = 0.0 1.300 p$i 1 ,200 psi íIIIoo- _ c: ¡:¡ ~ :;:¡ t: 1: '!:! 1.100 psi 1,000 psi 900 psi W 800 psi œ: ::::;:¡ !f} !f} w œ: 0. 700 psi ~~~~~-, - 600 psi ~._-- 500 psi 400 psi 100 stk 300 p$i BBLS BBLS TURN LEAK-OFF DATA CASING TEST DATA MINUTES FOR MINUTES -,....-----...--- ----....--......-- 150stk . 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Ð ~GI Ð ~ ~_:::=...- .................-1aW ~-O=::~-- flfl( rrç,fIfJIiIÞ_ ..xx / z.D,=xø:. / / / / I I 1 I \ \ . <:> .' ~ 100'-0' I / / / / / / ..- --- --- NIK. /4 \ \ \ \ , "- " , '.... -- I / / / / / / ,/ --- -- \ \ . -- I /'5'"MEOIC ~ ~ACC CONEX ¡r ~D 166'-2 ""'"" I RIG CAMP JJ ROWAN 54 CAMP J SEWAGE 250'-0' WARM STORAGE TENT D("::~~4~V;~0~TC) .. c:::::=r GEO SHA~. c:::::=r MUD LAB ~8-0~ I æ-o-----._ I r- RIG CAMP 1/ r RIG CAMP 12 r - ~, NORDIC /8 MAN ~ NORDIC 20 MAN 1:, ~ L- CAMP/OFFICE l t CAMP - f -=- (:ONf:t-J'n/AL 'IF-SKW 'D:tIMl-:NTI NOT TO BE II.'IED ~"OII CONSTlllJI.'TIIIN 011 ACTUAL EOUI'I>ENT LA YIIUT ~ ABRCBnorgyBorv'o.. V..... ....~ GENERAlARRANGEMENTD~GRAM WELL TEST EQUIPMENTIPAD LAYOUT (A-WELL) KERR McGEE EXPLORATION WEll TEST .... ,_.. ,_.. SEP1[U8£R 21. 201M BUD """"" O. SC011/O. .."'tR,o< ~ ClCaCCDIIII ~ NOI€ 0. SC011/D. "'_CH _ DAS KMG -... --- --- .... IÞ -..... - I - KMG-2005-001 01..01 I 0 DAS .. BUD .. 20'-0' (MlN - FIRE LANE) o _"7/111'ssutD roo CUENT _AI. - ..... ... .... - PAD ACCESS ROAD r ....-cz .. HDjINT... . . Schlumb8rg8r To: From: Skip Coyner ASRC Aron Kramer Formation Evaluation Team leader Schlumberger Nikaitchuq #1 Rw Evaluation 18-Nov-2004 Subject: Date: Dear Mr. Coyner: Schlumberger (myself and Mr. Doug Hupp) has reviewed the Nikaitchuq #1 wireline logs acquired on 21-Feb- 2004 and 02-Mar-2004 respectively to determine the formation water resistivity (Rw) as per your request. A basic Archie relationship approach was used incorporating the deep induction (AHF90J. the Gamma Ray, the formation density (RHOZ) and the neutron porosity (NPOR) measurements. The shallowest zone that was reviewed was found at 2,200 feet measured depth on the wireline log acquired on 21-Feb-2004. The Rw value for this zone was determined to be 0.9 ohm-m, which can be converted to a NaCI parts-per-million concentration (ppm) of approximately 9,000 ppm at 50 deg F (50 deg F is the lowest temperature on the charts and the formation temperature at this depth should be close to this). Several more zones were analyzed from the first logging pass (21-Feb-2004) and determined to have Rw values much less than the 2,200 foot zone with the typical values around to 0.1 ohm-m. The second set of logs using the same type of tools (platform Express - PEX) was acquired on 02-Mar-2004 to a depth of 10,996 feet measured depth. All of the zones analyzed in this logging pass had a computed Rw value of 0.1 ohm-m +/- 0.05 ohm-m. The deepest zone analyzed was at 10,800 feet measured depth with an Rw value of 0.1 ohm-m. The NaCI part-per-million concentration at 10,800 feet, assuming a formation temperature of 214 deg F is about 21,000 ppm as read from chart Gen-9. Please advise if you any further need of Schlumberger's assistance in this or any other matter. Regards, Aron Kramer Formation Evaluation Team Leader Schlumberger Data and Consulting Services All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not. except in the case of gross or willful negligence on our part, be liable or responsible for any loss, cost, damages or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers, agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule. ,. . f ) . '~ ) Water Salinity Analvsis for Nikaitchuq #1 - Rwa method The purpose of this short study is to attempt to define potable aquifer zones below the pennarrost in the vicinity of the Nikaitchuq prospect. The apparent water resistivity (Rwa) method is better suited for this particular case than SSP, given the drilling fluid and fonnation characteristic parameters. The following criteria and assumptions act as guidelines for the log analysis: 1) Potable water is defined as that containing 3000 ppm total dissolved solids (TDS), or less. 2) TDS is herein defined as NaCl equivalent. 3) Base pennarrost exists in the study well at 1840'TVD. 4) Base pennarrost is taken as 32 deg. F boundary as well, although this gives an anomalously high geothennal gradient of over 3 deg/l00 ft to be able to attain the 114 deg F bottom-hole temperature evident on the wireline logs. 5) Shale volume is calculated by both GR and Neutron-density methods, and the lesser of the two results finds use in the subsequent equations. 6) Porosity is calculated by both the N-D shale corrected average and sonic transit time using a Hunt-Raymer based algorithm (<1>s = 0.6*(ilt-56/ ilt). The lesser of the two porosities is used to calculate fonnation factor F. This will tend to err on the side of apparently fresher formation water. 7) The formation factor, F, is calculated using the Humble formula for unconsolidated sands (F = 0.62/<1>2.15). 8) The AHF90 resistivity curve from the wireline log is taken as Rt. 9) High resistivity is due either to a) decreased porosity, or b) decreased formation water salinity, not by the presence of hydrocarbons. Any gas or oil present would cause apparently high Rwa (low salinity), causing errors on the side of ftesher fonnation water. 10) Sand intervals, for analysis) are defined as having GR < 75 api (60 api after correcting for KCI mud), and thicker than 5 feet vertically. Given the above parameters and assumptions, Rwa analysis yields the following calculated salinities for the following sand intervals: Depth (TVD) Rwa @ of Chart-derived TDS Feet Q-m ppm NaCI 2038-2090 0.887 @ 50 10,000 2262-2271 1.29 @ 50 6,000 2310-2319 0.76 @ 55 11 ,000 3105-3114 0.42 @ 80 13,000 3540-3570 0.12 @ 100 41,000 3658-3673 0.126 @ 100 41,000 3726-3780 0.09@ 105 55,000 . . [) . f") The above calculations show no aquifers bearing concentrations less than 3000 PPM TDS. Two possible scources of error in the calculations may be temperature gradient, as it is uncertain if the 32 deg F isotherm actually exists at 1840 ft TVD, and the possible presence of small amounts of hydrocarbons in any of the sand sections. Hydrocarbons being present would produce an underestimation of the TDS content, whereas too high a temperature gradient would tend to produce Rwa that was lower than actual (underestimation ofTDS). R. Kalish 11/23/04 Sperry-Sun DrUllng Services . . (.,.) øRR-M"6EE CORPORA". Simultaneous Operations (production, Well Testing, Construction, Workover & Drilling) Site Specific Simultaneous Operations I. PURPOSE The purpose of this program is to assure safe simultaneous operations involving Drilling, Production Testing, Abandonment Operations, Trucking and all Personnel. For the purpose of clarity, a Simultaneous Operation is defined as any operation involving activity on the same pad that affects or involves two or more wells at the same time. This by definition includes any wire line work, Injection, or Stimulation type Pumping Services work, Coiled Tubing, Workover Operations, Well Testing work, Construction of Facilities, Production Operations, Rig Movement, etc on any other well or wells while drilling or workover operations are being conducted on another well on the same pad. In this specific case, Simultaneous Operations includes Sub-surface Operations as well. II. SCOPE This site specific program applies only to the Kerr McGee well Site Location for the Nikaitchug well numbers 3 and 4. A Site Drawing and Operations Coordinators are identified within the Drilling Prognosis for these wells. This document specifies that a permit to work system will be employed during Simops, and that the designated Supervisors will hold daily SimOps meetings, and coordinate activities to ensure adequate communications and safety precautions are in place during any and all Simultaneous Operations: on the drill site and sub-surface. III. PROGRAM A. Inspections 1. Onsite safety systems shall be tested and assured to be fully functional before the drilling rig and well testers commence simultaneous operations. Representatives from DrillinglWell Testing/Construction/etc. (as appropriate) will review equipment safety system test results and approve simultaneous operations plan prior to the scheduled startup. Well Testing and Drilling Rig Safety systems will be fully functional and tested prior to startup. 2. The Well Testing, Construction and DrillingIWorkover Supervisors (as appropriate) will jointly conduct a facility and rig substandard conditions inspection before Well Testing operations begin, using the Simultaneous Operations Check List attached hereto. Completed forms shall be sent to the respective Superintendent. . The inspection should be repeated on a weekly frequency while simultaneous operations are underway. The check list should be referenced and all applicable items addressed in order to ensure compliance. . . Simultaneous Operations (production, Well Testing, Construction, Workover & Drilling) 3. The Drilling/W orkover Supervisor and Well Testing Supervisor will jointly inspect the appropriate well site(s) when operations are completed. They are to check that the site(s) is/are clean and that all equipment utilized during simultaneous operations is in satisfactory condition. B. Responsibilities 1. The Drilling/W orkover Supervisor, Well Testing Supervisor, Construction Supervisor, and Production Supervisor (as appropriate) will be responsible for their respective operations on the facility to ensure compliance with Safe Practice Standards. . Welding and cutting will be done as per Rig Contractor welding policy and only with a permit to work system in place utilizing hot work permits fully signed and authorized by each of the following: Drilling/W orkover Supervisor, Well Testing Supervisor and Construction Supervisor, (as appropriate). 2. A qualified Rig Supervisor will be present and be responsible for ensuring communications between all of the appropriate supervisors on location and will attend the Drill Site at all times during simultaneous operations. 3. All new individuals arriving at the Drill Site will report immediately to the respective supervisor, or his designee, for orientation and instruction as to their duties in case of an emergency. Responsibilities shall be identified on the Drilling Contractors Drill Site station bill. The person responsible for maintaining the POB list shall be designated by the Drilling Rig Supervisor. 4. When conducting Well Testing Operations, Electric Wire line, Slick Line work, Pumping operations, and/or Coil Tubing Operations on another well simultaneously with any Drilling or Work Over rig operations, a supervisor other than the Drilling Rig Supervisor will be named and will be responsible for coordination of those projects activities with the Drilling Rig Supervisor. C. Communications 1. Before starting a Well Testing, Work Over, Construction operation, or Pumping Operation simultaneously with production and/or rig operations, affected personnel must be informed of the planned work scope and their responsibilities in the event of an emergency. 2. The Drilling/Workover, Well Testing, Well Work, Pumping Supervisor, and/or Construction Supervisor shall meet daily with the Drill Site Rig Supervisor to discuss operations. All parties shall note this meeting in their logbooks or daily reports. The roles and responsibilities of the supervisors on board should be clearly identified. The Rig Supervisor will ensure that the Permit to work system is clearly understood. Issues to review should include all permitted work POB capacities, drills, fluids movement and transfer, Trucking and Equipment movements (such as oil-based mud/ testing wells), waste streams, changes in scope, and upcoming operations. Page 2 of6 . . Simultaneous Operations (production, Well Testing, Construction, Workover & Drilling) 3. All supervisors of each discipline are to sign approval of each of the hot work permits/safe work permits prior to work commencement. 4. Drilling, W orkover, Well Testing, or Construction Operations, that could result in the release of hydrocarbons (such as well testing, wireline work, circulating hydrocarbons out of a well bore, process piping change-out, or tank/vessel opening) should be discussed and coordinated in advance between the Production, Construction Well Testing, and/or DrillingIWorkover Supervisor. 5. The DrillingIWorkover Supervisor will discuss well control issues and Safety Shut Down Systems and protocols with the other discipline Supervisors on a daily basis. 6. Any unscheduled or unplanned activity that occurs during Simultaneous operations activities will be communicated immediately to the DrillingIWorkover Supervisor, Well Testing, and Construction Supervisor. 7. Well Testing personnel, Workover Operations Personnel, Construction Personnel, and Trucking Personnel (as appropriate) will report unplanned venting or release of hydrocarbons to the Drilling/W orkover Supervisor, Well Test Supervisor, Construction Supervisor, and Production Supervisor immediately. Any planned venting and or releases will be discussed at the daily SIMOPS meeting. 8. Drilling shall provide voice communication between the DrillingIWorkover Supervisor, Well Test Supervisor, and Construction Supervisor, or Drilling Rig Supervisor (as appropriate). D. Drills 1. Upon commencement of simultaneous operations, joint emergency drills will be conducted on each tour on a weekly basis. Review and implement Emergency Response Drills. Well Testing, Workover, Drilling, Trucking and Construction personnel must participate in these common drills. 2. Verify that the emergency shutdown system is operational before the commencement of simultaneous operations and every week thereafter (actual shut-in may not be required). E. Safe Operations 1. The planned operations are scheduled to be manned 24 hours per day and as such there may be times when well safety shutdown systems are out of service. During these times the affected wells must either be shut in or personally manned by personnel with radio communications devices such that the Simultaneous Operations appropriate Supervisor is in direct contact with the Rig Supervisor and the rig floor. The DrillingIW orkover Supervisor must be notified immediately in the event that a Simultaneous Operation is about to start or stop. 2. Well Testing, Construction, Trucking and Drilling/W orkover Supervisors should determine if the offset well needs to be shut in before making a heavy lift, skidding rig, moving equipment, or perfonning a nipple-up operation. Page 3 of6 . . Simultaneous Operations (Production, Well Testing, Construction, Workover & Drilling) 3. Either well having sustained casing pressure during the well test should be monitored and secured as needed to ensure safe operations. This includes piping to a "bleed tank" and specific efforts to minimize the casing pressure. F. Well Control and Prevention of Cross Flow 1. The planned operations will include annular injection of drilling waste (if approved by AOGCC) into the 9-5/8" x 7" annulus of Nikaitchuq #4. The disposal zone will be opened during the drilling of the surface hole on Nikaitchuq #3. The Nikaitchuq #3 surface hole will be drilled on diverter, and therefore, every pre-caution will be taken to prevent an induced flow to surface and/or cross flow below surface. These wells are only 250 ft apart. 2. Annular inject into Nikaitchuq #4's outer annulus (OA) will be suspended beginning at the time when the drilling rig is accepted and ready to pick up the surface hole BRA to drill Niakitchuq #3, and ends only after the surface casing in Nikaitchuq #3 has been successfully cemented to surface. 3. Sub-surface cross flow will be mitigated by properly cementing the surface casing strings on all wells on this drill site with special attention to the cement across the disposal zone: ±2850' to ±2450'. a) In 2004, Nikaitchuq #1 set surface casing at 5712' MD / 4680' TVD. That casing string was cemented to surface and was properly plugged. b) Nikaitchuq #4 will set surface casing at ±2450': through the Prince Creek and will be cemented back to surface. To confirm up-hole isolation, a CBL will be run during the intermediate logging program. The top of cement on the 7" intermediate casing is planned to be ±2850'. c) Nikaitchuq #3 will set surface casing at ±4350': into the Colville mudstones, but this casing string will be cemented in two stages to ensure quality cement and isolation across the annular inject zones open in Nikaitchuq #4. The second stage cement job will place Class "G" cement across the disposal zone: ±2850' to ±2200' using a stage tool at ±2850' . Permafrost "L" cement will be pumped ahead of the class "G" and will fill the annular space from ±2200' back to surface. IV. REFERENCES Simultaneous Operations Check List Drilling Prognosis for Nikaitchug # 3 and # 4. General Arrangement Diagram for Well Test Equipment Pad Layout Drawing showing Rig Components Onsite Supervisor List Page 4 of6 . . Simultaneous Operations (Production, Well Testing, Construction, Workover & Drllling) SIMULTANEOUS OPERATIONS MEETING SCHEDULE AND DIRECTIVES A simultaneous operations meeting will be held daily in the early morning by the supervisors on location. It is preferable for this meeting to be held immediately following the morning report delivery. It should be held between 7am and 9am by the Drill Site Supervisor. The objective ofthe meeting is to inform all parties of the days activities and to obtain permits for work as needed. During this meeting all the supervisors should confer about safety requirements for the tasks at hand. It is mandatory that all supervisors attend. This is to include all ofthe Kerr McGee supervision on location and the Nordic Tool Pushers. Ifthere is room during the meeting, the Welder, and Tour Pushers are encouraged to attend. The Well Test Supervisor, any and all Work Over Supervisors, Pumping Supervisors, Construction Supervisors, Trucking Supervisors, Coiled Tubing, Wireline, Slickline, or any other Simultaneous Operation Supervisor is required to attend. The Drilling Rig Supervisor is responsible for seeing the meeting is attended and faciliatated. It is expected that the Rig Supervisor will direct the meeting. The agenda will be as follows: 1. Daily activities planned 2. Any required Permit work that is planned for the day is to be discussed and approved by appropriate personnel. 3. General Safety meeting information may be introduced or not as appropriate. 4. Follow up information from the previous 24 hours as appropriate 5. Materials and equipment movements 6. Required communications during the day and any notifications of events outstanding. 7. Critical path issues are to be voiced here on a daily basis. 8. Any significant item that one of the Supervisors believes should be addressed. 9. Attendees will sign an attendance sheet on a daily basis. The sheet should summarize the items discussed. A written agenda for the day and meeting is highly recommended. 10. The SimOps notes and attendee list will be filed with the well file records. Page 5 of6 . . Simultaneous Operations (Production, Well Testing, Construction, Workover & Drilling) SUPERVISOR LIST Drilling Site Rig Supervisors Well Test Supervisors Trucking Supervisors Construction Supervisors Wireline Supervisors Injection Supervisors Production Supervisors HSE Representatives Page 6 of6 ~~! .,. '"' f~í ,¡,~~ 1:" ~>\~' 0:" ø:.~;' i~" .¿~ ~~-' .,~~ rr.... ~.~~ ~., i::~-' 1I,i<~;' i:~-' .......~ ¿"'-' ø:~~ ,.::~ r;... I....~ ¡.~~ .". J~:; ~4~ Ii.,. "., ~'~-' ,. ., ./::' r.~., &,. ,'~'" ..~-' .'.~ ..... t.~f. t:~-' &;~~ .1:,~. I?",,:, ~.. ,.. ., ,. i~~ ,_._._._._._._._._._.~~,_._._. ...... 2500' ~~t. >:,'(', ~., ,. ., ~'~-" ,. ., ,}-' I(~t. "":'-: ._._._._._._'_._._._.~, ~':'~ ., /:;. lI'~í rr.., i~~ ~~ ri.:.~ ",." ,,« ..., ..,. ,..... ~'~.' ,. ., ~~~ ';:'" "., ~"* '., ..~~ f~:' /:; ~~ ..... Iì'~-' ,. ., ~~~ .:.\ ~.., 0;" II ...... S u If ....... 500' ....... 1000' ....... 1500' ....... 2000' ...... 3000' ...... 3500' ...... 4000' ...... 4500' S Coyner 1/29/05 Nikaitchuq #3 2005 Nikaitchuq #1 2004 .. ::.:'.~;. ¡il ~1' ;;;'J .g :$~.i .~;: ~;.":, ·n~ :?,i I':':' ;:;~j .~~ ~.:~~ it::: .1:':"t I~-:~ :~~¡ iž~~ .... t§: "í.I.1.: I . ., '}~¡ :~~iI I::~' ..:-¡...$.f ,," ....1 1~5; ;~~i ."" [~ií .1ii ....,; it,;;;: 1m ~w ,. ~:.:.:.~.':.:. ;~~. 15 : ~~i .~~~ ...... '\.., ~~~J i%~j ..... '.... !~~I m; ~r' -. -. -. -. -. -. - íf:{! . -. -. -.- ~~J I~;.; ~~tJ .~~; "', '.,. o 0 0 ~?~ ~~5; 0_ 0 - -1- - 0- 0 - 0 - 0 - 0 - ~~ - 0 m 0_ ,-,~i b~ :;::~ ,":;t ~~~, 1~0~ ~~ ~?~: :~$J .~$~ ti~! ~ii! ..... t. ~::,~ .:.~, ;'~~JI w:..c; ~?~j t~~~ ~U~ ~tf~ ,;",' I";'~ if~' ~~ J~~ b .. i~~: .~~: i ., R~ "? I~; ~~~ ..... ~~~ ~f~ ".~~ ." ., ~~j ~~j t~~ .::.:1 ,'.,¡o 5~~ 5~j ~~ï f~ d ~~J ~~ i~~ ~~~ .::.:¡ ~~1 ,,,,1 ~.~._._._._._._._._.- ~~~ b" ?~~ ~a ;~~ :::.. ~:I'-'-'-'-'-'-'-'-'-' ~~¡ n~ ;.~~ ~i~ ~~;1 ...... 5~~ ~~j .,. ~?~ .:~~ ~~~ ~~J ~~~ .... $~~ fi~ \:" }~J ~~~ i Nikaitchuq #4 2005 ::~%~ "~:,, ~~~: f.~~; ~f~¡ ~,.. .,. :::,.'; f:'" tm t":::"~ B:~':: ~$~i ~"f::; ". "a< (ig t·~:., b. .,. ~f,; ~$~i "';.:,:; 1';".. I i:::'; .;-::..-; 1:'" r..;~: E~-'~; ....' ~.~~; i~~i ..... .., ,.... .... I :~~~ ;~:1 '..... ;~~J ~~~ª :~;·:t ~~~~ ........ ~%~~ ~~~~ ~?~ª :~~~ ~~~~ ,..... :~~:I ~$~i ~~~ ~~ ::.~.'I ~~:..~ ,~.':I ~~~) ':'~~ -Pû. _~....5!ª·: )~5P~ .~I;)J.IVº. _._ I Annular : Disposal ¡~_._._._._._'_._._'_._._.- ~~5~ \~ ·~;Z~ . ~~"::.~;'~'''''''':''..'m~j.. .."'............."-.................... " ...hOo' ,~~:.~-'~;;,....... ............ .......... .....~~~~.:~~~~~~~~,. 7", 26#, l-80, BTC-Mod 4,880' MD ¡ 4,145' TVD Pilot Hole 4,300' MD March 3rd, 2005 . Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weeklv Operations Report No.5 2/25/05 2/26/05 2/27/05 2/28/05 3/01/05 3/02/05 7,577' MD / 4,186' TVD Pulled BPV. Started ESP and established initial, stable production rate. 7,577' MD /4,186' TVD SID ESP for initial "cleaned up" BHP data and bottom hole oil samples. RIU SLU. RIH with oil sampler. POOH. Slick line parted in the tree but the sampler fell to bottom. Attempted to fish same: no luck. Decided to continue the test with the sampler in the tubing. RID SLU. Re-Started the ESP & re-established a stabilized production rate. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. Increased the production rate with the VSD and re-establish stabilized rate. PIP = 1250 psi. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. Increased the production rate with the VSD and re-establish stabilized rate. PIP = 1030 psi. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. Increased the production rate with the VSD and re-establish stabilized rate. PIP = 1030 psi. 7,577' MD / 4,186' TVD Continued producing Schrader Bluff "OA" sand with ESP. PIP = 967 psi. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 e . February 25t\ 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weeklv Operations Report No.4 2/18/05 2/19/05 2/20/05 2/21/05 2/22/05 2/23/05 2/24/05 7,577' MD / 4,186' TVD Finished drilling "OA" lateral to 7577' MD /4186' TVD. CBU x 3. Pumped out to the 7" shoe. RIH. CBU x 3. Displaced the lateral with new OBM. Pumped out to the shoe. POOH. 7,577' MD /4,186' TVD Finished POOH. LID BHA. Tested BOPE. R/U tubing tools. Ran 3-1/2" slotted liner with TIW HGR and PKR. PIU DC's. RIH with 4" HWDP & 4" DP. 7,577' MD /4,186' TVD Continued RIH with 3-1/2" slotted liner to 7567' MD. Dropped the dart & pumped it down. Set the LNR HGR. Set the LNR PKR. TOL = 4672' MD. Tested the 7" casing & LNR PKR to 2500 psi. Released running tools. Displaced the 7" casing with 9.3 ppg brine. POOH. PIU ESP and RIH on 2-7/8" tubing. 7,577' MD / 4,186' TVD Continued RIH with ESP & tubing. At 4000', the cable test failed. POOH. Found the cable kinked and worn ~ way through just above the motor lead. Re- checked the ESP, OK. 7,577' MD / 4,186' TVD Re-Spliced ESP cable. RIH with 2-7/7" tubing from the derrick. Landed ESP (gauge carrier) at 4500' MD. Freeze protected the 7" x 2-7/8" annulus with diesel. Tested tubing to 1000 psi. Set BPV. NID BOP. 7,577' MD / 4,186' TVD Finished NID BOPE. NIU & tested the tree. Released the rig. Moved Nordic 3 to Nikaitchuq #3. Commenced R/U flowlines, etc. 7,468' MD / 4,186' TVD Finished R/U flowlines, etc. Held SimOps meeting. Made final checks & tests. Opened the well to the test equipment and started the ESP. On test this am. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 · February 18th, 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report No.3 2/11/05 2/12/05 2/13/05 2/14/05 2/15/05 2/16/05 2/17/05 3,150' MD / 3,032' TVD Finished plugging back the 8-1/2" pilot hole in two (2) stages: plug #1 304 sx Premium CMT (62 bbl) 4310'-3600', plug #2304 sx Premium CMT (62 bbl) 3600' -2900'. POOH. Test BOPE. RIH with "build BHA". Tagged TOC at 2853'. Drilled and built angle as per directional plan. 4,735' MD / 4,125' TVD Drilled ahead and built angle as per directional plan. 4,861' MD /4,154' TVD Drilled ahead and built angle as per directional plan to intermediate casing point in T/OB sand. CBD. POOH. RIU to run 7" intermediate casing. 4,861' MD / 4,154' TVD Ran 7" intermediate casing to 4851' MD / 4154' TVD. CBU. Cemented with 60 bbl of Premium CMT (341 sx). Reciprocated while pumping cement. Bumped the plug. Opened the H-ES tool at 2834' MD. CBU from 2834'. Dropped the bomb & closed the H-ES tool. NIU 7" packoff & test same. PIU lateral BHA. 4,970' MD /4,142' TVD Singled in the hole with 6-1/8" bit & BHA. Tested 7" casing to 2500 psi. C & C OBM. Drilled out the shoe track + 20' of new hole. FIT to 12 ppg EMW. Drilled ahead and built angle to horizontal. 6,304' MD / 4,170' TVD Drilled ahead and geo-steered in the OA lateral as directed. Pumped sweeps for hole cleaning. MW = 9.3. Made 1334' in 24 ms. 7,468' MD / 4,186' TVD Drilled ahead and geo-steered in the OA lateral as directed. Pumped sweeps for hole cleaning. MW = 9.3. Made 1164' in 24 ms. Performed an injection test down the 9-5/8" x 7" annulus with diesel at 4 bpm. Injection pressure at the wellhead was 1000 psi with a full column of diesel at 6.9 ppg. ISDP = 650 psi. 30 minute SICP was 550 psi. This am SICP = 260 psi. Well Test equipment is rigged up. ESP gen-sets and VSD are rigged up and tested. Sim-ops plan is place and in practice. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 Re: Kerr McGee / Nikaitchuq #1 Salinity Analysis e e Subject: Re: Kerr McGee / Nikaitchuq #1 Salinity Analysis From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Wed, 16 Feb 2005 14:16:34 -0900 To: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> cc: Jim Regg <jimJegg@admin.state.ak.us> Skip, Thanks for all the information from Nik 4, including the determined salinity information for the formations open below the shoe. Jim and I have looked at the LOT information. In each case, fluid is injected into the formations below the surface casing shoe. In the original LOT, steady injection is at 14.2 EMW and in the most recent freeze protection case steady injection is at 15.2 EMW. 20 AAC 25.080 (e)(2) prohibits a downhole disposal pressure exceeding that established with the initial LOT (14.2 EMW) unless the Commission finds that the higher pressure will not cause drilling waste to migrate above the confining zone. In this case you are seeking to pump a limited additional volume in attempt to "get past" wall cake and formation damage that might have developed across the available sands below the shoe during the 9 days of drilling operations since the original LOT. In consideration ofthe operations that have been conducted (drilling, pilot hole plugback, casing cementing and circulating via the DV) it is not unreasonable for some formation damage to have occurred. The limited volume proposed should not cause fluid migration above the confining zones. Your proposal to pump additional diesel limited to 50 to 100 bbls in an attempt to "get past" suspected formation damage is acceptable. Pressure and rate information should be gathered as this operation proceeds. Please keep us advised of your results. If it does not prove possible to "get past'I the formation damage, your future plans for ultimate abandonment need to allow for the possible recovery of the diesel in the open 9-5/8" x 7" annulus. Leaving a long "vertical" column of dieselinan abandoned wellbore is something that should be avoided if at all possible. Tom Maunder, PE AOGCC Coyner, Skip wrote: Attached are the independent analysis done by Schlumberger and by Sperry Sun on their respective logs run in Nikaitchuq #1 last year. We asked them to analyze the salinity of the sands exposed below the planned surface casing shoe. The exposed sands all have > 10,000 ppm. See attachment. Our proposal is to pump an additional 50 to 100 bbl of diesel down the 9-5/8" x 7" annulus at 3 - 4 bpm with the goal of breaking through the wall cake and formation damage. We could pump water instead but would then need to freeze protect afterward. Skjp Coyner 907-339-62690fc 907-748-3689 cell 1 of 1 2/16/20052:26 PM e e Schlllberg8r To: From: Skip Coyner ASRC Aron Kramer Formation Evaluation Team Leader Schlumberger Nikaitchuq #1 Rw Evaluation 18-Nov-2004 d()4~60 Subject: Date: Dear Mr. Coyner: Schlumberger Imyself and Mr. Doug Hupp) has reviewed the Nikaitchuq #1 wireline logs acquired on 21-Feb- 2004 and 02-Mar-2004 respectively to determine the formation water resistivity IRw) as per your request. A basic Archie relationship approach was used incorporating the deep induction (AHF90), the Gamma Ray, the formation density (RHOZ) and the neutron porosity INPOR) measurements. The shallowest zone that was reviewed was ,found at 2,200 feet measured depth on the wireline log acquired on 21-Feb-2004. The Rw value for this zone was determined to be 0.9 ohm-m, which can be converted to a NaGI parts-per-million concentration Ippm) of approximately 9,000 ppm at 50 deg FI50 deg F is the lowest temperature on the charts and the formation temperature at this depth should be close to this). Several more zones were analyzed from the first. logging pass (2l-Feb-2004) and determined to have Rw values much .Iess than the 2,200 foot zone with the typical values aròund to 0.1 ohm-m. The second set of logs using the same type of tools (Platform Express- PEX) was acquired on 02-Mar-2004 to a depth of 10,996 feet measured depth. All of the zones analyzed in this logging pass had a cornputed Rw value of 0.1 ohm-m +/- 0.05 ohm-m. The deepest zone analyzed was at 10,800 feet measured depth with an Rw value of 0.1 ohm-m. The NaCI part-per-million concentration at 10,800 feet, assuming a formation temperature of 214 deg F is about 21,000 ppm as read from chart Gen-9. Please advise if you any further need of Schlumberger's assistance in this or any other matter. Regards, Aron Kramer Formation Evaluation Team leader Schlumberger Data and Consulting Services All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall no!. except in the case of gross or willful negligence on our part. be liable or responsible for any loss. cos!. damages Or expenses incurred or sustained by anyone resulting from any interpretation made by any of our officers. agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule. · ~rrt- s..,., 'J' dOY,- ~Ù Water Salinity Analvsis for NikaitchuQ #1 - Rwa method The purpose of this short study is to attempt to define potable aquifer zones below the permafrost in the vicinity of the Nikaitchuq prospect. The apparent water resistivity (Rwa) method is better suited for this particular case than SSP, given the drilling fluid and formation characteristic parameters. The following criteria and assumptions act as guidelines for the log analysis: 1) Potable water is defined as that containing 3000 ppm total dissolved solids (TDS), or less. 2) TDS is herein defined as NaCI equivalent. 3) Base permafrost exists in the study well at 1840'TVD. 4) Base permafrost is taken as 32 deg. F boundary as well, although this gives an anomalously high geothermal gradient of over 3 deg/l00 ft to be able to attain the 114 deg F bottom-hole temperature evident on the wireline logs. 5) Shale volume is calculated by both GR and Neutron-density methods, and the lesser of the two results finds use in the subsequent equations. 6) Porosity is calculated by both the N-D shale corrected average and sonic transit time using a Hunt-Raymer based algorithm (4)s == 0.6*(M-56/ ð-t). The lesser of the two porosities is used to calculate formation factor F. This will tend to err on the side of apparently fresher formation water. 7) The formation factor, F, is calculated using the Humble formula for unconsolidated sands (F = O.62/cJ)2.15). 8) The AHF90 resistivity curve from the wireline log is takenas Rt. 9) High resistivity is due either to a) decreased porosity, orb) decreased formation water salinity, not by the presence of hydrocarbons. Any gas or oil present would cause apparently high Rwa (low salinity), causing errors on the side of fresher formation water. 10) Sand intervals, for analysis) are defined as having GR < 75 api (60 api after correcting for KCI mud), and thicker than 5 feet vertically. Given the above parameters and assumptions, Rwa analysis yields the following calculated salinities for the following sand intervals: Depth (TVD) Rwa @ of Chart-derived IDS Feet Q-m ppm NaCI 2038-2090 0.887 @ 50 10,000 2262-2271 1.29 @ 50 6,000 2310-2319 0.76 @ 55 11 ,000 3105-3114 0.42 @ 80 13,000 3540-3570 0.12 @ 100 41,000 3658-3673 0.126 @ 100 41,000 3726-3780 0.09.@ 105 55,000 fJ I ,f ;2- e t ) --e ,[ ) de) ~- if-Co cJ The above calculations show no aquifers bearing concentrations less than 3000 PPM IDS. Two possible scources of error in the calculations may be temperature gradient, as it is uncertain if the 32 deg F isotherm actually exists at 1840 ft TVD, and the possible presence ofsmaU amounts of hydrocarbons in any of the sand sections. Hydrocarbons being present would produce an underestimation of the TDS content, whereas too high a temperature gradient would tend to produce Rwa that was lower than actual (underestimation ofTDS). R. Kalish 11/23/04 Sperry-Bun Drilling Services fl9 .2 ðF :2- RE: Kerr McGee I Nikaitchuq #4 APD No.: 204-260 e e Subject: RE: Kerr McGee / Nikaitchuq #4 APD No.: 204-260 From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Wed, 16 Feb 200509:30:57 -0900 To: Thomas Maunder <tom_ maunder@admin.state.ak.us> Annular LOT curve attached. After this test, they finished pumping in a total of 69 bbl of diesel and flowed back 2 bbl. This am, SICP is 400 psi with diesel down to 2376' & 9.5 ppg mud below that. The Ugnu sand starts at 2500'. SÆjp Coyner 907-339-62690fc 907-748-3689 cell -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, February 16, 2005 9:18 AM To: Coyner, Skip Subject: Re: Kerr McGee jNikaitchuq #4 APD No.: 204-260 . , Interesting. What sort of a pressure graph do you have?? What EMW does that workout to be?? Tom Coyner, Skip wrote: We have now set & cemented out 7" intermediate casing in the T/OA sand. We had an ES Cementer in the string that we opened and circulated any excess cement out of the well for the sole purpose of maintaining the ability to use this annulus for disposal. All of that went well. ~ ,?o.. ~ ~c "'V\.Cc:. ~ c....~·ê \où.-\., ~ Cfc~C~ ~t'N£"'\ N)\-~~~ \; c.,~},~ c;.. 'è-\-"\o t)\J. Last night we "freeze protected" the 9-5/8" x 7" annulus VlJith dieserdown to the 9-5/8" shoe. Even though there is a pretty good Ugnu sand below the 9-5/8" shoe (2500' - 2590'), the annulus doesn't readily take fluid yet. Is that too unusual? What I would like to do is pump another 30 bbl of diesel down the annulus which may work its way through the wall cake and formation damage - thus reducing the injection pressure. I could use some feedback on this. Please give me a call in the office. Wellbore diagram attached. SÆjp Coyner 907-339-62690fc 907-748-3689 cell 10f2 2/16/2005 10:56 AM RE: Kerr McGee / Nikaitchuq #4 APD No.: 204-260 e e 20f2 Content-Description: Nik 4 Annular LOT.xIs Content-Type: application/octet-stream Content-Encoding: base64 2/16/2005 10:56 AM CASiNG TEST and FORMATION INTEGRITY TEST Well Name: NIKAITCHUQ#4 DURKIN/SPRINGER Date: D Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequancy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7" 26# L80 BTC eSG Casing Setting Depth: 2,459' TMD 2,834' TMD Hole Depth: 2,459' TVD 2,833' TVD 2,459' TVD Mud Weight: 9.5 ppg Length of Open Hole: 375' EMW= 730 + Mud Weight 730 psi + 9.5 ppg = 0.052 x TVD 0.052 x 2,459' Pump output" O.3~\", ~ 800 psi l 1 1 1 700 psi ------- Fluid Pumped = 69,4 bbl BLED BACK = 2.0 BBLS 600 psi 500 psi W It: :::J I/) 400 psi I/) W It: Q. 300 psi It> 200 psi 100 psi o psi Ostk 2 stk 4stk 6 stk 8stk 10 stk 12 stk 14 stk 16 stk 18 stk 20 stk 22 stk 24 stk 26 stk 28 stk 30 stk BBLS NOTE: BBLS TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA 32 stk MINUTES FOR lOT BBlS PRESSURE [~~~~~~~~~~~~~~r~~9~·~º~~ÞJ~~I~~~~~º~~~}~~] i ¡ 0.0 bbl ¡ 300 psi ¡ r-------------rn2j)"bbil--725psil r--------------¡---¡:Õ-bbi-r-72š--p-sil I I I I r--------n---T--ã:õ-bbTTn73Ò')sil }---------------i--------------+------------;--i : : 8.0 bbl : 730 pSI : r··-------------r1-Ó~Õ-bbIT-73(fpsi! r--------------1--------------¡---------------1 I : : : r--------------"'--------------,..---------------., I I I I I I I I t--------------1--------------t---------------i L______________l______________..L_______________J : : : : I I I I 1---------------..---------------1-----------------1 ! I I I I I I I I I I I r--------------'T--------------,---------------, I I I I ~--------------1--------------+---------------i I I I I ~--------------1--------------7---------------i I I I I I I I I ..~-------------..---------------I----------------..,¡ I I I I i I I I I I I I r--------------,.--------------,---------------., : I I I ~nnnnn--n1---n-nn-----~-----n--------~ i I I I I I I I L______________~______________..L._______________.J I : I : i I I I 1---------------4---------------I-----___________ooi I I I I i I I I I I I I r--------------"I'--------------.,..---------------., I I I I ~------nnn--4--------------+----------nn-~ I I I I i I I I ~--------------t--------------+---------------i i I i I i I I I 1----___________4______________-+-_______________00i i i i I ! i i I i I i I ! SHUT IN TIME: SHUT IN PRESSURE r-----------:----4--------------ï------------:---, L__º-~º_E!!.~IJ__L____________.L__?_~2_f?_~~_.J i 1,0 mìn ¡ i 700 psi ¡ 1----------------1---------------+----------------.... i 2.0 min ¡ i 675 psi ¡ t'--------------"f--------------.....---------------"1 i 3.0 mín ¡ i 675 psi ¡ r---..-----------'f--------------ï---------------, L__i~º_E!!.~IJ__L_____________l__~!..?_J:?~!__j i 5,0 mìn i i 613 psi ¡ 1-______________4______________-1-_______________..1 ¡ 6.0 mín i i 673 psi i ~--------------"t--------------.....-------------__"'1 i 7.0 mín ¡ i 612 psi ¡ r--ë.-õ-rñfñnr-------------T--672--ps¡-1 ~----------c---i--------------+-------n-n;ni : 9,0 mln : : 670 pSI : [I[:~º~~(6~1~~~~~~~~~~~~~]~~~~rp~!~~J CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [~~~~~~~~~~~~~]~~~~º~~Œ~~~I~~~~º~E~}~~~~J I I I I I I i I I i 10---------------1---------------1----------------... I I i i I I I I I 1"---------------1---------------1'"---------------"'1 I , I I ~--------------~---------------~----------------i : : : : ~--------------~---------------t----------------i : : : : Io______________-I_______________I-_______________.,J : I : I ~--------------~---------------:..--------------- I , I I I i I I I I I (--------------,---------------1"---------------, I I I }--------------~---------------~---------------~ : : : : 1-______________-1_______________1-_______________.. I I I I I I I I I I I I to--------------'1---------------I----------------oof I I I I I i I I I I r--------------,---------------,..---------------., I I I I }--------------~---------------~---------------~ i I I I I I 1.______________.1_______________1-_______________-' I I I I I I I I I I ,.--------------'1---------------...--------------_ooi I I I i I I I I I ,.--------------,---------------,..---------------, I I I ~-n--n-n--ni----n-----n--~n--n--n-----~ I I I , i I L______________.J_______________L._______________-' I I I i I I I ~--------------~---------------:..---------------..: : ! : I , I I i SHUT IN TIME i SHUT IN PRESSURE ~--------nc-ni----n-nnn--rn-----n--n--' : 0.0 mln : : #N/A : L______________.J_______________L._______________...I ! 1.0 mín ! ¡ ! '"--------------""---------------1-----------------1 ! 2.0 min ! ¡ : ,.--------------.,---------------t"'--------------- i 3.0 mìn ! : r______nn____'_n_nn______+n_n__nn____' : 4.0min : : : L______________.J_______________L-_______________J ¡ 5.0 mÎn ! ! ! "'______________01_______________1-_______________... ! 6.0 min ¡ ! ! t----------------t---------------t----------------"" ! 7.0 min ! ! ! r--8~Õ--mfñ--l---------------r---------------l :-----------:----1---------------1----------------, : 9,0 m:r: : : : 1.______________-1_______________100_______________... ¡ 10.0 min i ¡ i t'---------------t---------------r-----------------t i 15,0 min ¡ ¡ i r-2o,-Õ-rñTñ-l---------------r---------------l ~-----------.---i-----n-------+-n------------i : 25.0 mm : : : 1---------------"'---------------1,..----------------' l_A9_~º_!!!~~_J_______________L_______________J NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' - 4000' - 4500' 60 ft: Core 5.8. 4121'·4181' t~~ ..... 111I11I_ 1AI¡r,¡-' !\1III III~ .IWIil_ t~~ .,¡<, tf':. t: ~) Pilot Hole 4,310' MD 1 1 1 ...-1 ... :."o\,j ~1iI1iI .... ~~I ~;:J ". ¡\!Ifilli ~~~ j411« ø.::" -------------~---------~ I Rig RKB::: 35 ft I Nikaitchuq #4 (Schrader Bluff Horizontal) 12-1/4" Hole 9-5/8",40#, L-80, BTC-M 2457' MD / TVD · 9-5/8" Casing cemented with 315 bbl Lead cement followed by 40 bbl of Tail cement. Circulated 2: 60 bbl of cement to surface. · Drilled 8-1/2" pilot hole. Cored S.B. sand. Drilled rat hole to 4310'. Logged. Plugged back in two (2) stages: · 7" Casing cemented with 60 bbl of Premium cement. Opened the H-ES cementer at 2834' and CBU from 2834'. Closed the H-ES Tool. · Freeze protected the 7" x 9-5/8" annulus with 69 bbl diesel at 2 bpm. ISDp:::: 800 psi. Annular Disposal H-ES Cementer at 2,834' KOp:::: 3130' BUR~ 6°/100' ------------------------------. :-:-:-:-:-:-:-:-:-:-:-: 3-1/2",9.3#, L-80, EUE Slotted Liner ·:-:-:-:-:-:-:e 1 -------------------------______1 6-1/8" Hole, OBM 7,880' MD Q1i1J1;''";¡¡$;''",,*' _fÆl.liI~&fi. 7", 26#, L-SO, BTC-Mod 4,861' MD 14,154' TVD e February 11 th, 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weeklv Operations Report 2/04/05 2/05105 2/06/05 2/07/05 2/08/05 2/09105 2/10105 2,464' MD/TVD Circ & Cond mud while reciprocating casing. Cemented 9-5/8" surface casing with 315 bbl of lead and 40 bbl of tail. Had intermittent losses (pack offs). Circulate +1- 60 bbl of cement to surface. RID cement head. LID landing joint. RIH and opened FIO tool at 60' RKB. Circulated cement from the 13-3/8" x 9- 5/8" annulus. Freeze protected same. Closed FIO tool. NID diverter system. 2,464' MD/TVD NID Diverter & diverter spool. NIU Multi-bowl wellhead. NIU BOPE. Test BOPE as perADP (witnessed by AOGCC), PIU BHA. Single in the hole. 3,840' MD/TVD Singled in with drilling BHA. Tested casing to 2500 psi. Drilled shoe track + 20' of new hole to 2484' MD. CBU. LOT to 14.4 ppg EMW (graph attached). Drilled ahead to 3840' MDITVD. 4,120' MD/TVD Drilled from 3820' to 4120' MD I TVD. Circ & Cond for coring. Wiper trip. CBU. Spot Hi-Vis. POOH. PIU core barrel. Rlli. 4,180' MD/TVD Finished Rlli with core barrel. Washed to bottom & spaced out drill string. Cored 4120' to 4180' MD I TVD. POOH slowly. LID core and coring tools. Recovered 58' of 60' cut. Clear the floor & pack the core for shipment. 4,310' MD/TVD PIU BHA with LWD's (MRIL). RIH. Reamed out cored interval: 4120' - 4180' MD/TVD. Drilled4180't04310'MD/TVD. CBU. POOH. R/UE-Line. Rill with Run #1: PEX tools. Tools failed. POOH with E-Line. 4,310' MD/TVD Ran E-Line log suite. Ran CBL in 9-5/8" surface casing (good cement). RID E- Line. RIH with OEDP to 4310'. CBU. R/U Halliburton. Spot 710 ft, balanced cement plug: 4310 - 3600' (broke this plug back into two stages). 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 RE: Nikaitchuq #4 - Surface Cement Job . . Subject: RE: Nikaitchuq #4 - Surface Cement Job From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Mon, 07 Peb 200509:21:48 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> We used a flow loop in south Texas when this type of multi-bowl head came into use. It's just a matter of plumbing it in. We originally planned on using slips for this string but I'm not smart enough to figure out how to RIH and circulate the FIO tool before the cement sets up. All options along those lines are cumbersome and tine consuming: so we switched to the fluted mandrel hanger instead. We drilled out & performed our LOT yesterday afternoon and that went well: Shoe = 2457' MDfTVD Hole = 2484' MDfTVD MW ::: 93 ppg LOT:::: 655 psi EMW::: 14.4 ppg We pumped into the formation 2.4 bbl at 610-650 psi at did not get that fluid back (see attached) There are other anomalous LOT's out there that lend credibility to this LOT. We still plan on running a CBL in a few days. SRjp Coyner 907-339-62690fc 907-748-3689 cell -----Orig i na I Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, February 07, 20058:25 AM To: Coyner, Skip Subject: Re: Nikaitchuq #4 - Surface Cement Job Good news!!! Some time ago, I remember that on a well where were using a mandrel hanger that one of the company men made a "flow loop" around the hanger using chicksands in case of pack off. I don't quite remember all the hookup or if we were reciprocating. Might be something to consider. Also maybe looking at using slips. Mandrel hanger can work great if all goes well, but at that time the primary goal is to get the casing well cemented. How much cement was returned to surface?? Tom Coyner, Skip wrote: Just to confirm the events: § With 9-5/8" on bottom and full returns, we started pumping lead cement. § Working the pipe (reciprocation) was difficult due to the size of the mandrel casing hanger. It would hang up in the ram cavities. § As lead cement turned the corner, we lost returns, however, we continued to pump the job as planned. § Apparently the losses were induced by either a) a packoff or b) the casing hanger. Iof2 2/7/2005 9:40 AM RE: Nikaitchuq #4 - Surface Cement Job We did regatircUlatiOn and finish the cement job. tied upon the carbide lag we ran, we added 92 bbl (125 sx) of Permafrost L to the lead slurry just to give everyone a warm & fuzzy feeling about it. That turned out be a pretty good decision. We did get good cement back to surface and it did not fall back after we stopped pumping. When we circulated and freeze protected through the FIG tool at 60' MD, we got +1- 3 bbl of cement back. § § § Skip Coyrœr 907-339-62690fc 907-748-3689 cell Content-Description: Surface Casing LOT.xls Surface Casing LOT.xIs Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: Frac & Temp Gradients.xls Content-Type: application/octet-stream Content-Encoding: base64 20f2 2/7/2005 9:40 AM CASING AND PRESSURE INTEGRITY TEST Pump Rate: ... 1 J) I Strk/min Pressure Integrity Test Volume Input Volume/Stroke I... 0.0710\ BblS/Strkl CasinQ Test 2i6t2005 Date: NOHDH) 3 Rig 1<. LDNIß NIKAiTGHUQ '# 4. Well Name T Strokes ... #2 Mud Pump Pump used " v Drilling Supervisor: ... annulus and DP, Pumping down ... Casing Shoe Leak Off Test Type of Test: 620 615 610 600 W. ;. 580 570 1:.,' ",. :.ß.J:'J. 555 545 540 Shut-in Min psi o 0.25 0.5 1 1.5 2 2.5 3 3.5 4 4,5 5 o 50 120 'j50 180 210 240 260 320 :350 390 420 Pumping Strks psi ° 1 ":> "- .j 4 :. 6 7 a 9 10 5.5 5:30 6 525 6.5 520 7 510 7,5 500 8 490 8.5 480 9 4'15 9.5 46~ 10. 14 .~ Hi 365 22 320 26 360 2í3 330 30 320 3'¡ ~~10 32 310 Volume Bled Back 0.1 Bbls 450 490 520 550 580 610 640 660 670 680 690 690 680 650 650 (~'PD ) 12 < '; '" 14 'IS H¡ 17 18 19 20 2'~ 22 2~ ~, 24- :;W 32 '~" "'\:> 40 52 Volume 2580 25tH) 2570 2565 2560 2555 2550 2545 2540 2535 25:30 2495 .2485 2480 2480 Shut-in Min psi o 1 2 3 4 5 6 7 8 9 o 5 20 25 30 Volume Bled Back 2.0 Bbls 310 600 giG 790 1980 2150 2370 2530 2600 o o o o o o o o \) o o o o o o \) o o o o o Pumping Strks psi 4 8 1 a 21 23 25 27 28 o o o o ° o ° o {} o o o ° o ° o o o o o ° Volume Hole Depth 2,484 Ft-MD 2,484 Ft-TVD I'" Casing Shoe Depth 2,467 Ft-MD 2,457 Ft-TVD \9-5/8" 4O#/Ft L-80 BTC USE PICK UST 30.2 Ft Casinq Size and Description ... Hole Size: RKB-CHF Pressure InteqritvTest Mud Weight: 9.3 ppg Mud 10 min Gel: 10.0 Lb/100 Ft2 Rotating Weight (Pumps off): BlockslTop Drive Weight: Desired PIT EMW: Estimates for Test: Casinq Test Mud Weight: Mud 10 min Gel: 7$,000 Lbs 25,000 Lbs j 2.2 ppg 370 psi 9.3 ppg 10.0 Lb/100 Ft2 2,600 psi 78,000 Lbs 25,000 Lbs 1.7 bbls Test Pressure: Rotating Weight (Pumps oft; BlockslTop Drive Weight: Estimates for Test: 0.2 bbls I... PIT 15 Second Shut-in Pressure, psi 615 2457 + 9.3 655 0.052 x ... = = Leak-off Pressure + Mud Weight 0.052 x TVD EMW at 2457 Ft-MD EMW 1,1 Lost 1 00 psi during test, 96.1 % oftest pressure. '~~%:R«,*:4<~~.j~ .11 J J r,_ .. ~ ......~~~~.......:;$l::.......::sc: 14.4 ppg \\\~~ W~ ~šù ~t6~ ~') ~ c;..~ - - l (2457 Ft-TVD) "1':::::::::::::::::'::::::::::::\':':':'" '-, """..,.",.".. -..'·~I,··_·····,·:::::I:-,·:::·::,··..·J·,·,',..., .,....::::........ ,. ":' l·····~·=·, ..'--'..,' .. I .--,,:" : ....,:!...; - '. . o 5 . '10 15 20 25 30 Shut:.ln time,Minutes '0 "PIT'Pö1I1t 5 "'J '^'" !II ... Barrels 3000 2500 2000 1000 500 w 0::: :;) U) U) w 0::: D.. r;r o 500 o Pumped 3.7 Bbls Pumped 2.0 Bbls t'JJËCT¡ON RATE - LEAK-OFF TEST Casing t<:st with r¡g purop at 3 spm '" .21 bpm. LOT pumped at 1 spm '" .071 bprn PUMPED 2.4 B8L AFTËR LEl"f{.OFF TO ESH£US¡ -o-CASING TEST Comments , February 4th, 2005 Re: Nikaitchuq #4 APD: 204-260 Kerr McGee Oil & Gas Corporation Weekly Operations Report 1/24/05 1/25/05 1/26/05 1/27/05 1/28/05 1/30105 1/31/05 2/01105 2/02/05 2/03/05 137' MD/TVD Drove 102 ft of 13-3/8" conductor to 137' RKB. 137' MD/TVD Moved in Nordic camps and service modules. Moved Nordic 3 from lQ pad to the staging pad at Oliktok Point. Laid mats on ice road. 137' MD/TVD Moved Nordic 3 from Oliktok Point onto the ice road. Laying double mats in from of the rig. 13 7' MD/TVD Moved Nordic 3 on the lagoon ice road. Laying double mats in from of the rig. 13 7' MD/TVD Finished moving Nordic 3 across the lagoon ice roadto Spy Island. Laying double mats in from of the rig. Spot Nordic 3 over the conductor. , . 137' MD/TVD NIU wellhead and diverter system. Loaded pipe racks with 4" drill pipe, etc. Worked on benning and spill containment. Began PIU drill pipe. 137' MD/TVD PIU 4" drill pipe. RID diverter line, etc. RID mud loggers. Installed knife valve controls. PIU BHA. Function tested diverter system per AOGCC. Inspected rig instrumentation and gas detection systems per AOGCC. Off-loaded spud mud. 641' MD/TVD Spud Nikaitchuq #4 at 10:30 am on 2/01/05. Drilled to 215' while working on shakers. Circulated. POOH. PIU M/M, MWD and LWD, etc. Drilled from 215' to 641' MD/TVD. Short trip: WO trucks. 2,464' MD/TVD Drilled from 641' to 2464' MD/TVD. Circulated. Wiper trip. Circulated. 2,464' MD/TVD Circulated. POOH. RID and ran 9-5/8" surface casing to 2456'. Circulated. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 1000 2000 3000 = a. Q) C ca (,) 4000 ., ~ Q) > Q) ::::s ~ I- 5000 6000 7000 8000 10 sc . . Offset Wells (Frac Gradient) EMW (ppg) o Oliktok State #1 .. .. 11 17 18 12 13 15 16 14 9/02 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Submit to: tor:u.:aur,der@admin.state.ak.us aogcc...P'ucihoe...bay@adm:n.state.ak.us bob.J:0ckenstein@adrnin state aku:> Date: 31-Jan-05 Development Exploratory: X PTD # 204-260 Rig Ph. # 743-2956 e Drlg Contractor: Nordic Operator: Kerr-McGee Field/Unit & Well No.: NIKAITCHUQ 4 Location: Sec. 16 T. 14N MISC. INSPECTIONS: Location Gen.: x Housekeeping: x Reserve Pit: NA Well Sign: (Gen.) Drlg. Rig: Flare Pit: DIVERTER SYSTEM INSPECTION: Diverter Size: 13 5/8 in. Divert Valve(s) Full Opening: yes Valve(s) Auto& Simultaneous: yes Vent Line(s) Size: 16 in. Vent Line(s) Length: 85 ft. Line(s) Bifurcated: no Line(s) Down Wind: yes Line(s) Anchored: yes Turns Targeted I Long Radius: NA e R. Operation: Rig No. Oper. Rep.: Rig Rep.: R9E UM 3 Jim Mosley Ron Rice Merdian x x NA ACCUMULATOR SYSTEM: Systems Pressure: Pressure After Closure: 200 psi Attained After Closure~ min Systems Pressure Attained: 1 mim Nitrogen Bottles: <;(ð,2150 psig 2900 1950 17 25 psig psig sec. sec. MUD SYSTEM INSPECTION: Trip Tank: Mud Pits: Flow Monitor: Lig ht x x x Alarm x x x GAS DETECTORS: Methane Hydrogen Sulfide: Alarm x x Light x x ....................... . . . . . . . . . . . . . . . . . . '.- . . . . . . . . . . . . . . ~ ......... . .·.................·.·.··....·.·.·..bIVÊFttER.SCHEMATIò.................... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ......,........,.............,. ........................,...,....... ..... .......................................... . · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . · . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ................................... . . . . . ....................................',....'........ . . . . . . . . . , . . , . , . . , . . .........,. . Non Compliance Items --2..- Repair Items Within Remarks: Diverter Test 95 Ver(for rigs) BFL 11/002/01 o Day (5) And contact the Inspector @ 659-3607 AOGCC REP.: Jeff Jones OPERATOR REP.: Jim Mosley NORDIC #3 DiverterTest 01_31_05-1.xls RE: Nik #4 versus Nik #3--VERY IMPORTANT . . Subject: RE: Nik #4 versus Nik #3--VERY IMPORTANT From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Fri, 07 Ian 2005 12:10:20 -0900 To: Thomas Maunder <tom _maunder@admin.state.ak.us> Yes, it is planned to request AD in Tuvaaq State #1 located about 2-1/2 miles away. We also plan to request permission to AD from one site to the other to help cover the shut downs as you mention below. As you know, a CBL is planned in Nikaitchuq #4 to help prove up isolation. We certainly can run one in Nikaitchuq #3 after setting 9-5/8" surface. r appreciate you pointing that out - it slipped by me. r wanted to drill them in the numbered order which would have simplified all this a bit. r obviously lost that battle. I'm not sure which Jim you refer to below. SÆjp Coyner 907-339-62690fc 907-748-3689 cell -----Original Message----- From: Thomas Maunder [mailto:tohl_maunder@admin.state.ak.us] Sent: Friday, January 07,2005 10:28 AM To: Coyner, Skip Cc: Jim Regg Subject: Nik #4 versus Nik #3--VE,,{Y IMPORTANT Skip, I was just finalizing the #4 permit and beginning to get into #3. I have identified a significant question/issue . You are planning AD in #4 and #3 is planned to be subsequently drilled straight to a surface tvd well below #4 but only ~250' distant. The surface casing cementing on #3 is critical to maintaining the isolation necessary if AD is permitted on #4. Another operator had some communication issues with wellbores so proximate while doing AD. Has your sim-ops plan addressed sim-ops below ground?? The proximity and timing adds a new issue to this mix.. IF AD were to be approved for #4, it is probable that AD would need to be curtailed while the surface hole of #4 was being drilled and for some time after until the cement was set. A cement log might be needed in the surface casing of#3. The proximity and timing also raises additional concerns if produced fluid disposal were to be considered. These are matters that you need to consider. Was AD going to be proposed at Tuvaaq?? At least there, there would be no proximity concerns. Don't mean to throw "wrenches" at you, but neither of us want to have a waste disposal failure. Please call or message back. Copy Jim on any returns. 10f2 11712005 12:23 PM RE: Kerr McGee: Nikaitchuq #4 Application for Permit to Drill . . Subject: RE: Kerr McGee: Nikaitchuq #4 Application for Permit to Drill From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Wed, 05 Jan 2005 16:26:09 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> / 1. Having re-done the tvd's and pressures half way through the process, the correct BHP is as shown on page 4: 1927 psi & 1471 psi which matches the graph. Please change the pressures on the 10-401. 2. Yes, the fluid [produced or otherwise] can go to 1R-18 and/or DS-04 as per our agreements that are in place. There are logistical issues (trucking) and "Ballot" issues that just aren't kosher - but it is what it is. Todd Durkee is planning on getting with Mr. Norman and having a general discussion about all of this. I'm in the middle. 3. I did specify a LOT at the 9-5/8" shoe but did not specify how much to put away. Unless it's one of the anomalous LOT's out there, fluid should go away at < 14 ppg. 4. The Nik #4 ESP production test is supposed to last for + 10 days to get a good "dean up" and a good draw down. Basically, KMG wants to know (as we all do) if this sand will sustain enough rate to make the development economics fly. We expect 600-900 BOPD for 10 days, God willing. 5. This well is 125' east of Nik #1 and 57' south. Nik #1 KOP was at kicked off at 800' headed due north. Nik #4 kicks off at 3130'. Nik #1 is long gone by that depth [1700' further north]. Later, Nik #3 will be drilled & it's 250' west of Nik #4. Nik #3 kicks off at 7320' TVD. ._Well below Nik #4's entire well path~ Bart at Sperry did a close âpproach chart that looked fairly silly compared to what we look at in the producing areas. 6. Sim-ops procedure and check list are still at an informal stage. I will get that document toi you when available. Sk.Jp Coy11£r 907-339-62690fc 907-748-3689 cell -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 05,20053:30 PM To: Coyner, Skip Cc: Jim Regg Subject: Re: Kerr McGee: Nikaitchuq #4 Application for Permit to Drill Skip, I am looking at Nik #4. FYI 204-260, 50-629-23241-00. I have a couple of questions. 1. The BHP and MASP values on page 4 does not agree with what is on the 401 sheet. 2. AD of produced fluid. As we discussed some time ago, this will be a difficult issue. You indicate on page 4 that all drilling and completion fluid wastes will be hauled to lR-18 for disposal. Is that not feasible for your produced fluid as well?? Do you have agreements with both CP AI and BP to take produced fluid?? 3. For AD to be considered, fluid must be pumped into the formation when you do the LOT. CPAI, which is the only other company to do AD pumps in (~ 1.5 - 2 bbls) unless they reach 10f2 1/7/2005 9:44 AM RE: Kerr McGee: Nikaitchuq #4 Application for Pennit to Drill about 16.0 ppg. I w! suggest you cross reference with the .er wells you have drilled out there. You likely have that in the application, but I haven't gotten that far yet. 4. How long do you plan to test?? The tenn "extended" is used, but that is sort of indetenninate. What sort of production rate is expected?? 5. Speaking of other wells, what proximity issues are there?? I do see that you have all the wells on a plot, but I haven't gone through the details yet. 6. Have you all prepared a sim-ops procedure/document?? If so we request a copy. Thats it for now, I am sure we will be talking. Tom Maunder, PE AOGCC CQyner, Skip wrote: Hard to believe but I found a typo on the package I delivered last week. On page #1 of the Drill, Complete, Test and Plu.q program, in the mud program, surface hole: please omit any reference to a 16: Hole Opener run. There will not be one: only 12-1/4" hole and 9-5/8" surface casing. Thanks SRjp Coyner 907-339-62690fc 907-748-3689 cell 20f2 11712005 9:44 AM Re: Annular Disposal Question . . Subject: Re: Annular Disposal Question From: Thomas Maunder <tom _maunder@admin.state.ak.us> Date: Tue, 09 Nov 2004 10:17:55 -0900 To: skip.coyner@asrcenergy.com Skip, Todd was up asking some similar questions a while back. 1. Yes, it should be possible to walk through and discuss and application (10-403 AD) after you get your intennediate/production casing set. Initial (on drill out) and subsequent "LOTs" and the logs will help. KM's geologists should make salinity calculations based on the logs per EP A's protocol. I don't know that you can say "no fresh water", that is what the logs will prove. 2. With out an application requesting to "cross-inject", it is prohibited. Making such a request as part of your application is important and would likely be approved. Hauling to from 1 exploratory location to another for AD is something that has been previously approved. 3. Oil based mud is a drilling fluid, so no problem. I am not sure how injecting/disposing of any produced oil would be viewed. That would be considered waste and a royalty would be due. Todd is aware of this and he indicated that in asking the question there was no intent to avoid royalty. He did say that getting an agreement with CP AI to take produced fluids to CPF 3 was a major headache so I understand the hassle factor you are trying to avoid. I would suggest that it would be in KM's.interest to put this subject on the table sooner rather than later. Like I said, I do not know what the'. potential decision would be. Hope this helps. Tom Maunder, PE AOGCC Coyner, Skip (NA TCHIQ) wrote: The Kerr McGee wells I'm planning for the upcoming exploration season will include the possiblity on annular injection. I have a few questions that will help guide me through the planning process: o Is it possible to "walk through" the 10-403 application soon after the inner string of casing is set? . Exhibits: LWD logs, outter string FIT, inner string roc, casing tests, off shore - no fresh water. o Does 20 ACC 25.080 (d) (4) say that we cannot annular inject drilling waste from exploratory pad A into an annulus on exploratory pad B? We currently plan to have two rigs on separate pads. Both pads will have a potential annulus. We would like to have the fJexibilty to cross-inject approved waste if possible. What can I do (if anything) to make this happen? o 20 ACC 25.080 (h) (1) lists approved "inject-able" drilling wastes including dril/inq mud and formation fluids. Surely "driJIinq mud" includes L TV200 oil based mud, right? We plan to test two wells. Does "formation fluids associated with the act of dril/inq" include oil produced during an exploration well test since the well test will be included in the 1 0-401? lof2 11712005 9:53 AM Re: Annular Disposal Question "II call you and discuss thl questions this afternoon. . Skip Coyner 907-339-6269 ASRC 907-564-4395 BPXA 907-748-3689 cell 20f2 1/7/2005 9:53 AM ., . . ~j£år7! lIDJ !Æ~!Æ~A~ / ~1,A.~1iA OIL AND GAS / CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Todd Durkee Drilling Manager Kerr-McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage, Alaska 99503 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nikaitchuq #4 Kerr-McGee Oil & Gas Corporation Pennit No: 204-260 Surface Location: 350' FSL & 1460' FWL, Sec. 16, TI4N, R9E, UM Bottomhole Location: 1530' FNL & 923' FEL, Sec. 17, TI4N, R9E, UM Dear Mr. Durkee: Enclosed is the approved application for pennit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Samples and a mud log are not required for Nikaitchuq #4. Samples and a mud log were acquired across the same geologic section in nearby exploratory wells Nikaitchuq #1 and #2. The Commission offers the following responses regarding specific information/requests presented in your application. 1. Formation Abandonment Plug: It is not possible to approve a plug and abandonment ("P&A") proposal prior to the well being drilled. When it has been determined to P&A the well, Kerr-McGee must file a Sundry Notice (Form 403) providing the determined formation information and planned plug depths. 2. Annular Disposal of Drilling Wastes: Annular disposal will not be approved for this well until sufficient data are submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test ("FIT"). Cementing records, FIT data, subsequent leak-off test data following setting production casing, and any cement quality logs must be submitted to the Commission on fonn 10-403AD prior to the approval of disposal operations. · , If annular disposal is approved, you have requested that produced fluids (water and oil) be approved for disposal. It is noted that it is your plan to truck produced fluids to either ConocoPhillips or BP facilities for processing and that annular disposal of produced fluids would only be if "emergency situations" were encountered. The Commission strongly endorses your plan to transport produced hydrocarbons to the production facilities. Injection other than into the producing formation would be considered waste and is not an acceptable option. The Commission strongly encourages Kerr-McGee to secure the necessary agreements with ConocoPhillips or BP to allow transport of any oil as planned. 3. Completion Plan: Your completion is planned without a packer, which is one of the standard completion methods for the Schrader Bluff/West Sale Given that the location is distant from any enhanced recovery projects, there is little likelihood that well would be capable of flowing. Your completion plan is approved as provided by 20 AAC 25.200 (d). 4. Blowout Prevention Equipment: Testing frequency for this type of drilling operation is "less than 7-days". Since this is an exploration well and a non-operating rig start-up, the Commission will not modify this requirement. As operations proceed, your rig representative should contact the Inspections Supervisor (Mr. Jim Regg at 793-1236) to discuss the particular operating situation. Please note that the 7 -day test requirement can be extend depending on what the status of the then current operations; however, coordination with, and prior approval from, Mr. Regg is necessary. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to . ness any required test. Contact the Commission's North Slope petroleum field inspector õ59- 607 (pager). BY ORDER OF THE COMMISSION DATED this IJrday of January, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Annular Disposal of Produced Fluids . . Subject: Annular Disposal of Produced Fluids From: Thomas Maunder <tom_ maunder@admin.state.ak.us> Date: Thu, 13 Jan 2005 15:33:51 -0900 To: Todd Durkee <TDURKEE@KMG.com>, Skip Coyner <Skip.Coyner@asrcenergy.com>, Stu Gustafson <stu@annstrongoilandgas.com> CC: John D Hartz <jack_hartz@admin.state.ak.us>, Steve Davies <steve_davies@admin.state.ak.us>, Jim Regg <jimJegg@admin.state.ak.us> BCC: John Norman <john_norman@admin.state.ak.us>, Daniel T Seamount JR <dan _ seamount@admin.state.ak.us> Gentlemen: Kerr-McGee Corporation's ("KMC") primary plan for handling oil obtained through production testing of the proposed Nikaitchuq #3 and #4 wells is transportation to one of ConocoPhillips Alaska, Inc.' s ("CP AI") production facilities in the Kuparuk River Field. However, if "emergency conditions" such as inclement weather or CPAI's refusal to accept the oil occur, KMC proposes to inject and dispose of the oil in an approved annulus or Class II well. This is not an acceptable option. The Commission is charged with preventing physical waste of hydrocarbons. Inj ecting oil obtained through production testing into an annulus, a Class II well, or into any formation other than a, producing formation would constitute waste. As an alternative, KMC could provide sufficient : storage for the production test oil, and re-inject the oil into the producing formation. The Commission strongly encourages KMC establish an agreement with CP AI or BP Exploration . (Alaska) Inc. ("BPXA") to allow transfer of the produced oil to a production facility. According to information provided in KMC's meeting with Commission staff on January 11,2004 and the estimated well times in your applications, the earliest date testing is likely to occur is February 13, 2004. The Commission remains interested in the matter. IfKMC is not successful in negotiating a satisfactory agreement with CPAI or BPXA by February 4,2004, please contact either myself (907-793-1250), Jack Hartz (907-793-1232) or Steve Davies (907-793-1224). Please be aware, I will be out of state January 15-19. Tom Maunder, PE Alaska Oil and Gas Conservation Commission 1 of 1 1113/20053:34 PM ~: Kerr,]\1cGee: Nikaitchuq #4 APPlicatio.permit to Drill . Subject: RE: Kerr McGee: Nikaitchuq #4 Application for Permit to Drill From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Wed, 05 Jan 2005 16:26:09 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> 1. Having re-done the tvd's and pressures half way through the process, the correct BHP is as shown on page 4: 1927 psi & 1471 psi which matches the graph. Please change the pressures on the 10-401. 2. Yes, the fluid [produced or otherwise] can go to 1R-18 and/or 05-04 as per our agreements that are in place. There are logistical issues (trucking) and "Ballot" issues that just aren't kosher - but it is what it is. Todd Durkee is planning on getting with Mr. Norman and havi~g a general discussion about all of this. I'm in the middle. 3. I did specify a LOT at the 9-5/8" shoe but did not specify how much to put away. Unless it's one of the anomalous LOT's out there, fluid should go away at < 14 ppg. 4. The Nik #4 ESP production test is supposed to last for + 10 days to get a good "clean up" and a good draw down. Basically, KMG wants to know (as we all do) if this sand will sustain enough rate to make the development economics fly. We expect 600-900 BOPD for 10 days, God willing. 5. This well is 125' east of Nik #1 and 57' south. Nik #1 KOP was at kicked off at 800' headed due north. Nik #4 kicks off at 3130'. Nik #1 is long gone by that depth [1700' further north]. Later, Nik #3 will be drilled & it's 250' west of Nik #4. Nik #3 kicks off at 7320' TVD. Well below Nik #4's entire well path. Bart at Sperry did a close approach chart that looked fairly silly compared to what we look at in the producing areas. 6. Sim-ops procedure and check list are still at an informal stage. I will get that document toi you when available. S!¿jp Coyner \)~,,-/Jc~~ , ,,,- ~~ "0, """-,,,"';:,~ Š; ""01''1 ~-\\-., ~-\c.I'\'~~¡:'''-''' ~~'> .~~~ \L-~ ~\\...,..~\~~&~~~~\I\.~()~'&~ 907-339-62690fc J:; ~c£¡-Ç\~.~\......~ ~ ~ ~"'VF'\-'"\ ~\'S.\~~ 907-748-3689 cell ~-\-~\\ ~,w~\\ \r,esc~II'..':), f -\C)~~~ ~\~'--~~'5 ~ -----Original Message----- ..J~,,-;:>~ 0., ~ '> 0-~ <SO \-"-«=- Md-~\t)~t~ CQk~ From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] '-10'-.) \..9iJ'....~~~. . Sent: Wednesday, January OS, 2005 3:30 PM I ~ To: Coyner, Skip Cc: Jim Regg Subject: Re: Kerr McGee: Nikaitchuq #4 Application for Permit to Drill \ I Co Skip, I am looking at Nik #4. FYI 204-260, 50-629-23241-00. I have a couple of questions. 1. The BHP and MASP values on page 4 does not agree with what is on the 401 sheet. 2. AD of produced fluid. As we discussed some time ago, this will be a difficult issue. You indicate on page 4 that all drilling and completion fluid wastes will be hauled to 1R-18 for disposal. Is that not feasible for your produced fluid as well?? Do you have agreements with both CP AI and BP to take produced fluid?? 3. For AD to be considered, fluid must be pumped into the formation when you do the LOT. CP AI, which is the only other company to do AD pumps in (~ 1.5 - 2 bbls) unless they reach lof2 l/6/2005 4:05 PM 1lli: .Kerr McGee: Nikaitchuq #4 Application for Permit to Drill ~ \ . . about 16.0 ppg. I would suggest you cross reference with the other wells you have drilled out there. You likely have that in the application, but I haven't gotten that far yet. 4. How long do you plan to test?? The tenn "extended" is used, but that is sort of indetenninate. What sort of production rate is expected?? 5. Speaking of other wells, what proximity issues are there?? I do see that you have all the wells on a plot, but I haven't gone through the details yet. 6. Have you all prepared a sim-ops procedure/document?? If so we request a copy. Thats it for now, I am sure we will be talking. Tom Maunder, PE AOGCC Coyner, Skip wrote: Hard to believe but I found a typo on the package I delivered last week. On page #1 of the Drill Complete, Test and Pluq program, in the mud program, surface hole: please omit any reference to a 16: Hole Opener run. There will not be one: only 12-1/4" hole and 9-5/8" surface casing. Thanks S!ijp Coy1l£r 907-339-62690fc 907-748-3689 cell 20f2 1/6/20054:05 PM ~~'~\J0 (]A \(X:)bM4-~\Q~~ ~ T-\~,,~t\c.\\o.w ~C-1'O \.-EP't<. s\s ìS~\~, . · ~~\-.~~ --\e~" ~\~J ~ì>" ..k. D:~~ ~;~O~~mmi"iO" q:>k~ ~~~ prcblU'<'f Re: Nikaitchuq #4 í\ ~ I·l _ ~A' ß ":::>~ vJ. Kerr McGee Oil & Gas Corporation \ Ö t5 \.()S,~~~'-(. f Application for Permit to Drill (10-401) / ~0 Kè \.-Q'v.J ~> ?r'v-of. "'f ~ ~¡îQ) Ws D I. ~.\-CS) ~ -\- 'rot-:Þtj Attached for your review is our Application for Perinit to Drill the Nikaitchuq #4 ¿~' exploration well located approximately four (4) miles north ofOliktok Point. A This original APD is submitted along with one (1) copy and the $100.00 filing fee. The APD packages include form 10-401, an abnormal pressure analysis, a shallow hazard analysis, a comprehensive drilling hazard analysis, drilling program, directional drilling plan, drilling mud program, plats, graphs and diagrams as required. The package includes an "As Staked" location plat which will be followed by an "as built" plat when available. ./ This application for permit to drill includes a vertical pilot hole that will be drilled through the primary zone of interest, logged and then plugged back to the kick off point. We plan to cut a core in the pilot hole before actually reaching TMD and logging. After plugging " back with cement, the well will be sidetracked at 3130' MD/TVD following the attached directional drilling plan (wp03). It is our intention to apply for annular disposal if after we have set the intermediate casing string. That application for Sundry Approval will be accompanied by all of the required data necessary for expedited approval. Our application for annular disposal will include drilling waste from this well, Nikaitchuq #3 located on the same pad and (if approved) Tuvaaq State # 1 located near by on Spy Island. We hereby request approval in accordance with 20 ACC 25.200 (d) to complete and test this well without a packer in the completion. It is not planned to use a packer in this well because this is an ESP completion and a packer would be detrimental to the operation thereof. There exist several factors that justify this engineering decision and this course of action: 3900 C Street l u'-- \ \ \" _ ,,\-.(>¡,~ </', <....<:.J (907)-339-6370 Suite 702, Rm 744 V'J ,\/\ v ~'" "I' 'Q .:> ) Anchorage, AK 99503 . @ KERJ1..MCGEE CORPORA nON December 30,2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 . . ~ KERR-MCGEE CORPORATION · This well is not expected to be capable of unassisted flow to surface: due to the relatively low BHP in the Schrader Bluff and the high viscosity of the oil. · During the extended production test, the well site will be manned continuously, the annulus pressure will be monitored continuously, and gas pressure in the annulus will be bled off routinely to maintain that annulus pressure at or below 10% of the tubing head (penetrator) working pressure. · The success of this extended production test, and ultimately, the decision to develop this resource or not depends upon the efficient and continuous operation of the ESP. A packer would be detrimental to that effort because a packer would a) force gas through the ESP, b) potentially gas-lock the ESP, c) artificially reduce the intake pressure at the ESP, and d) artificially limit our ability to draw down the producing BHP. It is documented that ESP's produce better and last longer with a) down-hole gas separation, and b) high intake pressure (head). This can best be accomplished without a packer. Therefore to maximize production, the success of this test, and ultimately the potential for developing this offshore resource, it is not planned to use a packer if approved by AOGCC in accordance with 20 ACC 25.200 (d). / Our anticipated spud date for Nikaitchuq #4 is on or about January 17th, 2005. The construction of our ice road and drilling pad are well underway. 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. Your timely review of our APD and the accompanying data is greatly appreciated. Sincerely, s!;t7-- ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 1 a. Type of Work: . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 3 () PERMIT TO DRILL 20 MC 25.005 Ab"k'" m! x, Ii¡?~ r;lìns. Commissimt 11 b. Current Well Class: Exploratory 0 . -.. Oeveïòpm1l1t,gj1 .~J:J Multiple Zone 0 Stratigraphic Test 0 Service 0 DevelopmenQ'(;~~ ârJ Single Zone 0 5. Bond: Blanket 0 Single Well 0 11. Well Name and Number: Bond No. 3-798-381 Nikaitchuq #4 6. Proposed Depth: 12. Field/Pool(s): MD: 7880 J TVD: 4145 j 7. Property DeS, ~q~i~n:þ 38l!$&'8 þÞ ADI1r~~.¡ ADL 38ié81 ,. > .~ç 8. Land Use Permit: 13. Approximate Spud Date: 1/17/2005 9. Acres ~"lroperty: f<J'J1 .A {. S".~ 14. Distance to Nearest ,~c & ~c respectively Property: 3820 ft 10. KB Elevation 15. Distance to Nearest Well (Height above GL): 35 feet Within Pool: None - 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1830 psi Surface: 1415 psi Setting Depth Quantity of Cement c.f.orsacks Drill 0 Redrill 0 Re-entry 0 2. Operator Name: Kerr McGee Oil & Gas Corporation 3. Address: 3900 C Street, Ste 744, Anchorage, AK 99503 4a. Location of Well (Governmental Section): Surface: 350' FSL & 1460' FWL Sec. 16, T14N, R9E UM J Top of Productive Horizon: (Intermediate Casing shoe) 1175' FSL & 602' FWL Sec. 16, T14N, R9E UM Total Depth: 1530' FNL & 923' FEL, Sec. 17, T14N, R9E UM / 4b. Location of Well (State Base Plane Coordinates): Surface:x- 519,643./ y- 6,054,828 j Zone- 4 16. Deviated wells: Kickoff depth: 3130 feet ./ Maximum Hole Angle: 90 degrees 18. Casing Program: Size Casing 13-3/8" 9-5/8" Hole N/A 12-1/4" 8-1/2" 7" 6-1/8" 3-1/2" 19. Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Specifications Exploration Top Bottom Weight Grade Coupling Length MD TVD MD TVD (including stage data) 68# 'X-56 PE/BFW 80 35 35 115 115 N/A - Drive Pipe 40# L-80 BT&C 2415 35 35 2450 ./ 2450 302 sx Permafrost L (223 bbl) 186 sx Premium CMT (38 bbl) 26# L-80 BT&C-M 4845 35 35 4880 4145 293 sx Premium CMT (60 bbl) 9.2# L-80 IBT 3180 4700 4137 7880 4145 Slotted Liner - No Cement Mr. Todd Durkee PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Samples required Hydrogen sulfide measures Approved by: Form 10-401 Revised 06/2004 Length Size Junk (measured): Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot ~ Shallow Hazard Analysis ~ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date Contact Filing Fee ~ BOP Sketch ~ Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. 20. Attachments: Printed Name Drilling Program ~ Seabed Report 0 Title Drilling Manager, Kerr McGee Oil & Gas Corporation Signature . J J /"I /:'.AAI7..A..... hr f;ef,( j)/t(I'.k ~(!>hone 'to 7- 131- 1..2 £1 ~../ -71 ~ - Commission Use Only Permit to Drill " ß / , API Number: I Permit Approval Number: 2..b 'f ~ l..'='ð 50- 629- 232 vt--õO Date: Conditions of approval : Other: Date 12/28/2004 I See cover letter for other requirements. Yes 0 No~ Yes 0 No ~ Mud log required Directional survey required Yes 0 Yes ~ No ~ No 0 APPROVED BY THE COMMISSION Date: Submit inDuplicate · . Location Plat & Unit Plat ..vI DAlE I BY I OK I APP I . ~ NOTES: IREVI DAlE I BY" I APP I 3 ¿ 1. Basis of Location: Mon 3R South 2, by L.H.D. & Assoc. 2. Coordinates shown ar A.S.P., Zone 4, NAD 27 3. Location determined with Lieca 500 Series GPS Units, using Geoid 98 4. Geographic coordinates are NAD 27 :;:0:;:0 OJ CD 11 fTlfTl 11 8 9 11 "" , i 13 SqALE: 1" =11 Mile 14 i ~ Nikaitchuq-1 I I I 1 Ni<aitchuq-21 ~ i 23 I , 16 18 SPY ISLAND 17 15 S~oO\:.\~""S J. O~/' ~\,)~(,'>' \S'I. s't.~,';") S9'i coO .,/·;7 ~4 ' '" ",,',}7 L ~ 0' /""y; Q ~S5; 19 NIKA;~CHUQ #4 ~ Y = 6054828.0 X = 51964J.1 i LA T = 70' (33' 39 46" LONG = 14è· 50' 19.91" 350' F.S.L., 1460' F. W.L. SECTION 16, T14N, R9E, U.M. ! I I I I i 27 26 25 30 36 CH ~I 33 34 32 35 T14N T13N ~ o ^ \ S \:) ~~ 0~ -.{ 12 0 ~ OLlKTOK DOCK DESCRIPTION :;:0 :;:0 6 CD~ fTlO fTl 12 7 "^ ¡.:) 18 24 19 25 30 36 31 4 3 2 DEW liNE Sill±. I . DS-3R \\ " . .... I " ". OUKTO~ '/ilPINT STAGING AREA , . ,..-.I \15 \ Û . \ ~ ¡ 10 I I . NOTE: SHAPE AND CONFIGURATION OF SPY ISLAND IS FROM OLD MAPPING AND HAS BEEN ADJUSTED 16 TO FIT THE LOCATION OF EXPLORATORY WELLS. THE ~\) ACTUAL CONFIGURATION OF THE ISLAND MAY VARY GREATLY FROM THAT SHOWN ON THIS DRAWING. !f1 'J 'ç¡ 'i"f\J¡<b ~ Q ¿'~R 12 'L" ~O~: ~\ ~'\.\" 0 ( iD~" \ j Q j \ ~L5 ~ LOUNSBURY Be ASSOCIATES, INC. SURVEYORS ENGINEERS PLANNERS ~ NIKAITCHUQ #4 EXPLORATORY WELL CONDUCTOR AS-STAKED LOCATION NSK 6.01-d575 I PART: 1 OF 1 I REV: 0 (1ðø)Kal1 MCGEE CORPORATION CADD FILE NO. LK601D575 I DRAWING NO: 12/20/04 e . NikaitchuQ No.4 @3 KERR·MCGEE CORPORA T/ON Suñace Location: 70033' 39.46" N & 149050' 19.91" W 350' FSL & 1460 FWL of Section 16 T14N R9E / 6,054,828' N & 519,643' E NAD 27, Zone 4 LandinQ/Casina Point Location: 1175' FSL & 602' FWL of Section 16 T14N R9E 6,055,650' N & 518,780' E NAD 27, Zone 4 Bottom Hole Location: 1530' FNL & 923' FEL of Section 17 T14N R9E / 6,058,221' N & 517,235' E NAD 27, Zone 4 Nikaitchuq No.4 (Bottom Hole Location "Toe") r'''..'..' ~""~' I..,·..",,, !"" j"'" ........ . .... n . ,__, . H'"j ':'!U1.i:'¡~1!~Jì,¡,t:':,::; ~ ,-", ,.-...... . .. ~ '! :-¡: -":;':;::!;:'. '- ~, ;1:: J""::i",-¡:, ~, :¡"",'1:jmmr. , _ ,_ ~ . .,_ ~:' , _'..m.. """,, ".' ." \~.. - - 17 16 ADL 388583 . Armstrong 0 & G Kerr McGee 0 & G . "'A, Nikaitchuq No.1 / ". 1336' FWL & 404' FSL ....... (Plugged & Abandoned) .' Nikaitchuq No.4···... / (Landing/Casing Point "Heel") _ .~.4 . _ . _ . _ . ~. _ . \ 350' FSL ~1460' FWL ~I ... Nikaitchuq No.4 (Surface Location) 20 21 December 30,2004 J1 'i! :'1 -_N ADL 388582 "' (1280 acres) Armstrong 0 & G Kerr McGee 0 & G - EXPl (AI ¡\SKÁ') INf"' lnnní'l'/ /,,,,'_";' "lL",IL 1 r"DL 1>50.23 Bldl Ac rEr 12.50 % 3D.aO % (;'¡PI HBJJ · . @ KERß.CGEE CO TI Nikaitchuq #4 Drill, Complete, Test & Plug I Drilling Rig: Nordic 3 1 Drill, Complete, Test, Plug & Abandon 350' FSL & 1460' FWL of Section 16, T14N, R9E UM X = 519,643' Y = 6,054,828' 1175' FSL & 602' FWL of Section 16, T14N, R9E UM X = 518,780' Y = 6,055,650' 1530' FNL & 923' FEL of Section 17, T14N, R9E UM X = 517,235' Y = 6,058,221' Surface location: (and Pilot Hole BHL) landing/Casing Point: Bottom Hole location: I Estimated Spud Date: 11/17/05 \ I PTD: 17,880' I I TVD: 14,145' I I Operating Rig days: \18 I Pad Elev: \3 ft I I DF: 135 ft I Geologic Objectives: Schrader Bluff "OA" Sand ./ Mud Program: 12-1/4" Surface Hole & 16" H.O. (0' - 2450'): Density PV YP HTHP 9.0 - 9.8 I 15 - 25 I 30 - 45 In/a pH 9.0-9.5 8-1/2" Intermediate Pilot Hole (2723' - 4300'): Density PV YP HTHP 9.0-9.3 15-25 15-25 n/a pH 9.0- 9.5 8-1/2" Sidetrack "Build Section" (3130' - 4880'): Density PV YP HTHP 9.0 - 9.3 15 - 25 15 - 25 n/a pH 9.0- 9.5 6-1/8" Schrader Bluff lateral (4880' - 7880'): Density PV YP HTHP 9.0 - 9.3 10 -15 15 - 25 10 - 11 pH 9.0-9.5 S Coyner 1 KCUPolymer API W/l lG Solids < 6 < 10 KCUPolymer API W/l lG Solids < 6 < 10 KCUPolymer API W/l lG Solids < 6 < 10 l VT -200 MOBM ES Tauo 600 - 1000 4 - 7 12/27/2004 . . Recommended Bit Program: Bit Hole Size Depth (MD) Footage Bit Type TFA GPM 1 12-1/4 in Surf - 2,450' 2,415' GT-1 .75 - .90 450 - 650 2pi1ot 8-1/2 in 2,450 - 4,300' 1,850 GT-1 .50 - .75 400 - 500 3ST 8-1/2 in 3,000' -4,880' 1,880' GT-1 .50 - .75 400 - 500 4 6-1/8 in 4,880' - 7,880' 3,000' FM3643 .35 - .45 250 - 325 Casing Program Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD 1 TVD MD 1 TVD N/A 13-5/8" 68# L-80 BTC 80' 35' 115' 1115' 12-1/4" 9-5/8" 40# L-80 BTC 2,415' 35' 2,450' /2,450' 8-1/2" 7" 26# L-80 BTC 4,845' 35' 4,880' /4,145' Cement Program: Casing Size 9-5/8",40#, L-80, BTC Surface Casing at 2,450' MD Excess from B/Permafrost to Surface = 100% over gauge hole. Parameters Use 25% excess below the B/Permafrost. Shoe track = 85 ft. Total cement volume will be confirmed with carbide lag(s) Cement: 361 bbl Wash 10 bbl water Spacer 50 bbl of NSCI spacer mixed at 10 ppg Lead 223 bbl, 302 sx of Permafrost L: 10.7 ppg and 4.15 felsx Tail 38 bbl, 186 sx "G" mixed at 15.8Ib/gal & 1.15 ft3/SX Temp Casing Point BHST 750 F (from offset data) 7",26#, L-80, BTC-M Intermediate Casing at 4,880' MD Excess = 25% over gauge hole, TOC ± 2,880', Shoe track = 85' Wash 10 bbl water Spacer 30 bbl of NSCI spacer mixed at 10 ppg Slurry 60 bbl, 293 sx "G" mixed at 15.8 Ib/gal & 1.16 ft3/sx Temp Casing Point BHST 1120 F (from offset wells) Casing Size Parameters: Cement: 216 bbl Integrity Testing: Test Point: 9-5/8" Shoe 7" Shoe MD 1 TVD 2450' 1 2450' 4880' 14145' Kick Tolerance ~ 50 bbls > 50 bbls Test Type: LOT FIT EMW: 12.0 ppg 12.5 ppg S Coyner 2 12/27/2004 . Surveys & MWD: While Drilling: . Surface to TO: MWD surveys every 90 to 180 ft IIFR Casandra for magnetic survey verification Rig instrumentation: PVT, Flow-Show, gas detectors, H2S ,/ detectors as required. Mud loggers from 1200' to casing point: samples every 30 ft, '" gas detection & drilling parameters Rig instrumentation: PVT, Flow-Show, gas detectors, H2S detectors as required. Mud loggers to pilot hole TO: samples every 30 ft: every 10ft in - pay zones, gas detection & DRLG parameters Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. Mud loggers to landing point: samples every 30 ft: every 10ft in ,/ pay zones, gas detection & DRLG parameters Mud Logging: Surface Hole [12-1/4"]: Pilot Hole [8-112"] and Sidetrack "Build Section": S.B. Lateral [6-1/8"]: Evaluation Program: 12-1/4" Surface Hole Open Hole: MWD 1 LWD: Open Hole: E-Line: 8-1/2" Pilot Hole Open Hole: MWD 1 LWD: Open Hole: E-Line: Cased Hole: 8-1/2" Sidetrack Open Hole: MWD 1 LWD: Open Hole: E-Line: Cased Hole: 6-1/8" S. B. lateral Open Hole: MWD 1 LWD: Open Hole: E-Line: Cased Hole: S Coyner 3 MWD/GR/RES ./ Gas Detection, Mud Logging, samples -' None MWD 1 Triple-Combo ,¡' Gas Detection, Mud Logging, samples HRLA 1 DEN 1 NEU 1 Dipole Sonic 1 FMI CBL in the 9-5/8" casing MWD 1 Triple-Combo '" Gas Detection, Mud Logging, samples None None MWD 1 Triple-Combo 1 ABI /' Gas Detection, Mud Logging, samples ' None None 12127/2004 Formation Markers: Formation Tops Eocene Unconformity B/Permafrost B/Prince Creek T/Ugnu (Pilot/Sidetrack) T/SB (Pilot/Sidetrack) T/OA (Pilot/Sidetrack) PTD (Pilot Hole) T/Colville Well Control: . MD (ft) Pilot/Sidetrack 1,385 1,720 2,090 3,385 1 3,389 3,985/4,189 4,145/4,818 4,300 N/A . TVD (ft) 1,385 1,720 2,090 3,385 3,985 4,145 4,300 4,380 Pore Pressure (psi) EMW (Ib/gal) 916 1 ,484 1,824 1,927 1,974 8.43 8.43 8.80 8.94 8.83 The casing head will be installed on the 13-3/8" drive pipe along with a 13-5/8" diverter spool and the 16" Oiverter Line. The 13-5/8" BOP stack will be NU above the diverter spool and the BOP stack will be configured to use the 13-5/8" annular as a diverter. The surface hole [12-114"] will be drilled to casing point in the lower SV sands using the diverter system for secondary well control. At casing point, 9-5/8" surface casing will be set and cemented. It is planned to circulate cement to surface. It is also planned to use a 9-5/8" F /0 tool to circulate cement out of the 13-3/8" x 9-5/8" annulus and freeze protect same down to ± 80 ft below RKB. Both strings will be cut and recovered later. After setting and cementing the 9-5/8" surface casing, the diverter spool will be replaced with a multi-bowl casing spool. The 13-5/8" (5M) BOP stack will be reconfigured and tested. 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 / or flange "breaks" will be tested before continuing. The rams, valves and manifold will all be tested to 250 psi low 15000 psi high, the annular tested to 250 psi low 1 3500 psi high, the casing to 2500 psi. The maximum anticipated Surface Pressure is calculated from extrapolated BHP data recorded at MPU which include a 0.30 psilft oil gradient to correct for TVO and a gas gradient of 0.11 psi/ft to surface as required: Nikaitchuq #4, Schrader Bluff BHP = 1927 psi Maximum Surface Pressure = 1927 psi - (4145 ft x 0.11 psilft) = 1471 psi Disposal of Drillina Waste: · Cuttings Handling: Cuttings generated from drilling operations will be hauled using super suckers to G & I #3: located on 05-04, Prudhoe Bay, for disposal. · Fluid Waste Handling: All drilling and completion fluid wastes will be hauled to 1 R-18 at Kuparuk for disposal. S Coyner 4 12/27/2004 . . · NPEDS: Subject to an approved NDEPS disposal permit, approved solid and liquid waste may be dumped on or through the ice in the stipulated water depth. · Sewage (grey/black water): Camp waste water will be hauled to the sewage treatment plant(s) at Kuparuk / Prudhoe Bay / North Slope Borough where it will be treated and injected. Annular Disposal of Drillina Associated Waste: It is planned to apply for an annular disposal soon after the 7" intermediate casing is'" set and cemented. Upon approval, drilling waste from the oil based mud [6-1/8"] hole section will be injected via the 9-5/8" x 7" annulus into the Ugnu formation. Offset log ./ data shows that no fresh water sources exist within this geologic section, and any hydrocarbon bearing zones in the intermediate hole section will be covered by cement. It is planned to include with the 10-403 form the option of injecting drilling waste generated on Kerr McGee's other exploration wells, Nikaitchuq #3 (located on the same pad) and Tuvaaq State #1 (located nearby - on Spy Island). In no case shall the total volume of drilling waste disposed of through annular injection in this well exceed 35,000 bbl from either or both drill sites. Please note that in our application for annular disposal, we intend to include produced fluids as follows: · Produced formation water · Produced oil used for annular freeze protection · Produced oil with BS&W content that is unacceptable at CPF-3 and/or MPU · Produced oil that cannot be trucked in a timely manner due to weather and/or truck availability when those delays would negatively affect the extended production test. H2S: · H2S has not been detected or reported from any of the offset wells that produce from the Schrader Bluff formation. As a precaution, however, H2S monitors will be used at all times in accordance with State Regulations. ....' S Coyner 5 12/27/2004 . . DRILLING AND ABANDONMENT PROCEDURE Pre-Rig Work: 1. Install the cellar and drive the 13-3/8" non-insulated conductor to .:t 115' RKB. 2. NU the 13-5/8" (5M) casing head on the 13-3/8" drive pipe (conductor). 3. Spot and fill the reserve fuel tank. 4. Spot and fill the reserve water tank 5. Stockpile mud and cement supplies on location. 6. Stockpile casing and tubing on/near location. 7. Ensure communications are up and running: satellite phones, cellular phones & radios. 8. Spot the medic skid and have the PIA on duty. 9. Ensure the permits are in order. 10. Notify the AOGCC 24 hours prior to spud, diverter function test, 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 detailed trip sheet. Keep the hole full. Watch for swabbing. Drilling Operations: 1. MIRU Nordic 3, the camps, communications, medic skid, rig instrumentation, directional drilling equipment, LWD equipment, gas detectors, PVT, Flo-Show, etc. 2. N/U Nordics' 13-5/8" stack on the diverter spool. Configure and function test the BOP stackldiverter system with the AOGCC field supervisor present to witness the test. Surface Hole Section: 3. Take on water and/or mix spud mud. Make sure all solids control equipment if operating at capacity. Test run the pumps, Top Drive, SCR, Draw works, etc. before accepting the rig. 4. Clean out the conductor to 115'. P/U 4" drill pipe and rack it in the derrick. P/U 4" HWDP and rack it back. P/U the 12-1/4" Pilot Hole BHA with MWD/GRlRES tools. Prepare to spud. 5. Rotary drill to surface casing point. Control drill if necessary as limited by the solids control equipment, etc. Use Super Suckers and vac trucks to haul off the waste generated while drilling. The planned casing point is a shaley section to be confirmed by the wellsite geologist: .:t 2450' MD. This string will be set on slips. Do not drill extra rat hole. 6. At casing point, circulate the hole clean. Make a wiper. Pump out to the HWDP, and then finish POOH. UD LWD tools as required. RlU to run 9-5/8" surface casing. S Coyner 6 12/27/2004 . . 7. Run and cement the 9-5/8",40# surface casing as programmed. After circulating cement to surface, drain and wash out the BOP stack. RIH with the F/O tool. Open the F/O tool and circulate out the cement to ± 80' RKB with KCUPolymer mud. Close the F/O tool. POOH. 8. P/U the BOP stack and set the casing slips. Cut off the 9-5/8" casing and remove the diverter spool. N/U and test the 13-5/8" multi-bowl spool. N/U the 13-5/8" BOP's. Test the BOPE to 250 psi / 5000 psi. Test the annular to 250 psi / 3500 psi. The AOGCC field inspector should witness the BOP test. 9. P/U the 8-1/2" Pilot Hole BHA. RIH to the float collar. Test the casing to 2500 psi on chart for 30 minutes. Drill out the shoe track and 20 ft of new hole. Circulate the hole clean. Conduct a LOT on the 9-5/8" shoe: (LOT expected to be ~ 12 ppg EMW). Notify the Superintendent of the FIT results before drilling ahead. Intermediate 'Pilot" Hole Section: 10. Drill ahead to the Schrader Bluff core point at 4135' MD to be. confirmed by the wellsite geologist. At the core point, circulate and condition the hole, make a wiper trip, circulate bottoms up again. Pull (or pump) out of the hole. 11. P/U the 60 ft core barrel, etc. RIH to core point. Displace the drill string with clean mud. Commence coring: cut a 60 ft core. POOH slowly and UD the core and core barrel. 12. RIH with a bit and BHA. Drill to the pilot hole TMD of ±4300 ft. 13. At the pilot hole TMD, circulate and condition the hole for logs. Pull (or pump) out to the shoe and circulate bottoms up. Then finish POOH. UD LWD tools as required. 14. RlU E-Line. Run open hole logs as directed by wellsite geologists. Then run a GRlCBUCCL from the 9-5/8" shoe through the top of the tail slurry. RID E-line. 15. RIH with OEDP to 4300'. Circulate bottoms up while RlU cementers. Plug back the pilot hole with a balanced cement plug as follows: 557 sx (114 bbl) of Premium cement with CaCI2. POOH to 3000' and circulate the well and drill string clean. POOH. wac. Intermediate 'Sidetrack" Hole Section: ,;' 16. RIH with an 8-1/2" bit and the "build assembly". Rotary drill to the KOP of 3130' MDITVD. Orient the BHA and sidetrack the well as per the attached directional drilling well plan. Drill ahead to the casing/landing point in the Schrader Bluff "OA" sand at 4145' TVD. ./ 17. At intermediate casing point (±4880' MD), circulate bottoms up x 3. Make a wiper trip to the shoe. Circulate the hole clean. Pull (or pump) out ofthe hole to run casing. 18. RlU casing tools. Run 7" intermediate casing at ±4880' MD. Run an ES cementer at ±2850'. Cement the 7" casing as programmed. Open the ES cementer and circulate out any excess cement from above the ES cementer. Freeze protect the 7" x 9-5/8" annulus. Close the ES cementer. RID the cementers. Clean the pits. Install and test the 7" packoff. Schrader Bluff Lateral Hole Section: ./ 19. M/U 6-1/8" directional drilling assembly with Quad-Combo tool and RIH to ±2850'. Drill out the ES cementer and test the casing to 2500 psi. RIH and drill out the shoe track. Drill 20' of new hole, circulate bottoms up and pull up into the shoe. Perform an FIT to 12.5 ppg EMW. 20. Drill the 'OA" lateral as per the attached directional drilling program. Maintain the OBM properties to minimize the PV, surge, swab and ECD while still cleaning the hole. Drill ahead to TMD or as directed by the wellsite geologist. TMD is planned to be 7880'. 21. At TMD, circulate and condition hole as required. Pump out to the 7" shoe and circulate bottoms up. Return to TMD and circulate the hole clean. POOH to run the slotted liner. S Coyner 7 12/27/2004 . . Completion Operations: It is not planned to use a packer in this well in conjunction with this ESP completion. There exist several factors that justify this engineering decision and this course of action: · This Schrader Bluff well is not expected to be capable of unassisted flow to surface. · The well site and extended production test will be manned continuously and the annulus pressure will be continuously monitored and bled off as necessary. · The success of this extended production test depends upon the efficient and continuous operation of the ESP. A packer would be detrimental to that effort because it would a) force gas through the ESP, b) potentially gas-lock the ESP, c) artificially reduce the intake pressure at the ESP, and d) artificially limit our ability to draw down the producing BHP. It is documented that ESP's produce better and last longer with a) down-hole gas separation, and b) high intake pressure (head). This can best be accomplished without a packer. Therefore to maximize production, the success of this test, and ultimately the potential for developing this offshore resource, it is not planned to use a packer if approved by AOGCC in accordance with 20 ACC 25.200 (d). 22. Run the 3-1/2" slotted liner, Hyd'l HGR and Hyd'l PKR as programmed. Set the Liner HGR and PKR at ±4750' MD. Before disengaging the running tools, test the casing and PKR to 2500 psi. Disengage the running tools and pull up above the TaL. 23. Displace the 7" casing with kill weight brine. POOH. UD liner tools and excess drill pipe. 24. Run the ESP, flat cable and 2-7/8" tubing as programmed. Run the completion with a PX plug in the XN nipple. Run the TRSSV at ±500' MD. RILDS. Test the tubing to 2500 psi. 25. NO BOP's. NU and test the tree. Make surface connections and tests for the ESP cable and the %" control line. Tie in the flow line, casing bleeder line(s), etc. RID Nordic 3. Post-Rig Operations: 26. RU scaffolding and wind protection. RU Slick Line. RIH and retrieve the PX plug. Then retrieve the dummy GL V. Displace the well (freeze protect) with diesel. Set a BHP gauge in the GML. RD slick line. Prepare to test the well. 27. Insure that the 7" casing is tied in to the flow line as per the attached diagram. Test all lines, tanks, valves and test equipment. RU and test the generators and VSD. Make sure that tankers are on standby to transport produced oil, etc. Conduct a SIM-OPS safety meeting. 28. Start up the ESP using Centrilft's start up procedure. Produce the well to the test equipment and tank farm as necessary to establish a) maximum drawdown, and b) maximum stabilized production rate. Monitor the 7" casing annulus at all times (2417). Maintain the 7" casing pressure at or below 500 psi (10% ofWP) at all times. Produced Oil Sales/Disposal: It is essential that this production test proceed without interruption insomuch as that may be possible. The resulting test data will be used to ultimately determine the economic viability of developing this reservoir. Oil produced from this well will pass through the test separator and line heater before accumulating in the 3000-bbl tank farm. It is imperative that the ESP be allowed to run continuously, and not be shut down if at all practical. Therefore, we plan to have several options available to us which will enable us to avoid shut downs due to phase conditions (except phase III), problems at the "receiving end", truck availability, etc. S Coyner 8 12/27/2004 . . . . a. The primary means of dealing with produced oil is to truck it to an existing production facility such as CPF-3 in Kuparuk, or the facility at Milne Point. b. The tank farm which will have 3000 bbls of storage gives us a producing cushion with which to work in the event that trucks are delayed. c. The tank farm will be tied in to the annular disposal pump on location which gives us the ability to use produced oil to freeze protect the 9-5/8" x 7" annulus, and the ability to inject produced oil through that annulus in the event that: · Phase conditions cause trucking delays, or · Trucks become unavailable, or · The oil is turned away at the production facility. In any case, the produced oil will be accurately metered through the test equipment, strapped in the tanks and metered onto and off of the trucks. Post-Production Test Operations: 29. At the conclusion of the production test, shut down the ESP and remove the cable lead. Kill the 7" annulus with brine and/or kill weight mud. Pump a "Flo-Pro" pill if necessary to support the kill weight brine/mud. 30. RlU Sick Line and retrieve the pressure bomb from the GLM. Kill the tubing with brine. RID. 31. RlU Nordic 3 again to P & A. Circulate kill weight fluid through the GLM. Check for flow. Close the TRSSV. Nt the Tree. NtU and test BOPE. RlU the cable spooler. 32. POOH with the ESP and UD same. 33. RIH with an EZSV on tubing (or drill pipe). Set the EZSV ±4500' MD and test same. 34. RlU cementers. Mix and pump +22 bbl of Premium cement (107 sx) and squeeze cement across the 7" shoe - into the open-hole lateral. Leave the last 2 bbl (50') of cement on top of the EZSV. Pull ±10 stds. Circulate bottoms up. Test the EZSV and cement to 2000 psi. 35. Finish plugging the well in accordance with 20 ACC 25.112. 36. RID Nordic 3. Scrape the ice pad and roads. Properly dispose of the dirty ice, etc. 37. When appropriate, conduct a site survey with AOGCC and obtain clearance. Attachments: · "As Staked" survey plat · Nikaitchuq Unit Plat · Days -vs- Depth Graph · Frac Gradient Graph · Temperature Gradient Graph · Well bore Schematics · Directional Drilling Plan · Drilling Mud Program · Abnormal Pressure Analysis · Shallow Hazard Study · Nordic 3 BOP & Diverter diagram · Nordic 3 Choke Manifold Diagram · Wellhead Schematic S Coyner 9 12/27/2004 · . ~ KERR-MCGEE CORPORATION December 30, 2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RECEIVED DEC 3 02004 ,Alaska Oil & Ga~ Cons. Commission Anchorage Re: Nikaitchuq #4 Kerr McGee Oil & Gas Corporation Application for Pennit to Drill (10-401) Attached for your review is our Application for Pennit to Drill the Nikaitchuq #4 exploration well located approximately four (4) miles north ofOliktok Point. This original APD is submitted along with one (1) copy and the $100.00 filing fee. The APD packages include fonn 10-401, an abnonnal pressure analysis, a shallow hazard analysis, a comprehensive drilling hazard analysis, drilling program, directional drilling plan, drilling mud program, plats, graphs and diagrams as required. The package includes an "As Staked" location plat which will be followed by an "as built" plat when available. ./ This application for pennit to drill includes a vertical pilot hole that will be drilled through the primary zone of interest, logged and then plugged back to the kick off point. We plan to cut a core in the pilot hole before actually reaching TMD and logging. After plugging ,/ back with cement, the well will be sidetracked at 3130' MD/TVD following the attached directional drilling plan (wp03). It is our intention to apply for annular disposal! after we have set the intennediate casing string. That application for Sundry Approval will be accompanied by all of the required data necessary for expedited approval. Our application for annular disposal will include drilling waste from this well, Nikaitchuq #3 located on the same pad and (if approved) Tuvaaq State # 1 located near by on Spy Island. We hereby request approval in accordance with 20 ACC 25.200 (d) to complete and test this well without a packer in the completion. It is not planned to use a packer in this well because this is an ESP completion and a packer would be detrimental to the operation thereof. There exist several factors that justify this engineering decision and this course of action: 3900 C Street (907)-339-6370 Suite 702, RID 744 Anchorage, AK 99503 · . ~ KERR-MCGEE CORPORA nON · This well is not expected to be capable of unassisted flow to surface: due to the relatively low BHP in the Schrader Bluff and the high viscosity ofthe oil. · During the extended production test, the well site will be manned continuously, the annulus pressure will be monitored continuously, and gas pressure in the annulus will be bled off routinely to maintain that annulus pressure at or below 10% of the tubing head (penetrator) working pressure. · The success of this extended production test, and ultimately, the decision to develop this resource or not depends upon the efficient and continuous operation of the ESP. A packer would be detrimental to that effort because a packer would a) force gas through the ESP, b) potentially gas-lock the ESP, c) artificially reduce the intake pressure at the ESP, and d) artificially limit our ability to draw down the producing BHP. It is documented that ESP's produce better and last longer with a) down-hole gas separation, and b) high intake pressure (head). This can best be accomplished without a packer. Therefore to maximize production, the success of this test, and ultimately the potential for developing this offshore resource, it is not planned to use a packer if approved by AOGCC in accordance with 20 ACC 25.200 (d). / Our anticipated spud date for Nikaitchuq #4 is on or about January 17th, 2005. The construction of our ice road and drilling pad are well underway. 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. Your timely review of our APD and the accompanying data is greatly appreciated. Sincerely, s&r- ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 1a. Type of Work: AlASa'l AND ~~T~g:S~~:::;ON COMMI&N R;~;dYo~D PERMIT TO DRILL 20 MC 25.005 AI2ska on & GA~ CQn~COmmiSSion 1b. Current Well Class: Exploratory 0 'Developm'1f1t,gj1 Multiple Zone 0 Stratigraphic Test 0 Service 0 DevelopméhQ'dh~a Single Zone 0 5. Bond: Blanket U Single Well 0 11. Well Name and Number: Bond No. 3-798-381 Nikaitchuq #4 6. Proposed Depth: 12. Field/Pool(s): J MD: 7880 TVD: 4145 7. Property Des.!j!,,· q~i~n:2- 38ðS&'3 />1/ ADlj'tsnB I ADL 3B3681 ,. s .t{'" 8. Land Use Permit: 13. Approximate Spud Date: 1/17/2005 9. Acres ~nlroperty: /g'),/ A. '.í"",~ 1~~¡:J~;eJ<?~~J?hùot. ¡i¡+-<."V<t./. ,~c & ~c respectively Property: '3820 ft .Ai::> ¡'s"; 10. KB Elevation 15. Distance to Nearest Well 2>.) (Height above GL): 35 feet Within Pool: None, - 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) '-\ 1" Downhole: ~ Surface: )M'SPSi ~~NICÀ~ Yï:Jf.."'~ \~" Setting Depth \~~\ Quantity of Cement '\'(0 Top Bottom c.f. or sacks TVD MD TVD (including stage data) 35 115 115 N/A - Drive Pipe 35 2450 ./ 2450 302 sx Permafrost L (223 bbl) 186 sx Premium CMT (38 bbl) 4145 293 sx Premium CMT (60 bbl) 4145 Slotted Liner - No Cement Drill 0 Redrill 0 Re-entry 0 2. Operator Name: Kerr McGee Oil & Gas Corporation 3. Address: 3900 C Street, Ste 744, Anchorage, AK 99503 4a. Location of Well (Governmental Section): Surface: 350' FSL & 1460' FWL Sec. 16, T14N, R9E UM ) Top of Productive Horizon: (Intermediate Casing shoe) 1175' FSL & 602' FWL Sec. 16, T14N, R9E UM Total Depth: 1530' FNL & 923' FEL, Sec. 17, T14N, R9E UM / 4b. Location of Well (State Base Plane Coordinates): ... ... Surface:x- 519,643 y- 6,054,828 Zone- 4 16. Deviated wells: Kickoff depth: 3130 feet ... Maximum Hole Angle: 90 degrees 18. Casing Program: Size Casing 13-3/8" 9-5/8" Hole N/A 12-1/4" 8-112" 6-1/8" 7" 3-1/2" 19. Total Depth MD (ft): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Specifications Weight 68# 40# Grade Coupling PElBFW BT&C Length 80 2415 At Exploration MD 35 35 35 4700 4880 7880 'X-56 L-80 35 4137 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Mr. Todd Durkee Samples requi Hydrogen de me ure~s Other'<-~' .....t.., ..., . ~ ' \ '-""~.. Approved by: ' " , "', .... Form 10-401 Revised ~ Yes 0 NoP{! Mud log required Yes 0 No ¡g¡ Directional survey required ~V ~~'~,,--kNC-.\ b:. ~ ~<:3..'f~~ APPROVED BY THE COMMISSION Date: 26# 9.2# BT&C-M IBT 4845 3180 L-80 L-80 Length Size Junk (measured): Cement Volume MD TVD Perforation Depth TVD (ft): Time v. Depth Plot ~ Shallow Hazard Analysis ~ Drilling Fluid Program 0 20 AAC 25.050 requirements 0 Date Contact Filing Fee ~ BOP Sketch ~ Property Plat 0 Diverter Sketch 0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. 20. Attachments: Printed Name Drilling Program ~ Seabed Report 0 Title Drilling Manager, Kerr McGee Oil & Gas Corporation Signature . J J /"'I !:,I'I/Y'J _____ }Jf' f;ef,f f)1t I'J <'é'hone 9 () 7- ¡ J 1-1.2 t i ~./ -7" ~ - Commission Use Only Permit to Drill 1/ IAPI Number: I Permit APpro~a¡ , / Number: 2.b .., ... ¿~ð 50- 62 c:¡ - 232. efl -ðD Date: '¡" / CJ:;- Conditions of approval : Date 12/28/2004 I See ~ver letter for.oth,. requirements. V Yes 0 Yes ~ No ~ No 0 0'1/ ro- Submit in Duplicate Location Plat & Unit Plat REV I DATE I BY I CK I APP I ~IPlION REV DATE I BY I~APP I DESCRIPlION NOTES: 1. Basis of Location: Mon 3R South 2, by L.H.D. & Assoc. 2. Coordinates shown ar A.S.P., Zone 4, NAD 27 3. Location determined with Lieca 500 Series GPS Units, using Geoid 98 4. Geographic coordinates are NAD 27 :::0:::0 (X)tQ 11 rrJ rrr 11 8 3 2 :::0 ::::0 6 to-" rrJO rrr -^----_.._~~--_._--'-_.-._._-"'--\--'._-~~-------_._----.~, 11 11 12 7 i i: ~+....~.~-.--.,.-...--.-..-....,-.,-,~-,..-...-~.,.....J_..--...--~.,-~-"~.~~-+-~ .,... ."...'-... ~~····--·.-..-j'--_..-'_..·.._-.·..·t.-..-...~.---..-----..', ..--....-.-- ...-....-..- -....-- j : i I I SdALE: . , 1" = 11 Mile : 13 18 : Spy ISLAND 17 15 14 13 18 i i ~ NÎkaitchuq-11 '~ '20 21 : NIKAITCHUQi 114 ! y = 6054828.0 -T··--······-·-···-··,-·-··,·-··-·---·-···-·-·~·T-X'-';;-519·64P-·-····· ,."..-" ..-.....j.,..-.,.-.-.......---.....--+....--.---...-...--.+..-------,.-.--..-....---- I LA T = 70· 33' 39.46" i LONG = 14$· 50' 19.91"1 : 350' F.S.L., [1460' F. W.L. i ¡SECTION 16J T14N, R9E, ¡U.M. , __~_.--n-".--~'--_.-__.__._.--____ Ò' 'Eo ","",0 .ef .. ?" ~'t~ ~ ~o £~o // \~o Ò' ' /" . -.I s'l.! /.' . " S"QJ,po.</ ' ;/ 24 ~'!-///>""1; \::~;>:..:..:c..:>(;..-- i ' -.-.--+----- --·--N¡~-~·it~i~~q-=2T···-·-·-··--·--·-------· ~ ¡ 23 24 19 25 30 27 26 25 30 ; "" ( .,~-..--..---....--..-...,.-,---.-.--...,-,._..-.-.-..+....-'-..-.-.,..-.--,."..~--.-..-..-""'..-'-.".,.,-·-~--··,·,·-·--·-·,··,·--+--··-,-·,--···--···--t·_··-·--...--.-.,-.--- 36 31 32 :r: 34 35 36 31 T14N T13N NOTE: SHAPE AND CONFIGURATION OF spy ISLAND IS FROM OLD MAPPING AND HAS BEEN ADJUSTED ~ 6 TO FIT THE LOCATION OF EXPLORATORY WELLS. THE J\(-) ACTUAL CONFIGURATION OF THE ISLAND MAY VARY GREATlY FROM THAT SHOWN ON THIS DRAWING. i OLlKTOK D<J>CK o~ i \ S t) I ~ DEW LINE +-··--·---·-~--·--_·-·_-·_·---SrTt--·--· ~~ -{ 1 12 0 ~ 4 3 2 -~._----~----,-~_.-~,-~-,-----_. ,DS-ßR \\ t : ......~.. ". I .'. O[lKTOlt~öfNT 5T AGlN(:; AR~A ~-- ¡ :"15 \ Ij . \ /1 Øl LOUNSBURY Be ASSOCIATES, INC. SURVIIYORS ENGINEDS PL.\NNEIIS 'q¡a (I{íø)KERR-MCGEE CORPORA11ON CADD FILE NO. LK601D575 1 DRAWING NO: 12/20/04 NIKAITCHUQ #4 EXPLORATORY WELL CONDUCTOR AS-STAKED LOCATION NSK 6.01-d575 JPART: 1 OF 1 JREV:O NikaitchuQ.No. 4 Surface 70° 33' 39.46" N & 350' FSl & 1460 FWl of Section 6,054,828' N & 519,643' E NAD 27, Zone 4 landina/Casina Point Location: 1175' FSl & 602' FWL of 6,055,650'N & 518,780' E Bottom 1530' FNL & 6,058,221' N & 17 T14N NAD 4 Nikaitchuq No. (Bottom Hole Location 17 ADl 388583 Armstrong 0 & G Kerr McGee 0 & G 1 FSL (Plugged & Abandoned) 4 (Landing/Casing Point "Heel") 20 16 4 21 . . ~~ KERR-MCGEE CORPORATION Nikaitchuq #4 Drill, Complete, Test & Plug I Drilling Rig: Nordic 3 I Drill, Complete, Test, Plug & Abandon 350' FSL & 1460' FWL of Section 16, T14N, R9E UM X = 519,643' Y = 6,054,828' 1175' FSL & 602' FWL of Section 16, T14N, R9E UM X = 518,780' Y = 6,055,650' 1530' FNL & 923' FEL of Section 17, T14N, R9E UM X = 517,235' Y = 6,058,221' Surface Location: (and Pilot Hole BHL) Landing/Casing Point: Bottom Hole Location: I Estimated Spud Date: 11/17/05 1 I PTD: /7,880' I I TVD: 14,145' 1 I Operating Rig days: 118 I Pad Elev: 13 ft I I DF: 135 ft I Geologic Objectives: Schrader Bluff "OA" Sand v Mud Program: \JQ\<o\to~~~- r~\ . 12-1/4" Surface Hole. &16=" 11.0. (0' - 2450'): Density PV YP HTHP 9.0 - 9.8 I 15 - 25 I 30 - 45 In/a pH 9,0-9.5 8-1/2" Intermediate Pilot Hole (2723' - 4300'): Density PV YP HTHP 9.0-9.3 15-25 15-25 n/a pH 9.0-9.5 8-1/2" Sidetrack "Build Section" (3130' - 4880'): Density PV YP HTHP 9.0 - 9.3 15 - 25 15 - 25 n/a pH 9.0-9.5 6-1/8" Schrader Bluff Lateral (4880' - 7880'): Density PV YP HTHP 9.0-9.3 10-15 15-25 10-11 pH 9.0-9.5 S Coyner 1 KCUPolymer API W/L LG Solids < 6 < 10 KCUPolymer API W/L LG Solids < 6 < 10 KCUPolymer API W/L LG Solids < 6 < 10 L VT -200 MOBM ES Tauo 600 - 1000 4 - 7 12/27/2004 . . Recommended Bit Program: Bit Hole Size Depth (MD) Footage Bit Type TFA GPM 1 12-1/4 in Surf - 2,450' 2,415' GT-1 .75 - .90 450 - 650 2pilot 8-1/2 in 2,450 - 4,300' 1,850 GT-1 .50 - .75 400 - 500 3ST 8-1/2 in 3,000' -4,880' 1,880' GT-1 .50 - .75 400 - 500 4 6-1/8 in 4,880' -7,880' 3,000' FM3643 .35 - .45 250 - 325 Casing Program Hole Csgl WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD 1 TVD MD 1 TVD N/A 13-5/8" 68# L-80 BTC 80' 35' 115'/115' 12-114" 9-518" 40# L-80 BTC 2,415' 35' 2,450' 12,450' 8-1/2" 7" 26# L-80 BTC 4,845' 35' 4,880' 14,145' Cement Program: Casing Size 9-5/8",40#, L-80, BTC Surface Casing at 2,450' MD Excess from BIPermafrost to Surface = 100% over gauge hole. Parameters Use 25% excess below the B/Permafrost. Shoe track = 85 ft. Total cement volume will be confirmed with carbide lag(s) Cement: 361 bbl Wash 10 bbl water Spacer 50 bbl of NSCI spacer mixed at 10 ppg Lead 223 bbl, 302 sx of Permafrost L: 10.7 ppg and 4.15 ft3tsx Tail 38 bbl, 186 sx "G" mixed at 15.81b/gal & 1.15 ft3tsx Temp Casing Point BHST 750 F (from offset data) 7", 26#, L-80, BTC-M Intermediate Casing at 4,880' MD Excess = 25% over gauge hole, TOC ± 2,880', Shoe track = 85' Wash 10 bbl water Spacer 30 bbl of NSCI spacer mixed at 10 ppg Slurry 60 bbl, 293 sx "G" mixed at 15.8 Ib/gal & 1.16 ft3/sx Temp Casing Point BHST 1120 F (from offset wells) Casing Size Parameters: Cement: 216 bbl Integrity Testing: Test Point: 9-5/8" Shoe 7" Shoe MD 1 TVD 2450' 1 2450' 4880' 14145' Kick Tolerance ~ 50 bbls > 50 bbls Test Type: LOT FIT EMW: 12.0 ppg 12.5 ppg S Coyner 2 12/27/2004 . Surveys & MWD: While Drilling: . Surface to TD: MWD surveys every 90 to 180 ft IIFR Casandra for magnetic survey verification Rig instrumentation: PVT, Flow-Show, gas detectors, H2S ~ detectors as required. Mud loggers from 1200' to casing point: samples every 30 ft, / gas detection & drilling parameters Rig instrumentation: PVT, Flow-Show, gas detectors, H2S detectors as required. Mud loggers to pilot hole TD: samples every 30 ft: every 10ft in " pay zones, gas detection & DRLG parameters Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. Mud loggers to landing point: samples every 30 ft: every 10ft in .¡' pay zones, gas detection & DRLG parameters Mud Logging: Surface Hole [12-114"]: Pilot Hole [8-1/2"] and Sidetrack "Build Section": S.B. Lateral [6-1/8"]: Evaluation Prog.ram: 12-1/4" Surface Hole Open Hole: MWD / LWD: Open Hole: E-Line: 8-1/2" Pilot Hole Open Hole: MWD / LWD: Open Hole: E-Line: Cased Hole: 8-1/2" Sidetrack Open Hole: MWD / LWD: Open Hole: E-Line: Cased Hole: 6-1/8" S. B. Lateral Open Hole: MWD / LWD: Open Hole: E-Line: Cased Hole: S Coyner 3 MWD / GR / RES ./ Gas Detection, Mud Logging, samples -' None MWD / Triple-Combo ,/ Gas Detection, Mud Logging, samples HRLA I DEN I NEU / Dipole Sonic I FMI ~.:".."..: -!....,"'!t~ing MWD / Triple-Combo v' Gas Detection, Mud Logging, samples None None MWD / Triple-Combo / ABI '-' Gas Detection, Mud Logging, samples ' None None 12/27/2004 Formation Markers: Formation Tops Eocene Unconformity B/Permafrost BlPrince Creek T/Ugnu (Pilot/Sidetrack) T/SB (Pilot/Sidetrack) T/OA (Pilot/Sidetrack) PTD (Pilot Hole) T/Colville . MD (ft) Pilot/Sidetrack 1,385 1,720 2,090 3,385 1 3,389 3,985/4,189 4,145/4,818 4,300 N/A . TVD (ft) 1,385 1,720 2,090 3,385 3,985 4,145 4,300 4,380 EMW (Ib/gal) Pore Pressure (psi) 916 1,484 1,824 1,927 1,974 8.43 8.43 8.80 8.94 8.83 Well Control: The casing head will be installed on the 13-3/8" drive pipe along with a 13-5/8" diverter spool and the 16" Oiverter Line. The 13-5/8" BOP stack will be NU above the diverter spool and the BOP stack will be configured to use the 13-5/8" annular as a diverter. The surface hole [12-1/4"] will be drilled to casing point in the lower SV sands using the diverter system for secondary well control. At casing point, 9-5/8" surface casing will be set and cemented. It is planned to circulate cement to surface. It is also planned to use a 9-5/8" F/O tool to circulate cement out of the 13-3/8" x 9-5/8" annulus and freeze protect same down to ± 80 ft below RKB. Both strings will be cut and recovered later. After setting and cementing the 9-5/8" surface casing, the diverter spool will be replaced with a multi-bowl casing spool. The 13-5/8" (5M) BOP stack will be reconfigured and tested. 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 lor 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 extrapolated BHP data recorded at MPU which include a 0.30 psilft oil gradient to correct for TVO and a gas gradient of 0.11 psilft to surface as required: " \ <D~ct Ç?<L r<L....-o..\ \. Nikaitchuq #4, Schrader Bluff BHP = 1927 psi Maximum Surface Pressure = 1927 psi - (4145 ft x 0.11 psilft) = 1471 psi Disposal of Drilling Waste: · Cuttings Handling: Cuttings generated from drilling operations will be hauled using super suckers to G & I #3: located on OS-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. S Coyner 4 12/27/2004 . . · NPEDS: Subject to an approved NDEPS disposal permit, approved solid and liquid waste may be dumped on or through the ice in the stipulated water depth. · Sewage (grey/black water): Camp waste water will be hauled to the sewage treatment plant(s) at Kuparuk / Prudhoe Bay / North Slope Borough where it will be treated and injected. Annular Disposal of Drillina Associated Waste:. It is planned to apply for an annular disposal soon after the 7" intermediate casing is ." set and cemented. Upon approval, drilling waste from the oil based mud [6-1/8"] hole section will be injected via the 9-5/8" x 7" annulus into the Ugnu formation. Offset log >/ data shows that no fresh water sources exist within this geologic section, and any hydrocarbon bearing zones in the intermediate hole section will be covered by cement. It is planned to include with the 10-403 form the option of injecting drilling waste generated on Kerr McGee's other exploration wells, Nikaitchuq #3 (located on the same pad) and Tuvaaq State #1 (located nearby - on Spy Island). In no case shall the total volume of drilling waste disposed of through annular injection in this well exceed 35,000 bbl from either or both drill sites. Please note that in our application for annular disposal, we intend to include produced fluids as follows: · Produced formation water · Produced oil used for annular freeze protection · Produced oil with BS&W content that is unacceptable at CPF-3 and/or MPU · Produced oil that cannot be trucked in a timely manner due to weather and/or truck availability when those delays would negatively affect the extended production test. H2S: · H2S has not been detected or reported from any of the offset wells that produce from the Schrader Bluff formation. As a precaution, however, H2S monitors will be used at all times in accordance with State Regulations. ./ S Coyner 5 12/27/2004 . . DRilLING AND ABANDONMENT PROCEDURE Pre-Rig Work: 1. Install the cellar and drive the 13-3/8" non-insulated conductor to ± 115' RKB. 2. NU the 13-518" (5M) casing head on the 13-3/8" drive pipe (conductor). 3. Spot and fill the reserve fuel tank. 4. Spot and fill the reserve water tank 5. Stockpile mud and cement supplies on location. 6. Stockpile casing and tubing on/near location. 7. Ensure communications are up and running: satellite phones, cellular phones & radios. 8. Spot the medic skid and have the PIA on duty. 9. Ensure the permits are in order. 10. Notify the AOGCC 24 hours prior to spud, diverter function test, 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 drillslkick 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 tool pusher and company man will witness the first ten (10) stands off bottom for all trips. Use the trip tank. Keep a detailed trip sheet. Keep the hole full. Watch for swabbing. Drilling Operations: 1. MIRU Nordic 3, the camps, communications, medic skid, rig instrumentation, directional drilling equipment, LWD equipment, gas detectors, PVT, Flo-Show, etc. 2. N/U Nordics' 13-5/8" stack on the diverter spool. Configure and function test the BOP stackldiverter system with the AOGCC field supervisor present to witness the test. Surface Hole Section: 3. Take on water and/or mix spud mud. Make sure all solids control equipment if operating at capacity. Test run the pumps, Top Drive, SCR, Draw works, etc. before accepting the rig. 4. Clean out the conductor to 115'. P/U 4" drill pipe and rack it in the derrick. P/U 4" HWDP and rack it back. P/U the 12-1/4" Pilot Hole BHA with MWD/GRlRES tools. Prepare to spud. 5. Rotary drill to surface casing point. Control drill if necessary as limited by the solids control equipment, etc. Use Super Suckers and vac trucks to haul off the waste generated while drilling. The planned casing point is a shaley section to be confirmed by the wellsite geologist: ± 2450' MD. This string will be set on slips. Do not drill extra rat hole. 6. At casing point, circulate the hole clean. Make a wiper. Pump out to the HWDP, and then finish POOH. UD LWD tools as required. RIU to run 9-5/8" surface casing. S Coyner 6 12/27/2004 . . 7. Run and cement the 9-5/8",40# surface casing as programmed. After circulating cement to surface, drain and wash out the BOP stack. RIH with the FIO tool. Open the FIO tool and circulate out the cement to :!:: 80' RKB with KCUPolymer mud. Close the FIO tool. POOH. 8. P/U the BOP stack and set the casing slips. Cut off the 9-5/8" casing and remove the diverter spool. N/U and test the 13-5/8" multi-bowl spool. N/U the 13-5/8" BOP's. Test the BOPE to 250 psi I 5000 psi. Test the annular to 250 psi I 3500 psi. The AOGCC field inspector should witness the BOP test 9. P/U the 8-1/2" Pilot Hole BHA. RIH to the float collar. Test the casing to 2500 psi on chart for 30 minutes. Drill out the shoe track and 20 ft of new hole. Circulate the hole clean. Conduct a LOT on the 9-5/8" shoe: (LOT expected to be ~ 12 ppg EMW). Notify the Superintendent of the FIT results before drilling ahead. Intermediate 'Pilof' Hole Section: 10. Drill ahead to the Schrader Bluff core point at 4135' MD to be confirmed by the wellsite geologist. At the core point, circulate and condition the hole, make a wiper trip, circulate bottoms up again. Pull (or pump) out of the hole. 11. P/U the 60 ft core barrel, etc. RIH to core point. Displace the drill string with clean mud. Commence coring: cut a 60 ft core. POOH slowly and UD the core and core barrel. 12. RIH with a bit and BHA. Drill to the pilot hole TMD of :!::4300 ft. 13. At the pilot hole TMD, circulate and condition the hole for logs. Pull (or pump) out to the shoe and circulate bottoms up. Then finish POOH. UD LWD tools as required. 14. RlU E-Line. Run open hole logs as directed by wellsite geologists. Then run a GRlCBUCCL from the 9-5/8" shoe through the top of the tail slurry. RID E-line. 15. RIH with OEDP to 4300'. Circulate bottoms up while RlU cementers. Plug back the pilot hole with a balanced cement plug as follows: 557 sx (114 bbl) of Premium cement with CaCI2. POOH to 3000' and circulate the well and drill string clean. POOH. WOC. Intermediate 'Sidetrack" Hole Section: ",' 16. RIH with an 8-1/2" bit and the "build assembly". Rotary drill to the KOP of 3130' MDnvD. Orient the BHA and sidetrack the well as per the attached directional drilling well plan. Drill ahead to the casingllanding point in the Schrader Bluff "OA" sand at 4145' TVD. ./ 17. At intermediate casing point (±4880' MD), circulate bottoms up x 3. Make a wiper trip to the shoe. Circulate the hole clean. Pull (or pump) out ofthe hole to run casing. 18. RlU casing tools. Run 7" intermediate casing at :!::4880' MD. Run an ES cementer at :!::2850'. Cement the 7" casing as programmed. Open the ES cementer and circulate out any excess cement from above the ES cementer. Freeze protect the 7" x 9-5/8" annulus. Close the ES cementer. RID the cementers. Clean the pits. Install and test the 7" packoff. Schrader Bluff Lateral Hole Section: ./ 19. M/U 6-1/8" directional drilling assembly with Quad-Combo tool and RIH to :!::2850'. Drill out the ES cementer and test the casing to 2500 psi. RIH and drill out the shoe track. Drill 20' of new hole, circulate bottoms up and pull up into the shoe. Perform an FIT to 12.5 ppg EMW. 20. Drill the 'OA" lateral as per the attached directional drilling program. Maintain the OBM properties to minimize the PV, surge, swab and ECD while still cleaning the hole. Drill ahead to TMD or as directed by the wellsite geologist. TMD is planned to be 7880'. 21. At TMD, circulate and condition hole as required. Pump out to the 7" shoe and circulate bottoms up. Return to TMD and circulate the hole clean. POOH to run the slotted liner. S Coyner 7 12/27/2004 . . Completion Operations: It is not planned to use a packer in this well in conjunction with this ESP completion. There exist several factors that justify this engineering decision and this course of action: · This Schrader Bluff well is not expected to be capable of unassisted flow to surface. · The well site and extended production test will be manned continuously and the annulus pressure will be continuously monitored and bled off as necessary. · The success of this extended production test depends upon the efficient and continuous operation of the ESP. A packer would be detrimental to that effort because it would a) force gas through the ESP, b) potentially gas-lock the ESP, c) artificially reduce the intake pressure at the ESP, and d) artificially limit our ability to draw down the producing BHP. It is documented that ESP's produce better and last longer with a) down-hole gas separation, and b) high intake pressure (head). This can best be accomplished without a packer. Therefore to maximize production, the success of this test, and ultimately the potential for developing this offshore resource, it is not planned to use a packer if approved by AOGCC in accordance with 20 ACC 25.200 (d). 22. Run the 3-1/2" slotted liner, Hyd'l HGR and Hyd'l PKR as programmed. Set the Liner HGR and PKR at .:!:,4750' MD. Before disengaging the running tools, test the casing and PKR to 2500 psi. Disengage the running tools and pull up above the TOL. 23. Displace the 7" casing with kill weight brine. POOH. UD liner tools and excess drill pipe. 24. Run the ESP, flat cable and 2-7/8" tubing as programmed. Run the completion with a PX plug in the XN nipple. Run the TRSSV at .:!:,500' MD. RILDS. Test the tubing to 2500 psi. 25. ND BOP's. NU and test the tree. Make surface connections and tests for the ESP cable and the %" control line. Tie in the flow line, casing bleeder line(s), etc. RID Nordic 3. Post-Rig Operations: 26. RU scaffolding and wind protection. RU Slick Line. RIH and retrieve the PX plug. Then retrieve the dummy GL V. Displace the well (freeze protect) with diesel. Set a BHP gauge in the GML. RD slick line. Prepare to test the well. 27. Insure that the 7" casing is tied in to the flow line as per the attached diagram. Test all lines, tanks, valves and test equipment. RU and test the generators and VSD. Make sure that tankers are on standby to transport produced oil, etc. Conduct a SIM-OPS safety meeting. 28. Start up the ESP using Centrilft's start up procedure. Produce the well to the test equipment and tank farm as necessary to establish a) maximum drawdown, and b) maximum stabilized production rate. Monitor the 7" casing annulus at all times (24n). Maintain the 7" casing pressure at or below 500 psi (10% ofWP) at all times. Produced Oil Sales/Disposal: It is essential that this production test proceed without interruption insomuch as that ~/ may be possible. The resulting test data will be used to ultimately determine the economic viability of developing this reservoir. Oil produced from this well will pass through the test separator and line heater before accumulating in the 3000-bbl tank farm. It is imperative that the ESP be allowed to run continuously, and not be shut down if at all practical. Therefore, we plan to have several options available to us which will enable us to avoid shut downs due to phase conditions (except phase III), problems at the "receiving end", truck availability, etc. S Coyner 8 12/27/2004 . . a. The primary means of dealing with produced oil is to truck it to an existing production facility such as CPF-3 in Kuparuk, or the facility at Milne Point. b. The tank farm which will have 3000 bbls of storage gives us a producing cushion with which to work in the event that trucks are delayed. c. The tank farm will be tied in to the annular disposal pump on location which gives us the ability to use produced oil to freeze protect the 9-5/8" x 7" annulus, and the ability to inject produced oil through that annulus in the event that: · Phase conditions cause trucking delays, or · Trucks become unavailable, or · The oil is turned away at the production facility. In any case, the produced oil will be accurately metered through the test equipment, strapped in the tanks and metered onto and off of the trucks. Post-Production Test Operations: 29. At the conclusion of the production test, shut down the ESP and remove the cable lead. Kill the 7" annulus with brine and/or kill weight mud. Pump a "Flo-Pro" pill if necessary to support the kill weight brine/mud. 30. RlU Sick Line and retrieve the pressure bomb from the GLM. Kill the tubing with brine. RID. 31. RlU Nordic 3 again to P & A. Circulate kill weight fluid through the GLM. Check for flow. Close the TRSSV. N/ the Tree. N/U and test BOPE. RlU the cable spooler. 32. POOH with the ESP and UD same. 33. RIH with an EZSV on tubing (or drill pipe). Set the EZSV ±4500' MD and test same. 34. RlU cementers. Mix and pump +22 bbl of Premium cement (107 sx) and squeeze cement across the 7" shoe - into the open-hole lateral. Leave the last 2 bbl (50') of cement on top of the EZSV. Pull ±10 stds. Circulate bottoms up. Test the EZSV and cement to 2000 psi. 35. Finish plugging the well in accordance with 20 ACC 25.112. 36. RID Nordic 3. Scrape the ice pad and roads. Properly dispose of the dirty ice, etc. 37. When appropriate, conduct a site survey with AOGCC and obtain clearance. Attachments: · "As Staked" survey plat · Nikaitchuq Unit Plat · Days -vs- Depth Graph · Frac Gradient Graph · Temperature Gradient Graph · Wellbore Schematics · Directional Drilling Plan · Drilling Mud Program · Abnormal Pressure Analysis · Shallow Hazard Study · Nordic 3 BOP & Diverter diagram · Nordic 3 Choke Manifold Diagram · Wellhead Schematic S Coyner 9 12/27/2004 Wellbore Diagrams & Drilling Graphs 1000 2000· 3000 .r::. ...., g. 4000 C "C e ::s I« 5000 CD :i 6000 1000 8000· 9000 o Nikaitchuq Days ...v... Depth o 5 10 15 Rig Days 20 Nikaitchuq #4 Drilling S. Coyner MUD INFO 12/20/2004 þH/O~ LOGS CASING SPECS 13~3/8" 68 Iblft, Le80 Welded I Driven DIR I LWD MWD DEPTH MD I TVD FORM NONE NONE 9-5/8" 1"/0 Tool 85' 115' N/A N/A MWD/GR/RES NONE Surface Cst! 9-5/8" 40 Ibslft L-80, BTC-M Yield 57130 psi Collaspse 3090 psi Float Equipment: 1 ea Float Shoe 1 ea Float Collar 1 ea F/O Cementer Centralizers: 5 Straight Blade 5 Bow Top of Permafrost 400' IIFR/Cas Base Permafrost Top ofT ail Cement CBL NONE 7" HES Cementer 2,850' 2,850' Top of Cement 2,880' 2,880' Kick Off Point 3,130' 3130 Inter,Casin!:l 7 inch 26 Ibs/ft L-80, BTC-M In!. Yield 7240 psi Collaspse 5410 psi 000 IIFRfCas 0° Cement Slurry Premium Cement 60 bbls, 293 sx 22° 3,500'3,491' Float Equipment: 1 ea Float Shoe 1 ea Float Collar 1 ea H-ES Cementer Centralizers: 10 Straight Blade 10 40° 3,800' 3,746' 72° 4,300' 4,028' 4,530' 72° 90° Triple-Combo ABI Schrader Bluff Lateral Slotted Liner 3-1/2 inch 9.2 Ibs/ft L-80, IBTC 90° 90° Geo-Stear 15,376' 7,540' Centralizers: 110 Bow Spring 110 Lock Rings 16,876' 8,290' IFR/Cas 90° FORM Cut Off 9-5/8" Casing Cut Off 7" Casing Bottom of Cement Top of Permafrost Base Permafrost Top of Cement Plug Bottom of CMT Plug 7" HES Cementer Top of Cement Plug 7"EZSV Top of Liner Bottom of Cement Schrader Bluff Lateral Geo-Stear PEPTH (PF) MD I TVD 75' 115' 150' 250' 400' 2,850' 2,850' 4,450' 4,075' 4,500' 4,091' 4,700' 4,137' 5,080' 4,145' P&A :::¡CI~.e<t¡ 10 ppg Mud CASING SPECS 13-3/8" 68 Ib/ft, L -8.0 Welded / Driven Surface CSq 9-5/8" 40 Ibs/ft L-80, BTC-M In1. Yield 5750 psi Collaspse 3090 psi Inter. Casin¡:¡ 7 inch 26 Ibs/ft L-80, BTC-M In!. Yield 7240 psi Collaspse 5410 psi Slotted Liner 3-1/2 inch 9.2 Ibs/ft L-80, IBTC S. Coyner Down Open Hole Cement Slurry Premium Cement 60 bbls, 2938)( 15.8#, 1 % BWOC CaCI2 Cement Squeeze Premium Cement 22 bbl8, 107 sx 15.8#, 1.15 cf/sx 1 % BWOC CaCI2 uq Pilot Hole, Core, Plug Back s. Coyner 12/20/2004 DlR I LWD ~H/O~ FORM DEPTH HOLE CASING MUO INFO MWO lOGS MO TVO Freeze Protect w/ FIO Tool SIZE SPECS CEMENT INFO INFO 13-3/8" Wellhead NONE NONE 9-5113" F10 Tool 85' 68 Iblft, L-80 11" x 13-5/8" 5M 115' N/A Welded I Driven N/A 13-5/8" 5M MWD/GRlRES NONE Surface CSq !-ead Cement Test Csg to 9-5/8" 223 Bbls, 302 sx 2000 psi Top of Permafrost 400' 40 Ibs/ft 10.7 ppg IIFR/Cas L-80, BTC-M 4.15 ft3/sx In!. Yield 5750 psi 100% Excess Collaspse 3090 psi In Permafrost Mud Logging Float Equipment: 1 ea Float Shoe Base Permafrost 1 ea Float Collar Top of Tail Cement 1 ea F/O Cementer Premium Cement 25% Excess Centralizers: 38 bbls, 186 sx 5 Straight Blade 15.8#,1.15 cf/sx CBl 5 Bow Spring 2% 8WOC CaCI2 9-5/S" Casing Point 2,450' 12.25" 50° F KCUPOl YMER 9.3# - 9.6# Triple-Combo IIFR/Cas i u.. (J '2 W (þ o is. Õ 0° Mud Logging ::::I (þ z ::: (! C Top of Cement Plug 3,000' 3,000' Proposed TO 4,300' 4,300' 9.3# . 9.8# 8.5" 10S" F Plug Sack Cement Slurrv Premium Cement 114 bbls, 557 sx 15.8#, 1.15 cf/sx 2% BWOC CaCI2 KCUPOL YMER 25% Excess :3 0:: Possible MRIL :x: Across S.B. Core:SchraderBluff 4,135' 4,135' 4,195' 4,195' 4000 ø ::::s L. I- 5000 6000 7000 8000 10 set el (Frac Gradient) EMW (ppg) o 1000 2000 3000 11 12 13 14 15 16 17 18 10000 40 ffset el (Temperature Gradient) o 1000 2000 3000 4000 5000 6000 7000 8000 9000 60 80 100 120 140 160 180 200 220 240 - Surf - 500' - 2000' - 2500' - 3000' - 3500' I Rig RKB::; 35 ft Nikaitchuq #4 Bluff Horizontal} 12-1/4" · · · Anrmlar Disposal · x OBM and test AOGCC rate ........... ....- .....-.-..... ........IIIiIIr¡If.....¥iMIIiI', - Surf - 500' - 1000' - 1500' - 2000' - 2500' - 3000' - 3500' '" 3130' BUR:5. 6°/100' Pad Elev = 3 ft GLto RKB = 32 ft Rig RKB = 35 ft Nikaitchuq #4 (Schrader Bluff Horizontal) 2-7/8"" WellStar TRSSV at::t 500' 12-1/4" 2-7/8". 6.5#, l-80, EUE-M - down}: MD Annular Disposal MD JiIIisI¡.._ ... -......---....--.-....- , 5000# Gate Valve Annular Injection Valve Wing & Check Valves .......... 13-3/8" Drive Pipe it 9-5/8" BTC Casing iI!I 7" Casing r 2-7/8" EVE Tubing - Surf - 500' I Rig RKB == 35 ft I - 1000' Hole .... - 1500' - 2000' 00 - 2500' Nlkaitchuq #4 (Schrader . l'Q'i'( .,,~ NikaitchuQ #4 TUBING SIZE 2-7/8- EUE-M WEIGHT 6.5 ppf, L-80 ----- C4BLE CLAMPS 2-7/8-, #1 Lead Flat CENTRILlFT PART # 2875-A-82 QUANTITY 100 LENGTH (FT) 2.1 DIAMETER 4.45- WEIGHT (LB) 6.05 OWNERSHIP Centrilift IT g/~ DISCHARGE HEAD 38383 lENGTH (FT) 0.50 THREAD 2-7/8- 8 RND DIAMETER 5.13- =:J WEIGHT (LB) 12 OWNERSHIP Centrilift ------ PUMP .-- SERIAL # O1G85464 TYPE GC2900 STAGE 74 MODEL GPMT AR 1:1 LENGTH (FT) 16.00 DIAMETER 5.13- WEIGHT (LB) 705 OWNERSHIP Centrilift 11 ~ O-RINGS ~~ COUPLING o ~ GASSEPARATOR 6/ O -- O-RINGS 43245 +----- COUPLING 41433 a ~ SE4L SE25317SA ~ SERIAL # 31G92772 ~ MODEL GSB3DB UT IL PFS He LENGTH (FT) 6.90 DIAMETER 5.13- WEIGHT (LB) 267 OWNERSHIP CENTRlUFT 43245 41440 SERIAL # 42GOO16415 MODEL GRSTX FER N H6 AR CENTRILlFT PART # 424001378 LENGTH (FT) 6.20 DIAMETER 5.13- WEIGHT (LB) 260 OWNERSHIP Centrilift O-RINGS COUPLING 43245 41583 ~~ 0.... I I I I I I t____________________________________1 CABLE TYPE #1 AWG CELF LENGTH 5300' REEL NUMBER 85-_ CABLE OWNERSHIP Centrilift MOTOR LEAD EXTENSION PIN 54766, 61K-28377, 55',2 PC LEAD, 4KV, MONEL COMMENTS Nikaitchuq #4 Centrilfft Equipment Drawing . If&íitl BAKER HUGHES ,-------, I I I t i a~---- C.entrilift SEAL SERIAL # MODEL lENGTH (FT) DIAMETER WEIGHT (LB) OWNERSHIP Il O-RINGS ~ :========- COUPLING § /// / MOTOR SERIAL # HORSEPOWER VOLTAGE AMPERAGE MODEL LENGTH (FT) DIAMETER WEIGHT(LB) OWNERSHIP = / SENSOR TYPE SERIAL NUMBER LENGTH (FT) DIAMETER WEIGHT(LB} 55 TUBING OWNERSHIP SE25317SB 31G92771 GSB3DB LT H6 6.90 5.13- 267 CENTRIUFT 43245 41583 215033523 21K68902 133 2205 37 KMH 12.50 5.62- 899 Centrilift PumpMate PCT 7279 2.88 3.375- Body, 4.0- Flange 67.5 NlA Centrilift = / ç{ B CENTRAl.1ZER 63569-SPECIAL LENGTH (FT) 2.10 CONNECTION 2-318· 8 Rd Pin X 3-112· IF Pin DIAMETER 5.85" WEIGHT(LB) 25 OWNERSHIP Centrilift GAUGE C4RRlER / CONNECTION 3-1n"/F Box X 3-112· IF Pin TYPE HalliburlDn Model LENGTH (FT) DIAMETER WEIGHT(LB) OWNERSHIP SparteJr 3.42 4.75- 200 Halliburton iil CENTRALIZER 63569-SPECIAL 0/ LENGTH (FT) 2.10 CONNECTION 3-112- IF Box DIAMETER 5.85- CD WEIGHT(LB) 25 OWNERSHIP Centrilift BOTTOM OF EQUIPMENT 4880' +1- Feet (MD) Total Length #VALUEI Feet Max Diameter 5.85 Inches Total Weight #VALUEI Pounds 12/21/2004 Directional Drilling Plan a; Kerr-McGee Corporation Western North Slope, Alaska Spy Island Nikaitchuq #4 (wp03) Revised: 30 December, 2004 Sperry-Sun Proposal Report 30 December, 2004 Your Ref: 3000' Lateral Surface Coordinates: 6054828.00 N, 519643.00 E (70· 33' 39.4601" N, 149· 50' 19.9106" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Global Coordinates: 969.49 S, 26.03 W (Grid) Surface Coordinates relative to SHL of Nikaitchuq #1: 969.42 S, 28.60 W (True) Kelly Bushing Elevation: 35.00ft above Mean Sea Level Proposal Ref: pr0971 HALLIBURTDN . . :5 Co Q) CI ro 3250 - u 3300,00 t ~ Scale: 1 Inch = 700ft -2800 I Eastings -1400 I -2100 I -700 I - 3500 3500 - 1400 - - 1400 8 "- " 7" Csg Point ... i) 48/!!!.OOft ;§ (4105' FIIIL & 4618' ;; "8 <I> 700 - - 700 Current Well Properties Nìka¡tchuq#4 2800 - Horizontal CQordinates: Ref- Global Coordinates: Ref. Geographical Coordinates: 605482!tOQ N, 51$643.00 E 70' 33' 39.4601" N. 14$' 50' 19,$106" W 350' FSL & 1460' FWl, Sab. 16 - T14N - R9E 3S,OOftabove Mean Sea Leve! True North Feet (US Survey) RKS Elevation: North Refarence : Units: 2100 - 2250 - 9-518" Csg Point @ 2450.o0ft MD, 2450.ooft TVD ... Begin 8·112" Hole - Pilot Hole 2700,00 " 2750 - 3000,00 " A Halliburton Company 3750 - I -1400 3900.00 4200,00" 4250 - 1" I 500 I 2000 I 2500 I 3000 1 inch = 500ft - 2800 II) OJ c: :E 1::: C Z - 2100 o I -700 I 4000 Kerr McGee Corp. MD line I Azim. I SSTVD I TVD (ft) (Deg) (Deg) (ft) (ft) 3130.00 0.00 0.00 3095.00 3130.00 3388.13 15.49 311.36 3350.00 3385.00 4189.23 63.55 311.36 3950.00 3985.00 4329.94 72.00 311.36 4003.17 4038.17 4529.85 72.00 311.36 4064.96 4099.96 4817.64 90.00 324.50 4110.00 4145.00 4878.09 90.00 329.16 4110.00 4145.00 4880.00 90.00 329.16 4110.00 4145.00 7299.84 90.00 329.16 4110.00 4145.00 ,/ 7880.00 90.00 329.16 4110.00 4145.00 N/S (ft) 0.00 N 22.91 N 349.98 N 435.97 N 561.59 N 771.80 N 822.38 N 824.02 N 2901.58 N 3399.68 N EIW (ft) 0.00 E 26.03 W 397.54 W 495.22 W 637.92 W 826.56 W 859.63 W 860.61 W 2101.31 W 2398.77 W y (ft) 6054828.00 N 6054850.84 N 6055176.92 N 6055262.65 N 6055387.90 N 6055597.61 N 6055648.10 N 6055649.74 N 6057724.00 N 6058221.31 N I DLS I (ft) (°/1 OOft) 519643.00 E 0.00 519616.91 E 6.00 519244.53 E 6.00 519146.63 E 6.00 519003.59 E 0.00 518814.40 E 7.70 518781.20 E 7.70 518780.21 E 0.00 517534.00 E 0.00 517235.22 E 0.00 x V.S. (ft) 0.00 33.82 516.50 643.40 828.80 1109.67 1170.03 1171.93 3582.55 4160.50 Nikaitchuq #4 (wp03) . Comment ST off Cmt Plug in 8-1/2" Hole Top Ugnu Top Schrader Bluff Begin Pump Tangent Resume Dir @ 7.7001100ft Top OA Target (Heel) ; Hold 90.0° inc & 329.16° Az 7" Csg Point... Begin 6-1/8" Hole Target - Nikaitchuq #4 (Toe) PBHL . Kerr-McGee Corporation HALLIBURTON Western North Slope, Kerr McGee Proposal Report for Spy Island - Nikaitchuq #4 - Nik #4 (wp03) Your Ref: 3000' Lateral Revised: 30 December, 2004 Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment . (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) v 3130.00 0.000 0.000 3095.00 3130.00 0.00 N 0.00 E 6054828.00 N 519643.00 E 0.00 ST off Cmt Plug in 8-1/2" Hole I 6.00/100ft: 3130.00ft MD, 3130.00ft TVD 8 1/2in Open Hole 3200.00 4.200 311.359 3164.94 3199.94 1.69 N 1.92W 6054829.69 N 519641.07 E 6.000 2.50 3300.00 10.200 311.359 3264.10 3299.10 9.97 N 11.33 W 6054837.94 N 519631.65 E 6.000 14.72 3388.13 15.488 311.359 3350.00 3385.00 22.91 N 26.03 W 6054850.84 N 519616.91 E 6.000 33.82 Top Ugnu 3400.00 16.200 311.359 3361.42 3396.42 25.05 N 28.46 W 6054852.98 N 519614.47 E 6.000 36.98 3500.00 22.200 311.359 3455.81 3490.81 46.78 N 53.13 W 6054874.63 N 519589.74 E 6.000 69.03 3600.00 28.200 311.359 3546.25 3581.25 74.90 N 85.08 W 6054902.67 N 519557.73 E 6.000 110.53 3700.00 34.200 311.359 3631.75 3666.75 109.11 N 123.94 W 6054936.78 N 519518.77 E 6.000 161.03 3800.00 40.200 311.359 3711.37 3746.37 149.04 N 169.30W 6054976.59 N 519473.31 E 6.000 219.96 3900.00 46.200 311.359 3784.23 3819.23 194.26 N 220.66 W 6055021.67 N 519421.83 E 6.000 286.68 4000.00 52.200 311.359 3849.54 3884.54 244.25 N 277.45 W 6055071.52 N 519364.90 E 6.000 360.47 4100.00 58.200 311.359 3906.59 3941.59 298.49 N 339.06 W 6055125.59 N 519303.15 E 6.000 440.51 4189.23 63.554 311.359 3950.00 3985.00 349.98 N 397.54 W 6055176.92 N 519244.53 E 6.000 516.50 Top Schrader Sluff 4200.00 64.200 311.359 3954.74 3989.74 356.37 N 404.80 W 6055183.29 N 519237.26 E 6.000 525.93 . 4300.00 70.200 311.359 3993.47 4028.47 417.25 N 473.96 W 6055243.99 N 519167.93 E 6.000 615.78 4329.93 71.996 311.359 4003.17 4038.17 435.97 N 495.22 W 6055262.65 N 519146.63 E 6.000 643.40 End Dir, Start Sail @ 72.0· : 4329.93ft MD, 4038.17ft TVD 4400.00 71.996 311.359 4024.83 4059.83 480.00 N 545.23 W 6055306.55 N 519096.50 E 0.000 708.38 4500.00 71.996 311.359 4055.74 4090.74 542.84 N 616.62 W 6055369.20 N 519024.95 E 0.000 801.12 4529.85 71.996 311.359 4064.96 4099.96 561.59 N 637.92 W 6055387.90 N 519003.59 E 0.000 828.80 Resume Dir @ 7.70"/100ft: 4529.85ft MD, 4099.96ft TVD 4600.00 76.334 314.707 4084.10 4119.10 607.65 N 687.22 W 6055433.82 N 518954.17 E 7.700 895.01 4700.00 82.588 319.278 4102.40 4137.40 679.51 N 754.20 W 6055505.51 N 518887.00 E 7.700 992.48 4800.00 88.887 323.721 4109.83 4144.83 757.51 N 816.22 W 6055583.34 N 518824.78 E 7.700 1092.02 4817.64 90.000 324.500 4110.00 4145.00 771.80 N 826.56 W 6055597.61 N 518814.40 E 7.700 1109.66 Top OA 4878.09 90.000 329.155 4110.00 4145.00 822.38 N 859.63 W 6055648.10 N 518781.20 E 7.700 1170.03 Target (Heel) ; Start Sail @ 90.1 inc & 329.16" Az : 4878.09ft MD 4145.00ft TVD 30 December, 2004 - 11 :50 Page 2 of 7 DrillQuest 3.03.06.008 Kerr-McGee Corporation HALLIBURTON Western North Slope, Kerr McGee Proposal Report for Spy Island - Nikaitchuq #4 - Nik #4 (wp03) Your Ref: 3000' Lateral Revised: 30 December, 2004 Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9S Rate Section Comment . (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0'100ft) 4880.00 90.000 329.155 4110.00 4145.00 824.02 N 860.60 W 6055649.74 N 518780.21 E 0.000 1171.93 7" Csg Point... Begin 6-1/8" Hol : 4880.00ft MD, 4145.00ft TVD 7" Casing 4900.00 90.000 329.155 4110.00 4145.00 841.19 N 870.86 W 6055666.88 N 518769.91 E 0.000 1191.86 5000.00 90.000 329.155 4110.00 4145.00 927.05 N 922.13 W 6055752.60 N 518718.41 E 0.000 1291.47 5100.00 90.000 329.155 4110.00 4145.00 1012.90 N 973.40 W 6055838.32 N 518666.91 E 0.000 1391.09 5200.00 90.000 329.155 4110.00 4145.00 1098.76 N 1024.68 W 6055924.04 N 518615.41 E 0.000 1490.71 5300.00 90.000 329.155 4110.00 4145.00 1184.61 N 1075.95 W 6056009.76 N 518563.91 E 0.000 1590.33 5400.00 90.000 329.155 4110.00 4145.00 1270.47 N 1127.22 W 6056095.48 N 518512.41 E 0.000 1689.95 5500.00 90.000 329.155 4110.00 4145.00 1356.33 N 1178.49 W 6056181.19 N 518460.91 E 0.000 1789.57 5600.00 90.000 329.155 4110.00 4145.00 1442.18N 1229.77 W 6056266.91 N 518409.41 E 0.000 1889.19 5700.00 90.000 329.155 4110.00 4145.00 1528.04 N 1281.04 W 6056352.63 N 518357.91 E 0.000 1988.81 5800.00 90.000 329.155 4110.00 4145.00 1613.89 N 1332.31 W 6056438.35 N 518306.41 E 0.000 2088.43 5900.00 90.000 329.155 4110.00 4145.00 1699.75 N 1383.58 W 6056524.07 N 518254.91 E 0.000 2188.05 6000.00 90.000 329.155 4110.00 4145.00 1785.60 N 1434.85 W 6056609.79 N 518203.41 E 0.000 2287.67 6100.00 90.000 329.155 4110.00 4145.00 1871.46 N 1486.13 W 6056695.51 N 518151.91 E 0.000 2387.28 . 6200.00 90.000 329.155 4110.00 4145.00 1957.31 N 1537.40 W 6056781.23 N 518100.41 E 0.000 2486.90 6300.00 90.000 329.155 4110.00 4145.00 2043.17 N 1588.67 W 6056866.95 N 518048.92 E 0.000 2586.52 6400.00 90.000 329.155 4110.00 4145.00 2129.02 N 1639.94 W 6056952.67 N 517997.42 E 0.000 2686.14 6500.00 90.000 329.155 4110.00 4145.00 2214.88 N 1691.22 W 6057038.39 N 517945.92 E 0.000 2785.76 6600.00 90.000 329.155 4110.00 4145.00 2300.73 N 1742.49 W 6057124.11 N 517894.42 E 0.000 2885.38 6700.00 90.000 329.155 4110.00 4145.00 2386.59 N 1793.76 W 6057209.82 N 517842.92 E 0.000 2985.00 6800.00 90.000 329.155 4110.00 4145.00 2472.45 N 1845.03 W 6057295.54 N 517791.42 E 0.000 3084.62 6900.00 90.000 329.155 4110.00 4145.00 2558.30 N 1896.31 W 6057381.26 N 517739.92 E 0.000 3184.24 7000.00 90.000 329.155 4110.00 4145.00 2644.16 N 1947.58 W 6057466.98 N 517688.42 E 0.000 3283.86 7100.00 90.000 329.155 4110.00 4145.00 2730.01 N 1998.85 W 6057552.70 N 517636.92 E 0.000 3383.48 7200.00 90.000 329.155 4110.00 4145.00 2815.87 N 2050.12 W 6057638.42 N 517585.42 E 0.000 3483.09 7299.84 90.000 329.155 4110.00 4145.00 2901.58 N 2101.31 W 6057724.00 N 517534.00 E 0.000 3582.55 Target - Nikaitchuq #4 (Toe), 250.00 Radius., Current Target 30 December, 2004 - 11:50 Page 3 of7 DrillQuest 3.03.06.008 HALLIBURTON Kerr-McGee Corporation Western North Slope, Kerr McGee Proposal Report for Spy Island - Nikaitchuq #4 - Nik #4 (wp03) Your Ref: 3000" Lateral Revised: 30 December, 2004 Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastlngs Rate Section Comment . (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7300.00 90.000 329.155 4110.00 4145.00 2901.72 N 2101.40W 6057724.14 N 517533.92 E 0.000 3582.71 7400.00 90.000 329.155 4110.00 4145.00 2987.58 N 2152.67 W 6057809.86 N 517482.42 E 0.000 3682.33 7500.00 90.000 329.155 4110.00 4145.00 3073.43 N 2203.94 W 6057895.58 N 517430.92 E 0.000 3781.95 7600.00 90.000 329.155 4110.00 4145.00 3159.29 N 2255.21 W 6057981.30 N 517379.42 E 0.000 3881.57 7700.00 90.000 329.155 4110.00 4145.00 3245.14 N 2306.48 W 6058067.02 N 517327.92 E 0.000 3981.19 7800.00 90.000 329.155 4110.00 4145.00 3331.00 N 2357.76 W 6058152.73 N 517276.42 E 0.000 4080.81 7880.00 90.000 329.155 4110.00 4145.00 3399.68 N 2398.77 W 6058221.31 N 517235.22 E 0.000 4160.50 PBHL (Toe) : 7880.00ft MD, 4145.00ft TVD (Sec. 17 - T14N R9E, 1530' FNL & 930' FEL) 6-1/8" Open Hole All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. ~ Vertical depths are relative to RKB = 35' MSL. Northings and Eastings are relative to 350' FSL & 1460' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ./ The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 350' FSL & 1460' FWL and calculated along an Azimuth of 324.152° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7880.00ft., The Bottom Hole Displacement is 4160.77ft., in the Direction of 324.794° (True). . 30 December, 2004·11:50 Page 4 of7 DrillQuest 3.03.06.008 HALLIBURTON Kerr-McGee Corporation Western North Slope, Kerr McGee Proposal Report for Spy Island - Nikaitchuq #4 - Nik #4 (wp03) Your Ref: 3000' Lateral Revised: 30 December, 2004 Comments Measured Depth (ft) 3130.00 4329.93 4529.85 4878.09 4880.00 7880.00 Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) 3130.00 0.00 N 0.00 E 4038.17 435.96 N 495.21 W 4099.96 561.60 N 637.92 W 4145.00 822.38 N 859.63 W 4145.00 824.02 N 860.60 W 4145.00 3399.68 N 2398.77 W . Comment ST off Cmt Plug in 8-1/2" Hole @ 6.00/100ft : 3130.00ft MD, 3130.00ft TVD End Dir, Start Sail @ 72.0° : 4329.93ft MD, 4038.17ft TVD Resume Dir @ 7.70·/100ft: 4529.85ft MD, 4099.96ft TVD Target (Heel) ; Start Sail @ 90.0° inc & 329.16° Az : 4878.09ft MD, 4145.00ft TVD 7" Csg Point... Begin 6-1/8" Hole: 4880.00ft MD, 4145.00ft TVD PBHL (Toe) : 7880.0Oft MD, 4145.00ft TVD (Sec. 17 - T14N - R9E, 1530' FNL & 930' FEL) Formation TOlJs Formation Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Up-Dip Depth Depth Depth Northings Eastings Formation Name . (ft) Angle Dirn. (ft) (ft) (ft) (ft) (ft) 1350.00 0.000 0.152 1385.00 1385.00 1350.00 0.00 N 0.00 E Eocene Unconformity 1685.00 0.000 0.152 1720.00 1720.00 1685.00 0.00 N 0.00 E Base Permafrost 2055.00 0.000 0.152 2090.00 2090.00 2055.00 0.00 N 0.00 E Base Prince Creek 3350.00 0.000 0.152 3388.13 3385.00 3350.00 22.91 N 26.03 W Top Ugnu 3950.00 0.000 0.152 4189.23 3985.00 3950.00 349.98 N 397.54 W Top Schrader Bluff 4110.00 0.000 0.152 4817.64 4145.00 4110.00 771.80 N 826.56 W Top OA 30 December, 2004 - 11:50 Page 5 of7 DrillQuest 3.03.06.008 HALLIBURTON Kerr-McGee Corporation Western North Slope, Kerr McGee Proposal Report for Spy Island - Nikaitchuq #4 - Nik #4 (wp03) Your Ref: 3000' Lateral Revised: 30 December, 2004 Casina details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) 3130.00 2450.00 4880.00 <Run- TD> 3130.00 2450.00 4145.00 <Run-TD> Taraets associated with this welløath Target Name Nikaitchuq #4 (Heel) Nikaitchuq #4 (Toe) 30 December, 2004·11:50 . Casing Detail 8 1/2in Open Hole 9-5/8" Casing 7" Casing 6-1/8" Open Hole Target Entry Coordinates TVD Northings Eastings Target Target (ft) (ft) (ft) Shape Type 4145.00 360.09 N 409.05 W Circle Current Target . Mean Sea Level/Global Coordinates: 4110.00 6055187.00 N 519233.00 E Geographical Coordinates: 70· 33' 43.0017" N 149· 50' 31.9909" W Target Radius: 250.000 4145.00 2901.58 N 2101.31 W Circle Current Target Mean Sea Level/Global Coordinates: 4110.00 6057724.00 N 517534.00 E Geographical Coordinates: 70· 34' 07.9961" N 149· 51' 21.9899" W Target Radius: 250.00ft Page 60f7 DrillQuest 3.03.06.008 Kerr-McGee Corporation Western North Slope, Kerr McGee North Reference Sheet for Spy Island ~ Nikaitchuq #4 Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Source: Snyder, J.P., 1987, Map Projections Working Manual is North American Datum of 1927 (US48, AK, HI, and Canada) 294.978698213901 Mercator or Gauss Kruger Projection Scale N, 519643.00 E 33' 39.4601" N, 149" 50' 19.9106" W Drilling Fluids Program . Halliburton BAROID Program . Kerr McGee ~ KERJl.MCGEE CORPORATION Name (Printed) Originator Dave Soquet Reviewed by Dave Higbie Customer Approval Skip Coyner Version No: 2.0 Nikaítchuq #4 v2.0 12/21/04 I BA~OID Kerr McGee Nikaitchuq #4 Spy Island, Alaska Baroid Mud Program Halliburton Baroid Signature Date: December 21, 2004 Mud Date . Halliburton BAROID Program . Kerr McGee Mud Nikaitchuq #4 Mud Program General Discussion This well will be drilled from an off-shore ice pad near the Spy Island, basically due north of Oliktok Point on the North Slope of Alaska. A 12 %" suñace hole will be drilled vertically to a TO of z2,450 MO. A string of 9 5/8" casing will be run and cemented at this depth. An 8 W' pilot hole will then be drilled to 4135', where a 60' core will be cut through the Schrader Bluff. After coring, the pilot hole will be drilled to a final depth of 4300' MO. Then, the pilot hole will be logged with E-line and then plugged back to 3000' with cement. The 8 %" pilot hole will then be sidetracked building angle to 89° by 4,880' (4,145 TVO). A string of 7" casing will be run and cemented at this depth. Next, a 6 1/8" lateral will be drilled to TO at Z 7,880 MO (4,145 TVO). A 3 %" slotted liner will be run and set in the lateral. v An inhibited KCIIPolymer mud will be used to drill suñace and the 8 %" sidetrack interval. Mineral Oil Base Mud (MOBM) will be used to drill the horizontal interval. ./ As a general drilling fluids plan, spud the well with inhibited 9.0 ppg 12% KCIIPolymer mud. The mud weight will then be held between 9.0-10.0 ppg mud weight to the suñace hole TO / unless hole conditions dictate otherwise. Our primary focus for suñace hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with mechanisms to provide effective wellbore stabilization and to reduce drilling waste, i.e., ionic inhibition (KCI) and polymer encapsulation (PHPA). From the suñace shoe, the continued use of the inhibitive, KCIIPolymer mud is suggested. When drilling this interval of the well a certain amount of new mud will be required coming out of the suñace casing to re-adjust the low gravity solids content to within acceptable limits for continued drilling operations. For the most part, the mud density requirements will be met with additions of soluble salts (KCI) to allow maximum application of mechanical solids control support. This being the case, the mud filtrate salinity may range in the 80K-100K ppm range if additional mud weight is required. The KCI concentration is dependent upon MWO and 10QQinQ restrictions and could vary from this recommendation. After running and cementing the 7" casing string, the cementers will bump the plug with MOBM. Special Considerations 1. Waste minimization is critical to the success of this well. 2. Maintain a sufficient quantity of Oriltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. '" '" 3. Lime and zinc carbonate should be on location for an H2S contingency. 4. Maintain an adequate barite supply on location: enough to increase the mud weight of the active system by 1.5 ppg at any time (@2000 sxs barite on location at all times). 5. Oue 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. Well Specifics: Casing Program 12 %" hole (9 5/8" casing) 8 %" pilot hole 8 %" hole (7" casing) 6 1/8" Hole (3 %" liner) Nikaitchuq #4 v2.0 12/21/04 MD TVD Footage 2450 2450 2450 4300 4300 1850 4880 4145 2430 7880 4145 3000 2 . Halliburton BAROID Program . Kerr McGee Mud Formation Tops/Casina Proaram TMD TVD Comments Mud Wt Spud 0' 0' 9.0 ppg density 9.0 Base Permafrost 2000 2000 9.0-10.0 9 5/8" casing point 2450' 2450' Condition for casing 9.0-10.0 Top Schrader Bluff 4145' 4145 Coring point 9.2-9.6 Pilot Hole TD 4300' 4300' 9.2-9.6 PBTD I KOP 3130' 3130' Treat for cmt contamination 9.2-9.6 7" casing point 4880' 4145' Condition for casing 9.2-9.6 TD 7880' 4145' Oil Based Mud L VT -200 8.5-9.0 Surface Hole Mud Properties (12 Y4" Hole, 9 5/8" Casing at 2,450' MD) Mud Properties Initi,al Final Density 9.0 9.0-10.0 YP 35-45 15 - 30 Viscosity 80 - 120 50-80 PV 13 - 21 15 - 23 10 S. Gel 10 -15 10 -15 API FL <15 6-8 Surface Interval The surface interval will be drilled with 10-12% KCIIPolymer mud as formulated below: 9.0 PPQ Formulation Fresh Water KCI EZ Mud DP PAC-UR Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav D .95 bbl 37 ppb .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb o 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) Spud the well with maximum flow rates (600-1000 gpm assuming 12 %" hole w/4" drill pipe) to ensure good cuttings transport. Target an initial YP in the 35 range then adjust as dictated by the actual hole cleaning requirements of the well (minimum gravel is anticipated - mostly clays and sand). Reduce viscosity as allowed (previous wells in the area have TD'd the surface with a -20-25 YP). However, if hole cleaning appears to be inadequate, do not hesitate to quickly raise the viscosity as required. Polymer viscosity in the form of Barazan-D additions should be utilized to provide rheological support as needed. Utilize high viscosity sweeps to supplement the hole cleaning capabilities of the system. Barolift sweeps (.25 ppb Barolift in base mud) can also be utilized to minimize viscosity build up. With an initial mud density of 9.0 ppg, please note the other issues of concern as listed below: Nikaitchuq #4 v2.0 12/21/04 3 . Halliburton BAROID Program . Kerr McGee Mud 1. Make sure the drilling team is aware of the potential of encountering gas hydrates. 2. A mud weight increase is not currently programmed for drilling the gas hydrate interval of the well, if encountered. Nikaitchuq #1 was drilled to this depth with 9.6 ppg mud. 3. If gas hydrates are noted, treat the system with 2.0 ppb of Driltreat (Lecithin) and ~% by volume Dril-N-Slide. De-foamer additions may also be needed to help the gas break out. 4. Maintain the mud as cool as possible (under 60°F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of fluid for the spud. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment application. Mud maintenance issues for this interval of the well are as follows: 1. If possible, use pre-mixed KCI water to maintain volume while drilling ahead. The density of the KCI solution should be based upon mud weight requirements at any given point of the well. 2. Use PAC's/Dextrid for API filtration control. Target 6-12 ee's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. 3. Hold the pH in the 8.5-9.5 range with KOH. 4. By material balance, maintain the EZ Mud DP in the .75-1.0 ppb range. 5. Control drill based upon the ability of the surface system to process the drilling mud. 6. Daily additions of Aldacide G or X-Cide 207 are needed to control bacterial action. 7. Corrosion inhibitors should be run with this mud system. 8. Keep MBT as low as possible (generally <11 ppb). Heavy amounts of clay may be present below the permafrost that could require additions of ConDet and/or Dril-N-Slide to reduce BHA balling and screen blinding. Sweeping the hole prior to the short trip at TD and again prior to coming out of the hole to run the surface casing is recommended. If possible (keeping waste minimization in mind), reduce the fluid's rheology to <20 YP after the casing is on bottom prior to starting the cement job. 12 .25" Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 80 rpm 100 rpm 600 164 164 800 248 248 1000 309 309 Baroid's recommended flowrate for this interval is 800 gpm to maximize hole cleaning at these penetration rates. RPM's have a no effect on hole cleaning in this vertical section. Pilot Hole Mud Properties (8 %" Hole to 4300', Plugback to 3,000') Mud Properties Initial Final Density 9.0-9.6 9.0-9.6 Viscosity 40-60 40-60 YP 15 - 25 15 - 25 PV 9-18 9-18 pH 8.5-9.5 8.5-9.5 API FL <6 <6 CI 50-90K 50-90K Nikaitchuq #4 v2.0 12/21/04 4 · Halliburton BAROID Program e Kerr McGee Mud Pilot Hole Interval The pilot hole will be drilled and cored with the same KCIIPolymer mud as the surface hole: 9.0 ppg Formulation Fresh Water KCI EZ Mud DP PAC-UR Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav 0 .95 bbl 37 ppb .75 ppb .5 ppb 1 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 15 YP) (pH = 8.5-9.5) (X-Cide 207 for rig maintenance) (as needed) (corrosion inhibitor) (to be added at rig) Prior to drilling out the surface casing, condition the mud to a 9.2 ppg density with <4% LGS and an MBT of <6 ppb (a certain amount of new mud will be required for re-adjusting the properties of the mud to insure a quality fluid for the initial drilling operations of the 8 %" hole). As in the surface hole, KCI will be used for ionic inhibition and for the basic density requirements of the system. If additional mud weight as needed, increase it with KCI to the 65,000-90,000 ppm range so as to allow maximum application of centrifuge support to optimize solids control efforts. A minimum of 50,000 ppm CI- should be used. Work with the MWD ,. personnel on site to run the highest possible chloride concentration which will still allow their tools to read properly. Should the brine phase density be limited for the MWD, achieve the remaining density requirement with barite. Initially, target a mud density of 9.0-9.6 ppg with a YP in the 15 to 25 range. Adjust the YP as required with Barazan-D polymer for efficient hole cleaning. Pre-treat for screen blinding from heavy clays with Dril-N-Slide and/or ConDet treatments. Regular sweeping of the hole with high viscosity or Barolift sweeps is recommended every 4-6 hours while drilling to supplement the hole cleaning ability of the fluid. Flow rates in the 450 to 550 GPM range will provide ample flow to clean the hole. The 9.0-9.6 ppg density will be maintained down to the coring point at 4135'. The API filtrate should be dropped to <5 ccl30 min prior to coring. While coring, string in BARACARB 50 AT 5-10 sxlhr for bridging purposes. Maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 initially with PAC's and Dextrid. Reduce API filtrate to <5 prior to coring. Daily additions of X-Cide 207 should be made to control bacterial action. KOH should be used for pH control. Keep the MBT as low as possible «11 ppb). Maintain Barascav 0 and Baracor 700 specs to aggressively treat for corrosion. Heavy amounts of clay will be present which require additions of ConDet and/or Dril-N-Slide to reduce BHA balling and screen blinding. Sweeping the hole prior to the short trip at TO and again prior to coming out of the hole to log is recommended. If possible, reduce the fluid's rheology to <20 YP after the casing is on bottom prior to starting the cement job. Nikaitchuq #4 v2.0 12/21/04 5 . Halliburton BAROID Program . Kerr McGee Mud Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 80 rpm 100 rpm 400 212 212 450 251 251 500 302 302 Baroid's recommended flowrate for this interval is 450 gpm to maximize hole cleaning at these penetration rates. RPM have a no effect on hole cleaning in this vertical section. Intermediate Hole Mud Properties (8 Yz" Hole, 7" Casing at 4,880 MD) Mud Properties I I Density I Viscosity I yp I PV I pH I API FL I CI Build Sec 9-9.6 40 - 60 15 - 25 13- 23 8.5 - 9.5 <6 50-90K Intermediate Interval The build section will be drilled with the same KCI/Polymer mud as the pilot hole: 9.0 PPQ Formulation Fresh Water KCI EZ Mud DP PAC-UR Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav D .95bbl 37 ppb .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb 1.0 ppb .5ppb (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) As in the previous hole sections, KCI will be used for ionic inhibition and for the basic density requirements of the system. Increase the mud weight as needed with KCI to the 65,000-90,000 ppm range so as to allow maximum application of centrifuge support to optimize solids control efforts. A minimum of 50,000 ppm CI- should be used. Work with the MWD personnel on site to run the highest possible chloride concentration which will still allow their tools to read properly. Should the brine phase density be limited for the MWD, achieve the remaining density requirement with barite. Initially, maintain the mud density at 9-9.6 ppg with a YP in the 15 to 25 range. Adjust the YP as required with Barazan-D polymer for efficient hole cleaning. Pre-treat for screen blinding from clays with Dril-N-Slide and/or ConDet treatments. Regular sweeping of the hole with weighted high viscosity or Barolift sweeps is recommended every 4-6 hours while drilling to supplement the hole cleaning ability of the fluid. Flow rates in the 450 to 550 GPM range will provide ample flow to clean the hole. Nikaitchuq #4 v2.0 12/21/04 6 . Halliburton BAROID Program . Kerr McGee Mud Maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 with PAC's and Dextrid. Use KCI brine for daily volume additions (the brine density should be based on the mud weightlMWD objectives at the time). Daily additions of X-Cide 207 should be made to control bacterial action. KOH should be used for pH control. Keep the MBT as low as possible «11 ppb). Maintain Barascav D and Baracor 700 specs to aggressively treat for corrosion. Sweeping the hole prior to the short trip at TO and again prior to coming out of the hole to run the 7" is recommended. If possible (keeping waste minimization in mind), reduce the fluid's rheology to <20 YP after the casing is on bottom prior to starting the cement job. Maximum Acceptable ROP in fph at Specified GPM and RPM GPM 80 rpm 100 rpm 400 98 122 450 119 145 500 134 177 Baroid's recommended flowrate for this interval is 450 gpm to maximize hole cleaning at these penetration rates. A change in rotation from 80 to 100 has a significant effect on hole- cleaning capability. Production Hole (6 1/8" Hole, TD at 7,880' MD) Mud Type: Enviromul System Mud Properties ~ PV YP ES HTHP WPS OIW Lateral 8.5-9.0 10 - 20 18 - 25 800-1100 <6 250 to 300K 80/20 . Additional mud weight may be required for effective shale stabilization. System Formulation Product LVT-200 EZ MUL NT GEL TONE V Lime DURATONE Water CaCI2 Baracarb 5 Baracarb 25 Baracarb 50 Concentration 0.68 bbl 8 ppb 8-10 ppb 5 ppb 4 ppb 0.178 bbl 28.6 ppb 23 ppb 12 ppb 5 ppb Nikaitchuq #4 v2.0 12/21/04 7 . Halliburton BAROID Program . Kerr McGee Mud Concerns and ContinQencies 1. Mud weight: Maintain the density at 8.5 - 9.0 ppg. Increase density as required for hole stability. Maximize solids control usage. Maintain a YP between 18 and 25. Pump high viscosity or Barolift sweeps throughout the interval as needed, particularly prior to POH for casing. Optimized mud rheology and flow rate will be the primary mechanisms for achieving hole cleaning in this horizontal wellbore. Maximize pipe rotation (ideally ~ 100 RPM). 2. Rheology: 3. Other issues: The use of good drilling practices to minimize swab and surge pressures should be used to minimize losses and differential sticking. 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 fluid density by a minimum of 0.5 ppg may provide some relief. Corrosion Mitigation Barascav D and Baracor 700 will be run in the water base fluid system to mitigate corrosion. Daily sulfite and phosphonate checks will be run to monitor this program. Sulfite levels should be maintained at 200-300 ppm and phosphonate levels between 600-800 ppm. Lubrication: Due to the aggressive build in the intermediate interval, lubes probably will be required in the water based system. It is recommended to add 2% of the lube cocktail (0.5% BDF-263, 1 % EZ Glide or Torq Trim II, and .5% EP Mudlube) to provide adequate but minimal lubricant support. This concentration can be increased to 5% in 1 % increments if all other remedial actions have been taken (sweeps, etc.). Additions of Barofibre (2-3 ppb) while drilling can also reduce torque and drag. This method was used on the Witch Farm ERD wells. 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. Pipe should be kept moving at all times while circulating. HiQh speed pipe rotation is the most critical factor for hole cleaninQ. Rap rates above the recommended levels or with no (sliding) or low rpm will require an increased frequency of the following remedial hole cleaning practices: Nikaitchuq #4 v2.0 12/21/04 8 BAROID Surface - Modeled hole cleaning þperator. Kerr-McGee well: Nik~tclYJq #4 Cuttings T rampoo load. % r 2000 - I 5 10 15 20 25 0 50 1000 93 1B5 4 hi niT timp. Kerr McGee Hole Angle KCI/PHPA Flow Rate = 650 ROP ::: 100 It/hr MudWeÎght = 9,4 Cuttîng Dia. = .25 În Ib/jli1l R·1 s@1001t/hr·1OOrpm/HC·100rpm-5m/C=3m/ " 4 g 3.34 ~ 1591l0ftl i 4 K 2,256 K 660,0 Itl 12.25 În 18 K 2,8132 ~ 200,0 It I 2540,0 10.40 RPM's have no effect in this vertical wellbore. Maximize pump output at all times, Kerr McGee BAROID Pilot Hole - Modeled hole cleaning IOperator: Ker¡·McGee Contractor: Nord~ : Well: Nh~~ #4 R~ NOId~ 3 Cuttings T fi:1nq¡od Hole load, % AnØe KCIIPHPA Flow Rate:: 450 gal/m~ ECD MudWeìght:: 9.4lb/gal lb/gaI R·l S@1001l/hr·loo¡pml 4000 1000·, 2000, 3000- I ! 5 10 15 20 25 0 50 1000 207 413 30 60 90 9,40 9.90 4 hrn IT tim~ R935 in B.5În RPM's have no effect in this vertical well bore. Maximize pump output all times. ~/gal 4 K 3.34 K 3440.0111 4 K 2,256 K 660,0 Itl -\. 16,75 x 2,9132 x 2OŒOIII Kerr McGee BAROID Intermediate - Modeled hole cleaning IOpe¡ator: Kerr-McGee Contractor: Nordic : wcll: N~aitchuq #4 R~: Nord'¡c 3 CuUings T rilMpori Hole l~l% A~ KCIIPHPA ROP :: 100 Itthr [CD Cu~ting Dia.:: .15in Ib/gal R·1 $@100t~/hr·1oo¡prnIHC·Bßrpm·5m/C::3m/ , 'I 5 10 15 20 25 0 50 1000 207 413 30 60 909.40 9.90 qhrrJlT nmp. is recommended. flowrate gives good hole cleaning and a slight versus 400 or gpm. 100 gives a large advantage in both hole management versus 80 rpm. 1000- 2000 ~ 3000 - . A flowrate of 450 decrease in cleaning and 8.835 in 8.5În B.5În 8.5~ <1 4 x 134 x 4020.0 Itl 4 x 2.256 x 660.0 f! I 6.75 x 2.8132 x 200.0 It I -'r 5 10 15 20 25 0 50 1000 164 328 30 60 90 8.80 9.00 1 ~ nr n ITtimf! Good and hole cleaning with gpm hole cleaning deteriorates. A 300 gpm are used. however would then drive BAROID Production - Modeled hole cleaning þpe¡ator: Kerr·McGee Contractor: Nord~ : weir. Nikailchuq ~4 R~: Nord~ 3 Cuttings T ranspmt load. % Kerr McGee Envwomul Hole ÀrI9le ROP = 100 ft/hr fCD MudWeigh!=RSb/gal CuttingDia.=.125in IblgaI R·1 s@1001t/nr·OOrpm/HC·6Orpm·5m/C=3m/ 6.276 in 6.276 in i 4 x 3.34 x 702aOltl IbIga! 6.276 in ;t;_ ...:::. 14 x 2.256 x 660.0111 4.75 x 2.25 x 200.0 It I 80 However if only 60 rpm's are used would be needed to clean the hole if 60 rpm's to 10.9 ppg. . Halliburton BAROID Program . Kerr McGee Mud Fluid Volumes: Surface Interval: At spud approximately 550 barrels of new fluid will be delivered. Dilution rates for the 12 %" section are anticipated at .62 bbls/ft. Estimated Fluid Disposal Volumes: Initial build Dilution Reuse to next interval Total P10 500 1000 -500 1000 P50 550 1520 -500 1570 P90 650 2500 -500 2650 Estimated Drill Solids Disposal Volumes: Cuttings Volume Wetting Fluid Total P10 360 240 600 P50 440 440 880 P90 550 790 1340 Pilot Hole Interval: Dilution rates for the 8 %" pilot hole section are anticipated at .35 bbls/ft. Estimated Fluid Disposal Volumes: Initial build Dilution re-use Total P10 250 450 500 200 P50 400 650 400 650 P90 550 850 o 1400 Estimated Drill Solids Disposal Volumes: Cuttings Volume Wetting Fluid Total P10 130 80 210 P50 145 145 290 P90 170 220 390 Intermediate Interval: Dilution rates for the 8 %" intermediate section are anticipated at .4 bbls/ft. Estimated Fluid Disposal Volumes: Initial build Dilution Total P10 o 480 480 P50 200 750 950 P90 400 1260 1660 Nikaitchuq #4 v2.0 12/21/04 13 . Halliburton BAROID Program . Kerr McGee Mud Estimated Drill Solids Disposal Volumes: Cuttings Volume Wetting Fluid Total P10 130 80 210 P50 150 150 300 P90 165 335 500 Production Interval to TD: -700 barrels of MOBM will be initially be required for this interval. Dilution rates for this section are anticipated at 0.15 bbls/ft. Estimated Fluid Disposal Volumes: Initial Build Dilution Total re-use/buy back Net usage P10 650 300 950 800 150 P50 700 450 1150 800 350 P90 900 750 1650 600 1050 Estimated Drill Solids Disposal Volumes: Cuttings Volume Wetting Volume Total P10 110 50 165 P50 125 125 250 P90 155 300 455 Nikaitchuq #4 v2.0 12/21/04 14 Wellhead BOP, Diverter & Choke Manifold Diagram . ~ g 8: ~ -'- .I.- 6 ~ ~ ~ ? 5 ~ Þ 0) -1_1' 8 cr: I?~ g e § t ~ 3 Þ iii, i .cd! ct ~ cn [ ~ w ;> Q Q ..I u.J:i! ~.J:i! ~ 2 li-CI) \loCI) . ...... . ...... w !'j ia- z ;;j :;¡ "J¡~ <")::!i; :J I ;¡ , 1 · , 15 ~ ~ I · , · r- · -, · ~ ~ GI.L1! ~ I Iii I ~ ~Ii~i :t ::¡; e I,cn ;~ :I~ æ Q a:Bi ~tz :::111I z~ ~D. W ..Is §~ Q Operational Note: The landing ring and wellhead are installed on the 16" conductor, and this stack, with ram preventers disabled, and knife valve and diverter line in place, is nippled up on the wellhead and surface hole is drilled. After surface casing is set, a blind flange (Key #11 ) is installed. and the rams are, enabled. . Griffith MlJnuffJotuter ~ ManufaCfurer -'CIIII.D. Msnufsctursr TESCO I Hf-KAL MsrnJf8r;Wrør 3-~" ~UE Model 3-% IF IBðP Model 3·% IF Lo_r Kellv Model 3-% FH DUll Ball Modsl 5.000 DC! PIfJUUf8 Rating "900 DSI PrrJlSsure RElting 5,000 DIll P1f!J$$ure Rating 5.000 DIll Pressure Ratfng 5.000 øsi PresaUÆ Rating 5.100 fl.' Pressu/J! Rating S.OÐÐ asi PressuftJ Rating S.IOO aBI Pl'@SSIJÆ Raring 13 J:œHt! M1)nlJfacturer ~ MOrJel Shaffer Manufscturor "SL- Mlilln...U.Clck~ Madel 5.000 Mi PresslJff1 RØlirtg KEY: 1. Casing Head: 13-5/8",5000 psi x 13-3/8" Clamp-on 2. Spacer Spool: 13-5/8", 5000 psi 3. Single Ram BOP, with pipe f1Imø 4. D""lnll' Dhlerter Spao/, 5000 P'JÍ. wI Two 3-1/8" side autlet!i "nd one 16" Side Outlets 5. Double Ram BOP, with pipe rams on top and blind rams Dn Bottom 8. Annular BOP, Hydrf1 GK 7. Chøke Line Valve, Manual OperatiOn. 3-118' ( 5.000 psi 8. Choke UM Valve, Hydraulœlly Oper$telS, 3.118'· x 5.000 psi 9. Kltl Une Valve. Ml;1nual Operation, 3·118" :II: 5.000 pili 10. Kill Line Valve, Manual Operation. 3-1/8" c 5.000 psi 11. Adapter Spool, API 16"-5.000 ( ANSI 16".150. or 11. Blind Flange, API 16"·5,000 12. Knife "alve, Hydra~lIç Actuated, ANSI1~-150 1'. DlveI18r line, 16" Camoren Manufacturer 1.1/8" FC Modell Size CamerirJ Manuf8ctul'ti!r ~"1/a" FC. Hç: I( Modell Size CHOKE LINE VALVES L II ""1 11 12 4Ò @ r C]1 ! ~ Msnufar::lUfer :.&.: Modal 1&1 ... o z ¡¡ Nordic Rig #3 13-5/8" x 5,000 psi BOP I Diverter Schematic . . ~ JD ,~13-5/8 5M La.. æ -=t C) C> M Dr r . \0 -- p ~ -------- 60' 34-112' ~ tÞ---r- Dl .,~ d 13-5/8 5M 54' ~ Dr 19.50' Dl 1I! c ,w Ci o ,r*-- ~ ' f1II 13-5/8 5M -~ ~ -::Q~ Þ )...J LJ Þ 6.50' t GROUND LEVEL GROUND LEVEL 31.00 ~~ c[ -ß=_ L' - ~ 9 r-----CJ ~~ ~ 13-3/8' OD CSG ~ 9-5/8' OD CSG ALL DIMENSIONS ARE APPROX. SWE & FCE ENGINEERING ACAD vetcogray- 13-3/8 X 9-5/8 OD, 5M MSP ASSY VI /DIVERTER SPOOL , IDRAWN BY: C. RICE !ENG. APPR.: loA TE: 10 DEC 2004 II A_LE IIREFERENCE: IDA 1E: xv A SCALE: NA KERR-MCGEE NIKAITCHUQ 1t4 PROJECT NO.: II DRAWING NO. SP-5620-4 . ~ g 8: ~ -- .L.. 7 ~ ~ ~ Þ 6 ~ Þ .2' ,~ i ~ ¡~ g;l~ ~ ::.-)::: &: l co ~ u§ u~ ... 1&,(;) r.o.CI.I ~ Io~ . .... W iirI]¡ ~ ~i ~J. ... ... =! :.: .... ~ Ii !i I~ ~.m II ~ u Ii UI(i :¡¡ :Ié " ~tÞ !w CI)~ ;I~ I ~~ i! Zac «IL. . .idffJit! M"nlJ!/lctur"r ~ ManrJfscfu,..r ~ ManufsctUf'9f TEScø J HI~\. MønufaClurer 3-~" EUE Modsl ~.% If: 180P Model a.% IF Lower t<øn., Model 3-% FH Dpal 81J11 MOd,,1 5.01D HI ~asu" ReI/rig ¡GOO psi ~"U'" Rating S.DDO DIIII Pressure ReI/rig 5.JtDÐ Dsl PffMIIUI"Ð RlJl/l1g Hvdrll Manufacturer GK Modsl 5.Q!D asl PI'ENlf/Ure Rsling w II- ~ "SL. Manual LDCk" 5.000 D81 51 Ma"uf"cturor Modsl Pressure Rtlrlng 0 r<_m8rGln 3.1J8" FC I.DDD Þ!l1 MBrwfaGfurer Modøl I S,'zs PTU8/Jre Rating Camaron J-1{8" FC. HCR S.DÐO Elfl MS""fBCl",,,r Modø/ I Size Pml'lllun! Rating CHOKE LINE VALVES 4 Þ Ii a .J L.. ~ §bI1fat ~ !i 000 IIS CI ManuføcrUffJr Modøl PIIJSSIIff1 RIfling 3 z ¡;j - 2 5 ¡ . . . . . . ! 1 ¡ i ! k KEY: 1. Casing Head: 13-5/8",5000 psi x 13-3/8" Clamp-on 2. Casing Spool: 13-5/8",5000 psi Multi-Bowl 3. Aåpter.,... or F...... 88 neecIed. .. Single R8m BOP, wItt1_.... 5. Drllllnø Spøol, 5000 psi. wf 2 Side Outtets . 6. Double Ram BOP, with pIpe rams on top and blind rams on BoItom 7. Annu", BOP. .-.ydrll GK 8. Choke Un. Valve, Manual Operstion. 3-118· x 5,000 psi 9. Choke Une Valve. HyclrllulicIIlly Operated. 3-118'" ( 5.000 pal 10. Kill Un!! V.lye, Manual Operation, 3-118" x 5.000 psi 11. KIØ Une Valve. Manual Operation, 3-118" x 5.000 psi Nordic Rig #3 13·5/8" X 5,000 psi BOP Schematic . J I 4-0 . --f-Jt--H~ c[ r-l-tB I . L-j L¡ ~ , ~ c-1:ø:~ ~ c[ a~ b= 26.00' L-J ~ o 31.00' ;J c[ß=~ L' - ~ a:4 , '"' ALL DIMENSIONS ARE APPROX. . lIT I 13-5/8 5M 0-+- ~~~ -~:($r~ ~ Þ _L:t a L-j I ~-5/8 5~ =cj~þ b~L-j --, =Q :($a II a ~þ ;)~a L-' ~ -- ~ 54,00' 60,00' 6-112' GROUND LEVEL ,.. , __ I ~13--3/8' OD CSG ~ 9-5/8' OD CSG 7' OD CSG ACAD vetcogray' 8WE & FCE ENGINEERING 13-3/8 X 9-5/8 X 7 OD, 5M MSP MUL TIBO'w'L ASSY BOP MODE ¡DRAWN BY: C. RICE ENG. APPR.: IDA TE: 10 DEC 2004 II ~_LE IIREÆRENCE: DATE: xv A SCALE: NA KERR-MCGEE¡ NIKAITCHUQ 14 PROJECT NO.: II DRAWING NO. SP-5620-5 ·' ----"- Hydraulic Choke Outlet to nR Pressure gauges Degasser and transducers 2N1/16" x 51000 psi Valve mounted on inlet block :e /" ~ " ---.fL. OC,) .t::. - /' .. ~(.). /1 I -E Outlet to Flow Ø) Þ œo.- ._ .t::. Back Tank «au I uafl) - C!. '" "1:111)- a .2 z K._ .1: :: II !!!:& ... . CW) Manual '. Choke 8 \....C) Outlet to Degasser Inial from BOP Stack Note: All valves and piping 3-1/811 x 5,000 psi unless otherwise indicated - '. 114.14' 76.62' IJlr . 5M f JIJ I ~= ,l~ T-~-S/8 5M :DI1 I ...., ¡;; I n:o: 28.00' , ~ 'h.. '=- ; c;.,~ q~~ ~: Þ U~ç ~' LJ ~ -r '~~~-s/a SM !. '1 cø::-~ I ~ Ó - P= ::3:! ï-u - <¡¡ I 31.00 c[ å_ t.,..c 0-71" DD nGi All. DIMENSIONS ARE APPROX. vetcogray ~ ¡ 6.50" \ GROUND LEVEL "'- ~ ~ 13-3/8' CD CSG ~9-5/8' CD CSG 7' CD CSG 13-3/8 X 9-5/8 X 7 X 2-7/8 OD, 5M MSP MULTIBOYL ASSY SWE 8c FeE ENGINEERING ACAD kmAWN BY: C. RICE !ENa. APPR.: bAlE: 13 M:IV !G04 ~ÇE: ~ IIDWTtIfJQ .. bA"IE:. .XV~ 1scALE: NIl ~ÇT NO.: I DR/.'IIING NO. SP-5620-2 Nikaitchuq #4 3-1/8", 5000# Gate Valve ESP Wing & Check Valves ........ 13-3/8" Drive Pipe >I: 9-5/8" BTC Casing 111 7" BTC Casing EUE Tubing Abnormal Pressure Analysis · . @; KERR-MCGEE CORPORA nON December 27,2004 Nikaitchuq #4 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, Nikaitchuq #4, will be drilled on the same location as Nikaitchuq #1 which was drilled, tested and abandoned in 1Q, 2004. These wells lie within a large regional fault trend containing several lesser faults. Still, the depositional and tectonic mechanisms that affect reservoir pressures are uniform within the boundaries of this major fault trend, and pressure gradients used to extrapolate/predict formation pressures from known data are also consistent. No pressure data was collected from the Schrader Bluff in either Nikaitchuq #1 or #2, however, these wells are hydraulically connected to the Schrader Bluff at Milne Point: the O/W contact is the same. As such, the pressure in the "OA" sand is calculated as follows: OA pressure at MPU: 2035 psi at 4505 ft TVD, Oil Gradient = 0.30 psi/ft Nikaitchuq #4: [(4145'-4505') x 0.30 psi/ft] + 2035 psi = 1927 psi ./ Formation Top TlSchrader Bluff "OA" MD 4,145 TVD 4,145 Pore Pressure 1,927 EMW 8.94 The captioned well will be drilled basically from the Nikaitchuq # 1 location and the formation pressures are expected to be the same. Nikaitchuq # 1 was drilled from surface to the Colville and logged with 9.2 ppg mud weight. .I sær ASRC Energy Services Project Drilling Supt. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6269 o 200 400 600 800 1000 1200 Pressure '\ , \ \ \ \ \ \ 1400 1600 1800 2000 2200 -4500 ·5000 Shallow Hazard Analysis . . Shallow Drilling Hazards Evaluation Kerr McGee Nikaitchuq #3 and #4 Locations Alaska State Leases ADL 388582, 388583 Spy Island, Alaska Summary Pursuant to 20AAC 25.061, all available data from proximal wells 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 minor amounts of v natural gas hydrates in sands and gravels ofthe Sagavanirktok Formation associated with ice in the permafrost wedge. There is also the possibility of encountering heavy oil accumulations in the U gnu and/or Schrader Bluff sections. Our well plan is designed for the case that both the shallow gas hydrates and heavy oil-saturated strata are to be penetrated in both the Nikaitchuq #3 and #4 wellbores. Seismic data does not define any ./ anomalous shallow hazard zones. Nikaitchuq #3 well is planned to be drilled from an ice pad to be located on Spy Island approximately 4 miles north of Oliktok Point (Fig. 1). The proposed surface location is 350' FSL and 1210' FWL of Section 16, TI4N, R9E of the Umiat Meridian (6,054,827' N & 519,393' E, NAD 27, Zone 4) (Fig. 2). The bottomhole location is projected to be 1120' FNL, 202' FEL, Sec. 21, TI4N, R9E (6,053,368'N & 523,268' E, NAD 27, Zone 4). The well is planned to be drilled to the Sag River Formation at a total measured depth of 12,500' (8870' TVD). Nikaitchuq #4 well will be drilled from the same oversized ice pad as the Nikaitchuq #3 is located. The proposed surface location is 350' FSL and 1460' FWL of Section 16, TI4N, R9E ofthe Umiat Meridian (6,054,827.95' N & 519,643.01' E, NAD 27, Zone 4). The bottomhole location is projected to be 1120' FNL, 202' FEL, Sec. 21, TI4N, R9E (6,057,724.4'N & 517,533.7' E, NAD 27, Zone 4). The well is planned to be "' drilled to the Schrader Bluff Formation to a total measured depth of7800' (4145' TVD). v Geology: Shallow and Intermediate Depth Horizons Nikaitchuq #3 will penetrate strata ranging from the Gubik Formation (Pleistocene) at the surface, to the Shublik Formation (Triassic) at the base ofthe pilot hole (Fig. 3). Nikaitchuq #4 will TD in the Late Cretaceous Schrader Bluff Formation. v The Gubik Formation, as well as a superficial covering of Quaternary sediments, are comprised of approximately 800' of interbedded sand, gravel, mud, and some low- grade coal deposited in marine and marginal marine settings. The Gubik Formation unconformably overlies the Sagavanirktok Formation (Late Cretaceous through Eocene). The Sagavanirktok Formation consists of complexly interbedded sand, shale, and conglomerate deposited in multiple sequences of marine and T 14 N T -<?- Plono.'J0' ~1 N L , , , #3 8 17 20 9 4 \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ " " 16 21 10 15 .... -^ ....~ 22 1"=1000' Figure 2. Location map for the Kerr McGee Nikaitchuq #1, #3,and #4 wens, TI4N, R9E, Umiat Meridian, Alaska. u ...... o N o W .....I C a.. AGE u ...... o N o Z w U QUAT = c .... ¡... 1:1I:: w ¡... en :) o w u ~ W 1:1I:: U 100 L N P I OL . . fig...re 3. Stratigraphic co....mn for the Spy Island/ Nikaitchuq area, North S'ope, Alaska. u ...... o N o U» w :Ii u ¡ = 1:1I:: :) , u ~ ~ z c .... :I 1:1I:: W L z z W L en en .... :I z z ~ 200 300 ST MY S1'RIU1GRAPIft ROCK MAJOR BP TYPE SEQI.EN:E SAGAVANIRKTOK FM BROOKIAN SEQUENCE W UGNU filii ..JI ..JI :; ~CHRADER BLUff ..JI 8 COLVillE MS KAI.UB.K fM KUPARUK (C & D) (A& B) :I -iïü¡ŸEÃëHfM u. ~ C e z !i2 RIFT SEQUENCE NUIQSUT SS NECHEUK SS L KINGAK SH SAG RIVER FM SHUBLIK FM I:::: I fi IVISHAK FM ~ KAVIK SHALE ECHOOKA FM ~'_."~-~-='""-"""'- UPPER EU.IESMEmAN SEQUENCE LISBURNE GF LOWER ELLIESMERlAN SEQUENCE ENDICOTT GF BASEMENT FRANKlINBAN SEQUENCE N HYDROCARBON OCCURRENCES Heavy Oil Schrader B'uff Nikaitchuq Unit Milne Point . . non-marine strata deposited in deltaic to coastal plain environments. These sediments are all unconsolidated. The Sagavanirktok is projected to be over 2500' thick in the Nikaitchuq area. The Late Cretaceous Colville Group is comprised (from younger to older) ofthe Ugnu Formation, Schrader Bluff Formation (also known as the West Sak Formation), and the Colville Mudstone. The Colville Group represents an overall upward shallowing, v progradational sedimentary package deposited in environments ranging from open marine basinal to fluvial settings. Both Nikaitchuq #3 and #4 wells will penetrate approximately 600' ofUgnu Formation sediments, mostly comprised of unconsolidated to slightly cemented sand and gravel. The Ugnu Formation overlies 400-500' of upward coarsening cycles of interbedded sand, silt and mud ofthe Schrader Bluff Formation. Many of the sands developed in the U gnu and Schrader Bluff formations contain reserves of heavy oil in both the Milne Point and Kuparuk fields. Geophysics The 3D seismic grid covering the Nikaitchuq area was analyzed for potential shallow and intermediate depth drilling hazards (Fig. 4). This seismic data was then compared to wireline logs, mud logs and scout information from uphole sections in wellbores in North Milne Point area. There is no geophysical evidence such as amplitude anomalies or velocity sag suggesting the proposed Nikaitchuq #3 and #4 wells will encounter any form of shallow entrapped natural gas, or intersect any conductive faults (Fig. 5 and 6). Potential Shallow Drilling Hazards Permafrost Nikaitchuq #3 surface location is on Spy Island, a low-relief barrier island north of Oliktok Point. The surface location for Nikaitchuq # 1, drilled by Kerr McGee in February, 2004, is located 128' ENE. Nikaitchuq #1 drilled through the permafrost from 830 to 1750' TVD. The Nikaitchuq #3 should encounter permafrost in approximately the same depth interval. Nikaitchuq #4 surface location is also on Spy Island. The surface location for Nikaitchuq #1 is located 135' WNW. The Nikaitchuq #4 should encounter permafrost through approximately the same depth interval as observed in the Nikaitchuq #1 borehole, and is projected for the Nikaitchuq #3 well.. "^ -_.,.~------- &. . . Shallow Hydrocarbon Accumulations There is no evidence of any significant accumulations of gas hydrates in the shallow sands ofthe Nikaitchuq area. Mudlogs from the Nikaitchuq #1 well showed the presence of minor gas hydrates within the permafrost between 1200-1750' TVD, with a ./ maximum hotwire reading of 400 units gas (1280' TVD). The Exxon Thetis Island well (6 miles west of proposed location) was characterized by similar indications of gas v hydrates contained within the permafrost wedge. The Nikaitchuq #1 and #2 wells penetrated several Schrader Bluff sands with or shows of heavy oil (4000-4200' TVD). There were no well control problems observed while drilling through these show zones in either of these previously drilled Nikaitchuq wells. No hydrocarbon shows are associated with this interval in the Exxon Thetis Island well, or the Conoco Northwest Milne Point #1 well (3 miles ESE). Conclusions No drilling hazards associated with natural gas hydrates, shallow trapped natural gas or oil are anticipated in the drilling of the Nikaitchuq #3 and #4 wells. Although minor amounts of gas hydrates are associated with the permafrost layer, these amounts can and will be dealt with by prudent drilling practices. Any heavy oil entrapped in either the Ugnu and/or Schrader Bluff intervals are not considered to present any drilling risks. &: &: 8. I 58 00 VI 8 o -õ '¢ q "" 1 49 00 VI 'I "I"" I 1 49 54 VI 149 52 00 VI 1 49 50 00 VI Nikaitchuq #4 Proposed Exploratory 2042600 SFD 1/5/2005 t 510,000 I I 149 00 530,000 ¡ < ;:/> (~) ';:1~?r2¿;'PA:PT1Jl~'~~~i:(~~:;':~l:;:" ,,;,~~ "",,:;:,',<~, ',,' ,.'<' ~'"''''''<''' ".; ,-:.,..","{"" 'i' ,/'/'''~i,_",/~"~;,;",-¥~~'d....~,-,,,,:: -,';/I,{'/,,.;, , '-,; /"/'r:~;' '~;^~^~~!'¡~'.r~1.¡!~äl1:Q~;t ;> };'<:: >:<J<'"< """"",, '-"" ,,_,j,-;,-,' J~;~'" _", ,;<"<,,~,,,.;, ,.,Ù-"'\, ;;, ","-,,' -;"h -..<:,~/ ~, "~:-;:.»- .-,,;-,- -,'<~~: " t~":\.\sl, u,"~¡'d,'¡~\;,v,< "jjfA~,"Ì>', s,í¡;'pe"·,'R,,E\ä,tø....t;ê ",P, a' ra i:'.~.'.':"'~,,',.',.>:'~,~ ,","" .'.' ',.., ._.:,:-...."~" , ,',..."",..",.""v,.,,','," " ','" '/ ,"', ''/'' ' , ¡ \ \, 1~~~~w:J9:~:;r:;J)ii,r'1¡n ! . " A907)\1~9-~2!)O·..<,: . "..... . N ' ".~j ? iE.:" , ,,'1/-., /' ';"">-'/ .,.,,'" .<~'.,'" ,".-",', ~" PA.y.. dNE HUNDÍŒD;'DOLLARS'Ar'm 00 CEN'tS **'*'***"*****';'********~*****"**~****Úêl'***********,';';';'*****êI'~*..***k**~**~*~********";êI'***¡';'*******·'· VOID OVER $100,00 STATE OF ALASKA Ô~rfOFOIL & GAS CONSERVATION COMMISION ".. 333 W 7TH AVE STE 100 ANCHORAGE, AK 99501 . III . . 5 ~ 2 ? III I:. 2 5 20 0 OS? I: 31? II' ? ß 2 ? . .111 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME AIk~II"4! t/ PTD# 20,-/- UD Development Service CHECK WHAT APPLIÈS ADD-ONS (OPTIONS) MULTI LA TERAL (If API Dum ber last two, (2) digits are between 60-69) / Exploration Stratigraphic ~'CLUEn Tbe permit is for a Dew weUboresegment of existing we))'. . Permit No, .' API No. . ProductioD. sbould continue to be reported as a function' of tbe original API number. stated above. HOLE )n accordaDce witb' 20 AAC 25.005(f), aU records, data and logs acquired ,for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) and API Dumber (50- ~~ - L"32.cll- ,'76 ~from records, data and logs acquired for we)) (name on permit). P1LOT (PH) ,/ SPACING EXCEPTION DRY DITCH SAMPLE Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25..0SS~ Approval to perlorate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing .exception tbat may occur. AU dry ditcb sample sets submitted to tbe Commission must be in no greater -tban 30' sample intervals from below tbe permafrost or from wbere samples are fint caught and ] 0' sample iJiter:vals tbrough target zones. brs ///7 /5' '\ \~~:~ Offshore exploratory well drilled north west from Spy Island in the Beaufort Sea. The well will target the Schrader Bluff OA sand. A pilot hole will be drilled to determine OA top and base, then plugged back. A horizontal sidetrack will be drilled within the OA sand, and an extended duration production test conducted. Mudlog and samples not required as Nikaitchuq #1 drilled from this same location, recorded mudlog and collected samples from 245' to 11,010'. Mudlog and samples were also obtained in NikaitchuQ #2 well. 2 miles to SE. Geologic Commissioner: Appr SFD Date 1/5/2005 35 36 37 38 39 Date: Engineering Commissioner: Date _S.ßabedcondWoo survey _(if Qff-!;ho(e) Conta_ct namelphQlle _ fQr 'Ale~kly progress reports [explQratoryonlYl Y.ßs Y.ßs Yes NA Y.ßs N/A; ~IJ Skip CQyner, NQne_oÞseJ'..' I Jle Jocaltor od EJÇp~cted ,w_,~ .,...v !d with 9.0 ." ¡LmiooJ "J"_:~'~w ',w,o, ,.¡v".'_ -J75Q' ND. lv"'" ", '''v'-! from oaJura _offsh_ore_ island, 90] -3_39-.63'Z0 i.s _bo:nn ....,.alo.J Same. expec_te.dat thislocatio_n, j~ oveJPressure _ZOne$ _S.ßtsmicanalysjs_ of sbaJlow gas_zooes Nikaitcbuq r.ß~ervojr pre_s~"ro ,~ o.9ppg 1 ~\I....I..f'I"'OIt"o "'..nrn O"3n" th(Ough_ ,n,8,ppg mud. P.ßrmit _D_ata_presented Oil pote_ntial Geology c_an Þe tssued w/o hydrogen s,ulfide measu(eS 32 33 34 Work will OCCur withoutoperatjon _Shutdown Js pres.ence of H2S gas_ prob_aÞI~ Mecbanicalcondjlton of wells wtthin AOB verified (Forße(Vjc~ W.ßIJ Qnly) . Appr TEM Date 1/6/2005 18 19 20 21 22 23 24 25 26 27 28 29 30 31 ,BOPEs.dolt ' BOPE_pre.ss ,W,' ','" ......, Jest to (puJ ChOke_ manifold compJies w/API RF'-53. (May 84) r~'inn ~nDropriate; reguJation _DJilliog f]ujd program sc.h~matic_& eq_uip r~guJations ist adequat.ß Jfare-drilt has,a _Adequate _'Alellbore. separatjoÐ proposed Jf div~rter Jeq_uiJed, does it me~t to-403 for abandQllmeÐt be.ßO apPJov~d AdequatetankageoJ re_serve pit ,C_asiog designs ad_equa,te for C,T, B_&permafr,ost _C,onducl _S_urfacef_~ _CMT v_ol ad~qu : circ_ulj ,g~,:I, LV tie-tn_,~,.v _~~.I~I'¡;; I ........,.....!O"I_ aJl known_pro,ductiye bori;!:ons _CMT v_ol ad~qu~'''' '^ _CMTwill coyer Innn ~"''':nn +n r<tlrf csg_ ~asing_ pJotec.ls. all & SUJfC$g Y.ßs NA Y.ßs No, No_ Y.ßs Y.ßs NA Y.ßs Y.ßs YßS Yes Yes Yßs Y.ßs No NA the same geologic se.ction~ ti2S ba_s ,not b.e~n repQrted jn 5c.hrader_Bluff_ s_ands, Rig is equipped with s_ensors_ and _alarms.. psig incor:!lments) MAS¡=> calçulatedat 1 4r1 psi, 50QO_pst SQF' t~stp!anoed, Rig has nQtdrilJedstnçe Jastyear._ Maximum eJÇp~cted forma,tiOIl pressure8,9_EMW jn 8.5"hoIß. MW plalln~d 9.2 - 9..6 ppg. AlthOughJbere are oth~r_ weJls tntbe_ immßdiat~ _are¡;¡. there ¡;¡re,no _cQlljsjo_n issues, Big js_equipped'Alith $t.ßelpits. No resel"\le_pjtplanned, AJI waste to,approved_dispos,al wells. All Slotte_d lioer _cor:!lp1elton plaOlled._ Offshore JocatioÐ, no USQWs. ,SFD_ KM re_quests to Use_ AD {or produ_ced f]ujds be, cemented. hydrocarbonzones_'Alill jfCPAJ refu$es at ,Annular djsposaJ KRU. AD ,not recomme_nded, may be_ prQPosed, Use_ CI¡;¡ss_ I well Engineering e· Appr SFD 1/5/2005 Date o 11 12 13 14 15 16 17 strillgpJovid~d _AJI w~lJs_'Alithtn Jl4_mile_are.a_of review idßotified (FOr servjCßwell only) Pre-produced inj~çtQr; dur¡;¡tion_of pr~-production Ißss. than_ 3 montbs (for_s~rvtce well QnJy) _ACMP F.indjngof Con$i$tencyhas bee_n i$.sued, for, this project or or Jorce c_an be tssued witbout co_nservation order Permit can be tssued witbQut ad_ministrati\le_approvaJ Can permit be approved before We.ll located wtthin area alldstrat¡;¡ _authQrized by_ 15-day wait PTD#: 2042600 Administration bas_appropriate_ bond tn We.ll JQc¡at~ in a_ defined _POI We.IIJoc¡;¡t~d properdtstance riJling unitb_ound_al"Y_ We.llloc¡;¡t~d properdtstance tber welJs ,S_ufficient _acreage_ayail¡;¡ble ,,' "_' "..,J Jf deviated. incJu_ded Company KERR-MCC 3AS CORP Permit fee atta lease _number _W..r<' Vr<' .... _ _ _ _ n_am.e _aod numb_er 2 3 4 5 6 7 8 9 only c ftected party js weJlbQre plat njeçtioo Ordß( # (put 10# in_cpmmßnts) (for Pßrmit :n ..Jr:"'ng unjt _U_ntque well Field & Pool "nn"^nri~+e Initial ClasslType Yes No_ Xes No_ Yes Yßs Xes Yes Yes _Yes Yes Yßs Yes NA _NA NA NA NeaJbYßxplor¡atory _'Ale II Nikaitchuq #1 is pluggßd ¡and ab¡;¡odoned_. CQrreçtjon _made to_ 40.1 Ije_ withtn Well Name: NIKAITCHUQ 4 EXP / PEND GeoArea 973 _the_Nilsajtchuq _Unit surface and .tQP_ p,rQd, th¡at lntel"\lal in ADL. 388582. TD is OWlled Þy Kerr-McGee_ (70%>- Unit 11400 Program EXP On/Off Shore in ADL 388583.. & Arrostrpog (30%1. On Both, leases Well Annular bore seg Disposal o . . 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 finding infomlation, 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. Sperry..Sun End of Well Report Nikaitchuq #4 Exploration os NWMUnePoint DirectionalDrilling & MWD/L WD Services I I I I I I I I I I I I I I I I I I I 5p=i II 1,:/-r::I In CRIL.L.ING seRVices End of Well Report Nikaitchuq #4 Kerr McGee Corporation 21 February 2005 R ~\IED OCT 2 0 ¿005 Ala:;,,'" v" _Jmmissioll l~f~chJfage I I 1 I 1 1 I 1 1 1 1 1 17 1 I 1 1 1 1 Keff McGee Nikaitchuq #4 Operator Kerr McGee Well Nikaitchuq #4 Job Objectives: Nikaitchuq #4 will comprise a pilot hole for evaluation. to be plugged back; and a horizontal producer with an electric submersible pump in the Schrader Bluff. Summary of Results: r BRA #1 This assembly drilled its way into the hole with no major problems. Initially, it was necessary to reduce o~ 300 gpm in order to start shearing the mud as well avoiding any washing of the shoe at 115'. As we got deeper, the mud smoothed out and we were able to drill with 600+ gpm. The mud cleaning systems seemed best able to cope with a rate of penetration of 200 fþh or less. 1bree short slides were necessary to keep the hole near vertical. We drilled to the casing point picked by the customer at 2464' and the assembly was pulled out of the hole. Altogether this assembly was on bottom for 23.75 hours. The bit was graded as 4.3. WT.A.E.1.ER.TD BRA #2 This BHA tagged the plug at 2333'. We drilled through the plug and stopped ten feet above the float collar. The casing test at 2500 psi for one halfhour was successful. We then continued to drill cement. the float collar, shoe and rathole to 2464' Twenty feet of new hole was drilled and a leak off test performed Drilling commenced with a low flow rate until the mud wanned up and sheared. Flow rates were increased until we could circulate 500 GPM. The assembly drilled fairly straight, having an average dogleg of -0.23 degrees per hundred feet and an average build of -0.0 1 and walk: of -1.04. Core point was called at 4120 and the assembly was pulled out of the hole. The bit was graded as 1.2.WT.G.E.1/8.NO.CP BHA3 The assembly ran easily into the hole. Sixty feet offormation were cored and the assembly was pulled out of the hole. BHA4 The section of the well that wascorecJ. 4120' to 4180', was reamed and once through this section we drilled to aMD of4310which "'"' ~e pilot hole. At TD we circulated two bottoms up and POOH. The trip out went without any issues. The wen bore mclination declined slightly ftom 1.34° to 1.14° between POOH for the core run and TD of the well. The azimuth also onlytumed slightly ftom 87.42° to 98.49 0. BRA 5 At 2863 we taged cement and circulated bottoms up as the shaker was overflowing at our desired flow rates. When we tagged the cement we were able to apply 20k WOR We started time drilling at 2.5 minutes an inch for 3' and observed that the string was taking weight and slight indications of reactive torque. We were using 450 GPM flow rates. We drilled an additional 3' at 2 minutes an inch and then increased the drilling time to 1 minute an inch down to 2875'. At this depth we were able to drill ahead without any time drilling. Drilling down to 3031 produced varying ROP's but the assembly would produce calculated 7.81 doglegs in complete slide. At 3055' and again at 3058' we encountered hard stringers that slowed the ROP down to 15'!hour. Drilling continued without incident. Once into the Ugnu formation the assembly produced consistent 4.5° to 5° doglegs with 55 to 60' of slide; this calculated out to -8.75 dogleg assembly production for complete sets. As we drilled deeper to - 65°, into the Sbraeder Bluff formation. the dogleg increased to calculated 10's with maximums up to 13's. As the geologiacl samples were taken and extrapolated, it was decided to aim for a landing at 4160' TVD. Our directional plans were altered to suit the needs of the customer. We drill to a total depth of 4861' and the assembly was pulled out of the hole. Altogether this assembly drilled 1998' of hole of which 1133' were oriented and 865' were rotated. The rate Page 3 Speny-Sun Drilling SeMces I I I I I I I I I I I I I I I I I I I Keff McGee Nikaitchuq #4 of penetration averaged 87 feet per hour with 77 feet per hour orienting and 100 feet per hour rotating. The bit was graded as 2I3/WT1 AfFjI/CT (rD. BHA6 BHA was made up and singled in to ES cementer valve. drilled up and continued RIB to plugs at 4761' MD, performed casing test and drilled up plugs, cement, float collar, shoe and 20' new hole. Target given to land, 4164-4166' TVD. Target was reached and Geo wanted to come up to 4162' TVD. 1800 hrs, 5580' MD, 4162' TVD, 89.5° requested. Geologist thinking we are between calcite zones and would like to hold this ine following down dip. 5600' MD, drilling on hard spot. 89.2 ine once through, hit another deflecting us down , 90 requested. 2015 Hrs,. 5675' MD, 90.5 requested. Built to 90.5, dropping rotating, @ 89.5 @ 5771' MD, havent seen any hard spots for awhile, will hold 89.5 for awhile. 0100 Hrs,. 598TMD, 90-90.5 requested. 0230 Hrs,. 6108' MD, let drop rotating to no more than 88.5. BHA has been dropping in rotation about 2°1100, and walking left about .25°1100, we are controlling ROP from 120-150'/hr for logs. Assembly has been putting out 10-12° DLS last 600'. 0300 Hrs,. 6140' MD, 88.6° ABI, continue to let drop rotating till advised by Geologist. 0307 Hrs, 6151' MD, 88.2" ABI, 90° ine requested. 1730 Hrs,. 6858' MD, 89.5° inc requested, currently at 88, slid 22' up, rotated 32', seen 88.8 ABI once then dropped to 88 rotating. Geo now wants to come up 2' TVD aggressively. 92° ABI @ 6983' MD. Got up a couple feet, slid down to 90.3, drill ahead average 89.5 requested. dropped to 89 rotating to 7133' MD. Goo wants to keep rotating ahead letting it drop some. 2400 Hrs 719T MD, 8&.5 - 89" inc requested. @ 7200 MD, had a little firmer formation deflected us up to 90.8 from 89. 0145 Hrs,. 89.5 - 90" ine requested. 0620 Hrs, Geologist requested 91 degrees inclination We started sliding at 60L for build and turn 0730 Hrs. Geologist informed us the wen would be TD at 7577'. We finished our slide at 60L and rotated to TD. After the well was cleaned, the BHA was pulled out of the hole. Page 4 Sperry-Sun Drilling Services I I Keff McGee Hours by Operation Summary I I c o ii .. . Q. o I I I I I I I I I I I I I I 8000 o I 72 DrIllIng RIg Up I Tear 0.-. Tripping 54.24 Rm~=~75 54 CkQdate ~ 35~~ ~ 27.35 - NlppleUpBOP _ 19.75 WIreIIne Logs _ 18.5 Other 72.26 o Total Hours During Job . I 1\ I I~ L.........-." Hours per BHA Breakdown Nikaitchuq #4 co .... :..., œ 70 Days vs. Depth 0 '---, 500 1000 1500 2000 2500 3000 £ 3500 .: ã. ~ 4000 I ::I .. 4500 II I 5000 5500 6000 6500 7000 7500 60 ~ ~ 50 a: 43 ~ 40_ ãi ID I! 30 ::J 0 :%: 20 j 0 I- 10 0 1 100 . Drilling . Circulating III Reaming 0 Other 67 47 ::r7 ~ 13 2 3 4 5 6 BHA Number Average Rate of Penetration per BHA 120 110 100 98-9 90 80 "t:" 70 .: ~ 60 II.. ~ 50 40 30 20 10 0 - 1 Footage per BHA 3000 \ 2500 ?'>AO £ 2000 -a .!! :¡: 1500 CI . œ .! 1000 0 0 II. 500 0 1 I!I Rotated III Oriented Page 5 2 4 6 8 10 12 14 16 18 20 Day 112.1/ 87.1 2 8.0 ~ 3 79.4 , 56.5 , . I 4 5 6 BHA Number 2716 1998 t 1656 60 130 ...... .. 2 3 4 5 6 BHA Number Speny-Sun Dri/ling Services I I 'SperT'y-5UI1 ORILLIIIIG !n!RVICI!S A_,,- Kerr-McGee Corporation Eastings I DrillQuest I I I I I I I I I 1000 - I I ..c: ... c. ~ 2000 (ij o t ~ I 3000 I ¢:: o o o ..... 1\ ~ o .= 4000 ..... I I Q) ã; o en Kerr McGee Spy Island Nikaitchuq #4 Legend Actual Profile Proposed Profile I o --1--- 600.,=OO,QB 1200."";206.1)1) Well: Scale: 1inch = 750ft -2250 -1500 I I \ ",.. \~ % -.\ .f185_'S~ 145." -750 I o I I I I I I I I I I I I I I I I I I I I I - 750 ¢:: o I() "- 1\ ~ o .= ..... - 3000 - 2250 f/) C> .£;; ..c: 1:: - 1500 0 Z -0 Q) ã; o C/) 1100.: FOG.IIO Horizontal Coordinates: Ref. Global Coordinates : Ref. SHl of Nikaitchuq #1 : Ref. Geographical Coordinates: 2)80 RKB Elevation : 16i1,1I0 North Reference : Units : 2910....." ,'oa.oo Current Well Properties Nikaitchuq #4 6054828.00 N, 519643.00 E 969.42 S, 28.60 W 70· 33' 39.4601" N, 149050' 19.9106" W 35.ooft above Mean Sea level True North Feet (US Survey) ~.zoD.8' The "Directional Difficulty Index" for this profile is 5.8 3S00.0". 48fiO_¡~eC jUO ~4r,' iJ,.,·øø ~t.o~ ..208,01 ,.~r" ,.I'OO_ot ~'M ¿40ø.oa Nikaitchuq #4 Actual 4100.0. I o Scale: 1 inch = 1000ft I 1000 2000 Vertical Section DrillQuest 3,03.06.008 I N"dtailcbuq 114 Proposed I 3000 4000 Section Azimuth: 324.152° (True North) ---------------- - -- Ei~I1!rIr'Y-!ILrI Pa¡:¡e: 1 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 location: Spy Island a"ILLIN~ .."VIC.. Rig: Nordic 3 Job # :AK-MJ-0003523133 Survey and rUling Parameters North Ref: True Declination: . VS Dlr : 324.150 (from Wellhead) VVELLBORE SURVEY DRIWNG PARAMETERS lIeasured Incl Azl Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth AnAle Dlr Depth Section NIS EM Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (01100') (01100') (01100') (klbl) (gpm) (pII) (ft) (ft) (deg) :ftlhr) (#) 0.00 0.00 0.00 0.0 0.0 0.0 0.0 0.00 0.00 0.00 TllIOn 204.13 2.81 82.61 204.0 -2.4 0.6 5.0 1.38 1.38 0.00 3 50 300 300 60 1 294.31 2.30 74.73 294.1 -4.1 1.4 8.9 0.69 -0.57 -8.74 10 60 600 1600 267 287 262m 200 1 386.47 1.24 69.66 386.3 -5.0 2.2 11.6 1.16 ·1.15 ·5.50 10 60 600 1600 357 375 255m 100 1 477.59 1.41 75.96 477.3 -5.7 2.9 13.6 0.25 0.19 6.91 10 80 600 1350 100 1 568.76 1.06 89.85 568.5 -6.6 3.1 15.6 0.50 ·0.38 15.24 10 80 600 1350 50 1 660.79 1.63 83.70 660.5 -7.7 3.3 17.7 0.64 0.62 -6.68 15 60 600 1350 55 1 754.38 1.60 64.75 754.1 -8.6 4.0 20.2 0.57 -0.03 -20.25 15 60 600 1350 110 1 849.15 1.85 55.12 848.8 -8.9 5.4 22.7 0.40 0.26 -10.16 15 60 600 1400 92 1 943.44 2.05 61.74 943.0 -9.1 7.1 25.4 0.32 0.21 7.02 10 80 635 1450 114 1 1039.73 1.24 68.30 1039.3 -9.6 8.3 27.9 0.86 -0.84 6.81 10 80 650 1525 1011 1031 242m 128 1 1134.68 1.30 78.64 1134.2 -10.3 8.9 29.9 0.25 0.06 10.89 12 80 650 1650 88 1 1228.46 1.36 92.64 1227.9 -11.5 9.0 32.1 0.35 0.06 14.93 15 80 650 1650 114 1 1324.18 1.47 103.37 1323.6 -13.1 8.7 34.4 0.30 0.11 11.21 15 80 650 1675 114 1 1418.77 1.38 110.56 1418.2 -15.0 8.0 36.6 0.21 -0.10 7.60 15 80 650 1750 142 1 1513.81 1.42 111.83 1513.2 ·16.9 7.2 38.8 0.05 0.04 1.34 15 80 650 1750 162 1 1608.98 1.41 115.25 1608.4 ·18.9 6.2 41.0 0.09 ·0.01 3.59 15 80 650 1750 103 1 1704.65 1.63 109.84 1704.0 -21.1 5.3 43.3 0.27 0.23 ·5.65 15 80 650 1850 190 1 1798.11 1.77 114.05 1797.4 -23.4 4.2 45.9 0.20 0.15 4.50 10 80 650 1850 190 1 1894.41 1.72 107.72 1893.7 -25.9 3.2 48.6 0.21 '0.05 -6.57 10 80 650 1850 152 1 1989.13 1.59 106.24 1988.3 -28.1 2.4 51.2 0.14 -0.14 -1.56 10 80 650 1950 142 1 2084.30 1.60 110.18 2083.5 -30.2 1.6 53.7 0.12 0.01 4.14 10 80 650 1975 128 1 2179.53 1.63 102.66 2178.7 -32.3 0.8 56.3 0.22 0.03 -7.90 10 80 650 2000 142 1 2274.24 1.46 104.19 2273.3 -34.3 0.2 58.8 0.18 ·0.18 1.62 10 80 650 2000 103 1 2369.41 1.48 106.06 2368.5 -36.1 ·0.4 61.1 0.05 0.02 1.96 10 80 650 2000 100 1 2463.52 1.64 103.97 2462.6 -38.1 ·1.1 63.6 0.18 0.17 -2.22 10 80 650 2000 100 1 2557.62 1.47 107.42 2556.6 -40.1 ·1.8 66.1 0.21 ·0.18 3.67 5 80 450 1650 126 2 ------------------- !5pEIT'Y-BLrI Pa!:!e: 2 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 Location: Spy Island CI..ILL.I Nil ....VIC.. Rig: Nordic 3 Job # :AK-MJ-0003523133 Survey and Drilling Parameters North Ref: True Declination: . VS Dlr : 324.15' (from Wellhead) WEU..BORE SURVEY DRILUNG PARAMETERS "easured Incl Azl Vertical Vertical Coordinates DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Angle Dlr Depth Section NIS eM Rate Rate Rate Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbs) (gpm) (PII) (ft) (ft) (deg) :ftIhr) (#) 2652.42 1.34 106.38 2651.4 -42.0 -2.4 68.3 0.14 -0.14 -1.10 10 80 450 1650 114 2 2747.56 1.10 87.06 2746.5 -43.4 -2.7 70.3 0.50 -0.25 -20.31 10 80 450 1650 103 2 2842.58 1.43 84.79 2841.5 -44.5 -2.6 72.4 0.35 0.35 -2.39 10 80 450 1500 123 2 2937.80 1.27 92.64 2936.7 -45.7 -2.5 74.6 0.26 -0.17 8.24 10 80 500 1850 121 2 3032.57 1.23 86.90 3031.5 -46.9 -2.5 76.7 0.14 '().04 -6.06 10 80 500 1650 100 2 3128.01 1.47 74.79 3126.9 -47.9 -2.1 78.9 0.39 0.25 -12.69 10 80 500 1950 87 2 3223.00 1.30 76.02 3221.8 -48.7 -1.5 81.1 0.18 -0.18 1.29 10 80 500 1950 162 2 3317.74 1.44 75.10 3316.5 -49.6 -1.0 83.3 0.15 0.15 -0.97 10 80 500 1950 146 2 3413.53 1.27 84.57 3412.3 -50.5 -0.6 85.5 0.29 -0.18 9.89 10 80 500 1950 172 2 3508.64 1.19 82.22 3507.4 -51.5 -0.3 87.5 0.10 .().08 -2.47 10 80 500 1950 132 2 3603.20 1.10 92.14 3601.9 -52.6 -0.2 89.4 0.23 -0.10 10.49 10 80 500 1950 135 2 3698.56 1.02 85.67 3697.3 -53.6 -0.2 91.2 0.15 -0.08 -6.78 10 80 500 1950 172 2 3792.50 0.98 99.38 3791.2 -54.6 -0.3 92.8 0.26 -0.04 0.00 10 80 500 2000 94 2 3888.81 1.22 95.55 3887.5 -55.8 -0.5 94.6 0.26 0.25 0.00 15 80 500 2000 76 2 3983.27 1.39 91.45 3981.9 -57.2 -0.6 96.8 0.21 0.18 -4.34 15 80 500 2000 135 2 4058.93 1.27 88.60 4057.6 -58.2 -0.6 98.5 0.18 -0.16 -3.77 15 80 500 2050 92 2 4115.93 1.34 87.42 4114.6 -58.9 -0.6 99.8 0.13 0.12 -2.07 15 80 500 2100 67 2 4211.39 1.13 95.63 4210.0 -60.2 -0.6 101.9 0.29 -0.22 8.60 15 80 500 2375 55 4 4246.84 1.14 98.49 4245.4 -60.7 -0.7 102.6 0.16 0.03 8.07 15 80 500 2375 55 4 ------------------- spEIrIrIy-an I PaRe: 1 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 Kin 4 ST Location: Spy Island CI.ULL.I NCI ....VIC.. Rig: Nordic 3 Job # :AK-MJ-0003523133 Survey and Drilling Parameters North Ref: True Declination: " VS Dlr : 324.15" (from Wellhead) WEUBORE SURVëY DRlWNG PARAMETERS "eaaured Incl Azl Vertical Vertical Coordlnatel DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth AnRle Dir Depth Section NIS r:NJ Rate Rate Rate Pipe From To Flee No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) ("/100') ("/100') ("/100') (klbl) (gpm) (pII) (ft) (ft) (deg)ftlhr) (#) 2842.58 1.43 84.79 2841.S -44.5 -2.6 72.4 0.00 0.00 0.00 10 80 450 1500 123 Tieon Kin 4 5T 2863.00 1.39 86.32 2861.9 -44.7 -2.5 72.9 0.27 -0.20 7.49 15 450 1625 47 5 2937.44 1.44 322.11 2936.4 -44.3 -1.7 73.2 3.36 0.07 ·166.86 10 80 450 1600 2863 2929 311m 131 5 3032.66 5.13 323.79 3031.4 -38.8 2.7 69.9 3.88 3.88 1.76 10 80 450 1600 2966 3031 311m 67 5 3127.98 9.49 326.59 3125.9 -26.7 12.7 63.1 4.59 4.57 2.94 10 450 1625 3061 3086 311m 100 5 3089 3128 24L 5 3223.17 14.31 322.16 3219.0 -7.1 28.5 51.6 5.15 5.06 -4.65 20 450 1625 3128 3156 24L 105 5 3184 3223 24L 5 3318.79 18.95 316.46 3310.6 20.1 49.1 33.6 5.14 4.85 -5.96 20 450 1625 3223 3251 24L 89 5 3279 3319 24L 5 3413.84 23.35 310.10 3399.3 53.7 72.4 8.S 5.21 4.63 -6.69 20 450 1625 3319 3346 24L 86 5 3374 3414 30L 5 3508.95 28.44 308.91 3484.8 93.9 98.8 -23.5 5.38 5.35 -1.25 20 450 1625 3414 3446 30L 160 5 3469 3509 HS 5 3604.54 33.88 311.00 3566.6 141.8 130.6 -61.4 5.80 5.69 2.19 20 450 1625 3509 3541 HS 78 5 3564 3605 HS 5 3697.87 39.38 312.76 3641.5 196.2 167.8 -102.8 6.00 5.89 1.89 20 450 1625 3605 3631 HS 72 5 3659 3698 10L 5 3793.61 43.66 311.69 3713.1 258.3 210.4 -149.8 4.53 4.47 -1.12 20 450 1625 3698 3719 10L 49 5 3754 3794 10L 5 3887.04 47.79 310.32 3778.3 323.4 254.3 -200.3 4.54 4.42 -1.47 20 450 1625 3794 3806 10L 89 5 3850 3887 10L 5 3984.16 52.98 309.42 3840.2 395.9 302.2 -257.7 5.39 5.34 -0.93 20 450 1625 3887 3914 10L 47 5 3945 3984 HS 5 4078.31 57.19 309.61 3894.1 470.6 351.3 -317.2 4.47 4.47 0.20 20 450 1625 3984 3997 HS 69 5 4040 4078 HS 5 4173.49 62.35 309.77 3942.0 550.2 403.9 -380.5 5.42 5.42 0.17 20 450 1625 4078 4094 HS 85 5 4135 4173 HS 5 ------------------- 1:IJ.Ir::!rT'Y-5LI1 PaQe: 2 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 Kin 4 ST Location: Spy Island aft.L.L. Nil.. "VIC.. Rig: Nordic 3 Job # :AK-MJ-0003523133 Survey and Drilling Parameters North Ref: True Declination: ° VS Dlr : 324.15° (from Wellhead) WEU.BORE SURVEY DRIWNG PARAMETERS lIeasured Incl AzI Vertical Vertical Coordinates DLS Build Turn VVOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth Anale Dlr Depth Section NIS EM Rate Rate Rate PID8 From To Face No. (ft) (des) (des) (ft) (ft) (ft) (ft) (°1100') (°1100') (°1100') (klba) (spm) (pII) (ft) (ft) (deg)ftIhr) (#) 4268.85 65.62 310.64 3983.8 633.3 459.2 -445.9 3.53 3.43 0.91 20 450 1625 4173 4187 HS 200 5 4230 4269 HS 5 4363.02 69.24 310.25 4020.0 717.8 515.6 -512.1 3.86 3.84 -0.41 20 450 1625 4269 4270 HS 140 5 4325 4363 HS 5 4458.12 72.06 311.69 4051.5 805.2 574.4 -579.8 3.29 2.97 1.51 20 80 450 1700 4363 4395 HS 110 5 4552.91 71.66 311.77 4081.0 893.1 634.4 -647.0 0.43 -0.42 0.08 20 80 450 1700 110 5 4648.88 75.77 312.01 4107.9 983.1 695.9 -715.6 4.29 4.28 0.25 20 450 1700 4610 4649 15R 52 5 4743.72 77.49 312.83 4129.8 1073.5 758.1 -783.7 2.00 1.81 0.86 20 80 450 1700 4649 4665 15R 110 5 4705 4710 15R 5 4801.70 77.69 313.34 4142.3 1129.0 796.8 -825.1 0.93 0.34 0.88 20 450 1700 4800 4802 30R 70 5 4899.23 82.88 315.61 4158.8 1223.8 864.1 -893.6 5.79 5.32 2.33 10 300 3450 4802 4861 30R 36 6 4881 4899 30R 6 4944.03 88.02 318.39 4162.3 1268.1 896.8 -924.1 13.03 11.47 6.21 15 250 2750 4899 4917 30R 10 6 4917 4944 30R 6 4993.44 88.64 324.70 4163.7 1317.4 935.4 -954.8 12.83 1.25 12.77 15 250 2500 4944 4951 30R 84 6 4951 4991 84R 6 4991 4993 84R 6 5039.61 89.51 326.86 4164.5 1363.5 973.6 -980.7 5.04 1.88 4.68 5 60 275 2740 4993 5009 84R 60 6 5009 5028 60R 6 5099.28 89.01 329.19 4165.3 1423.0 1024.2 -1012.3 3.99 -0.84 3.90 5 60 275 2850 5054 5076 84R 93 6 5134.14 89.45 330.08 4165.7 1457.7 1054.3 -1029.9 2.85 1.26 2.55 5 60 275 2950 80 6 5179.09 90.80 330.97 4165.6 1502.4 1093.4 -1052.1 3.60 3.00 1.98 5 60 275 3050 5136 5166 14R 78 6 5229.13 89.57 329.97 4165.5 1552.1 1136.9 -1076.7 3.17 -2.46 -2.00 8 60 275 3150 112 6 5278.45 93.09 330.76 4164.3 1601.2 1179.8 -1101.1 7.31 7.14 1.60 15 275 3150 5245 5278 14R 80 6 5323.22 91.05 330.55 4162.7 1645.6 1218.8 -1123.0 4.58 -4.56 -0.47 8 60 275 3250 5278 5281 14R 116 6 5373.00 87.96 329.99 4163.1 1695.1 1262.0 -1147.7 6.31 -6.21 -1.12 8 60 275 3300 5326 5346 170R 110 6 5418.59 89.20 331.05 4164.3 1740.4 1301.7 -1170.1 3.58 2.72 2.33 8 60 275 3300 5390 5410 11R 110 6 5464.03 92.22 331.56 4163.1 1785.5 1341.5 -1191.9 6.74 6.65 1.12 20 275 3000 5438 5464 11R 19 6 ------------------- sperT'y-!5U1 PaQe: 3 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 Kin 4 ST Location: Spy Island CI...I.L. Nil.. ..VIC.. RIg: Nordic 3 Job 1# :AK-MJ-0003523133 Survey and Drilling Parameters North Ref: True Declination: " VS Dlr : 324.15" (from Wellhead) WEU..BORE SURVEY DRlWNG PARAMETERS lIea.ured Incl Azl Vertical Vertical Coordinate. DLS Build Turn WOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth AnRle Dlr Depth Section NIS r:M Rate Rate Rate Pipe From To Face No. (ft) (des) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbl) (gpm) (pII) (ft) (ft) (deg) .ftlhr) (#) 5513.96 90.86 331.44 4162.4 1835.0 1385.4 -1215.8 2.73 -2.72 -0.24 8 60 275 3100 5464 5468 11R 128 6 5558.88 89.20 331.28 4162.3 1879.5 1424.8 -1237.3 3.71 -3.70 -0.36 8 60 275 3100 5532 5535 LS 115 6 5608.70 89.01 330.84 4163.1 1929.0 1468.4 -1261.4 0.96 -0.38 -0.88 8 60 275 3000 40 6 5660.58 89.94 330.54 4163.6 1980.5 1513.6 -1286.8 1.88 1.79 -0.58 5 60 275 2900 5638 5645 HS 130 6 5706.12 90.00 330.49 4163.6 2025.8 1553.3 -1309.2 0.17 0.13 -0.11 5 60 275 3000 5675 5684 HS 120 6 5749.96 89.26 330.36 4163.9 2069.4 1591.4 -1330.8 1.71 -1.69 -0.30 5 60 275 2900 123 6 5801.31 88.70 330.51 4164.8 2120.4 1636.1 -1356.2 1.13 -1.09 0.29 5 60 275 2900 113 6 5851.41 88.58 330.45 4166.0 2170.2 1679.7 -1380.9 0.27 -0.24 -0.12 5 60 275 3000 5816 5825 10R 112 6 5896.40 89.44 330.90 4166.8 2214.9 1718.9 -1402.9 2.16 1.91 1.00 5 275 3000 5889 5896 10R 150 6 5948.19 89.38 330.49 4167.3 2266.3 1764.0 -1428.2 0.80 -0.12 -0.79 5 60 275 3100 5896 5904 10R 140 6 5945 5947 10R 6 5991.26 90.25 330.58 4167.5 2309.1 1801.5 -1449.4 2.03 2.02 0.21 5 60 300 3300 5952 5961 10R 120 6 5972 5987 HS 6 6041.68 90.06 330.07 4167.3 2359.2 1845.3 -1474.4 1.08 -0.38 -1.01 5 60 300 3300 95 6 6086.06 89.07 328.58 4167.7 2403.4 18~3.5 -1497.0 4.03 -2.23 -3.36 5 60 300 3300 . 6042 6050 HS 107 6 6140.41 88.40 327.79 4168.9 2457.6 1929.7 -1525.7 1.91 -1.23 -1.45 5 60 300 3300 100 6 6181.68 90.25 327.99 4169.3 2498.8 1964.6 -1547.6 4.51 4.48 0.48 5 60 300 3450 6151 6173 20R 93 6 6234.41 89.75 327.58 4169.3 2551.4 2009.2 -1575.7 1.23 -0.95 -0.78 5 60 300 3450 117 6 6277.34 89.26 327.74 4169.7 2594.3 2045.5 -1598.7 1.20 -1.14 0.37 10 60 275 3250 6246 6247 70R 62 6 6326.07 88.52 328.09 4170.7 2642.9 2086.8 -1624.5 1.68 -1.52 0.72 10 60 275 3250 112 6 6373.02 87.59 327.64 4172.2 2689.7 2126.5 -1649.5 2.20 -1.98 -0.96 10 60 275 3300 104 6 6420.47 89.81 329.80 4173.3 2737.0 2167.1 -1674.1 6.53 4.68 4.55 20 275 3300 6381 6420 45R 33 6 6467.73 89.44 330.39 4173.6 2784.0 2208.0 -1697.7 1.47 -0.78 1.25 10 60 275 3300 6420 6426 45R 69 6 6515.29 88.83 330.04 4174.4 2831.3 2249.3 -1721.3 1.48 -1.28 -0.74 10 60 275 3400 100 6 6562.61 87.35 329.06 4175.9 2878.4 2290.1 -1745.3 3.75 -3.13 -2.07 10 60 275 3400 130 6 6608.25 90.12 329.70 4176.9 2923.8 2329.3 -1768.5 6.23 6.07 1.40 20 275 3400 6581 6608 45R 120 6 6657.62 88.83 329.97 4177.4 2972.9 2372.0 -1793.3 2.67 -2.61 0.55 10 60 275 3400 6608 6611 45R 130 6 6706.23 91.48 331.01 4177.3 3021.2 2414.3 -1817.3 5.86 5.45 2.14 10 60 275 3400 6675 6695 20R 108 6 ------------------- Ei~erarv·!5U1 PaQe: 4 Operator: Kerr McGee Field: Western North Slope Well: NikaitchuQ #4 Kin 4 ST Location: Spy Island a"II..L.1 Nil.. ..VIC.. Rig: Nordic 3 Job # :AK~MJ·OOO3523133 Survey and Drilling Parameters North Ref: True Declination: ° VS Dlr : 324.15° (from Wellhead) WEU.BORE SURVEY DRlWNG PARAMETERS IIeasurad Incl Azl Vertical Vertical Coordinates DLS Build Turn VVOB RPM Flow Stand Orientation Tool ROP BHA Comment Depth AnAle Dlr Depth Section NIS ew Rite Rite Rite Pipe From To Face No. (ft) (deg) (deg) (ft) (ft) (ft) (ft) (°/100') (°/100') (°/100') (klbs) (gpm) (pII) (ft) (ft) (deg) :ftlhr) (#) 6751.83 89.14 330.24 4177.0 3066.5 2454.0 -1839.6 5.40 -5.13 -1.69 10 60 275 3400 6728 6738 LS 113 6 6813.37 87.78 329.90 4178.7 3127.7 2507.4 -1870.3 2.28 -2.21 -0.55 10 60 275 3400 96 6 6848.17 87.59 329.94 4180.1 3162.3 2537.4 -1887.8 0.56 -0.55 0.11 10 60 275 3400 6817 6832 20R 124 6 6896.20 87.90 330.93 4182.0 3210.0 2579.2 -1911.4 2.16 0.65 2.06 10 60 275 3400 6858 6880 20R 96 6 6942.18 91.36 331.12 4182.3 3255.7 2619.4 -1933.7 7.54 7.53 0.41 5 275 3400 6912 6942 HS 125 6 6992.03 91.67 331.87 4180.9 3305.1 2663.2 -1957.5 1.63 0.62 1.50 10 60 300 3700 6942 6962 HS 42 6 7036.49 90.49 332.24 4180.1 3349.1 2702.5 -1978.3 2.78 -2.65 0.83 5 275 3300 7024 7036 LS 60 6 7084.36 89.38 331.70 4180.2 3396.6 2744.7 -2000.8 2.58 -2.32 -1.13 5 60 275 3400 7036 7041 LS 114 6 7132.16 88.46 331.69 4181.1 3443.9 2786.8 -2023.5 1.92 -1.92 -0.02 5 60 290 3400 132 6 7180.29 88.64 331.78 4182.3 3491.6 2829.2 -2046.3 0.42 0.37 0.19 5 60 290 3400 7160 7172 HS 100 6 7226.83 88.46 330.50 4183.5 3537.8 2869.9 -2068.7 2.78 -0.39 -2.75 5 60 290 3400 7197 7212 70L 97 6 7272.86 90.25 332.65 4184.0 3583.4 2910.4 ~2090.6 6.08 3.89 4.67 5 60 290 3400 7252 7257 HS 100 6 7322.64 89.38 332.12 4184.1 3632.7 2954.5 -2113.7 2.05 -1.75 -1.06 5 60 290 3400 120 6 7372.19 89.32 332.41 4184.7 3681.8 2998.4 -2136.8 0.60 -0.12 0.59 5 60 275 3200 7330 7348 40L 112 6 7417.40 90.31 331.62 4184.8 3726.5 3038.3 -2158.0 2.80 2.19 -1.75 5 275 3200 7408 7417 45L 83 6 7468.08 89.14 332.09 4185.1 3776.8 3083.0 -2181.9 2.49 -2.31 0.93 5 60 275 3200 7417 7426 45L 96 6 7511.90 90.19 329.88 4185.3 3820.3 3121.3 -2203.1 5.58 2.40 -5.04 5 275 3200 7482 7512 60L 42 6 7577.00 89.00 329.88 4185.8 3885.0 3177.6 -2235.8 1.83 -1.83 . 0.00 7512 7512 60L 6 I I I I I I I I I I I I I I I I I I I Operator: Kerr McGee Well: NikaitchUQ #4 Field: Western North Slope Location: Spy Island Rig: Nordic 3 Jœ f' AK-MJ-0003,)~3133 !iLJM C..ILLI Nil B...VIC.. I BHM 1 : Date In 2/112005 MD In (ft): 115 TVD In(ft) : BlTDATA I Bit" OD (in) 1 12.250 MOT~ DATA I Run" OD (in) 8.000 RHA Report MFR t-luRhes MFR SSDS COMPONENT DATA Item Description #I 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 Roller Cone Steel 8" SpenyDriI Lobe 6/7 - 4.0 stø Non-MaQ Float Sub NM Sleeve Type Stabilizer 8" Gamma , Resistivitv f1' OM HOC f1' 1M HOC Non-Maø Flex DriI Collar Non-Mag Flex DriI Collar Non-Maø Flex CriR Collar Cross Over Sub Cross Over Sub 6 x H\NDP DrillinQ Jar 14 x HWDP RHV1 Date Cur 2/112005 Me Cur(ft): 287 TVD Cur(ft): Style GT1 Nozzles (132'8) TFA (in2) Dull Condition 1x18. 1x12, 2x16 0.752 Seria.. 5065661 Model Bend 1.50" NzI (132's) Ava Dif (psi) Cum Cirç Hrs I 101 4.58 SøenvDriII Seria.. 800306 Serial OD ID Gauae WeiAht Top Con LenAth Bit - Center #I (in) (in) (in) (lbsIft) (ft) Blade (ft) 5065661 12250 3.000 12.250 377.57 P 6-518" Rea 1.00 aoœœ 8.000 5.250 12.000 97.54 B 6-518" H90 29.20 3.25 4149 8.090 2.780 154.49 B 6-5/t1' H90 2.29 77005 8.120 2.870 12.125 154.44 8 6-518" H90 5.16 35.89 69362 8.010 2.880 149.53 8 6-518" Rea 23.20 167964 8.000 3.250 143.03 8 6-518" Reø 9.20 143784 8.130 2.880 154.72 86-518'" H90 9.59 192417 8.040 2.870 150.97 B 6-518'" H90 31.02 192413 8.040 2.870 150.97 86-518'" H90 31.01 192421 8.040 2.870 150.97 B 6-518ft H90 31.00 3706 7.790 2.870 140.38 84-112" IF 3.01 O3T 6.500 3.000 89.00 8XT39 1.14 4.000 2.563 29.70 BXT39 184.11 16220016 6.250 2.250 91.01 B XT39 31.44 4.000 2.563 29.70 8XT39 429.46 821.83 Parameter 'M)8 (klbs) : RPM (rpm) : rww huml) ; CjPP (.,.1) : PERFORMANCE Min Max 3 10 50 60 300 600 X'O 2075 Ave ActiVitY Hrs BHA Weipht (Ib) Drill String 6 Drilling : 2.00 in Air (Total) 46299 54 Reaming: 0.75 in Mud (Total) 426 ::irc-Other : 1.83 in Air (Bel Jar! : 3C582 10>t Tobl: 458 " iø tI\Id (9.' Jar: In Out Inclination (deA) Azimuth (deA) COMMENTS I Motor = .15 RevIGaI Bit to Dir = 65.47 Bit to Res = 48.50 Bit to Ganvna = 40.98 OD(in) Len(ft) Oriented : Rotated : Tntal . Dlstançe (ft) 10.00 162.00 17?M Builet (°/100'\, Tum CO/1OO') DLS <:"100') ROP(ftlhr) 145 82 AA I I I I I I RHA ~port p!2g~ ? Operator: Kerr McGee Well: NikaitchuQ #4 Field: Western North Slope Location: Spy Island Rig: Nordic 3 Job 11: ~Y.-MJ-Q003.5')'jn) SLfAff 1 sr....1 -I Y-SL..rI a"U..L.IN. ....Vl~.. ~CTlVES: This BHA win spud the well and drill a straight hole to approximately 2450'. RESULTS: y I I I I I I I I I I I I I This assembly drilled its way into the hole with no major problems. Initially, it was necessary to reduce o'~ 300 gpm in order to start shearing the mud as well avoiding any washing of the shoe at 115'. As we got deeper, the mud ~ out and we were able to driB with 600+ gpm. The mud cleaning systems seemed best able to cope with a rate of penetration of 200 fph or less. Three short slides were necessary to keep the hole near vertical. We drilled to the casing point picked by the customer at 2464' and the assembly was pulled out of the hole. Altogether this assembly was on botIDrn for 23.75 hours. The bit was graded as 4.3.WT AE.1.ER.TD I I I I I I I I I I I I I I I I I I I 0.0. 12.25" 8" 8.09" 8.12" 8.01" 8" 8.13" 8.04" 8.04" 8.04" 7.79" 6.5" 4" 6.25" 4" ...,. 1~-5I.Jn CAIL.L.ING seAVlces Length l' 29.2' 229' 5.16' 23.2' 92' 9.59' 31.02' 31.01' 31' 3.01' 1.14' 184.11' 31 .44' 429.46' BHA Schematic Kerr McGee Nikaitchuq #4 BHA IO#: 1 Spud Assembly BHA Configuration Description Roller Cone Steel 8" SperryDrilllobe 6/7 - 4.0 ág Non-Mag Float Sub NM Sleeve Type Stabilizer 8" Gamma / Resistivity 8" OM HOC 8" TM HOC Non-Mag Flex Drill Collar Non-Mag Rex Drill Collar Non-Mag Rex Drill Collar Cross Over Sub Cross Over Sub 6 x HWDP Drilling Jar 14 x HWDP BHA Discussion Motor = .15 Rev/Gal Bit to Dir = 65.47 Bit to Res = 48.50 Bit to Gamma = 40.98 Box XT39 14 x HVVDP Box XT39 Drilling Jar Box XT39 6xHWDP Box XT39 Cross Over Sub Box 4-112" IF Cross Over Sub Box 6-5/8" H90 Non-Mag Flex Drill Collar Box 6-5/8" H90 Non-Mag Flex Drill Collar Box 6-5/8" H90 Non-Mag Flex Drill Collar Box 6-518" H90 8" TM HOC Box 6-518" Reg 8" OM HOC Box 6-5/8" Reg 8" Gamma I Resistivity Box 6-5/8" H90 NM Sleeve Type Stabilizer Box 6-518" H90 Non-Mag Float Sub Box 6-5/8" H90 8" Sperry Drill Lobe 6/7 - 4.0 stg Pin 6-5/8" Reg Roller Cone Steel I I I I I I I I I I I I I I I I I I I Operator: Kerr McGee Well: NikaitchuQ #4 Field: Western North SlOPe Location: Spy Island Rig: Nordic 3 Job.: AJ(-MJ-OOO'3'>1'31'3'3 f'HA1t ., C..ILLINII ....VIC.. RHA Report BHA# 2 : Date In 2/612005 MD In (ft): 2464 TVD In(ft) : 2463 Date Out2f712OO5 YO OUt(ft): 4120 1VD OUt(ft): 4119 BrrDATA I Bit, œ (in) MFR Style Serlal# Nozzles (/32'5) lFA (ioa) Dull Condition 2 8.500 HUQhes GT1 5061473 3x16 0.589 1-2-wT -G -E-2-NO-CP MOTOR DATA I Run' œ (in) MFR Model SeriaI# Bend NzI (/32's) Ava Dif (psi) Cum Circ Hrs I 2 6.920 SSDS SperrvDriH 76658 1.50" 172 23.64 cowaoNENT DATA Item Description Serial œ ID GauQe WeiQht Top Con LenAth Bit - Center f. # (in) (in) (In) (lbsIft) (ft) Blade (ft) 1 Roller Cone Steel 5061473 8.500 3.000 8.500 169.30 P 4-1fZ' Rea 0.80 2 T SøenYDrilllobe 7/8 - 6.0 stø 76668 6.920 4.753 8.190 67.71 84-1fZ' IF 24.65 2.91 3 Non-MaQ Float Sub 3785 6.700 2.880 97.95 8 4-1fZ' IF 2.43 4 InteQral Blade Stabilizer 184970 6.760 2.880 8.250 100.11 84-1fZ' IF 5.62 30.20 5 GamnaIRes 66153 6.750 2.880 99.75 8 4-1fZ' IF 23.73 6 eM HOC 195258 6.800 2.880 101.57 8 4-1fZ' IF 9.14 7 1M HOC 143792 6.580 2.880 93.69 84-1fZ' IF 9.95 8 Non-Maa FIeK DriB CoIar 1~ 6.750 2.880 99.75 84-1fZ'1F 31.08 9 Non-Maa FIeK DriB CoIar 216435 6.750 2.880 99.75 84-1fZ' IF 31.09 10 Non-Maø FIeK DriB Collar 215436 6.750 2.880 99.75 84-112" IF 31.09 11 Cross Over Sub 03T 6.500 3.000 89.00 8XT39 1.14 12 6 x H\MJP 4.000 2.563 29.70 8XT39 184.11 13 DriIIinQ Jar 16220016 6.250 2.250 91.01 8 XT39 31.44 14 14xH\M)p 4.000 2.563 29.70 8XT39 429.46 815.73 Parameter Min Max Ave ActiVity Hrs BHA Weight (lb) Drill String COUn) Len(ft} WOB(klbs) : 5 15 10 Drilling : 14.55 In Air (Total) 37321 DP(S)-XT3915.66tI 4.000 3304 RPM (rpm) : 70 80 80 Reaming: 2.40 in Mud (Total) 31974 Flow (gpm} : 100 500 4741 "'Irc-othor : 6.69 In Air (Be' Jar! : 21705 SPP (I"i) . 8~ 2100 1823 r T(\taJ . 23.64 iA flu<l (S.I J..., : 18~5 PERFORMANCE In Out Pistar'lce(ft) RQP(ftlhr) Inclination (deg) 1.64 1.18 Oriented : 0.00 0 Azimuth (dea) 103.99 85.88 Rotated : 1656.00 114 Tn"" . 11t'iR no 114 Build ("/100') Tu'r'I ("/100') Dl.S ("/100') 0.23 -0.01 -11m -1.04 _1 no 004 COMMENTS Motor = .29 RevIGaI Bit to Gamma: 37.25 Bit to Res: 45.00 Bit to Survey: 61.93 I I I I I I I I I I I I I I I I I I I Operator: Kerr McGee Well: NikaitchuQ #4 Field: Western North SloPe Location: Spy Island Rig: Nordic 3 J9b 11: ÞI" .14J OD03'j?31'33 ~HA:' 2 g".I.....1 Nil .."VII:.. RHA RE'rort ~~? OBJECTIVES: This BHA will driB the pilot hole to core point RESULTS: This BHA tagged the plug at 2333'. We drilled through the plug and stopped ten feet above the float collar. The casing test at 2500 psi for one half hour was successful. We then continued to drill cement. the float collar, shoe and rathoIe to 2464' Twenty feet of new hole was drilled and a leak off test performed. DriHing commenced with a low flow rate until the mud warmed up and sheared. Flow rates were increased until we could circulate 500 GPM. The assembly drilled fairly straight, having an average dogleg of -0.23 degrees per hundred feet and an average build of -0.01 and walk of -1.04. Core point was called at 4120 and the assembly was pulled out of the hole. The bit was graded as 12.WT.G.E.118.NO.CP I I I I I I O.D. 8.5" 6.92" 6.7" 6.76" 6.75" 6.S" 6.SS" 6.75" 6.75" 6.75" 6.5" 4" 6.25" 4" I I I I -, ~-!5LJn CAIL-L.INtI SEAVICES BHA Schematic Motor = .29 Rev/Gal Bit to Gamma: 37.25 Bit to Res: 45.00 Bit to Survey: 61.93 I I I I I I I I I Kerr McGee Nikaitchuq #4 BHA ID#: 2 Pilot Hole Assembly BHA Configuration length 0.8' 24.65' 2.43' 5.62' 23.73' 9.14' 9.95' 31.08' 31.09' 31.09' 1.14' 184.11' 31.44' 429.46' Descñption Roller Cone Steel 7" SpenyDrilllobe 7/8 - 6.0 stg Non-Mag Float Sub Integral Blade Stabilizer Gamma/Res OM HOC 1M HOC Non-Mag Flex Drill Collar Non-Mag Rex Drill Collar Non-Mag Rex Drill Collar Cross Over Sub 6 x HIi'JDP Drilling Jar 14 x HWDP BHA Discussion Box xn9 14 x HINDP Box XT39 Drilling Jar Box XT39 6 x HVVDP Box XT39 Cross Over Sub Box 4-1/2" IF Non-Mag Flex Drill Collar Box 4-1/2" IF Non-Mag Flex Drill Collar Box 4-1/2" IF Non-Mag Flex Drill Collar Box 4-1/2" IF TM HOC Box 4-1/2" IF OM HOC Box 4-1/2" IF Gamma/Res Box 4-1/2" IF Integral Blade Stabilizer Box 4-1/2" IF Non-Mag Float Sub Box 4-1/2" IF 7" SperryDrill Lobe 718 - 6.0 st9 Pin 4-1/2" Reg Roller Cone Steel I I I I I I I I I I I I I I I I I I I IiLJn C..ILLI NCI !I...VIC.. ~HA R£..port Operator: Kerr McGee Well: NikaitchUQ #4 FJeld: Western North Slope Location: Spy Island Rig: Nordic 3 Job,: WrMJrOOO'35?'31'3'3 RHNt 3 BHA# 3 : Date In 217/2005 MD In (ft) : 4120 TVD In(ft) : 4119 Date Cur2J9/2005 MD Cur(ft): 4180 TVD Cur(ft): 4179 BlTDATA I Bit. œ (in) 8.500 IIIFR HuQhes MOTOR DATA_ I Run" œ (in) COMPONENT DATA Item Description ## 1 2 3 4 POC Corinø Bi Core Barrel Assrr Cross Over Sub 18 x HINDP Parameter V\.a3 (klbs) : RPM (rpm) : FfOWfapm) : 'PP (psi) = PERFORMANCE Min Max Inclination (dea) Azimuth (dea) In 1.18 85.88 COMMENTS IIIFR Out 1.09 82.76 Style Serial# Nozzles (/32's) TFA (io2) Dull Condition GT1 5061473 0.000 Model SeriaI# Bend NzI e/32's) Ava Dif (psi) Cum Clre Hrs t Serial OD ID Gauae Weiaht Top Con Lenath Bit - Center ## (in) (in) (In) (lbsIft) (ft) Blade (ft) 5061473 8.500 3.000 8.500 169.30 P 4-1J2" Rea 1.30 6.750 5.375 44.62 B 4-1J2" IF 77.07 03T 6.500 3.000 89.00 B XT39 1.14 4.000 2.563 29.70 B XT39 553.42 632.93 Ave Activity Drilling: Reaming: ::irc-other : Tot~l= Oriented : Rotated : Tnt2I- Hrs 7.50 0.00 0.00 7.'50 BHA Weight in Air (Total) In Mud (Total) in Air (Bel Jan : iA .'ud (h' Jar: (lb) 20197 17304 I) o Drill String DP(S)-XT3915.66# œ(in) len(ft) 4.000 3547 Distance (ft) 0.00 60.00 MOO ROP(Whr) o o R 01R Build ('"MOO') Tum e/100') DLS (o/1QO') ..0 1~ -~ ?1 I I I I I I I I I I I I I I I I I I I g",. L.L.I Nil .."'VI a:: _. RHA RJ?port p.?~? OBJECTIVES: The objective of this run is to core 50' of formation. RESULTS: The assembly ran easily into the hole. Sixty feet of foonation were cored and the assembly was pulled out of the hole. Operator: Kerr McGee Well: NikaitchuQ #4 Field: Western North Slope Location: Spy Island Rig: Nordic 3 Jcb 1f' Þr MJ-aoo'k~)n) 91.f^tf ') I I I I I I I I I I I I I I I I I I I 0.0. 8.S" 6.75" 6.5" 4" .., ~-sun CRI~~INI3 SERVICES Length 1.3' 77.07' 1.14' 553.42' BHA Schematic Kerr McGee Nikaitchuq #4 BHA ID#: 3 Coring Assembly BHA Configuration Description PDC Coñng Bit Core Barrel Assm Cross Over Sub 18 x H'v\OP Box XT39 18 x H\IIJ[)P Box XT39 Cross Over Sub Box 4-1/2"'F Core Barrel A$sm ~ Pin 4-1/2" Reg ~U.)p! PDC Coring Bit I I I I I I I I I I I I I I I I I I I Operator: Kerr McGee Well: NikaitchUQ #4 FJeld: Western North Slope Location: Spy Island Rig: Nordic 3 Jobf: ~KrMJ-0003S2'313'3 RHV. C"ILLINII .."VIC.. RHA Report l BHA# 4 : Date In 21912005 MD In (ft) : 4180 TVD In(ft) : 4119 Date CUt 211 012005 MD Cur(ft): 4310 TVD Cur(ft): 4309 BIT DATA I Bit. OD (in) MFR Style Seria.. Nozzles (132's) TFA (ina) Dull Condition 2n1 8.500 Huøhes GT1 5061473 3x16 0.589 1-2-wT-G -E-2-NO- TD MOT~DATA , Run' OD (in) MFR Model Seria.. Bend NzI (l3r8) Ava Dif (psi) Cum Circ Hrs t 3 6.920 SSDS SøerrvDriII 76658 1.50" 98 28.49 COMPONENT DATA Item Description Serial OD ID Gauge Weiaht TOD Con LenathBit - Center , t (in) (in) (in) (lbsJft) . (ft) Blade (ft) 1 Roller Cone Sleet 5061473 8.500 ' 3.000 8.500 169.30 P4-112" Reø 0.80 2 T SoenvDriII Lobe 7/8 - 6.0 sta 76658 6.920 4.753 8.190 67.71 B 4-112" IF 24.65 2.91 3 Non-MaQ Float Sub 3785 6.700 2.880 97.95 84-112"F 2.43 4 In1eQra1 81ade Stabilizer 184970 6.760 2.880 8.250 100.11 B 4-112" IF 5.62 30.20 5 GarrrnaIRes 66153 6.750 2.880 99.75 B 4-112" IF 23.73 6 [».1 HOC 195258 6.800 2.880 101.57 B 4-112" IF 9.14 7 1M HOC 143792 6.580 2.880 93.69 84-112" IF 9.95 8 Non-MaQ Flex DriI Collar 184655 6.750 2.880 99.75 84-112" IF 31.08 9 NR- 90069827Y6 6.570 2.810 94.40 B4-1I2"F 38.70 10 Non-MaR Flex DriB Collar 216435 6.750 2.880 99.75 B 4-112" IF 31.09 11 Non-MaQ Flex DñI Collar 215436 6.750 2.880 99.75 B 4-112" IF 31.09 12 Cross Over Sub 03T 6.500 3.000 89.00 BXT39 1.14 13 6 x HV\IDP 4.000 2.563 29.70 BXT39 184.11 14 DrillinQ Jar 16220016 6.250 2.250 91.01 B XT39 31.44 15 14 x HV\IDP 4.000 2.563 29.70 BXT39 429.46 854.43 Parameter Min Max Ave Activity Hrs BHA WeiAht (lb) Drill StñnA OD(in) Len(ft) WOB (klbs) : 15 20 16 Drilling : 2.30 In Air (Total) 40975 DP(S}-XT3915.66# 4.000 3456 RPM (rpm) : 80 80 80 Reaming: 0.79 in Mud (Total) 35104 Flow (APm) :' 500 500 500 :irc-Oti\fír : 1.70 I In Air (Bel Jar! : 25359 C)PP (p.i) . 2'375 2'375 7)75 To"·: 485 iA "ud (9.1 Jar' 21725 PERFORMANCE I Inclination (dea) Azimuth (dea) In 1.20 92.61 Out 1.16 103.44 ~tØld (°/100') ,rum (0/100') DLS (°/1 00') PI~nce(ft} 0.00 130.00 1::!onn ROP(ftlhr} o 57 !'o7 Oriented : Rotated : Tnbl' .nO? R~"'I 017 CO_ENTS I Motor = .29 RevIGal Bit to Gamma: 37.25 Bit to Res: 45.00 Bit to Survey: 61.93 I I I I I I I I I I I I I I I I I I I a.. 11.."" Nil ....VII:.. RHA ~port p:}~ ? OBJECTIVES: Operator: Kerr McGee Well: NikaitchUQ #4 Field: Western North Slope Location: Spy Island Rig: Nordic 3 J~ 1f ·~YMJw)11j21111 PH~4 This BHA will TO the pilot hole at 431 rr. It will also run the MIRL through the cored section. RESlL TS: The section of the well that was cored, 4120' to 4180', was reamed and once through this section we drilled to a MD of 431 0 which TO'ed the pilot hole. At TO we circulated two bottoms up and POOH. The trip out went without any issues. The well bore inclination declined sflQhtIy from 1.34° to 1.14° between POOH for the core run and TO of the well. The azimuth also only turned slightly from 87.42" to 98.49 0. I I I I I I I I I I I I I I I I I I I lip" 'V-15I.Jn C"ILLI Nil .."VIC.. RHA R~.port BHAI 5 : Date In 2I12J2Oœ MD In (ft) : 2863 BIT DATA J BIt ## OD (In) 4 8.500 MOTOR DATA I Run ## OD (in) 3 6.920 MFR HuQhes Style MX-C1 Operator: Kerr McGee Well: NikaítchuQ #4 Kin 4 ST Field: Western North Slope Location: Spy Island Rig: Nordic 3 Job1f' ~MJ-OOO'3"?'31'3'3 RHJ\# 5 MFR SSDS Model SøerrvDnll TVD In(ft) : 2862 Date Cur2J13/2005 MD Cur(ft): 4861 TVD Cur(ft): 4153 Seria.. 6021025 Nozzles (/32°s) TFA (inZ) Dull Condition 3x15,1x12 0.628 2-3-WT-A-E-1-CT-ID SeriaW 76658 NzI (/32"s) Avø Dif (osi) Cum Cire Hrs 199 63.31 Bend 1.50" COMPONENT DATA Item Description Serial OD ID Gauae Weight Top Con Length Bit - Center ## #I (In) (in) (in) (lbsIft) (ft) Blade (ft) 1 Roller Cone Steel 6021025 8.500 3.000 8.500 169.30 P 4-1fZ' Rea 0.80 2 T SøerrvDrilllobe 7/8 - 6.0 sfA 76658 6.920 4.753 8.190 67.71 84-1/Z' IF 24.65 2.91 3 Non-Maø Float Sub 3785 6.700 2.880 97.95 B4-1/Z' IF 2.43 4 GarrmaIRes 66153 6.750 2.880 99.75 B4-1fZ' IF 23.73 5 ~HOC 195258 6.800 2.880 101.57 B 4-1fZ' IF 9.14 6 1M HOC 143792 6.580 2.880 93.69 B4-1fZ' IF 9.95 7 Non-Maø Flex DriB Collar 184655 6.750 2.880 99.75 B 4-1fZ' IF 31.08 8 Non-Maa Flex DriB Collar 216435 6.750 2.880 99.75 84-1fZ' IF 31.09 9 Non-Maa Flex DriI Collar 215436 6.750 2.880 99.75 B 4-1/Z' IF 31.09 10 Cross Over Sub 03T 6.500 3.000 89.00 B XT39 1.14 11 6 x HVIDP 4.000 2.563 29.70 B XT39 184.11 12 DnllinQ Jar - 63.87 Hrs 16220016 6.250 2.250 91.01 B XT39 31.44 13 14 x HIMJP 4.000 2.563 29.70 B XT39 429.46 810.11 Parameter Mln 'M)ß (klbs) : 10 RPM (rpm): 80 Flow lapm) : 450 SPP (psi) : 1600 PERFORMANCE I Inclination (dea) Azimuth (dea) COMMENTS Motor = .29 RevIGaI Bit to Gamma: 31.63 Bit to Res: 39.38 Bit to Survey: 56.31 Max 20 80 450 171"0 Ave 18 80 450 1641 , Activity Drilling : Reaming: ::;¡'G-otnet . Tobl: In Out 1.39 81.80 86.32 315.00 Oriented: Rotated: Tnbl· HIS 22.95 4.74 7:13 34.82 BHA Weight (lb) In Air (Total) 36759 in Mud (Total) 31548 inAir (BelJal'i~ 21143 Ir Vud (p.lJar· 1814/3 Drill String DP(S)-XT3915.66# OD(in) len(ft) 4.000 4051 Distance (ft) 1133.00 865.00 1QMM ROP (ftlhr) 71 100 trT Build ("/1,00') Turn (°/100") OLS r(1000) 4.14 4.02 40? -6.57 ..R !'t7 414 I I I I I I I I I I I I I I I I I I I Operator: Kerr McGee Well: NikaitchuQ #4 Kin 4 S1 Field: Western North Slope Location: Spy Island Rig: Nordic 3 Jnþ1t. 41': MJ-~1113 ~Nt$ CI"II.L.INII .."VIC.. RHA RÆ'rort p:i{)ß? OBJECTIVES: This BHA wi! kick off the well at 2863' inthe direction of 311 degrees azimuth and build at a maximum of 6 degrees per hundred feet until the pump setting zone at 72degrees inclination. We will run a tangent section of two hundred feet and continue building at 7.7 degrees per hundred feeet until landing 90 degrees at a vertical depth of 4145'. RESULTS: At 2863 we !aged cement and circulated bottoms up as the shaker was overflowing at our desired flow rates. lNhen we tagged the cement we were able to apply 20k VIIOB. We started time driling at 2.5 minutes an inch for 3' and observed that the string was taking weight and slight indications of reactive torque. We were using 450 GPM flow rates. We drilled an additional 3' at 2 minutes an inch and then increased the drilling time to 1 minute an inch down to 2875'. At this depth we were able to driB ahead without any time drilling. DriUing down to 3031 produced varying ROP's but the assembly would produce calculated 7.81 doglegs in complete slide. At 3055' and again at 3058' we encountered hard stringers that slowed the ROP down to 15'1hour. Drilling continued without incident. Once into the Ugnu formation the assembly produced consistent 4.5· to 5· doglegs with 55 to 60' of slide; this calculated out to -8.75 dogleg assembly prodUCtion for complete sets. As we drilled deeper to - 65·. into the Shraeder Bluff formation, the dogleg increased to calculated 10's with maximums up to 13'5. As the geologiacl samples were taken and extrapolated, it was decided to aim for a landing at 4160' TVD. Our direåionaI plans were altered to suit the needs of the customer. We driB to a total depth of 4861' and the assembly was pulled out of the hole. Altogether this assembly drilled 1998' of hole of which 1133' were oriented and 865' were rotated. The rate of penetration averaged ffT feet per hour with T7 feet per hour orienting and 100 feet per hour rotating. The bit was graded as 2J3IWT1AJE/1/CfITD. - - -- spEr'r"'V-sun CAIL..L..INCI .."'VIC.1ii BHA Schematic - O.D. 8.5" 8.92" 8.7" 8.75" 8.8" 8.58"' 8,7&' 8.7&' 6.7&' 6.&' 4" 6.25" 4" Motor = .29 Rev/Gal B~ to Gamma: 31.63 Bit to Res: 39.38 SU" Survey: 56.31 Kerr McGee Nikaitchuq #4 BHAID#: 5 Build Assembly BHA Configuration Length 0.8' 24.6fI 2.43" 23.7"$ 9.14' 9.95' 31.08' 31.09' 31.09' 1.14' 184.11' 31.44' 429.46" D.....rlptlon Roller Cone Steel 7" Sperr)Ðrill Lobe 7/8 " E. C sig Non-Mag Floe! Sub Ganma/Rea DM HOC TM HOC Non-Mag FIØ)C Drill Collar Non-Mag FIØ)C Drill Collar Non-Mag FIØ)C Drill Collar Cross O\er Sub 8) HWDP Drilling Jar " 63.87 Hrs 14)HWDP BHA Discussion - - - - i Box XT39 14xHWDP Box XT39 Drilling Jsr - 63.87 Hrs _ Box XT39 § 8 x HWDP Box XT39 CION Over Sub Box 4-1/2" IF Non-Msg Flex Drill Collsr Box 4-1/2" IF Non-Msg Flex Drill Collsr Box 4-1/2" IF Non-Msg Flex Drill Collsr Box 4-1/2" IF TM HOC Box 4-1/2" IF DM HOC Box 4-1/2" IF Gllmme/Res Box 4-1/2" IF Non-Meg Floet Sub Box 4-1/2" IF 7" SpenyDrill Lobe 7/8 ,,6.0 stg Pin 4-1/2" Reg Roller Cone Steel - - - - - - - - - - I I I I I I I I I I I I I I I I I I I SLrI Operator: Kerr McGee Well: NikaitchuCl #4 Nik 4 5T FIeld: Western North Slope Location: Spy Island Rig: Nordic 3 Job.: AK,MJ-OOO'35?'313'3 RHA1f 6 a..ILLI Nil ....VICII. RHA Report BHM 6 : Date In 2I1512oœ MD In (ft) : 4861 1VD In(ft) : 4153 Date Cur2l1912OO5 MD Cur(ft): 7577 1VD Cur(ft): 4186 BIT DATA I Bit. CO (In) IIFR Style Seria.. Nozzles (132's) TFA (InZ) Dull Condition 6 6.125 Seauity FM3641 10605472 6x10 0.460 1-1-ER-C -X-I-PN- TD MOTOR DATA I -,- Run' CO (in) MFR Model Seria.. Bend NzI (132"81 Ava Dif (psi) Cum Circ Hrs I 5 5.000 SSDS SperrvDrilf 500011 1.50· 152 64.11 COMPONENT DATA .-.---..- Item Description Serial CO 10 Gauae Weiøht Top Con Lenath Bit - Center #I , (in) (in) (in) (lbsIft) (ft) Blade (ft) 1 PDC 10605472 6.125 1.500 6.125 94.39 P 3-112" Reg 0.68 2 5° SperryDriII ABl6I1 - 6.0 stø 500011 5.000 2.794 6.000 46.02 B 3-112" IF 32.58 1.99 3 Non-Ma!:r Float Sub 528 4.770 2.250 47.35 B 3-1/Z' IF 1.84 4 GanmaIRes 70717 4.720 1.250 55.45 B 3-112" IF 24.17 5 œÆ HOC 156248 4.720 2.500 42.90 B 3-112" IF 8.55 6 ASlDCTN 67906 4.760 2.250 47.10 B3-112" IF 25.44 7 1M HOC 143904 4.700 2.630 40.61 B3-112"1F 10.98 8 Non-Maø Rex DriI Collar C-1ooo 4.620 2.250 43.58 B 3-112" IF 30.84 9 Non-Maø Rex DriI Collar C-941 4.550 2.120 43.38 B 3-1/Z' IF 30.99 10 Non-Maø Flex DriB Collar C-945 4.540 2.250 41.62 B 3-112" IF 30.95 11 Cross Over Sub N-3 5.020 2.500 50.72 B 3-1/Z' IF 0.98 12 3 x tM[)p 4.000 2.563 29.70 B XT39 92.09 13 Drillinø Jar - 34.58 Hrs 14001130 4.800 2.250 48.12 B XT39 29.53 14 2 x tM[)p 4.000 2.563 29.70 B XT39 61.34 15 120 x DP (S) - XT39 -14.001# 4.000 3.340 16.38 B XT39 3803.64 16 Z7 x HIM)p 4.000 2.563 29.70 B XT39 828.31 5012.91 I I !!ILIn Operator: Kerr McGee Well: NikaitchuQ #4 Nik 4 ST field :c Western North Slope Location: Spy Island Rig: Nordic 3 Job". A (,MJ-OOO'352'31'33 RHNf 6 I CRILLI Nil !I...VIC.. I RHA Report I I I I I I I I I I Parameter Min Max Ave Activity HIS BHA Weight (lb) Drill String OD(in) Len(ft) 'M)B (klbs) : 5 20 8 Drilling : 34.21 in Air (Total) :101910 DP(S}-XT3915.66# 4.000 2564 RPM (røm) : 50 60 60 Reaming: 5.25 in Mud (Total) 87465 Flow (APm) : 250 300 278 ;irc-Other: 24.65 in Air (Bel Jan ; 11753 SPP (p9i) . 2500 3700 3210 Tobll; 64.11 in Mud ~.I Jar: 10096 PERFORMANCE I I I In Out Distance (ft) ROP(ftlhr) Inclination (deg) 80.84 89.00 Oriented: 712.00 52 Azimuth (deg) 314.73 329.88 Rotated : 2004.00 85 Tnbl . ?71R no 7~ Build (°/100') Turn (°/100') DLS (°/100') n='4n nM nFr.'l I COMMENTS Mtr - 200 - 300 GPM I .77 RevsIGaI Bit -> DIR = 64.27 Bit -> ASI = 11.5' Bit -> RES = 45.41' Bit -> GR = 52.47' Bit -> ALD = 73.20' Bit -> NEU = 87.95 I I I I I I I RHA ~port pê,gi'? Operator: Kerr McGee Well: NikaitchuQ #4 Nik 4 ST Field: Western North Slope Location: Spy Island Rig: Nordic 3 Job,: I\I",WJ..L)OO~1n1 ~Nt' sr&..' -I Y-SLrI gflt.L....INII .."VII:.. I OBJECTIVES: This BHA will land the weU at a vertical depth determined by the weU site geologists. We wiU then work closely with them and keep the assembly in the best possible production zone. RESULTS: I BHA #6: BHA was made up and singled in to ES cementer valve, drilled up and continued RIH to plugs at 4761' MD, performed casing test and drilled up plugs, cement, float collar, shoe and 20' new hole. Target given to land, 4164-4166' TVD. Target was reached and Geo wanted to come up to 4162' TVD. I 1800 hrs, 5580' MD, 4162' TW, 89.5° requested. Geologist thinking we are between calcite zones and would like to hold this inc following down dip. 5600' MD, driUing on hard spot 89.2 inc once through, hit another deflecting us down ,90 requested. 2015 Hrs, 5675' MD, 90.5 requested. Built to 90.5, dropping rotating, @ 89.5 @ 5771' MD, havent seen any hard spots for awhile, will hold 89.5 for awhile. 0100 Hrs, 5987'MD, 90-90.5 requested. 0230 Hrs, 6108' MD, let drop rotating to no more than 88.5. BHA has been dropping in rotation about 2°/100, and walking left about .25°/100, we are controlling ROP from 120-150'!hrfor logs. Assembly has been putting out 10-12° DLS last 600'. 0300 Hrs, 6140' MD, 88.6" ASI, continue to let drop rotating tiU advised by Geotogist. 0307 Hrs, 6151' MD, 88.2" ABI, 90" inc requested. I I I I I I I I I 1730 Hrs, 6858' MD, 89.5° inc requested, currenUy at 88, slid 22' up, rotated 32', seen 88.8 ASI once then dropped to 88 rotating. Geo now wants to come up 2' TVD aggressively. 92° ASI @ 6983' MD. Got up a couple feet, slid down to 90.3, drill ahead average 89.5 requested. dropped to 89 rotating to 7133' MD. Geo wants to keep rotating ahead letting it drop some. 2400 Hrs 7197' MD, 88.5 - 89" inc requested. @ 726( MD, had a little firmer formation deflected us up to 90.8 from 89. 0145 Hrs, 89.5 - 90° inc requested. 0620 Hrs, Geologist requested 91 degrees inclination We started sliding at 60L for build and tum 0730 Hrs.. Geologist informed us the well would be TD at 7577'. We finished our slide at 60L and rotated to TD. After the weU was cleaned, the BHA was pulled out of the hole. Assembly produced 10" DLS average oriented motor dogleg, showed a drop tendency of about 2°/100 controUing ROP for log quality, depending on formation and had a slight left hand walk till the last few hundred feet it wanted to go right Assembly was deflected off nodules/stringers in varying degrees. Bit Grade=: I I - - - - - 5ipEr"r"'\I-5Un CPlI L.L.I Nil ....VIC.. BHA Schematic Kerr McGee Nikaitchuq #4 BHA ID#: 6 lateral Assembly BHA Configuration 0.0. Length Descrlptlon 6.125" 0.68' PDC 5" 32.58' 5" SperryOrill ABI 617 ·6.0 stg 4.77' 1.84' N~Mag Float Sub 4.72' 24,17' GIIIM1WRes 4.72' 8.55' OM HOC 4.76" 25.44' ASLDCTN 4.7" 10.96' TM HOC 4.62" 30.84' N~Mag Fle¡c Drill Collar 4.55" 30.99' N~Mag Fle¡c Drill Collar 4.54" 30.95' N~Mag Fle¡c Drill Collar 5.02" 0.98' Cross Owr Sub 4" 92.09' 3)HWOP 4.8" 29.53' Drilli"" Jar 4" 61.34' hHWOP 4" 3803.64' 120) DP (S) - XT39 - 14.001II 4" 828.31' 2]) HIIIIOP BHA Discussion Mtr·200 - 300 GPM I .77 Revs/Gal Bit -> DIR '" 64.27' Bit .> ABI '" 11.5' Bit -> RES'" 45.41' Bit -> GR '" 52.47' Bit -> ALO '" 73.20' Bit-> NEU =87.95 - - - - Box XT39 27 x HWOP Box XT39 120 x DP (S) . XT39 ' 14.00# Box XT39 2 x HWOP Box XT39 Drilling Jar _, Box XT39 3xHWOP Box 3-112" IF Cross Over Sub Box 3-112" IF Non·Mag Flex Drill Collar Box 3-112" IF Non-Mag Flex Drill Collar Box 3·112" IF Non-Mag Flex Drill Collar Box 3-112" IF TM HOC Box 3-112" IF ASLDCTN ...... Box 3-1/2" IF ,-/. DM HOC - Box 3-1/2" IF = Gamma'Res ~ Box 3-1/2" IF Non-Mag Float Sub Box 3-1/2" IF .... 5"SpenyDriIlABI617 -6.0stg ...... I' " .,. . ",', Pin 3-1/2" Reg ., PDC - - - - - - - - - - From Bit (It) Component 'f\¡pe Diam In/Out (in) 1 1.99 Sleeve StablPad Yas Stab: 4 I a· 6.000 6.000 2 5.42 Bent Housing Yes Adjustable: 1.50· bend 3 Housing Tool Used No i - 4 33.26 Stator Elastomer -;- 5 Bent Sub I 2nd Bent Hsg No "" ¡;-: - 6 Lower String Stab No II 7 Upper String Stab No Additional Features Arr Ret 1234587 Flex Collar : No No /32'5 Yas Yes .. . I . I I I I _1- I "" .: . I .ý-5iI..Jn C."L.LI NGI ..."'VII:__ I Motor Serial # : 500011 lirectional Driller(st : MVCoker, J McMahonlK. Harding Location Spy Island Well NikaitchuQ #4 DePth InlOut 4861 / 7577 ft Job# : Operator : Rig : Bit Run # : Date InIOut : Kerr McGee Nordic 3 6 BHA# : 6 2/15/2005 / 2/19/2005 I I I I I te. eJ:':O '''' .,~ Max Dogleg While Rotating Max Dogleg OvefPulled In Max Dogleg Pushed Through Hole Azimuth start I End Interval Oriented I Rot. Jarring Occ:ured : No Diff Press (psi) Str RPM 152 Rotn Torque (ft-Ibs) 2900 Drag UplDn (lbf) 5000 I 5000 WOB (klbs) 8 ROP Oriented °11t)(Y "11t)(Y Force Force 5000 fbf 5000 fbf Motor stalled : Float Valve: Yes DP Filter: No 80.84° I 89.00° I °11t)(Y I Inc start I End Directional Perf Orll Rot 314.73° I 329.88° 712 I 2004 It I 60 I I Motor Tested Pre-Run Dump Sub Operating NI A Flow 1: 250 !IfJrTI Flow2 : !IfJrTI Driveshaft Rotation Observed Bearing Leakage Observed Motor Tested Post-Run Dump Sub Operating NI A Flow1 : !IfJrTI Flow 2 : gpm Driveshaft Rotation Observed Bearing Leakage Observed Driveshaft Rotated to Drain Mud Fluid Flushed I Brg Play Pressure 1 Pressure 2 No No psi 0.1 rrm 1800 psi I I '. I MaIcIt : Security Type: FM3641 Pre Existing Hours From Other Wells: Prey Drilling Hrs : 0.00 Prey Reaming Hrs: 0.00 Jet Sizes (132'5) : 6x10 TFA: 0.460 No of Runs This Bit: 1 in' Gage Length: 6.125 in In Out I Motor Run #: 5 Hole Size: 6.125 in Prey Job/Well Hrs Drilling Hrs Circ Hrs Reaming Hrs Total Hrs this Run New Cumulative Hrs (ftIhr) ROP Rotated 24.65 5.25 64.11 64.11 (ftlM 62 85 Brg Play Pressure 1 . Pressure 2 Yes Yes Yes 0.2 am psz psi ER N C PN TO E X W I I "~=-:~;(~~I, ,~n[~::r:l!eJI'I~II=-~.". Problem Perceived No Problem Date Performance Motor : Yas Tandem Motor No Service Interrupt No LIH No Service Interrupt Hrs PPR Ref # I I I I I I I I I I I I I I I I I I I I MOTOR PERFORMANCE REPORT Motor Serial # : 76658 Directional Driller(s) : M.v.Coker, Joe McMahon Location : Spy Island Well : Nikaitchuq #4 Depth In/Out: 2863 I 4861 ft Application Details : Job# : Operator : Rig : Bit Run # : Date In/Out : AK-MJ-Q003523133 Kerr McGee Nordic 3 4 BHA# : 5 2/12/2005 / 2/13/2005 Max Dogleg wtùle Rotating Max Dogleg Overpußed In Max Dogfeg Pushed Through Hole AzImuth Start I End Interval Oriented I Rot. Jarring Occured : No Diff Press (psi) 199 225 Motor Stalled : Float Valve : DP Filter : 1.39" 180.84" 4.14/5.90 °/100' '/100' °/100' 86.32" 1314.73" 1133/865 ft Ibf Ibf 1m: Start I End Directional Perf Ori I Rot Drag UpIDn (Ibf) 1 1 WOB (klbs) 18 20 ~~:B~Åþf§.~~"'······ , Motor Tested Pre-Run Dump Sub Operating N/A Flow 1: gpm Flow 2: gpm Driveshaft Rotation Observed Bearing Leakage Observed No Make : Hughes Type: MX-C1 Pre existing Hours From Other Wells: Prev DriHing Hrs : 0.00 prey Reaming Hrs : JetSizes (/32's) : 3x15,1x12 TFA: .~A;~~.~~,~~.í;.t.]I""I'jl~!.\; Problem Perceived No Perfonnance Motor : Yes Serial#: 6021025 Dull Grade 1 Problem Date Tandem Motor No Service Interrupt No LlH No Customer Representative's Signature (optional) : .............................................................. Motor Run #: 4 Hole Size: 8.500 in prey JobIWeIl Hrs Drilling Hrs Clrc Hrs Reaming Hrs Total Hrs This Run New Cumulative Hrs (ftlhr) ROP Rotated (ftlhr) 100 230 2 345 6 1 8 Service Interrupt Hrs PPR Ref # Date: ............................................. I I I I I I I I I I I I I I I I I I I , ,,~·t - I' - I .ý-ssa..a,}~" '~'I ~~TÔ~PERFORMANCE REPORT DFUL.L.INB .....vu:__ <' ., '.' ::~ I Motor Serial # : 76658 lirectional Driller(s) ; M.V.Coker, Joe McMahon Location : Spy Island Well : NikaitchuQ #4 Depth InIOut: 4180 / 4310 Job # Operator Rig BitRun# : Date InIOut : AK-MJ-0003523133 Kerr McGee Nordic 3 2rr1 BHA# : 4 2/9/2005 / 2/10/2005 Motor Run #: 3 Hole Size: 8.500 in " From Bit (It) Component 1 2.91 Sleeve StabIPad Yes 2 6.77 Bent Housing Yes ~ 3 Housing Tool Used No ~ - 4 25.45 Stator Elastomer ...i., 5 Bent Sub 1 2nd Bent Hsg No ~ - & 30.20 Lower String Stab Yes !ï 7 Upper String Stab No Additional Features 1234567 Flex Collar : No No .. . . . . . Arr Ret Yes Yes ~ Type Stab: 4 I O· Adjustable: 1.50° bend Diam In/Out (ill) 8.190 8.190 "".... -.rStM..PW5* 'Y,¡.:Jt! ')i}~i .....T.. ')",,;. p.,.¡¡ Stab: 4 I O· 8.250 8.250 ~ , i;ft -- 'S _Tool -t':t' >::f?~ -_C,y<c'~ ~;¡,-" 1~[~)~;:';:\IfE -. Max Dogleg While Rotating Max Dogleg Overpulled In Max Dogleg Pushed Through Hole AzImuth Start 1 End Interval Oriented 1 Rot. Jarring Occured : No Diff Press (psi) Str RPM Yes Prey JobIWell Hrs Drilling Hrs Clrc Hrs Reaming Hrs Total Hrs This Run New Cumulative Hrs (Mlr) ROP Rotated (Mlr) Force Ib' Force Ib' Inc Start I End Directional Peri Orll Rot ·1100' °/100' DP Filter: No 1,20° /1.16° 0.17 / 0.17 °/100' 92~61· /103.,44· 0/130 It Rotn TOf'CIue 1ft-IDS) 2600 Drag Up/Dn (Ib/) 1000/1000 woe (klbs) 16 ROP Oriented Avg : Max : 98 80 o 57 "'---b};<:;-'-'->" ìi~~:;:~;:J.;:~· Motor Tested Pre-Run Dump Sub Operating NI A Flow 1: 450 gpm Flow 2 : gpm Drlveshaft Rotation Observed Bearing Leakage Observed with : 2 Collars, Brg Play Pressure 1 1170 psi Pressure 2 psi No No -....~~~~ ~<, Base: Water Make : Hughes Type : GT1 Pre Existing Hours From Other Wells: Prey Drilling Hrs : 22.0! Prey Reaming Hrs: 5~23 No of Runs This Bit: 3 Jet Sizes (/32's) : 3x16 TFA: 0.589 ill' Gage Length: In Out 2 'NT G 2 WT G E 2 NO CP E 2 NO TO ill .¡ ::t:~:f.];:~~~ ~hl ::aeI.]~' ~¡ :: ~.". Problem Perceived No Problem Date Performance Motor : Yes Tandem Motor Service Interrupt No LIH No Service Interrupt Hrs PPR Ref # No I I I I I I I I I I I I I I ,il~ -- I 'I ·Y-~ ,CflUL.L.INaI ....VII:.. MOTOR PERFORMANCE REPORT Job# : Operator : Rig : Bit Run" :, Date In/Out : Motor Serial # : 76658 Directional Driller(s) : MVCoker Location : Spy Island Well : Nikaitchuq #4 Depth In/Out: 2464 / 4120 ft Application Details : Performance Drilling Motor Run #: 2 Hole Size: 8.500 in 8.250 8,250 Arr Ret Yes Yes prey JobJWell Hrs Drilling Hrs Clrc Hrs Reaming Hrs Total Hrs This Run New Cumulative Hrs (ftlhr) ROP Rotated (ft/hr) 114 172 0.1 mm psi psi Mud WI : 4.70 % Sand : 4.00 FlowRate AyglMax: 474/500 SPP StartlEnd ; psi PV: 11 cp YP: 19.0 Ibl/looft' pH : 9.2 gpm Chloride Content : 39000 ppm I I I ~- Œ ~-«-~ t {~ -v .fJ:; .-,,'0 f i ~" · .. , I ¡ I I I r I 1'j. (e:: ~..:. Î Max Dogleg WhIle Rotating Max Dogleg Overpulled In Max Dogleg Pushed Through Hole Azimuth Start, End Interval Oriented , Rot. Jarring Occured : No Diff Press (psi) 172 200 Motor Tested Pre-Run Dump Sub Operating N/A Flow 1: 450 gpm Flow 2: gpm Driveshaft Rotation Observed Bearing Leakage Observed .11....t.,.:.1Ir;. Base : Water % OillWater : / DH Temp AvgIMax : / Prinelple Fonnation Name(s) AK-MJ-0003523133 Kerr McGee Nordic 3 2 BHA., : 2 2/6/2005 I 217/2005 Make Hughes Type: GT1 Serial # : 5061473 Dull Grade 1 2 3 4 5 6 7 8 Pre existing Hours From Other Wells: prey Drilling Hrs : 0.00 Prey Reaming Hrs : 0.00 No of Runs This Bit : 1 In N E W Jet Sizes (/32'5) 3x16 TFA: 0.589 in2 Gage Length : in Out 2 \NT G E 2 NO CP Component 1 Sleeve StablPad Yes 2 Bent Housing Yes 3 Housing Tool Used No 4 25.45 Stator Elastomer 5 Bent Sub ,2nd Bent Hsg No 6 30.20 Lower String Stab Yes 7 Upper StrIng Stab No Additional Features Flex Collar : No : No Type Stab: 4 I 0° Adjustable: 1.50° bend Stab: 4 I 0° /32's I I 0.50 Motor Stalled : 0.50 '/100' 1000 Ibl Float Valve : Yes 0.50 '/100' 1000 Ibl DP Filter : No 103.99° /87.72° lne Start' End 1.64° /1.33° 0/1656 It Directional Perf Orf , Rot 0.23/0.03 '/100' woe (klbs) 10 15 ROP Oriented o with : 2 Collars, Brg Play Pressure 1 Pressure 2 No No .' - - -~ '-" -:--. - '- -" '-' :,' , .,~~;¡~¡~. Motor Tested Post-Run Dump Sub Operating Flow 1 : gpm Flow 2 ; gpm Driyeshaft Rotation Observed Bearing Leakage Observed Driveshaft Rotated to Drain Mud Fluid Flushed mm psi psi .i·~~d:~., t~~AJ~.~~JI.~~II".< Problem Perceived No Problem Date Peñonnance Motor : Yes Tandem Motor Service Interrupt No LIH No Service Interrupt Hrs PPR Ref # No Customer Representative's Signature (optional) : .............................................................. Date: ............................................. I I I I I I I I I I I I I I I I I - Motor SeriaJ. : 800306 lirectional Driller(s) : MVCoker Location : Spy Island Well : NikaitchUQ #4 Depth In/Out: 115 I 2464 Job. : AK-MJ-0003523133 Operator: Kerr McGee Rig : BitRun# : Date InIOut ; Nordic 3 1 BHA. : 1 2/1/2005 / 2/3/2005 ...- From Bit (It) Component Type 1 3.25 Sleeve StablPad Yes Stab: 4 I 0' 2 10.15 Bent Housing Yes Adjustable: 1.50' bend 3 10.43 Housing Tool Used Yes Pad 0.250 in Th 4 30.20 Stator Elastomer 5 Bent Sub I 2nd Bent Hsg No 6 35.89 Lower String Stab Yes Stab: 3 180' 7 Upper String Stab No Additionaf Features Flex Collar : No No Rtr Hoz I Size: 132's '" LM...Pad.. - ":,' _T... :,r- -fi~-1f' Pad \, -- _TOOl 1234507 II I I I I I ~--.. v, :_-,; >(<:,' "T- n- 0" .~.}í;~~dl~;¡\" Max Dogleg While Rotating Max Dogleg OvCHpU/Ied In Max Dogleg Pushed Through Hole Azimuth Start I End Interval Oriented I Rot. Jarring Occ:ured : No Diff Press (psi) Str RPM Force Force 1000 Ibf 1 000 Ibf Motor Stalled : Float Valve: Yes DP Filter: No 1.58' I 1.50' 5.60 I 0.12 '1100' '1100' '!100' 82.61' I 107.87' 58 I 2291 It Inc Start I End Direc:tional Perf Oñ I Rot WOB (kIbs) 12 15 ROP Oriented 87 Rotn Torque 1ft-1M) 2567 Drag Up/Dn ObI) 1000 I 1000 145 74 Motor Tested Pre-Run Dump Sub Operating N/A Flow 1: 6000 ¡¡pm Flow 2 : gpm Driveshaft Rotation Observed Bearing Leakage Observed Brg Play Pressure 1 Pressure 2 No No 1950 psi psi .If¡I'J~'J:'\':'.· .' . Base : Water -.;'- ;----i--;:,;"'__;c;-_~·; - - Motor Run #; 1 Hole Size: 12.250 in Diam In/OUt (in) 12.000 12.000 12.125 12.125 Arr Rat Yes Yes Prey JoblWe" Hrs Drilling Hrs Clrc Hrs Reaming Hrs Total Hrs This Run N_ Cumulative Hrs (fflhr) ROP Rotated 99 Whr) Mud Wt: 9.4 ppq % Sand : 4.00 PII: 11 cP SPP Start/End: '1IP: 19.0 IMII00ft' Chloride Content pH: 9.2 : 39000 IJ{Jrri Additives : % Solids 4.70 % OillWater : I DH Temp AvgIMax : I Principle Formation Namelsl FIowRata AvgIMax : 620 I 650 q(Jm Make : Hughes Type: GT1 Pre Existing Hours From Other Wells: Prev Drilling Hrs : 0.00 Prev Reaming Hrs : Jet Sizes (132'5) : 1x18. 1x12. 2x16 TFA : 0.00 No of Runs This Bit: 1 In OUt Gage Length : 0.752 In' in PSI 8 4 N WT A E E ER TO IN 3 _i=-:~;(e]"~I'¡'.!.'[":: [ere]I'¡II~~J.... Problem Perceived : No Problem Date Performance Motor : Yes Tandem Motor No Service Interrupt No LIH No Service Interrupt Hrs PPR Ref # I I I I I I I I I I I I I I I I I I I c::;r, I .. ·ý-sun OF" L.L.I N ts SERViCe S JAR PERFORMANCE REPORT JarSerial#: 14001130 Directional Driller(s): MVCoker. J McMahonlK. HardinQ Location: Spy Island Well: NikaitchuQ #4 Job# : AK-MJ-Q003523133 Operator : Kerr McGee Rig : Nordic 3 Well Type : Horizontal Date In/Out : 2I15/2oofJ 2/19/2005 Ine In/Out : 80.84° /89.00° i~f* BHA Elements Below Jal : Bit, PDM, Sub, MIND, MWD, MIND, MIND, Flex, Flex, Flex, Sub, 3 x HlNDP '. BHA Elements Above Jal : [Jar], 2 x HWDP, DP (S), H\lllDP Tvpical Drag Up Typical Drag Dowr 15 Ibf 20lbf ,V'd--. : ..]:¡~b~"¡\[;'.I~A~ ., No. of Times Jarred Up (estimate) No. of Times Jarred Down (estimate~ Wt. Indicator Reading to Jar Up Wt. Indicator Reading to Jar Dow : Ibf Ibf o o <,-';+ Problem Perceive.: No ,~=-~t.~~ ' '~~[tt~.t~¡.!~~i"::· · . '..... ..' " ' o hrs on jars in. 34.58 Hrs on jars out. Customer Representative's Siqnature ¡optionall : ............................................................... Date: ........................................ Please fax copy of this report to DTDG, Aberdeen: (44) 1224 727324. I I spsr...--v-sun C'UL.LI NEil SSPlV'C_S JAR PERFORMANCE REPORT I Jar Señal #: 16220016 Directional Driller(s): M.V.Coker, Joe McMahon Location: Spy Island Well: Nikaítchuq #4 Job# : AK-MJ-0003523133 Operator : Kerr McGee Rig : Nordic 3 Well Type: Horizontal I Date InJOut : 2I121200!:l 2/13/2005 Inc In/Out: 1.39· I 80.84° I I I I BHA Elements Below Jar Bit, PDM, Sub, MWD, MWD, MWD, Flex, Flex, Flex, Sub, 6 x HWDP BHA Elements Above Jar [Jar], HWDP I Typical Drag Up Typical Drag Down 2000 Ibf 2000 Ibf I I No. of Times Jarred Up (estimate) No. of Times Jarred Down (estimate) o o Wt. Indicator Reading to Jar Up Wt. Indicator Reading to Jar Down Ibf Ibf Problem Perceived No I I Jars were not fired. Total hours on jars after this run is 63.87 Hours. 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 I I I I I I I < I: } 1- I .¡ -!I-sun CRIL.L.INIS SERVICES Jar Serial': 16220016 Directional Driller(s): MVCoker. Joe McMahon Location: Spy Island Well: NikaitchuQ #4 Job' : AK-MJ-0003523133 Operator : Kerr McGee RkI : Nordic 3 Well Type : Horizontal Date InIOut : 2/9/2005/ 2/10/2005 Inc In/Out : 1.20° /1.16° ':;<' BHA Elements Below Jal : Bit, PDM, Sub, Stab, MWD, MWD, MWD, Flex, MWD, Flex, Flex, Sub, 6 x HWDP BHA Elements Above Jal : [Jar], HWDP Typical DraQ Up Typical Drag Dowr o Ibf o Ibf I~.]~~:j~\,~;l'=-Î~,i . I I I I I I I I I No. of Times Jarred Up (estimate) No. of Times Jarred Down (estimate~ o o Wt. Indicator ReadinQ to Jar Up Wt. Indicator Reading to Jar Dow : Ibf Ibf Problem Perceive.: No , '_.".'_ - '._..".'_n"._ "_' _ n_ '_,. _ _ _ ·..i~:~;(·'~,' .~\~ej:a:~·Ít~;¡ ~m_ .... Jar hrs in = 38.3 Jar hrs out= 40.6 Customer Representative's Siq,nature (optional) : ............................................................... Date: ........................................ Please fax copy of this report to DTDG, Aberdeen: (44) 1224 727324. I I I I I I I I I I I I I I I I I I I :::II-I....J "Í ·ý-sun CFUL.L.INI3 SEAVIt::ES JAR PERFORMANCE REPORT Jar Serial #: 16220016 Directional Driller(s): MVCoker Location: Spy Island Well: NikaitchuCl #4 Job # : AK-MJ-0003523133 Operator : Kerr McGee Rig : Nordic 3 Well Type : Horizontal Date InIOut : 2/6/2005 I 217/2005 Inc In/Out : 1.640 /1.33° Jar hrs in= 23.75 Jar hrs out= 38.3 Customer Reøresentative's Siqnature (oøtional! : ............................................................... Date: ........................................ Please fax copy of this report to DTDG. Aberdeen: (44) 1224727324. I I I I I I I I I I I I I I I I I I I spa .'""V-5I....n CAIL.L.I NG SElAVICeS JAR PERFORMANCE REPORT Jar Serial #: 16220016 Directional Driller(s): MVCoker Location: Spy Island Well: Nik:aítchuQ #4 Job # : AK-MJ-0003523133 Operator : Kerr McGee Rig : Nordic 3 Well Type : Horizontal Date InIOut : 2/1/2005 / 2/3/2005 Inc In/Out : 1.58° 11.64° Depth In/Out: 115 I 2464 ft Mud Wt : Avg Flow Rate: Pressure Drop Below Jar: 9.4 ppg 620 gprr: 1000 psi Hours Below Rotary: 42.52 BHA Elements Below Jal : Bit, PDM, Sub, Stab, MVVD, MVVD, MVVD, Flex, Flex, Flex, Sub, Sub, 6 x HWDP \\; BHA Elements Above Jal : [Jar], HWDP Typical Drag Up Typical Drag Dowr o Ibf o Ibf ,. ~-¡'--:,-'-: _ _i ',-, ,_ _ ,','-,"> '''' ,'_->_~-:._:~:'- : -;:>~r'¿;,i1---~-~_:~ '·.I·~:¡A;:~~,.'~[ctI'J::II'~'1 No. of Times Jarred Up (estimate) No. of Times Jarred Down (estimate~ Wt. Indicator Reading to Jar Up Wt. Indicator Reading to Jar Dow : o o Ibf Ibf Problem Perceive.: No 'li~;:~;(.J;:~¡,l~~;It~.t.JI' \I~~~.~'J_ . . Jar Hrs in= 0 Jar hrs out= 23.75 Customer Representative's SiQnature (optional! : ............................................................... Date: ........................................ Please fax copy of this report to DTDG, Aberdeen: (44) 1224 727324. I , I Sperry-Sun I I I End of Well Report for I Kerr-McGee Corporation I Rig: Nordic 3 I Well: Nikaitchuq #4 Field: Exploration I Country: USA Job No: AK-MW-0003523133 I Date: 31-Jan-05 API No: 50-629-23241-00 I I I I I I I I HA~. B.R·O\ I I I I I I I I I I I I I I I I I I I I HALLIBURTON Sperry-Sun 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: Job No.: AK-MW-0003523133 Kerr-McGee Corporation Nordic 3 Nikaitchuq #4 Exploration USA 50-629-23241-00 AK-MW-0003523133 31-Jan-05 19-Feb-05 True 24.429 80.892 57594.000 31-Jan-05 70 deg. 33 min 39.460 sec North 149 deg. 50 min 19.900 see West 324.152 deg C. Ewing P. Orth D. Richardson D. Hawkins S. Lewis deg deg nT S. Lemaire B. Henningsen J. Pitcher R. Springer D. Sterns 110 Alaska North Slope Well No.: Nlkaitchuq #4 End of Well Report Page 1 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 to provide MWD and LWD services on Kerr McGee Corporations well Nikaitchuq #4 on January 28, 2005. The well was spudded in on February 1, 2005. MWD run 100 was Directional with Gamma Ray and 4 Phase Resistivity. This run spudded the well and drilled to the 9 5/8" casing point at 2464'md. MWD run 200 was Directional with Gamma Ray and 4 Phase Resistivity. This run drilled from the 9 5/8" casing shoe to the coring point at 4120'md. POOH to run 60' core. MWD run 300 was Directional with Gamma Ray, 4 Phase Resistivity, and MRIL. This run logged the cored interval from 4120' to 4180' and drilled to TD of well Nikaitchuq #4 P81 at 431 O'md. POOH for wireline logs and plug back. MWD run 400 was Directional with Gamma Ray, and 4 Phase Resistivity. This run kicked off a cement plug at 2863'md and drilled the build section to 4861 'md. POOH to run 7" casing. MWD run 500 was Directional with Gamma Ray, 4 Phase Resistivity, Compensated Neutron Porosity, and Azmuthal Litho Density. This run drilled the horizontal section to TD at 7577'md / 4184'TVD. POOH to run completion. Job No.: AK-MW-0003523133 Well No.: Nikaitchuq #4 End of Well Report Page 2 ------------ - - - - - - - HALLIBURTON Sperry-Sun Summary of MWD runs Run No. Bit No. Hole Size (in) MWD Service Start Depth (ft) End DrillJWjpe Run Start Depth Distance Date Time (ft) (ft) Run End Date Time BRT Oper. Circ. Max. Hrs. Hrs. Hrs. Temp. (degF) 31.10 I Servo Trip for Failure Int. MWD Type No No TOTALS ====> 8809.00 242.47 243.22 156.63 o o Job No.:AK-MW'0003523133 Well No.: Nikaitchuq #4 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 MWD Run: Rig Bit No: Hole Size: Run Start : Run End: BRT Hrs : Circ. Hrs : Oper. Hrs : (6) (5) (4) (3) (2) (1) Run Time Data 0100 1 12.25 in 01-Feb-0516:44 03-Feb-05 12:30 43.75 31.10 44.29 MWD Schematics 6. Mk VII SN: 8353 5. TM SN: 131568 4.DM SN: 10505073 65.66 ft From Bit 3. HCIM SN: 124215 *' 2. E\NR-P4 SN: 108506 48.69 ft From Bit 1. DGR SN: 149206 41.11 ft From Bit Drill to Surface Casing Point Bitrun Summary Drilling Data Start Depth: 215.00 ft End Depth: 2464.00 ft Footage: 2249.00 ft Avg. Flow Rate: 650.00 gpm Avg. RPM : 80.00 rpm Avg. WOB: 10.00 klb Avg. ROP: 120.00 fph Avg. SPP : 1600.00 psig Component (14) (13) (12) (11) (10) (9) 14. 14x HWDP 13. Drilling Jars 12. 6xHWDP (8) Sperry-Sun Mud Data Mud Type: KCl/Polymer Weight I Vise: 9.40 ppg I Chlorides: 37120.00 ppm PV/YP: 11.00 cp I Solids/Sand: 4.7 % I %OiI/O:W: 0 % I pH/Fluid Loss: 9.20 pH I Max. Temp.: 91.40 degF BHA Schematics 42.00 spqt 19.00 4 0:94 1.00 Ihf2 % mptm Length O.D. (ft) (in) I.D. (in) 429.46 4.000 2.563 31.44 6.250 2.250 184.11 4.000 2.563 1.14 6.500 3.000 3.01 7.790 2.870 31.00 8.040 2.870 31.01 8.040 2.870 31.02 8.040 2.870 9.78 8.120 2.880 9.20 8.000 3.250 30.00 8.010 2.880 2.29 8.090 2.780 29.20 8.000 5.250 1.00 12.250 3.000 11. Cross Over Sub 10. Cross Over Sub 09. NMDC Flex 08. NMDC Flex 07. NMDC Flex 06. TM HOC 05. DM HOC 04. PB90069362HRG8 03. Float Sub 02. 8" SperryDrill 6/7 -4stg 01. Tricone (7) (6) (5) (4) (3) (2) (1 ) Comments Job No.: AK-MW-0003523133 Well No.: Nikaitchuq #4 MWD Performance Tool OD /Type: 8.00 in PFE MWD Real-time%: 99.25 % MWD Recorded%: 100.00 % Min. Inc. : 1.06 degl 568.76 ft Max. Inc. : 2.81 deg I 204.13 ft Final Az. : 106.65 deg Max Op. Press.: 2000.00 psig End of Well Report Page 4 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 MVIID Run : 0200 Start Depth : 2464.00 ft Mud Type : KCIIPolymer Rig Bit No: 2 End Depth: 4120.00 ft Weight I Vise: 9.30 ppgl 39.00 spqt Hole Size: 8.50 in Footage : 1656.00 ft Chlorides: 45000.00 ppm Run Start : 06-Feb-05 03:55 Avg. Flow Rate: 500.00 gpm PV/YP: 13.00 cpl 11.00 Ihf2 Run End: 07-Feb-0519:45 Avg. RPM : 80.00 rpm Solids/Sand: 4 % I 0.75 % BRT Hrs : 39.82 Avg. WOB : 10.00 klb %Oil/O:W: 0 % I 0:96 Circ. Hrs : 23.63 Avg. ROP : 180.00 fph pH/Fluid Loss: 9.80 pH I 6.80 mptm Oper. Hrs : 39.99 Avg. SPP : 2000.00 psig Max. Temp.: 93.20 degF MOO Schematics BHA Schematics Component Length O.D. I.D. (6) (13) (ft) (in) (in) (12) (5) (11 ) 1 -: - (10) 4 (4) 6. Positive Pulser :4 SN: 8353 ,,¡ 13. Drill Pipe (S) 31.50 4.000 3.240 (9) 1 12. HWDP 429.46 4.000 2.563 5. TM (8) , 11. Drilling Jars 31.44 6.250 2.250 SN: 131568 (3) 10. HWDP 184.11 4.000 2.563 (7) 1 4.DM \1 09. Cross Over Sub 1.14 6.500 3.000 SN: 10505073 08. NMDC 31.09 6.750 2.880 (2) 62.16 ft From Bit (6) 3. HCIM 07. NMDC 31.09 6.750 2.880 SN: 168347 (5) 4 06. NMDC 31.08 6.750 2.880 ;j 05. MWD 42.71 6.726 2.452 2. EWR-P4 .. (1 ) SN: 76987 (4) .. 04. Integral Blade Stabilizer 5.62 6.760 2.880 .. 45.23 ft From Bit (3) '" 03. Float Sub 2.43 6.700 2.880 1. DGR (2) SN: 149205 í 02. 7" SperryDrill Lobe 7/8-6stg 24.65 6.920 4.753 f -- 37.48 ft From Bit (1 ) . 01. Tricone 0.80 8.500 3.000 Comments MWD Performance Drill 8 1/2" hole to coring point at 4120'. POOH to run Tool OD /Type: 6.75 in I PFE core. MWD Real-time%: 99.25 % MWD Recorded%: 100.00 % Min. Inc. : 0.98 degl 3792.50 ft Max. Inc. : 1.64 degl 2463.52 ft Final Az. : 88.60 deg Max Op. Press. : 1991.00 psig Job No.: AK·MW·0003523133 Well No.: Nikaitchuq #4 End of Well Report Page 5 I I I I I I I I I I I I I I I I I I I HALLIBURTON MV\ID Run : Rig Bit No: Hole Size: Run Start : Run End: BRT Hrs : Circ. Hrs : Oper. Hrs : (6) (5) (4) (3) (2) (1) Run Time Data 0300 3 0.00 in 09-Feb-05 09:27 10-Feb-05 02:00 16.55 4.80 16.89 MWD Schematics 6. Positive Pulser SN: 8353 5. TM SN: 131568 4. DM SN: 10505073 62.16 ft From Bit 3. HCIM SN: 168347 2. E\./lJR-P4 SN: 76987 45.23 ft From Bit 1. DGR SN: 149205 37.48 ft From Bit Sperry-Sun Bitrun Summary Drilling Data Mud Data Start Depth : 4120.00 ft Mud Type : KCllPofymer End Depth : 4310.00 ft Weight I Vise: 9.30 ppgl 39.00 spqt Footage: 190.00 ft Chlorides: 45000.00 ppm Avg. Flow Rate: 440.00 gpm PV/YP: 9.00 cpl 7.00 Ihf2 Avg. RPM : 80.00 rpm Solids/Sand : 3.6 % I Tr % Avg. WOB : 10.00 klb %Oill O:W : 1 % I 1:91.8 Avg. ROP : 60.00 fph pH/Fluid Loss: 9.80 pH I 5.80 mptm Avg. SPP : 1900.00 psig Max. Temp.: 84.20 degF (13) .... ~ '1 ~ (12) (11) ~ i' ~ (10) ~ (9) " .. (8) ~ (7) t (6) 1 , I ..2 (5) ~ . , 1 .:g (4) JI (3) """"J (2) ¡¡ ~ Job No.: AK-MW-0003523133 BHA Schematics Component Length 0.0. (ft) (in) 1.0. (in) (1) Comments Log over cored interval and drill to TO. 13. HWDP 429.46 4.000 2.563 12. Drilling Jars 31.44 6.250 2.250 11. HWDP 184.11 4.000 2.563 10. Cross Over Sub 1.14 6.500 3.000 09. NMDC 31.09 6.750 2.880 08. NMDC 31.09 6.750 2.880 07. MRIL 38.70 6.750 2.880 06. NMDC 31.08 6.750 2.880 05. MWD 42.71 6.726 2.452 04. Integral Blade Stabilizer 5.62 6.760 2.880 03. Float Sub 2.43 6.700 2.880 02. 7" SperryDrilf Lobe 7/8-6stg 24.65 6.920 4.753 01. Tricone 0.80 8.500 3.000 MWD Performance Tool 00 I Type: 6.75 in MV\ID Real-time%: 99.25 % MWD Recorded%: 100.00 % Min. Inc. : 1.13 degl Max. Inc. : 1.34 deg I Final Az. : 98.49 deg Max Op. Press. : 2083.00 psig PFE 4211.39 ft 4115.93 ft Well No.: Nikaitchuq #4 End of Well Report Page 6 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 : 2863.00 ft Mud Type: KCIIPolymer Rig Bit No: 4 End Depth : 4861.00 ft Weight I Visc : 9.30 ppgl 44.00 spqt Hole Size: 8.50 in Footage: 1998.00 ft Chlorides: 42000.00 ppm Run Start : 11-Feb-05 19:30 Avg. Flow Rate: 450.00 gpm PV/YP: 9.00 cpl 12.00 Ihf2 Run End: 13-Feb-05 19:35 Avg. RPM : 80.00 rpm Solids/Sand : 3.5 % I 0.50 % BRT Hrs : 48.08 Avg. WOB : 15.00 klb %Oil/O:W: 0 % I 0:91.8 Circ. Hrs : 34.30 Avg. ROP : 120.00 fph pH/Fluid Loss: 10.70 pH I 6.40 mptm Oper. Hrs : 48.19 Avg. SPP : 2000.00 psig Max. Temp. : 96.80 degF (6) (5) (4) (3) (2) (1) MWD Schematics (12) (11) (10) 6. Positive Pulser (9) SN: 8353 (8) 5. TM (7) SN: 131568 4. DM (6) SN: 505073 56.42 ft From Bit (5) 3. HCIM SN: 168347 (4) 2. EWR-P4 SN: 76987 (3) 39.38 ft From Bit (2) 1. DGR SN: 149205 31.63 ft From Bit (1 ) Comments Sidetrack off cement plug at 2863', Drill build to 80 deg. POOH to run casing. Job No.: AK-MW-0003523133 BHA Schematics Component Length O.D. (ft) (in) I.D. (in) 12. Drill Pipe 31.50 4.000 3.240 11. 14x HVVDP 429.46 4.000 2.563 10. Drilling Jars 31.44 6.250 2.250 09. 6x HWDP 184.11 4.000 2.563 08. Cross Over Sub 1.14 6.500 3.000 07. NMDC 31.09 6.750 2.880 06. NMDC 31.09 6.750 2.880 05. NMDC 31.08 6.750 2.880 04. MWD 42.82 6.726 2.452 03. Float Sub 2.43 6.700 2.880 02. 7" SperryDrill Lobe 7/8-6stg 24.65 6.920 4.753 01. Tricone 0.80 8.500 3.000 MWD Performance Tool OD I Type: 6.75 in MOO Real-time%: 99.00 % MWD Recorded%: 100.00 % Min. Inc. : 1.39 deg I Max. Inc. : 77.69 deg I Final Az. : 313.34 deg Max Op. Press.: 1982.00 psig PFE 2863.00 ft 4801.70 ft Well No.: Nikaitchuq #4 End of Well Report Page 7 I I I I I I I I I I I I I I I I I I I HALLIBURTON MWD Run: Rig Bit No: Hole Size: Run Start : Run End: BRT Hrs : Circ. Hrs : Oper. Hrs : (8) (7) (6) (4) (3) (2) ~ ~ f/ ( ,;~ (1 ) "I'" ;\1' ~.~ f .-: ~:~t Run Time Data 0500 5 6.13 in 15-Feb-0510:44 19-Feb-05 09:00 94.27 62.80 93.86 MOO Schematics 8. Positive Pulser SN: 8331 7. TM SN: 131568 6. CTN SN: 109091 87.95 ft From Bit 5. ASLD SN: 204408 73.20 ft From Bit 4. DM SN: 168285 64.27 ft From Bit 3. HCIM SN: N/A 2.DGR SN: 151107 52.47 ft From Bit 1. 4-3/4" EWR-P4 SN: 119578 45.41 ft From Bit Sperry-Sun Bitrun Summary Drilling Data Mud Data Start Depth : 4861.00 ft Mud Type: ENVIROMUL End Depth: 7577.00 ft Weight I Vise: 9.30 ppgl 40.00 spqt Footage: 2716.00 ft Chlorides: 50600.00 ppm Avg. Flow Rate: 290.00 gpm PV/YP: 21.00 cp I 10.00 Ihf2 Avg. RPM : 60.00 rpm Solids/Sand: 78 % I 1 % Avg. weB : 5.00 klb %Oill O:W: 72 % I 80:20 Avg. ROP : 100.00 fph pH/Fluid Loss: 0.00 pH I 0.00 mptm Avg. SPP : 3500.00 psig Max. Temp. : 130.44 degF (13) (12) (11) (10) (9) (8) (7) (6) (5) (4) (3) (2) (1 ) Comments Drill horizontal section to TO. Sources used: ALD 2744 GW I eTN 8302103 NK Job No.: AK-MW-0003523133 BHA Schematics Component Length O.D. (ft) (in) I.D. (in) 13. HWDP 500.00 4.000 2.563 12. Drill Pipe (E) 3803.64 4.000 3.340 11. HWDP 61.34 4.000 2.563 10. Drilling Jars 29.53 4.800 2.250 09. HWDP 92.08 4.000 2.563 08. Cross Over Sub 0.98 5.020 2.500 07. NMDC 30.95 4.540 2.250 06. NMDC 30.99 4.550 2.120 05. NMDC 30.84 4.620 2.250 04. MWD 69.97 4.750 1.670 03. Float Sub 1.84 4.770 2.250 02. 4-3/4" SperryDrill Lobe 7/8 - 32.58 5.000 2.794 01. PDC 0.68 6.125 1.500 MOO Performance Tool OD /Type: 4.75 in I MWD Real-time%: 95.83 % MWD Recorded%: 100.00 % Min. Inc. : 87.35 deg I Max. Inc. : 92.22 deg I Final Az. : 329.88 deg Max Op. Press.: 2035.00 psig PFE 6562.61 ft 5464.03 ft Well No.: Nikaitchuq #4 End of Well Report Page 8 I I Kerr McGee NW Milne Point Spy Island Nikaitchuq #4 Nikaitchuq #4PB1 Company: Field: Site: Well: Wellpath: Survey: -".--"-~- I I Company: Tool: I Field: NW Milne Point Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level I Site: Spy Island I ¡\¡orthing: Easting: 6054881.08 ft 519518.28 ft Site Position: From: Map Position Uncertainty: Ground Level: 0.00 ft 0.00 ft I Well: Nikaitchuq #4 I Well Position: +N/-S -53.03 ft +E/-W 124.58 ft Position Uncertainty: 0.00 ft \' "rthi ng: Easting: 6054828.38 ft 519642.99 ft Wellpath: Nikaitchuq #4PB1 506292324170 Current Datum: Nik#4: Magnetic Data: 1/31 ¡2005 Field Strength: 57594 nT Vertical Section: Depth From (TVD) ft 30.06 I Height 31.26 ft +N/-S ft 0.00 I Survey Program for Definitive Wellpath Date: 3/23/2005 Validated: No Actual From To Su "\'ey ft ft 204.13 4310.00 --,.__.~.'~ I Nikaitchuq #4Pß1 (204.13-4310.00) --, ---.- I Survey 1-- --------,.-.- -. -.-..---,....--------- MD loci Azim "I'V)) Sys TVD ft deg deg ft ft .--.----- 30.06 0.00 G.GO 3::.06 ·1.20 I 204.13 2.81 82.61 204.06 172.80 294.31 2.30 74.73 294.15 262.89 386.47 1.24 69.66 386.26 355.00 477.59 1.41 75.96 477.36 446.10 I 568.76 1.06 89.85 568.51 537.25 660.79 1.63 B3.70 660.51 629.25 754.38 1.60 li4.75 ·'54.07 722.81 I 849.15 1.85 55.12 848.79 817.53 943.44 2.05 61.74 943.03 911.77 1039.73 1.24 68.30 039.28 1008.02 1134.68 1.30 78.64 134.21 1102.95 I 1228.46 1.36 ~,2.64 227.96 1196.70 1324.18 1.47 103.37 323.65 1292.39 1418.77 1.38 110.56 418.21 1386.95 I 1513.81 1.42 111.83 1513.22 1481.96 1608.98 1.41 115.25 1608.36 1577.10 1704.65 1.63 109.84 1704.00 1672.74 1798.11 1.77 114.05 1797.42 1766.16 "' ".--------- .-'-'. I Halliburton Global Date: 3/23/20)5 Co-ordioate(:\L I<dercrl"c: Vertical (TV))) ¡(d'crcllce': Section (VS) Rl' I,' rl" nce: Survey Calenla!.')!l Mttll"d: Time: 14:18:54 Page: Well: Nikaitchuq #4, True North Nik#4: 31.3 Well (0.00N,O.00E,324.15Azi) Minimum Curvature Db: Oracle -_..__._~-- Start Datt': DEFINITIVE Engineer: Tied-to: - -.---.----- --- --~-- ;Vlap ZOlll': Cool'dinatl' :" ,\tem: Geomagllt,tl, \lodd: Alaska, Zone 4 Well Centre bggm2004 Latitude: 70 33 Longitude: ',49 50 North Rl'fl'I'l"lIl'e: Gdd Convl'.-gl'lIee: 39.985 N 23.590 W True 0.15 deg Slot Naml': Latitude: Longitudl': 70 33 39.464 N 49 50 19.911 W D.-illcd Fro",: Tie-on Dl'pl ¡" '\bove SySIl'[¡¡ ¡)atlllli: )eclinatioll: Mag Dip Anck: +E/-W ft 0.00 Well Ref. Point 30.06 ft Mean Sea Level 24.43 deg 80.89 deg Direction deg 324.15 -- ..-------- VC¡'sion: Toolcode 1'001 Name MWD+IFR-AI< :;''Z-SC V1WD+IFR AK CAZ SCC N/S Em ~,:tpN MapE Tool ft ft it ft 0.00 0 (;:;A823.38 519642.99 TIE LINE 0.56 4, 60:i4828.95 519647.31 MWD+IFR-AK-CAZ-SC 1.32 8.¿"3 60'54829.72 519651.25 MWD+IFR-AK-CAZ-SC 2.16 10.';3 60;4830.56 519653.96 MWD+IFR-AK-CAZ-SC 2.77 12S;C) 60)4831.18 519655.97 MWD+IFR-AK-CAZ-SC 3.04 14.';' 6004831.46 519657.91 MWD+IFR-AK-CAZ-SC 3.19 17.' .:', 6014831.62 519660.06 MWD+IFR-AK-CAZ-SC 3.89 19 60'54832.33 519662.56 MWD+IFR-AK-CAZ-SC 5.33 22'. 604833.77 519665.01 MWD+IFR-AK-CAZ-SC 7.00 24 60)4835.45 519667.74 MWD+I FR-AK-CAZ-SC 8.20 27 60)4836.65 519670.22 MWD+I FR-AK-CAZ-SC 8.79 2~',. 60';4837.25 519672.23 MWD+IFR-AK-CAZ-SC 8.95 31 6054837.42 519674.38 MWD+I FR-AK-CAZ-SC 8.62 33. 60>4837.09 519676.71 MWD+IFR-AK-CAZ-SC 7.94 3:). 60 A836.41 519678.96 MWD+I FR-AK-CAZ-SC 7.10 3tì. 60 A835.58 519681.13 MWD+IFR-AK-CAZ-SC 6.16 40,:; , 60')4834.64 519683.28 MWD+IFR-AK-CAZ-SC 5.19 4:2. ,,-'-; 60')4833.69 519685.63 MWD+IFR-AK-CAZ-SC 4.15 4:) : 60,4832.65 519688.20 MWD+IFR-AK-CAZ-SC I I c Halliburton Global -~-- Company: Kerr McGee Date: 3/23/20:)5 Time: 14:18:54 Page: 2 Field: NW Milne Point Co-onJinate(l\ ¡.) I{eferl'!lce: Well: Nikaitchuq #4, True North Site: Spy Island Vertical (TVD) IÜ·ferelll'l': Nik#4: 31.3 Well: Nikaitchuq #4 Section (VS) Hl'krl'llce: Well (0.00N,0.00E,324.15Azi) Wellpath: Nikaitchuq #4PB1 Survey Calcul:llillll i\kthlld: Minimum Curvature Db: Oracle -.------ Survey ~_.-.._-_.--"_._--- MD Ine! Azilll TVD Sys TVD N/S Em .\ '<lIJN MapE Tool ft deg deg ft ft ft ft ft ft ---. 1894.41 1.72 107.72 1893.68 1862.42 3.11 470Ci 60'54831.62 519690.94 MWD+IFR-AK-CAZ-SC 1989.13 1.59 106.24 1988.36 1957.10 2.31 50.C:S 6054830.82 519693.55 MWD+IFR-AK-CAZ-SC 2084.30 1.60 110.18 2083.49 2052.23 1.48 53',~'j 60'54830.00 519696.07 MWD+IFR-AK-CAZ-SC 2179.53 1.63 102.66 2178.68 2147.42 0.73 55 " 6054829.25 519698.64 MWD+IFR-AK-CAZ-SC 2274.24 1.46 104.19 2273.36 2242.10 0.13 58 ., 60')4828.67 519701.13 MWD+IFR-AK-CAZ-SC 2369.41 1.48 106.06 2368.50 2337.24 -0.50 60:) 60')4828.04 519703.49 MWD+IFR-AK-CAZ-SC 2463.52 1.64 103.97 2462.57 2431.31 -1.16 62."0 6054827.38 519705.96 MWD+IFR-AK-CAZ-SC 2557.62 1.47 107.42 2556.64 2525.38 -1.85 65J13 60'14826.70 519708.42 MWD+IFR-AK-CAZ-SC 2652.42 1.34 106.38 2651.41 2620.15 -2.53 67.% 6054826.03 519710.65 MWD+IFR-AK-CAZ-SC 2747.56 1.10 87.06 2746.53 2715.27 -2.79 69 \:)4 6054825.77 519712.63 MWD+IFR-AK-CAZ-SC 2842.58 1.43 84.79 2841.52 2810.26 -2.64 71.73 6054825.93 519714.72 MWD+IFR-AK-CAZ-SC 2937.80 1.27 92.64 2936.72 2905.46 -2.58 7397 6054826.00 519716.95 MWD+IFR-AK-CAZ-SC 3032.57 1.23 86.90 3031.46 3000.20 -2.57 76.03 6054826.01 519719.02 MWD+IFR-AK-CAZ-SC 3128.01 1.47 74.79 3126.88 3095.62 -2.20 78:':J 6054826.39 519721.22 MWD+IFR-AK-CAZ-SC 3223.00 1.30 76.02 3221.84 3190.58 -1.62 80Al) 6054826.98 519723.44 MWD+IFR-AK-CAZ-SC 3317.74 1.44 75.10 3316.55 3285.29 -1.05 82,,,5 60)4827.55 519725.63 MWD+I FR-AK-CAZ-SC 3413.53 1.27 84.57 3412.32 3381.06 -0.64 84.!'? 60')4827.96 519727.85 MWD+I FR-AK-CAZ-SC 3508.64 1.19 82.22 3507.40 3476.14 -0.41 86,,)0 60';4828.20 519729.88 MWD+IFR-AK-CAZ-SC 3603.20 1.10 ~)2.14 3601.95 3570.69 -0.31 88./3, 60'54828.31 519731.76 MWD+I FR-AK-CAZ-SC 3698.56 1.02 85.67 3697.29 3666.03 -0.28 90.:-,:) 6054828.34 519733.52 MWD+IFR-AK-CAZ-SC 3792.50 0.98 99.38 3791.21 3759.95 -0.35 92. " f5054828.28 519735.15 MWD+IFR-AK-CAZ-SC 3888.81 1.22 \)5.55 3887.51 3856.25 -0.58 94. 60>\828.05 519736.98 MWD+IFR-AK-CAZ-SC 3983.27 1.39 D1.45 :)981.94 3950.68 -0.71 g(). "i é'O';Cj827.93 519739.13 MWD+IFR-t-CAf-SC 4058.93 1.27 B8.60 4057.58 4026.32 -0.71 97 130'4827.93 519740.88 MWD+IFR- -CAZ-SC 4115.93 1.34 B7.42 4114.57 4083.31 -0.66 99.;"[) 60 14827.98 519742.18 MWD+IFR-AK::cÀZ-SC 4211.39 1.13 95.63 4210.01 4178.75 -0.71 101.: 5 60)4827.94 519744.23 MWD+I FR-AK-CAZ-SC 4246.84 1.14 98.49 4245.45 4214.19 -0.79 101 60'54827.86 519744.93 MWD+I FR-AK-CAZ-SC 4310.00 1.14 98.49 4308.60 4277.34 -0.98 103. f30')4827.68 519746.17 MWD+IFR-AK-CAZ-SC _._-~.._~..- --- I I I I I I I I I I I I I I I I -~--------- I I Hallib urto I Global Survey Program for Definitive Well path Date: 3/23/2005 Validated: No V crsion: ", Actual From To Sun-l'Y T()oi<"odt' Tool Name ft ft 204.13 2842.58 Nikaltchuq #4PB1 (204,13-4310.00) (1) MWD+IFR-Ai' ,J\Z-~ C MWD+IFR AK CAZ SCC 2863.00 7577.00 Nikaitchuq #4 (2863.00-7577.00) MWD+IFR-Ai< '~¡:\Z-~C MWD+IFR AK CAZ SCC ----.------ Survey -~_._.,_..._-_._,- MD Incl Azinl 1'\"1) Sys TVO N/S E/\\ \bpN MapE Tool ft deg deg It ft ft ft ft ft .-----~._------- 30.06 0.00 0.00 30.06 -1.20 0.00 054828.38 519642.99 TIE LINE 204.13 2.81 82.61. 204.06 172.80 0.56 :j '054828.95 519647.31 MWD+IFR-AK-CAZ-SC 294.31 2.30 74.73 294.15 262.89 1.32 \(j, .0,') '054829.72 519651.25 MWD+IFR-AK-CAZ-SC 386.47 1.24 69.66 386.26 355.00 2.16 1 (\ '054830.56 519653.96 MWD+IFR-AK-CAZ-SC " 477.59 1.41 /5.96 477.36 446.10 2.77 i ¿. 054831.18 519655.97 MWD+IFR-AK-CAZ-SC 568.76 1.06 ¡'9.85 568.51 537.25 3.04 ' 054831.46 519657.91 MWD+I FR-AK-CAZ-SC 660.79 1.63 "3.70 (360.51 629.25 3.19 054831.62 519660.06 MWD+I FR-AK-CAZ-SC 754.38 1.60 b4.75 754.07 722.81 3.89 054832.33 519662.56 MWD+I FR-AK-CAZ-SC 849.15 1.85 ~;5.12 348.79 817.53 5.33 054833.77 519665.01 MWD+I FR-AK-CAZ-SC 943.44 2.05 131.74 943.03 911.77 7.00 ,,:'_.'-¡ f f 054835.45 519667.74 MWD+I FR-AK-CAZ-SC 1039.73 1.24 !38.30 1039.28 1008.02 8.20 2/ '054836.65 519670.22 MWD+I FR-AK-CAZ-SC 1134.68 1.30 /8.64 1134.21 1102.95 8.79 054837.25 519672.23 MWD+I FR-AK-CAZ-SC 1228.46 1.36 92.64 1227.96 1196.70 8.95 J'1. 1,- ,054837.42 519674.38 MWD+I FR-AK-CAZ-SC 1324.18 1.47 1C!3.37 1323.65 1292.39 8.62 JJ 054837.09 519676.71 MWD+I FR-AK-CAZ-SC 1418.77 1.38 110.56 1418.21 1386.95 7.94 3~; ,054836.41 519678.96 MWD+I FR-AK-CAZ-SC 1513.81 1.42 111.83 513.22 1481.96 7.10 ' 054835.58 519681.13 MWD+IFR-AK-CAZ-SC 1608.98 1.41 115.25 608.36 1577.10 6.16 4i 054834.64 519683.28 MWD+I FR-AK-CAZ-SC 1704.65 1.63 1D9.84 704.00 1672.74 5.19 ..¡ 054833.69 519685.63 MWD+I FR-AK-CAZ-SC L_~ ..-...---- I Company: Field: Site: Well: Wellpath: Survey: Kerr McGee NW Milne Point Spy Island Nikaitchuq #4 Nikaitchuq #4 I -. ------_._~-- .-.--- I Company: Tool: Field: NW Milne Point I Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level I Site: Spy Island I ,\orthing: Eastillg: 6054881.08 ft 519518.28 ft Site Position: From: Map Position Uncertainty: Ground Level: 0.00 ft 0.00 ft I Well: Nikaitchuq #4 I Well Position: +N/-S -:,3.03 ft +E/-W 1 ;'4.58 ft Position Uncertainty: 0.00 ft '\orthing: 6054828.38 ft Fasting: 519642.99 ft ._-----,---- --..',----.-. Wellpath: Nikaitchuq #4 506292324100 Current Datum: Nik#4: Magnetic Data: 1/31 /2005 Field Strength: 5/594 nT Vertical Section: Depth Fro'l> (TVD) ft 30.06 I Height 31.26 ft +N/-S ft 0.00 I I I I I I I I I Oall': 3/23/2,. Time: 14:19:18 Page: Co-ordinatl'( '\: '{Cfl" ,'nce: Well: Nikaitchuq #4, True North Vc,.lical ('1'\'1); ,:,· 'crc,.ce: Nik#4: 31.3 Section (VS) H,·,,·,enel Well (O.00N,0.00E,324.15Azi) SlIrvcy Caklll"¡""1 \ldlOd: Minimum Curvature Db: Oracle Stal·t ¡hll': Engineer: Tied-to: DEFINITIVE \Iap ZOIlI': ("oonlinall' ','slt"n: Gcomaglll'I:,' \¡odd: Alaska, Zone 4 Well Centre bggm2004 L,ltitnde: 70 33 I.nngihllk: 149 50 :\(,,'th Rdl'rt'Iil'e: GI~id COin t'r~l'l1~l': 39.985 N 23.590 W True 0.15 deg Slot NanH': (.atitlllit': l.olIgitu{k: 70 33 39.464 N 149 50 19.911 W ¡killed Fr"",' Tie-nn lhop' .\ho\'eS,..",,¡ I)al. m: Ih·clina(ioii .\Ing Dip .\¡¡~:j(.': H:/-W ft 0.00 Nikaitchuq #4PB1 2842.58 ft Mean Sea Level 24.43 deg 80.89 deg Direction deg 324.15 I Halliburto n Global I Company: Kerr McGee Dat<': 3/23/20',) 5 Time: 14:19:18 Page: 2 Field: NW Milne Point Co-ordinate!"¡':; ¡tde,'coce: Well: Nikaitchuq #4, True North I Site: Spy Island Vel·tical (TYDI !',·rcn',lce: Nik#4: 31.3 Well: Nikaitchuq #4 Seetioll (\'5) l{eic' (l'II(',': Well (0.00N,0.00E,324.15Azi) Wellpáth: Nikaitchuq #4 Sur\'(~y Calculat,'"1 Method: Minimum Curvature Db: Oracle Survey I MD loci Azilll TV ) Sys TVD N/S EI\\ MapN MapE Tool ft deg deg ft ft ft ft ft ft 1798.11 1.77 114.05 1797.42 1766.16 4.15 4' " 3054832.65 519688.20 MWD+IFR-AK-CAZ-SC :~ L J 1894.41 1.72 107.72 1893.68 1862.42 3.11 47 .~'. 3054831.62 519690.94 MWD+IFR-AK-CAZ-SC I 1989.13 1.59 106.24 1988.36 1957.10 2.31 50.::<: 3054830.82 519693.55 MWD+IFR-AK-CAZ-SC 2084.30 1.60 110.18 2083.49 2052.23 1.48 53.(.::; '3054830.00 519696.07 MWD+IFR-AK-CAZ-SC 2179.53 1.63 102.66 2178.68 2147.42 0.73 55.6(; 3054829.25 519698.64 MWD+IFR-AK-CAZ-SC I 2274.24 1.46 104.19 2273.36 2242.10 0.13 5(3.1·:; 3054828.67 519701.13 MWD+IFR-AK-CAZ-SC 2369.41 1.48 106.06 2368.50 2337.24 -0.50 60.~ü 6054828.04 519703.49 MWD+IFR-AK-CAZ-SC 2463.52 1.64 103.97 2462.57 2431.31 -1.16 62D3 5054827.38 519705.96 MWD+IFR-AK-CAZ-SC 2557.62 1.47 107.42 2556.64 2525.38 -1.85 65.4:3 3054826.70 519708.42 MWD+IFR-AK-CAZ-SC I 2652.42 1.34 106.38 2651.41 2620.15 -2.53 57.6e G054826.03 519710.65 MWD+IFR-AK-CAZ-SC 2747.56 1.10 87.06 2746.53 2715.27 -2.79 69.fA 3054825.77 519712.63 MWD+IFR-AK-CAZ-SC 2842.58 1.43 34.79 2841.52 2810.26 -2.64 71 T: ,3054825.93 519714.72 MWD+IFR-AK-CAZ-SC I 2863.00 1.39 86.32 2861.94 2830.68 -2.60 72.:'( 6054825.97 519715.22 MWD+IFR-AK-CAZ-SC 2937.44 1.44 322.11 2936.37 2905.11 -1.80 72,:,(; '5054826.77 519715.54 MWD+IFR-AK-CAZ-SC 3032.66 5.13 323.79 3031.41 3000.15 2.58 69.31 3054831.14 519712.28 MWD+IFR-AK-CAZ-SC 3127.98 9.49 326.59 3125.94 3094.68 12.58 62.4C 3054841.12 519705.41 MWD+IFR-AK-CAZ-SC 3223.17 14.31 322.16 3219.05 3187.79 28.43 50 .~:-¡~: 3054856.94 519693.82 MWD+IFR-AK-CAZ-SC I 3318.79 18.95 316.46 3310.66 3279.40 49.03 32.~jC 3054877.49 519675.81 MWD+IFR-AK-CAZ-SC 3413.84 23.35 310.10 3399.29 3368.03 72.36 7 -3054900.76 519650.70 MWD+IFR-AK-CAZ-SC 3508.95 28.44 308.91 3484.83 3453.57 98.75 2" ( ·')054927.05 519618.57 MWD+IFR-AK-CAZ-SC - -r _ , I 3604.54 33.88 311.00 3566.60 3535.34 130.55 -c:( 3054958.75 519580.64 MWD+IFR-AK-CAZ-SC 3697.87 39.38 312.76 :j()41.4 7 3610.21 167.75 -10:,.'_ : 3054995.83 519539.14 MWD+IFR-AK-CAZ-SC 3793.61 43.66 311.69 3713.13 3681.87 210.37 -1 be:. 3055038.33 519492.03 MWD+IFR-AK-CAZ-SC 3887.04 47.79 310.32 3778.35 3747.09 254.23 -20U«( 3055082.05 519441.44 MWD+I FR-AK-CAZ-SC I 3984.16 52.98 309.42 3840.25 3808.99 302.15 -25k~,:','; '3055129.82 519383.90 MWD+IFR-AK-CAZ-SC 4078.31 57.19 309.61 3894.13 3862.87 351.27 -317 3055178.77 519324.23 MWD+IFR-AK-CAZ-SC 4173.49 62.35 309.77 3942.03 3910.77 403.77 -3(31 3055231.10 519260.84 MWD+IFR-AK-CAZ-SC I 4268.85 65.62 310.64 3983.85 3952.59 459.09 -44C,: 3055286.24 519195.27 MWD+IFR-AK-CAZ-SC 4363.02 69.24 310.25 4019.99 3988.73 515.49 -512 3055342.46 519128.95 MWD+IFR-AK-CAZ-SC 4458.12 72.06 311.69 4051.50 4020.24 574.32 -580A',; 3055401.10 519061.07 MWD+I FR-AK-CAZ-SC 4552.91 71.66 311.77 4081.01 4049.75 634.28 -647 Cd 3055460.87 518993.69 MWD+IFR-AK-CAZ-SC 4648.88 75.77 312.01 4107.92 4076.66 695.77 -71(::": ·3055522.18 518924.98 MWD+IFR-AK-CAZ-SC I 4743.72 77.49 312.83 4129.85 4098.59 758.01 -784.:;', '3055584.24 518856.71 MWD+IFR-AK-CAZ-SC 4801.70 77.69 313.34 4142.31 4111.05 796.69 -825J: 3055622.80 518815.26 MWD+IFR-AK-CAZ-SC 4899.23 82.88 315.61 4158.76 4127.50 864.03 -894 3055689.95 518746.53 MWD+IFR-AK-CAZ-SC I 4944.03 88.a:.! 318.39 4162.31 4131.05 896.68 -924 _~' ;055722.51 518716.00 MWD+IFR-AK-CAZ-SC 4993.44 88.64 324.70 4163.76 4132.50 935.33 -95~).·\ ;055761.08 518685.20 MWD+IFR-AK-CAZ-SC 5039.61 89.51 326,86 4164.50 4133.24 973.50 -98: ;055799.18 518659.15 MWD+IFR-AK-CAZ-SC I 5099.28 89.01 3:!9.19 4165.27 4134.01 1024.11 -1 01~' :055849.70 518627.42 MWD+IFR-AK-CAZ-SC 5134.14 89.45 330.08 4165.74 4134.48 1054.19 -1030. '.( 3055879.72 518609.72 MWD+IFR-AK-CAZ-SC 5179.09 90.80 330.97 4165.64 4134.38 1093.32 -105:' h', 3055918.79 518587.51 MWD+IFR-AK-CAZ-SC 5229.13 89.57 329.97 4165.48 4134.22 1136.85 -1077 ;055962.26 518562.73 MWD+IFR-AK-CAZ-SC I 5278.45 93.09 330.76 4164.34 4133.08 1179.70 -1101 T. 3056005.04 518538.24 MWD+IFR-AK-CAZ-SC 5323.22 91.05 330.55 4162.72 4131.46 1218.70 -1123lJ'J ,3056043.98 518516.22 MWD+IFR-AK-CAZ-SC 5373.00 87.96 329.99 4163.15 4131.89 1261.92 -114lU,; 3056087.13 518491.42 MWD+IFR-AK-CAZ-SC 5418.59 89.20 331.05 4164.28 4133.02 1301.60 -117(; ;056126.74 518468.89 MWD+I FR-AK-CAZ-SC I 5464.03 92.22 3:11 .56 4163,72 4132.46 1341.45 -11 ~i:): 3056166.53 518446.97 MWD+IFR-AK-CAZ-SC 5513.96 90.86 3:.11.44 411.32.37 4131.11 1385.31 -121 ;056210.32 518423.04 MWD+IFR-AK-CAZ-SC 5558.88 89.20 3::1.28 " C32.35 4131.09 1424.73 -12::, 3056249.68 518401.41 MWD+IFR-AK-CAZ-SC 5608.70 89.01 3:10.84 " 63.13 4131.87 1468.33 -12[j2 3056293.21 518377.19 MWD+IFR-AK-CAZ-SC I 5660.58 89.94 3:\0.54 4 !33.60 4132.34 1513.56 -12U ')056338.37 518351.68 MWD+IFR-AK-CAZ-SC 5706.12 90.00 3'iO.49 4 f,)3.63 4132.37 1553.20 -13(' :056377.95 518329.16 MWD+IFR-AK-CAZ-SC -----~._._._--- "_._>..__._-~---._._~-,----- I I, I Company: Kerr McGee Field: NW Milne Point I Site: Spy Island Well: Nikaitchuq #4 Wellpath: Nikaitchuq #4 Survey I MD lncl Azi11l ft deg oeg 5749.96 89.26 330.36 5801.31 88.70 330.51 I 5851.41 88.58 330.45 5896.40 89.44 330.90 5948.19 89.38 330.49 I 5991.26 90.25 330.58 6041.68 90.06 330.07 6086.06 89.07 328.58 6140.41 88.40 327.79 I 6181.68 90.25 327.99 6234.41 89.75 327.58 6277.34 89.26 327.74 6326.07 88.52 328.09 I 6373.02 87.59 327.64 6420.47 89.81 329.80 6467.73 89.44 330.39 I 6515.29 88.83 3:50.04 6562.61 87.35 3~)9.06 6608.25 90.12 329.70 6657.62 88.83 329.97 I 6706.23 91.48 331.01 6751.83 89.14 330.24 6813.37 87.78 329.90 6848.17 87.59 329.94 I 6896.20 87.90 330.93 6942.18 91.36 331.12 6992.03 91.67 3:J1.87 7036.49 90.49 332.24 I 7084.36 89.38 3:; 1.70 7132.16 88.46 331 .69 7180.29 88.64 3:\1.78 I 7226.83 88.46 330.50 7272.86 90.25 332.65 7322.64 89.38 3:\2.12 7372.19 89.32 332.41 I 7417.40 90.31 331.62 7468.08 89.14 332.09 7511.90 90.19 3:)9.88 7577.00 90.19 3')9,88 I I I I I Halliburton Global Dale: 3/23/:)} . Time: 14:19:18 Page: 3 Co-onlinale('\ ¡.:, ¡,eft-,'coee: Well: Nikaitchuq #4. True North Verlieal (TYi)ì ¡,:,'i'Ci"l'¡¡ee: Nik#4: 31.3 Section (VS) ¡¡,dc'i'enCl'; Well (O.00N.0.00E.324.15Azi) Survey Calcllial"ill ;\'I"lhod: Minimum Curvature Db: Oracle --..--.---- '1\'1) Sys TVD N/S IU\\ MapN MapE Tool ft ft ft ft ft ft 4163.91 4132.65 1591.33 -1331 3056416.02 518307.43 MWD+IFR-AK-CAZ-SC 4164.83 4133.57 1635.99 -135,:" ¡ 3056460.60 518281.98 MWD+I FR-AK-CAZ-SC 4166.01 4134.75 1679.57 -1381 3056504.12 518257.19 MWD+IFR-AK-CAZ-SC 4166.79 4135.53 1718.79 -1403,. :, 3056543.27 518235.06 MWD+IFR-AK-CAZ-SC 4167.33 4136.07 1763.95 -1428. C:. 3056588.36 518209.59 MWD+I FR-AK-CAZ-SC 4167.46 4136.20 1801.45 -145U.('; 3056625.80 518188.31 MWD+IFR-AK-CAZ-SC 4167.33 4136.07 1845.26 -1475.C'" -3056669.53 518163.23 MWD+IFR-AK-CAZ-SC 4167.66 4136.40 1883.42 -14~¡7 3056707.64 518140.49 MWD+IFR-AK-CAZ-SC 4168.86 4137.60 1929.60 -1526:' 13056753.73 518111.73 MWD+IFR-AK-CAZ-SC 4169.35 4138.09 1964.55 -1548J" 3056788.62 518089.70 MWD+IFR-AK-CAZ-SC 4169.35 4138.09 2009.16 -1516,: 3056833.15 518061.48 MWD+IFR-AK-CAZ-SC 4169.72 4138.46 2045.43 -15%:; : 3056869.36 518038.42 MWD+IFR-AK-CAZ-SC 4170.67 4139.41 2086.71 -162':, 3056910.56 518012.44 MWD+I FR-AK-CAZ-SC 4172.26 4141.00 2126.44 -16':30 '3056950.23 517987.37 MWD+IFR-AK-CAZ-SC 4173.34 4142.08 2166.98 -1674 7 '3056990.70 517962.64 MWD+IFR-AK-CAZ-SC 4173.64 4142.38 2207.95 -169[: 3057031.60 517938.97 MWD+IFR-AK-CAZ-SC 4174.36 4143.10 2249.22 -1 (;' , 3057072.80 517915.24 MWD+IFR-AK-CAZ-SC 4175.94 4144.68 2289.99 -174::"", 3057113.50 517891.17 MWD+IFR-AK-CAZ-SC 4176.95 4145.69 2329.25 -176:) 3057152.70 517867.83 MWD+IFR-AK-CAZ-SC 4177.40 4146.14 2371.93 -1793 13057195.31 517842.92 MWD+IFR-AK-CAZ-SC 4177.27 4146.01 2414.23 -18'in:: 3057237.54 517818.86 MWD+IFR-AK-CAZ-SC 4177.02 4145.76 2453.97 -184CU ',J, 3057277.21 517796.40 MWD+I FR-AK-CAZ-SC 4178.68 4147.42 2507.28 -187C)~J¡ ·3057330.44 517765.56 MWD+I FR·AK-CAZ-SC 4180.08 4148.82 2537.37 -188~:~.4 ; 3057360.48 517748.06 MWD+IFR-AK-CAZ-SC 4181.97 4150.71 2579.11 -191 : 3057402.15 517724.27 MWD+I FR-AK-CAZ-SC 4 liJ2.27 4151.01 2619.33 -19:3'1 3057442.31 517701.90 MWD+IFR-AK-CAZ-SC " 180.95 4149.69 2663.12 -19':)6 3057486.03 517678.00 MWD+IFR-AK-CAZ-SC 4180.11 4148.85 2702.39 -197 ß' 3057525.24 517657.07 MWD+IFR-AK-CAZ-SC 4180.17 4148.91 2744.64 -200; 3057567.43 517634.46 MWD+IFR-AK-CAZ-SC 4181.07 4149.81 2786.72 -2024, 3057609.44 517611.69 MWD+IFR-AK-CAZ-SC 4182.29 4151.03 2829.10 -2046~;J . 3057651.76 517588.80 MWD+I FR-AK-CAZ-SC 4 i 83.46 4152.20 2869.84 -206C):\t 3057692.44 517566.24 MWD+IFR-AK-CAZ-SC 4183.98 4152.72 2910.32 -20~)1 3057732.85 517544.22 MWD+I FR-AK-CAZ-SC 4184.14 4152.88 2954.42 -2114 3057776.89 517521.04 MWD+IFR-AK-CAZ-SC 4184.70 4153.44 2998.28 -21 J, 3057820.68 517497.86 MWD+IFR-AK-CAZ-SC 4184.85 4153.59 3038.20 -215ö< j057860.54 517476.55 MWD+IFR-AK-CAZ-SC 4185.09 4153.83 3082.89 -21 e:è 3057905.16 517452.52 MWD+IFR-AK-CAZ-SC 4185.35 4154.09 3121.20 -220' 3057943.42 517431.17 MWD+IFR-AK-CAZ-SC 4i85.13 4153.87 3177.51 -22:;',·· 3057999.64 517398.36 MWD+IFR-AK-CAZ-SC I I I I I I I I I I I I I I I I I I I SSDS Job # Date Field Name Rig Name Well Identification Side Track N orthings Eastings Latitude Longitude Data Source SSDS MAGUTM State / Zone If no, be specific: Geomag. Values Dip Angle Total Intensity (nT) Declination (deg)* Convergence (deg)* * Where appropriate SSDS GEOMAG. SHEET AJ(-MVV-3523133 31-Jan-05 Exploration Nordic 3 Nikaitchuq #4 No 6054828.0 M/ft* 519643.0 M/ft* 70:33:39.460 N/S* 149:50:19.911 E/VV* (y/n) . BGGM2004 Alaska I 4 Office Generated 80.892 57594 24.429 N/A Field Generated "20. gc¡ z. S7.::;,c:{4 ;14 -tf;z. q N/A Signature Tim Flynn SSDS District Supervisor SSDS Lead Engineer Þ tY /-_.-" , ~.J.:>L- sperrv-sun CRII-L..INt3 seRVices - 6~--O ~V/ 1/ ~ '~'-f ~5~ Date 31-Jan-05 /- 3/~òS- 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: Ken Harding Date: 2/21/05 Well: Nikiatchuq #4 Hole Section: 12.25 What went as, or better than, planned: Only three slides were required to keep hole near vertical to a TD of 2464'MD. Difficulties experienced: Initially, it was necessary to reduce our flow to 300 gpm in order to start shearing the mud as well avoiding any washing of the shoe at 115'. As we got deeper, the mud smoothed out and we were able to drill with 600+ gpm. The mud cleaning systems seemed best able to cope with a rate of penetration of 200 fph or less. Recommendations: None Innovations and/or cost 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 Directional Drilling After Action Review Employee Name: Ken Harding Date: 2/21/05 Well: Nikiatchuq #4 Hole Section: 8.5 What went as, or better than, planned: The assembly drilled fairly straight, having an average dogleg of -0.23 degrees per hundred feet and an average build of -0.01 and walk of -1.04. Core point was called at 4120' MD. The coring assembly ran easily into the hole. Sixty feet of formation were cored and the assembly was pulled out of the hole. Next assembly drilled to pilot hole TO of 4310' MD. Next assembly kicked off cement plug with-out problems and built at planned 6°/100 with max 6°/100 to 200' pump tangent angle of 72° and assembly landed as per geology. Difficulties experienced: Each time drilling commenced with a low flow rate until the mud warmed up and sheared. Flow rates were increased until we could circulate at desired rate. Recommendations: Innovations and/or cost 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 Directional Drilling After Action Review Employee Name: Ken Harding Date: 2/21/05 Well: Nikiatchuq #4 Hole Section: 6.125 What went as, or better than, planned: Worked closely with wellsite geologists to stay in most produdive sand. Difficulties experienced: Again mud needed to be shearedl warmed to obtain full drilling rate. Assembly was deflected off nodules/stringers in varying degrees. Recommendations: Innovations and/or cost savings: Sperry-Sun Confidential I I I I I I I I I I I I I I I I I I I ,; HALLIBU~ATON Sperry-Sun MWD/L WD After Action Review Employee Name: P. Orth, C. Ewing, S. Lemaire, B. Henningsen Date: 2/10/2005 Well: Nikaitchuq #4 Hole Section: 12 1/4" What went as, or better than, planned? 100 % Run - excellent detection. What experienced difficulty? N/A Recommendations? N/A Were there any innovations and/or cost savings realized on this well? The pulser was installed into the HOC in the pipeshed prior to run 100, saving 15 min of time. Sperry-Sun Confidential I,' , ,... , ,>' ~< I' I I I I I I I I I I I I I I I I I "c'·MALLIBU,;~·..fTDN Sperry-Sun . MWDILWD After Action Review Employee Name: S. Lemaire, B. Henningsen Date: 2/18/2005 Well: Nikaitchuq #4 Hole Section: 6 1/8" What went as, or better than, planned? 100 % Run - excellent detection. What experienced difficulty? N/A Recommendations? N/A Were there any innovations and/or cost savings realized on this well? The pulser was installed into the HOC in the pipeshed prior to run 500, saving 15 min of time. Sperry-Sun Confidential I, 1 I I I I I I I I I I I I I I I I 1 HALLIBURTON Thank you for utilizing Sperry-Sun Drilling Services. Job No.: AK-MW-0003523133 Well No.: Nikaitchuq #4 Sperry-Sun End of Well Report Page 14 · Core Lab RESERYOIR DPTIHIZATlOX ó<o L/ - 2 G 0 Petroleum Services Division 6316 Windfern Houston, Texas 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 CONVENTIONAL CORE ANAL YSIS DA TA FINAL REPORT FOR Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 ClB mrmJ NYSE · [ore Lab RESERVOIR OPTlKIZATIOH Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska Table of Contents 16-May-05 Discussion.................................................................... ...................................................... Page(s) i - iv Data Tables Routine Core Analysis ProQram Core Analysis Data............................... ........... ...................................................... Page(s) 1-3 Analysis Protocol........................................ ....... ... ............ .......... .......... ... ... .., ....... Page(s) 4 Description & Lamination Key................................................................................. Page(s) 5 Laser Particle Size Analysis Data...... ..... .......... ........................................................ Page(s) 6-7 Detailed Particle Size Analysis (Graphical & Tabular Data) Figures Routine Core Analysis Program Permeability vs Porosity @ Various NCS .................................................................... Figure 1 Permeability vs Porosity @ 600 psig NCS ................................................................... Figure 2 Permeability vs Porosity @ 1200 psig NCS (Mean Net Effective Stress) ........................... Figure 3 Permeability vs Porosity @ 1800 psig NCS ................................................................. Figure 4 Permeability vs Porosity @ 2400 psig NCS ................................................................. Figure 5 Permeability vs Porosity @ 3000 psig NCS .............. .............. ... ................. ................. Figure 6 (K/<Þ)o.s vs Water Saturation @ 1200 psig NCS (Mean Net Effective Stress) ..................... Figure 7 Permeability vs Grain Density @ 1200 psig NCS (Mean Net Effective Stress) ................... Figure 8 Permeability vs Mean Grain Size @ 1200 psig NCS (Mean Net Effective Stress) ............... Figure 9 Spectral Core Gamma (4100 ft - 4250 ft) .................................................................... Figure 10 Depth Plot (4100 ft - 4250 ft) .................................................................................... Figure 11 Profile Permeability Plot (4100 ft - 4250 ft) ................................................................. Figure 12 Statistical Histograms (Mean Net Effective Stress) ............... .......................... ............. Figure 13 Appendix I Core Inventory ...... .......................... .....................................................................' Page(s) 1 Appendix II Sample Inventory ...... ............ ............. .................................. ...... ........................... Page(s) 1-4 Appendix III Statistical Averages ............................................................................................... Page(s) 1 Appendix IV Pilot Study ProQram Laser Particle Size Analysis Data............................................................................. Page(s) 1 Detailed Particle Size Analysis (Graphical & Tabular Data) Appendix V Viscosity Comparison Data ..................................................................................... Page(s) 1 - 2 API Gravity Measurements.......... ........................................................................... Page(s) 3 Appendix VI Spontaneous Imbibition Report Analytical Protocol /Table of Contents...................................................................... Page(s) i Spontaneous Imbibition Images .. .... .... ........... .................. ......... ...... ..... ......... ........... Page(s) 1-12 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the dient. The conclusions. inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Arry reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division . 6316 Windfern . Houston, TX 77040 USA . Tel: 713-328-2565 . Fax: 713-328-2567 .. [ore Lab RESERVOIR OPTIMIZATION Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska Table of Contents 16-May-05 Appendix VII Preliminary Routine Core Analysis Instructions ................ .......................... .......... ....... Page(s) 1-4 Appendix VIII Final Report Distribution......... ................................................................................ Page(s) 1 CD-ROM Contains all core analysis data (graphical & tabular) This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the infonnation contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division 6316 Windfern Houston, TX 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 · HnlLnllSUtlnS Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska HOU-050167 Conventional Core Analysis Final Report The laboratory core processing and measurements discussed herein were performed by Core Laboratories, Houston, Texas under the direction of Dr. Howard White, of Kerr-McGee Oil & Gas Corporation, and Dr. Robert Skopec, of Petrophysical Applications International, The Woodlands, Texas. At this time, a number of additional studies remain in progress, including Advanced Rock Properties & Geology. ROUTINE CORE ANALYSIS PREPARATION Inventory Upon arrival (February 16, 2005), an inventory of the core was first prepared to verify the shipment contents. The core inventory, including core number, segment or tube number and depth interva', was forwarded to the client and posted to a secure website. An inventory of the disposable inner barrel tubes is included as Appendix I of this report. Core Gamma The spectral gamma activity of the core was measured, converted to API units using calibration tubes of known activity and reported to the client in tabular and digital formats. These data are illustrated in Figure 10 of this report. CT Scanning Core Lab's High Resolution UltraScansm CT Scanner was used to assure proper orientation of laminae prior to slabbing and plug acquisition. This aided in the exposure of maximum dip and strike for plugging and photography. SlabbinQ and PhotoQraphy A low vibration vertical band saw was used to slab the friable core per instructions from Kerr-McGee. The geological slab thickness was cut to client specifications (specified by Kerr-McGee as 1/4 of the segment diameter). The geological slab was prepared for photography by carefully removing cutting debris. Photographs were taken as soon as possible after slabbing to ensure core and fluorescence integrity under visible and ultraviolet light sources. Photographs were provided to Kerr-McGee for proofing. Core Laboratories was then authorized to print five (5) sets of half-scale and overview format prints. Photography reports were issued under separate cover (March 2, 2005). Sample ACQuisition A set of one hundred forty-two (142) 1.5" & 1.0" diameter plugs were cut at specified locations as directed by Kerr-McGee. These included plugs designated for routine core analysis (horizontal (AH) & vertical (BV)), thin section, X-ray Diffraction, scanning electron microscopy & long-term storage (CH). Sample density, orientation and location decisions were made in conjunction with the client on the basis of log data, core gamma data and lithological observations. Decisions were also made regarding sample diameter; drilling fluid and end trim preservation and storage technique. A comprehensive sample inventory is included as Appendix II of this report. Sample Preparation Upon completion of sample acquisition, a 1/4" trim was taken from each end and archived for future use. Each sample was then carefully inspected for parallel ends, cleaned of all cutting debris along sample axis and end faces and encapsulated using Teflon tape, nickel foil & two (2) sets of stainless steel screens (250 mesh screens in direct contact with each sample end & 100 mesh screens on top to provide structural support at each sample end). The encapsulated samples were then "seated" at a nominal stress (200 psig NCS), liberally wrapped with plastic wrap and placed into opaque, hermetically sealed sample containers. The samples & trims were then placed into a freezer until required for additional tests. A comprehensive sample inventory highlighting specific sample tests and location can be found in Appendix II of this report. Horizontal & vertical routine plugs were selected on 6-ft increments in the depth interval of 4120.00 ft - 4138.50 ft (shale) as core quality allowed. In the depth interval of 4138.50 ft - 4178.50 ft (sand), sample density for horizontal routine core analysis plugs was increased to 1 per ft and routine vertical samples were selected at a frequency of 1 sample every 3-ft. ROUTINE CORE ANALYSIS PROCEDURES Pilot Study Samples A subset of six (6) samples was selected for a Pilot Study to determine the impact of routine core analysis methods on data quality. Laser particle size analysis was performed on these samples; these data can be found in Appendix IV of this report. A number of geological tests, including XRD, SEM & thin sections description, were also performed on these samples. It was determined from XRD analyses that routine extraction and drying methods would have no adverse affect on routine rock properties. These data have been reported under separate cover (Core Lab File No.: BR#050224-1). The Petrophysical portion of the pilot study measurements is still in progress and will be reported under separate cover upon completion. Routine Core Analysis rDean-Stark Analysis / Extraction for Water and Oil Saturationl Dean Stark analysis follows API RP 40 procedures. Toluene was conditioned (pre-boiled) to remove any absorbed water. Each sample was placed in a pre-weighed thimble to save any lost grains during the extraction process. All glass joints of the Dean Stark apparatus were sealed with Teflon tape. A moisture trap (desiccant tube with fresh activated silica gel) was placed on the top of each condensation tower. Specific Dean-Stark Procedures Fresh reagent grade toluene was used for each plug analyzed. The flasks and glassware were cleaned between each use to ensure there was no residual water or tracer present. An aliquot of toluene (approx. 25Occ) and 1.0 cc of water was added to the flask and conditioned. Each calibrated Dean Stark sidearm was inspected and an initial water measurement was made at this time. The system was kept closed except when adding or removing the sample in order to keep toluene loss to a minimum. After determining that sample mineralogy was not heat sensitive via XRD analysis (File No.: BR#050224-1), each core plug was weighed to an accuracy of ±O.001 g, placed into a pre-dried and pre-labeled glass thimble to trap lost grains and re-weighed to the same precision. A fiber filter was placed on top of each sample to minimize grain loss due to the capillary effect of toluene being dripped onto the sample during Dean Stark extraction / distillation. The plug was then immediately loaded into the Dean Stark apparatus. All joints were sealed and extraction / distillation was initiated. Toluene was refluxed until no further change in the water volume in the receiver was observed for twelve (12) hours (minimum Dean Stark extraction time is 48 hours). A Teflon swab was used to remove water droplets from the neck of the condenser and the sidearm. The water volume was recorded to within :I:O.025cc (1.2% PV @ 10% porosity). Upon completion of Dean Stark extraction/distillation, the samples were batch extracted using chloroform/methanol (83:17) & methylene chloride/methanol (75:25) azeotropes. Solvent discoloration was used as an initial indicator of cleanliness. Once the solvent showed no sign of staining, the samples were soaked in methylene chloride for six (6) hours and the effluent was inspected for fluorescence. The samples were then transferred to methanol in the absence of effluent fluorescence to remove the remaining salt from the samples. A silver nitrate solution was used daily to indicate the presence or absence of salt in the effluent. Once all salt and hydrocarbons were extracted from the samples, they were moved to a convection oven for drying. Each sample and thimble apparatus was dried in a convection oven at 240°F until weight stabilization, :1:0.001 grams to facilitate a total porosity model. Upon weight stabilization, the samples were removed from heated drying and placed into desiccators. Each plug & thimble apparatus was weighed within ±0.001 g. Each sample was then removed from the thimble and weighed independently. Petrophvsical Measurements Grain Volume Direct grain volume measurements for the horizontal and vertical plugs were made using an automated porosimeter. This instrument utilizes the principle of gas expansion as described by Boyle's Law. Helium was used as the test gas. Material balance adjustments were made for sleeve and screen volumes. The instrument calibration is maintained on a daily basis and test standards were run to verify instrument accuracy. Grain Density Calculated grain densities were obtained utilizing grain volume measurements and sample weights. Material balance adjustments were made for sleeve and screen weights. Grain densities were checked against lithology standards. ii PluQ Dimensions Sample lengths and diameters were measured using digital metric calipers. Material balance adjustments were made for sleeve and screen thickness. Porosity Pore volumes were directly measured on all routine samples at a mean net effective stress of 1200 psig net confining stress (NCS) in a hydrostatic core holder using the Boyle's Law double-cell technique (API RP-40, See 5.3.2.2). Every fifth horizontal sample was measured at four additional stresses (600, 1800, 2400 & 3000 psig NCS) provided by representatives from Kerr-McGee. Porosity was calculated using the following equation: Porosity = Pore Volume I (Pore Volume + Grain Volume) X 100 Permeabilitv Values for permeability to air were measured using the steady state method at a mean net effective stress of 1200 psig net confining stress (NCS) in a hydrostatic core holder (API RP-40, Sec 6.3.1.1). Every fifth horizontal sample was measured at four additional stresses (600, 1800, 2400 & 3000 psig NCS) provided by representatives from Kerr-McGee. Sample permeability was calculated using the following equation: Kair = Q x 1.1. X L x Pa åP x Pm x A where: Q = Gas Flow Rate (cc/sec) µ = Gas Viscosity (centipoise) L = Sample Length (em) åP = differential pressure across sample (atms) Pm = mean pressure (atms) A = Sample cross-sectional area (cc) Pa = atmospheric pressure (atms) Profile Permeability After dissipation of volatile hydrocarbons, unsteady-state profile permeability measurements were made on the ~ sections of a specified core interval (4129.00 - 4178.00) at a frequency of ten (10) measurements per foot. Four hundred (400) total measurements were performed to characterize core heterogeneity. The results of these measurements are illustrated in Figure 12 of this report. VlSCositv I Gravity Measurements Two (2) samples (4143.70 & 4157.40) were selected for viscosity measurements & three (3) samples (4140.50, 4151.50 & 4160.50) across the recovered core interval were selected for, API gravity measurements to illustrate the mud filtrate invasion profile. The results of these analyses are found in Appendix V of this report. Additional samples were forwarded to Humble Geochemistry for oil characterization. Soontaneous Imbibition StudY Immediately following core photography of selected 14 slabs, a qualitative spontaneous imbibition study was performed on three (3) depth intervals [4140.00 ft - 4140.25 ft, 4151.00 ft - 4151.25 ft & 4161.00 ft 4161.25 ft], employing synthetic formation brine (35000 ppm TDS) and lab oil (420 API) as test fluids, in order to qualitatively determine apparent core wettability. The results of these analyses should be considered qualitative at best. Upon review of the qualitative report on the ~ segments, Core Lab was requested to perform the imaging technique on one (1) % segment [4140.00 ft - 4140.25 ft]. The spontaneous imbibition report can be found in Appendix VI of this report. Laser Particle Size Analvsis (LPSA) The Laser Particle Size Analyzer determines particle size by measuring the amount of light refracted by the particle surface. This is accomplished by the use of a Fourier lens and a light diffraction detector system consisting of three sets of photo diode detectors for low, medium, and high angle light diffraction. Measured particle size can range from 0.1 to 2000 microns and is determined as sample material dispersed in a transport fluid is circulated through a laser beam. A 0.5% hexa-metaphosphate solution is used as the transporting fluid to de-ionize particles prior to measurement. Quality standards are measured, and background checks on the transporting fluid are performed to ensure data integrity on a daily basis. Cumulative and incremental data are presented both in tabular and graphical formats. The moments of sorting are presented using the Trask, Inman, and Folk classifications on a per sample basis. 111 Accurate measurement of grain size by the laser particle size analyzer is dependent on several factors including: representative sampling, granular angularity, proper cleaning of samples, proper operation of the LPSA unit, and quality control I review of the data generated. Laser Particle Size Analysis was performed on all routine core analysis samples. Sample Acquisition A representative end trim from each 'AH' routine core analysis sample was used for LPSA. Each trim was inspected and cleaned of any debris andlor fines material that may have been produced during sample preparation. Sample Preparation - Extraction Water and hydrocarbon extraction is necessary prior to LPSA measurement. Hydrocarbons were removed using a series of toluene rinses. Excess toluene was "wicked" from the samples using an absorbent material. The samples were then placed under a heat lamp to ensure complete drying. Sample Preparation - DisaQQreaation All samples were gently disaggregated using a mortar and Teflon pestle. Extreme care was taken during this process to prevent grain breakage. The material to be measured was added to a solution of 0.5% sodium hexa-metaphosphate to de-ionize particles. System Set-up & Operation The laser optics particle size analyzer was rinsed prior to making any measurements. Laser alignment was performed prior to each sample run. A "background" reading of the carrier fluid was also performed prior to each sample run. A selection of standard samples is run on a weekly basis to check the machine's calibration. The system is drained of water and opened for cleaning and inspection every week. The system is also serviced on an annual basis to ensure proper calibration. The system must be operated according to the instructions provided by the manufacturer. Any attempt to circumvent the programmed procedures of the system is prohibited. Report preparation The raw data file created by the software was copied into proprietary software for the preparation and production of reports. Additional Notes · Sample lithology is determined using the laser particle size data. · The Vshale (%) presented here is calculated from the laser particle size data and includes the range from clay through medium grain silt. · The Surface Area (Cs) assumes smooth, solid, spherical, particles. · The Standard Deviation describes the width of the measured particle distribution. It does not provide an indication of statistical error about the mean value. · The Gravel Pack is calculated according to Saucier's technique, which assumes a ratio of six between the median grain size of the gravel pack and the median grain size of the sample. Twelve (12) copies of this report have been prepared for Kerr-McGee Oil & Gas Corporation et al. The final report distribution can be found in Appendix VIII of this report. The contents of this report, the CT scans and all graphs & plots are presented on the CD ROM located at the back of this report. ~e.s~~e~~eciate the opportunity to provid~ these data to Kerr-McGee Oil & Gas Corporation. Russ Peacher Core Laboratories Houston A TC Laboratory Supervisor February 10, 2005 References 1. "Recommended Practices for Core Analysis·, RP 40, Second Edition, American Petroleum Institute, February 1998. tV .. [ore Lab RESERVOIR DPTIJ1IZATIUN ROUTINE CORE ANALYSIS DATA for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 9, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES DIVISION 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 Kerr McGee 011 & Gas Corporation  File No.: HOU-050167 Nikaitchuq 4 Date: May 9, 2005 NW Milne Point Analyst(s): RP, MM Alaska 'tn.1tU"trUltn Cores: Conventional CORE ANAL YSIS DATA II> g 600 Dsio NCS 1200 Dsio NCS 1800 oslo NCS 2400 Dsio NCS 3000 DsiQ NCS Grain 0 Smpl c DEPTH Kair POR Kair POR Kalr POR Kair POR Kair POR Density KIPhi Sco Stw "8 No u. (ft) (mD) (%) (mD) (%) (mD) (%) (mD) (%) (mD) (%) (glee) sq rt (%) (%) LITHOLOGY FLU 7BV 4120.00 0.548 23.41 2.743 1.5 1.0 93.4 Shale vslty no 9AH 4120.50 1.79 23.42 1.21 22.86 0.656 22.32 0.484 21.43 0.322 20.17 2.746 2.3 2.7 92.2 Shale vslty no 11BV 4126.00 0.576 21.91 2.743 1.6 2.9 92.0 Shale vslty no 13AH 4126.45 1.53 22.47 2.747 2.6 1.2 93.3 Shale vslty no 15BV 4132.00 0.351 23.04 2.740 1.2 4.8 90.9 Sd vfg vshy lam(2,3) vslty stks ft 17AH 4132.35 3.27 22.72 2.734 3.8 6.7 89.5 Sd vfg vshy lam(2,3) slty stks gld 19AH 4138.50 507 34.40 2.685 38.4 66.3 26.0 Sd vf-1g vsshy sslty gld 21AH 4139.50 936 36.88 850 35.65 778 35.00 734 34.51 698 34.07 2.673 48.8 66.1 26.1 Sd f-vfg cln sslty gld 23AH 4140.50 962 36.18 2.666 51.6 64.7 25.1 Sd 1-vfg cln sslty gld 25BV 4140.80 818 36.23 2.661 47.5 65.0 25.3 Sd 1-vfg cln sslty gld 27AH 4141.20 902 34.03 2.705 51.5 64.4 24.3 Sd 1-vfg cln vfoss gld 29AH (1) 4142.80 10.8 18.38 2.727 7.7 35.7 53.9 Silt shy lam(2,3) stks gld 31AH 4143.50 235 32.47 2.719 26.9 51.5 37.7 Sd vfg vsshy lam(2) vslty stks gld 33BV 4143.80 135 32.06 2.703 20.5 51.6 42.9 Sd vfg vsshy lam(2) vslty stks gld 35AH 4144.50 373 33.34 360 32.95 351 32.30 347 32.05 335 31.84 2.718 33.1 64.8 27.6 Sd vfg cln slty gld 37AH 4145.20 260 32.25 2.719 28.4 63.5 29.7 Sd vfg vsshy vslty gld 39AH 4146.50 278 32.64 2.739 29.2 64.2 27.0 Sd vfg vsshy slty gld 41BV 4146.80 173 32.67 2.740 23.0 64.3 26.6 Sd vfg vsshy slty gld 43AH 4147.50 196 31.66 2.774 24.9 67.7 21.8 Sd vf-fg cln sslty gld 45AH (1) 4148.70 19.8 32.76 6.35 32.21 4.34 32.01 3.53 31.73 3.05 31.62 3.062 4.4 2.0 93.5 Shale lam(2,4) vslty stks ft gld 47AH 4149.70 342 31.25 2.697 33.1 63.3 31.6 Sd vf-1g vsshy slty gld 49BV 4150.20 387 34.01 2.691 33.7 69.1 23.6 Sd vf-fg vsshy slty gld 51AH 4150.50 458 34.14 2.692 36.6 67.3 23.6 Sd vf-1g cln sslty gld 53AH 4151.50 399 33.80 358 32.96 348 32.52 336 32.18 327 31.93 2.703 33.0 67.2 24.5 Sd vf-fg cln sslty gld 55AH 4152.50 337 32.98 2.708 32.0 67.1 24.0 Sd vf-1g cln sslty gld Page 1 Nlkaltchuq 4 Core Analysis Data May 9, 2005 Kerr McGee 011 & Gas Corporation  File No.: HOU-050167 Nikaitchuq 4 Date: May 9, 2005 NW Milne Point Analyst(s): RP, MM Alaska ,tt"ttu"unltt~ Cores: Conventional CORE ANALYSIS DATA '" Q> 600 psia NCS 1200 Dsia NCS 1800 oslo NCS 2400 Dsia NCS 3000 Dsia NCS Grain Õ Smpl c DEPTH Kair POR Kair POR Kair POR Kair POR Kair POR Density KIPhi Sco Stw No ~ (ft) (mD) (%) (mD) (%) (mD) (%) (mD) (%) (mD) (%) (glee) sq rt (%) (%) LITHOLOGY FLU 57BV 4152.80 143 32.01 2.716 21.1 70.1 23.7 Sd vf-fg cln sslty gld 59AH 4153.50 54.9 29.48 2.724 13.6 52.8 43.5 Sd vf-fg vsshy lam(2,3) slty stks gld 61AH 4154.60 75.8 30.18 2.719 15.8 59.3 32.1 Sd vf-fg cln slty molt gld 67AH 4156.50 379 32.14 2.696 34.3 62.5 25.6 Sd vf-fg vsshy lam(2) stks gld 69AH 4157.50 591 35.11 2.699 41.0 63.1 23.5 Sd vf-fg cln sslty gld 71AH 4158.50 681 35.18 639 34.44 628 34.02 608 33.69 594 33.43 2.698 43.1 69.5 20.2 Sd f-vfg cln gld 73BV 4159.00 244 34.70 2.701 26.5 39.8 53.7 Sd vf-fg cln gld 75AH 4159.50 1010 36.22 2.698 52.8 59.5 30.4 Sd vf-fg cln gld 77AH 4160.50 1170 36.78 2.685 56.4 60.6 28.8 Sd vf-fg cln gld 79AH 4161.50 1140 36.40 2.682 56.0 63.0 26.4 Sd vf-fg cln gld 81BV 4162.30 787 35.92 2.687 46.8 58.1 35.4 Sd vf-fg cln gld 83AH 4162.70 1140 36.54 1020 35.66 972 35.20 932 34.80 901 34.48 2.681 53.5 50.3 43.3 Sd vf-fg cln gld 85AH 4163.70 534 34.71 2.710 39.2 55.4 38.1 Sd vfg vsshy slty gld 87AH 4164.50 489 33.90 2.719 38.0 68.6 23.9 Sd vf-fg cln slty gld 89BV 4164.80 290 33.73 2.721 29.3 37.2 35.4 Sd vf-fg cln slty gld 91AH 4165.50 569 35.02 526 33.97 506 33.44 489 33.04 476 32.68 2.701 39.4 65.0 24.7 Sd vf-fg cln slty gld 93AH 4166.60 538 34.61 2.704 39.4 68.4 26.1 Sd vf-fg cln slty gld 95AH 4167.70 32.8 28.18 2.719 10.8 33.3 60.9 Sd vfg sshy lam(2,3) vslty stks gld 97BV 4168.30 107 32.32 2.719 18.2 43.8 50.1 Sd vfg vsshy lam(2) vslty stks gld 99AH 4168.65 242 32.77 2.720 27.2 51.3 40.1 Sd vfg vsshy lam(2) vslty stks gld 101AH 4169.40 58.9 30.51 2.729 13.9 49.2 44.5 Sd vf·silt sshy lam(2,3) stks gld 103AH 4170.50 260 33.67 239 32.83 231 32.39 223 32.04 218 31.76 2.707 27.0 58.0 35.3 Sd vfg vsshy vslty gld 1 05BV 4171.00 0.261 20.11 2.958 1.1 25.7 69.9 Shale vslty lam(2,3) stks ft 9 Id 1 07 AH 4171 .50 2.79 24.84 2.752 3.4 5.6 90.9 Shale vslty lam(2,3) stks ft gld 109AH 4172.30 395 33.49 2.707 34.3 53.8 41.3 Sd vf-fg vsshy lam(2) sslty stks gld 111AH 4173.30 78.1 31.15 2.731 15.8 36.8 58.6 Sd vfg vsshy lam(2,3) vslty stks gld Page 2 Nikaitchuq 4 Core Analysis Data May 9, 2005 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska ., CI> 600 csia NCS Õ Smpl c DEPTH Kair POR 8 No u. (ft) (mD) (%) 113BV 4174.00 115AH 4174.50 117AH 4175.50 119AH 4176.50 10.3 27.53 121AH 4177.35 1200 csia NCS Kair POR (mD) (%) 148 32.79 308 32.99 45.8 30.40 7.09 27.03 5.68 25.24 1800 Dsio NCS Kair POR (mD) (%) 2.92 26.38  'ttllllt!lHHUICn CORE ANALYSIS DATA 2400 Dsio NCS Kair POR (mD) (%) 3000 DsiQ NCS Kair POR (mD) (%) 2.03 25.85 1 .55 25.43 Footnotes: (1) : Fractures. chips and/or partings along laminae may yield optimistic permeability and/or porosity values. Fluid saturations were determined by the Dean Stark technique using the following fluid properties: Brine 1.016 glcc Oil 0.916 glee Page 3 Nlkaitchuq 4 Core Analysis Data File No.: HOU-050167 Date: May 9. 2005 Analyst(s): RP, MM Cores: Conventional Grain Density KIPhi Sco Stw (glee) sq rt (%) (%) LITHOLOGY FLU 2.715 21.2 25.1 67.6 Sd vf-fg vsshy lam(2) slty stks gld 2.726 30.6 38.6 53.4 Sd vf-fg vsshy lam(2) slty stks gld 2.737 12.3 22.8 72.0 Silt shy lam(3,4) mott gld 2.741 5.1 12.5 82.3 Silt vshy lam(3,4) stks gld 2.749 4.7 12.2 80.9 Shale vslty lam(2,4) stks gld May 9. 2005 Kerr McGee Oil & Gas Corporation Nìkaitchuq 4 NW Milne Point Alaska  I'ttltlIUU"SUVIUS File No.: HOU-OS0167 Date: May 9, 200S Analyst(s): RP, MM Cores: Conventional ANAL YSIS PROTOCOL Sample Preparation 1.S" (AH & BV samples) diameter plugs were drilled with liquid nitrogen and trimmed into right cylinders with a diamond-bladed trim saw. The samples were encapsulated in teflon tape, nickel foil, and stainless steel screens. All sample trims were archived. Core Extraction Plugs selected for routine core analysis were placed In Dean Stark equipment using toluene, followed by Soxhlet extraction cycling between a methylene chloride I methanol (7S:2S) azeotrope and methanol. Sample DrvinQ Samples were oven dried at 2400 F to weight equilibrium (+1- 0.001 g). Porositv Porosity was determined using Boyle's Law technique by measuring grain volume at ambient conditions & pore volume at indicated net confining stresses (NCS) Grain Densltv Grain density values were calculated by direct measurement of grain volume and weight on dried plug samples. Grain volume was measured by Boyle's Law technique. Permeabilltv Permeability to air was measured on each sample using steady-state method at indicated NCS. Fluid Saturations Fluid saturations were determined by the Dean Stark technique using the following fluid propreties: Brine 1.016 glcc Oil 0.916 glee Page 4 Nlkaltchuq 4 Core Analysis Data May 9, 2005 Kerr McGee 011 & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska DESCRIPTION CODE KEY AND ABBREVIATIONS UTHOLOGY FLUORESCENCE INTENSITY Anhy Anhydrite ev even bt bright Cgl Conglomerate stk streaks(ed) ft faint Dol Dolomite spt spots(ed) dl dull Glauc Glauconite mott mottled vft very faint H Halite Lig Lignite COLOR MODIFIERS Ls Limestone b blue u unconsolidated Pyr Pyrite bow blue-white vs very slightly Sd Sand bz bronze s slightly Sh Shale gld gold m moderately Sit Silt w white mw moderately well Sf Shell Fragments y yellow v very w well GRAIN SIZE OTHER vfg very fine grain calc calcareous ha high angle fg fine grain cln clean hd hard mg medium grain carb carbonaceous lam lamlriâted(lon) cg coarse grain cem cementation mlc micaceous con consolidated ms mudshot dns dense shy shaley flu fluorescence slty silty foss fossiliferous tr trace fre fraclured(s) wg wggy f flushed vt vertical  Jnlnn" JtJ.'fltn OTHER ABBREVIATIONS POR porosity. % Sco core 011 saturation, % pore volume Stw total water saturation. % pore volume Vsh volume of shale. % bulk volume Cs surface area (m4/cc) Mean mean grain size. microns File No.: HOU-050167 Date: May 9, 2005 Analyst(s): RP, MM Cores: Conventional IINTERLAMsm THIN BED SAMPLE DESCRIPTION I TYPE 1 SHALE LAMINATIONS < 1 mm TYPE 3 SHALE LAMINATIONS 5-10 mm Page 5 Nikaltchuq 4 Core Analysis Data TYPE 2 <-.~ ( .... . . : . . .' . . . . . ~. . . : . . : '. .' . . . :.' . \ '~(j' .:......./...~:~ ,., . . ..:." SHALE LAMINATIONS 1-5 mm TYPE 4 - - SHALE LAMINATIONS> 10 mm May 9, 2005 Kerr McGee Oil & Gas Corporation  File No.: HOU-050167 Nikaitchuq 4 Date: March 10, 2005 NW Milne Point Analyst(s): RP, SR Alaska ,tnOttlltlStIIYltrs PARTSIZsM ANAL YSIS SMPL DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO (ft) (mD) (%) GRVL VCRS CRS MED FINE VFIN CRS MED FINE VFIN (%) (%) (m2/cc) (µ) LlTHOLOGY* 9AH 4120.50 1.21 22.86 0.0 0.0 0.0 0.0 0.4 4.3 7.7 20.8 26.8 21.5 18.5 88 1.12 12 Shale vslty 13AH 4126.45 1.53 22.47 0.0 0.0 0.0 0.0 0.0 0.1 5.5 20.0 26.7 24.0 23.7 94 1.32 10 Shale vslty 17 AH 4132.35 3.27 22.72 0.0 0.0 0.0 0.0 0.5 8.5 16.4 20.1 20.6 17.3 16.5 74 0.99 19 Sd vfg vshy slty 19AH 4138.50 507 34.40 0.0 0.0 0.0 1.7 32.1 41.1 9.1 4.0 5.3 3.5 3.3 16 0.26 102 Sd vf-fg vsshy sslty 21 AH 4139.50 850 35.65 0.0 0.0 0.0 2.4 35.9 41.6 7.0 3.1 4.6 2.8 2.7 13 0.22 111 Sd f-vfg cln sslty 23AH 4140.50 962 36.18 0.0 0.0 0.0 2.9 37.5 40.8 6.1 2.9 4.4 2.7 2.6 13 0.21 115 Sd f-vfg cln sslty 27 AH 4141.20 902 34.03 0.0 0.0 0.0 3.5 42.6 40.0 3.7 2.6 3.5 1.9 2.1 10 0.18 124 Sd f-vfg cln vfoss 29AH 4142.80 10.8 18.38 0.0 0.0 0.0 0.0 2.9 23.9 27.~ 15.4 12.7 10.0 7.8 46 0.57 38 Silt shy 31 AH 4143.50 235 32.47 0.0 0.0 0.0 0.0_ 14.7 44.1 21.3 5.2 6.7 4.5 3.4 20 0.30 73 Sd vfg vsshy vslty 35AH 4144.50 360 32.95 0.0 0.0 0.0 0.1 20.2 47.6 17.8 2.8 5.5 3.5 2.6 14 0.25 85 Sd vfg cln slty 37 AH 4145.20 260 32.25 0.0 0.0 0.0 0.0 15.2 44.3 21.3 4.8 6.4 4.5 3.5 19 0.30 74 Sd vfg vsshy vslty 39AH 4146.50 278 32.64 0.0 0.0 0.0 0.1 19.7 45.0 17.8 3.4 5.8 4.2 4.1 17 0.31 82 Sd vfg vsshy slty 43AH 4147.50 196 31.66 0.0 0.0 0.0 1.4 30.6 45.4 8.1 2.1 4.8 3.9 3.7 14 0.26 102 Sd vf-fg cln sslty 45AH 4148.70 6.35 32.21 0.0 0.0 0.0 0.0 0.6 7.6 15.6 20.0 19.6 14.4 22.2 76 1.27 17 Shale vslty 47 AH 4149.70 342 31.25 0.0 0.0 0.0 3.4 28.4 36.3 11.9 5.7 6.2 4.2 3.9 20 0.30 95 Sd vf-fg vsshy slty 51 AH 4150.50 458 34.14 0.0 0.0 0.0 0.3 25.9 47.0 12.9 2.7 5.2 3.1 2.8 14 0.24 94 Sd vf-fg cln sslty 53AH 4151.50 358 32.96 0.0 0.0 0.0 0.4 27.1 47.1 12.7 2.6 4.9 2.8 2.5 13 0.23 96 Sd vf-fg cln sslty 55AH 4152.50 337 32.98 0.0 0.0 0.0 0.7 29.6 46.4 10.8 2.2 4.7 2.8 2.8 13 0.23 100 Sd vf-fg cln sslty 59AH 4153.50 54.9 29.48 0.0 0.0 0.0 0.3 23.2 44.9 15.5 3.1 5.3 3.8 3.9 16 0.29 88 Sd vf-fg vsshy slty 61 AH 4154.60 75.8 30.18 0.0 0.0 0.0 0.7 25.3 44.8 14.3 3.0 5.0 3.5 3.4 15 0.27 92 Sd vf-fg cln slty 67 AH 4156.50 379 32.14 0.0 0.0 0.0 0.6 33.6 50.3 5.1 2.5 3.6 1.9 2.4 10 0.20 109 Sd vf-fg cln 69AH 4157.50 591 35.11 0.0 0.0 0.0 0.2 27.7 53.2 7.7 2.1 4.0 2.4 2.8 11 0.22 100 Sd vf-fg cln sslty 71 AH 4158.50 639 34.44 0.0 0.0 0.0 1.2 38.5 46.9 4.1 1.9 3.2 1.7 2.4 9 0.19 115 Sd f-vfg cln 75AH 4159.50 1010 36.22 0.0 0.0 0.0 0.3 30.2 52.0 6.0 2.3 4.2 2.4 2.7 12 0.22 104 Sd vf-fg cln 77 AH 4160.50 1170 36.78 0.0 0.0 0.0 0.7 33.3 50.1 5.2 2.2 4.0 2.2 2.3 11 0.20 108 Sd vf-fg cln Page 6 Kerr McGee Oil & Gas Corporation . File No.: HOU-050167 Nikaitchuq 4 Date: March 10, 2005 NW Milne Point Analyst(s): RP, SR Alaska 'tTlUtttll1tSUVlttS PARTSIZsM ANAL YSIS SMPL DEPTH Kair POR SAND % SILT % CLAY Vsh Cs MEAN NO (ft) (mD) (%) GRVL VCRS CRS MED FINE VFIN CRS MED FINE VFIN (%) (%) (m2/cc) (µ) LlTHOLOGY* 79AH 4161.50 1140 36.40 0.0 0.0 0.0 0.1 28.6 55.8 5.1 2.0 4.0 2.1 2.3 10 0.20 103 Sd vf-fg cln 83AH 4162.70 1020 35.66 0.0 0.0 0.0 0.4 32.2 51.7 5.6 2.1 3.8 2.0 2.2 10 0.19 107 Sd vf-fg cln 85AH 4163.70 534 34.71 0.0 0.0 0.0 0.1 21.5 46.3 15.1 3.1 6.0 4.2 3.8 17 0.30 86 Sd vfg vsshy slty 87AH 4164.50 489 33.90 0.0 0.0 0.0 0.2 24.2 47.5 14.5 2.4 5.1 3.3 2.8 14 0.25 91 Sd vf-fg cln slty 91 AH 4165.50 526 33.97 0.0 0.0 0.0 0.1 23.8 48.3 15.3 2.2 4.8 3.0 2.5 13 0.23 91 Sd vf-fg cln slty 93AH 4166.60 538 34.61 0.0 0.0 0.0 0.0 22.0 48.4 16.1 2.4 5.1 3.3 2.7 13 0.25 88 Sd vf-fg cln slty 95AH 4167.70 32.8 28.18 0.0 0.0 0.0 0.1 11.9 31.2 22.1 13.9 9.3 5.8 5.7 35 0.43 56 Sd vfg sshy vslty 99AH 4168.65 242 32.77 0.0 0.0 0.0 0.0 16.2 43.8 21.5 4.4 6.0 4.5 3.6 18 0.30 76 Sd vfg vsshy vslty 101 AH 4169.40 58.9 30.51 0.0 0.0 0.0 0.0- 3.5 29.4 33.4 14.4 7.8 6.2 5.3 34 0.43 47 Sd vf-silt sshy 103 AH 4170.50 239 32.83 0.0 0.0 0.0 0.0 15.8 42.4 21.4 5.3 6.4 4.8 3.9 20 0.32 73 Sd vfg vsshy vslty 107 AH 4171.50 2.79 24.84 0.0 0.0 0.0 0.0 0.0 6.1 20.6 25.9 20.8 14.1 12.6 73 0.85 20 Shale vslty 109 AH 4172.30 395 33.49 0.0 0.0 0.0 5.3 31.7 35.2 11.6 4.4 4.8 3.5 3.4 16 0.26 106 Sd vf-fg vsshy sslty 111 AH 4173.30 78.1 31.15 0.0 0.0 0.0 0.1 13.4 38.7 23.8 6.8 6.5 5.6 5.2 24 0.38 66 Sd vfg vsshy vslty 115 AH 4174.50 308 32.99 0.0 0.0 0.0 3.0 25.9 38.5 15.3 4.1 5.3 4.1 3.7 17 0.29 93 Sd vf-fg vsshy slty 117 AH 4175.50 45.8 30.40 0.0 0.0 0.0 0.0 1.3 21.6 28.6 15.8 12.8 10.6 9.4 49 0.64 35 Silt shy 119 AH 4176.50 7.09 27.03 0.0 0.0 0.0 0.0 0.0 11.1 24.6 20.7 17.3 14.0 12.3 64 0.81 25 Silt vshy 121 AH 4177.35 5.68 25.24 0.0 0.0 0.0 0.0 0.1 9.4 22.9 20.9 17.6 15.2 14.0 68 0.87 23 Shale vslty Footnotes: . Lithology determined using laser particle size distribution. Page 7 Kerr McGee Oil & Gas Corporation ~ File No.: HOU-050167 Nikaitchuq 4 ~ Date: March 10, 2005 NW Milne Point Depth : 4120.50 Core lfII:Ï Sample: 9AH JCS(mlt;~ EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partslz am Distribution 25 kcrlJ®8 " t j 'ª · ~ kõ~t · · · · ~ · ~ · · · · -=--~ ~-: 20 · _.._.-,.._-"---------~- 80 ~ · :@I · @» · ~ · ~~ · 0 ~ · ~ · · · c: -15 · · 603 ~ " · · c: c: · · ã cP · · =' · · ;¡:- ~ 10 · · CD " , 40 ~ u.. · ~ · · · · 5 · 20 · .. . .N'.Jd1f · · · · · 0 . . . . . . . . . . I ... 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -125 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0602 0.0024 4.0549 VCRS SD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0362 0.0014 4.7896 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0264 0.0010 5.2427 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0200 0.0008 5.6450 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0102 0.0004 6.6163 CAS so 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0049 0.0002 7.6656 40 125 0.0165 0.<4200 0.0 0.0 84 0.0035 0.0001 8.1428 45 1.50 0.0136 0.3500 0.0 0.0 80 0.0027 0.0001 8.5454 MED 50 1.75 0.0117 02970 0.0 0.0 95 0.0019 0.0001 9.0604 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 225 0.0083 02100 0.0 0.0' 60 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 SURFACE AREA (m^2Icc): 1.1246 SAND 120 3.00 0.0049 0.1250 0.4 0.4 0.4 140 3.25 0.0041 0.1050 0.9 1.3 170 3.50 0.0035 0.0880 1.1 2.4 VFINE 200 3.75 0.0029 0.0740 12 3.6 STD DEVIATION (mm) : 0.0114 SAND 230 4.00 0.0024 0.0620 1.2 4.3 4.7 270 4.25 0.0021 0.0530 1.3 6.0 325 4.50 0.0017 0.0440 1.5 7.5 CRS 400 4.75 0.0015 0.0370 2.1 9.6 STD DEVIATION (Inches): 0.0005 SILT 500 5.00 0.0014 0.0310 2.9 7.7 12.5 525 0.0010 0.0260 3.8 16.3 5.50 0.0009 0.0220 4.8 212 GRAVEL PACK : NlA MED 5.75 0.0007 0.0190 5.7 26.9 SILT 6.00 0.0006 0.0160 6.4 20.8 33.2 625 0.0005 0.0130 6.7 40.0 6.50 0.0004 0.0110 6.8 46.8 TRASK" FOLK- MOMENT- FINE 6.75 0.0003 0.0093 6.7 53.5 SILT 7.00 0.0003 0.0078 6.5 26.8 60.0 MEAN 0.0125 6.6673 6.7550 7.25 0.0002 0.0065 6.1 66.1 MEDIAN 0.0102 6.6163 6.6163 7.50 0.0002 0.0055 5.6 71.7 SORTING 2.0144 1.4834 1.4528 VFINE 7.75 0.0002 0.0046 5.2 76.9 SKEWNESS 0.9473 0.0147 -0.1306 SILT 8.00 0.0001 0.0039 4.6 21.5 81.5 KURTOSIS 0.2249 1.0152 2.6646 8.25 0.0001 0.0033 4.1 85.6 8.50 0.0001 0.0028 3.6 89.2 8.75 0.0001 0.0023 3.1 92.3 9.00 0.??oo 0.0019 2.5 94.8 9.25 0.??oo 0.0016 2.0 96.8 . COMPUTED USING MilliMETER VALUES 9.50 0.??oo 0.0014 1.5 98.3 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 1.2 99.4 CLAY 10.00 0.??oo 0.0010 0.6 18.5 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ð' ~ Lab InlØlllI1'ftlllUorM File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4126.45 13AH EXTENDED RANGE PARTS/28M ANAL YS/S Laser Partsiz am Distribution 25 ~D'~J~~ : ~ kMt . 100 · · · 'l§j ~ · · (1@ .~ 20 ---------- 80 · @I» · · · ~ ~ · ~ · ~ · · ~ ~ 0 · · c ';: 15 - · · -60g · . u · · · c · · · i CII · · · :I · · · :C' W 10 · · · CD · · · ---~ -- 40 -- IL -. · · ~ · · · · · · · · · · · · . ""tíí 5- 0 · · 1 --. -20 · 'c · - · · · -lit - t 0 · · ~o 0 · · · · · 0 · · 0 ........1' . . ..... . . . ~. . . ~ 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PEFlCENTlLES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0324 0.0013 4.9501 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0254 0.0010 5.3004 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0209 0.0008 5.5813 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0163 0.0006 5.9388 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0083 0.0003 6.9106 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0041 0.0002 7.9431 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0030 0.0001 8.3811 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0023 0.0001 8.7858 MED 50 1.75 0.0117 0.2970 0.0 0.0 85 0.0017 0.0001 9.2214 SAND 80 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0.' 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 SURFACE AREA (m^2Ic:C:): 1.3248 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 3.25 0.0041 0.1050 0.0 0.0 170 3.50 0.0035 0.0880 0.0 0.0 VFINE 200 3.75 0.0029 0.0740 0.0 0.0 STD DEVIATION (mm) : 0.0089 SAND 230 4.00 0.0024 0.0620 0.1 0.1 0.1 270 4.25 0.0021 0.0530 0.3 0.4 325 4.50 0.0017 0.0440 0.9 1.3 CRS 400 4.75 0.0015 0.0370 1.7 3.0 STD DEVIATION (Inches) : 0.0004 SILT 500 5.00 0.0014 0.0310 2.6 5.5 5.6 5.25 0.0010 0.0260 3.7 9.3 5.50 0.0009 0.0220 4.7 13.9 GRAVEL PACK : NlA MED 5.75 0.0007 0.0190 5.5 19.5 SILT 6.00 0.0006 0.0160 6.1 20.0 25.6 6.25 0.0005 0.0130 6.5 32.2 6.50 0.0004 0.011 0 6.7 38.9 TRASK' FOLK- MOMENT- FINE 6.75 0.0003 0.0093 6.7 45.6 SILT 7.00 0.0003 0.0078 6.7 26.7 52.3 MEAN 0.0102 6.9576 7.0998 7.25 0.0002 0.0065 6.5 58.7 MEDIAN 0.0083 6.9106 6.9106 7.50 0.0002 0.0055 6.2 64.9 SORTING 2.0030 1.3471 1.2963 VFINE 7.75 0.0002 0.0046 5.9 70.8 SKEWNESS 0.9588 0.0662 0.1222 SILT 8.00 0.0001 0.0039 5.5 24.0 76.3 KURTOSIS 0.2648 0.8734 2.2291 8.25 0.0001 0.0033 5.0 81.3 8.50 0.0001 0.0028 4.5 85.8 8.75 0.0001 0.0023 3.9 89.7 9.00 0.??oo 0.0019 3.3 93.0 9.25 0.??oo 0.0016 2.6 95.7 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 2.0 97.7 .. COMPUTED USING PHI VALUES 9.75 O. ??oo 0.0012 1.6 99.3 CLAY 10.00 0.??oo 0.0010 0.7 23.7 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~, ÚJn! l.IIt:Ì -'"""""'" File No.: Date: Depth : Sample: HOU-050167 March 10,2005 4132.35 17 AH EXTENDED RANGE PARTS/Z5M ANAL YS/S Laser Partsiz am Distribution 25 k~~J~1 bõ~t . . 100 ~ 20 80 @J» ¡: ~ 0 c: ";:15 --- 60 g u c: ã GI ::J i cr f10 40 ~ u. $ 5 f . - 20 --~O 0 ~ r .... ..... . . ... . . . 10 0.1 0.01 0.001 Particle Diameter (mm) GRAJN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 ·1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0794 0.0031 3.6540 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0597 0.0024 4.0656 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0455 0.0018 4.4565 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0317 0.0012 4.9797 30 0.75 0.0236 0.8000 0.0 0.0 50 0.0135 0.0005 6.2134 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0056 0.0002 7.4802 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0038 0.0001 8.0372 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0028 0.0001 8.4795 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0019 0.0001 9.0445 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0 ! 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 SURFACE AREA (m^2Icc): 0.9939 SAND 120 3.00 0.0049 0.1250 0.5 0.5 0.5 140 3.25 0.0041 0.1050 1.1 1.7 170 3.50 0.0035 0.0880 1.8 3.5 VFINE 200 3.75 0.0029 0.0740 2.5 6.0 STD DEVIATION (mm) : 0.0209 SAND 230 4.00 0.0024 0.0620 3.1 8.5 9.1 270 4.25 0.0021 0.0530 3.6 12.7 325 4.50 0.0017 0.0440 4.0 16.7 CRS 400 4.75 0.0015 0.0370 4.3 21.0 STD DEVIATION (Inches): 0.0008 SILT 500 5.00 0.0014 0.0310 4.5 16.4 25.5 5.25 0.0010 0.0260 4.8 30.3 5.50 0.0009 0.0220 5.0 35.2 GRAVEL PACK : NlA MED 5.75 0.0007 0.0190 5.1 40.4 SILT 6.00 0.0006 0.0160 5.2 20.1 45.6 6.25 0.0005 0.0130 5.3 50.8 6.50 0.0004 0.0110 5.2 56.1 TRASK' FOLK- MOMENT" FINE 6.75 0.0003 0.0093 5.1 61.2 SILT 7.00 0.0003 0.0078 5.0 20.6 66.2 MEAN 0.0186 6.2357 6.3743 7.25 0.0002 0.0065 4.8 71.0 MEDIAN 0.0135 6.2134 6.2134 7.50 0.0002 0.0055 4.5 75.5 SORTING 2.3788 1.7119 1.6343 VFINE 7.75 0.0002 0.0046 4.2 79.6 SKEWNESS 0.9774 0.0345 0.0978 SILT 8.00 0.0001 0.0039 3.8 17,3 83.5 KURTOSIS 0.2292 0.8835 2.1864 8.25 0.0001 0.0033 3.5 86.9 8.50 0.0001 0.0028 3.1 90.0 8.75 0.0001 0.0023 2.7 92.7 9.00 0.??oo 0.0019 2.3 95.0 9.25 0.??oo 0.0016 1.8 96.8 - COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 1.5 98.3 -. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 1.2 99.4 CLAY 10.00 0.??oo 0.0010 0.6 16.5 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 'i ">:15 () c GI ::I ~10 u. GRAVEL VCRS so CAS so MED SAND FINE SAND VFINE SAND CRS SILT MEO SILT FINE SILT VFINE SILT CLAY 25 ~U'~J®~ 20 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 A GJn! laI:i -~ EXTENDED RANGE PARTSIZSM ANALYSIS · , , , , , · · · , · · , ..--.-------.--- · , · · · · · · · · · · · · · · · · "'@} @í?) , ........1 Laser Partsiz SIn Distribution GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 025 0.50 0.75 1.00 125 1.50 1.75 2.00 225 2.50 2.75 3.00 325 3.50 3.75 4.00 4.25 4.50 4.75 5.00 525 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo ~- 1~ j ~... -- ~ I,., ¡ :é§I:f9I: . ~ ~ : ~: : · . . . ~'-~---~-------- . · · · · · · - . · · ~ : 31- '. · . . . I . . . · . . . ... ~...~ _:- : ·........-.111 I 0.1 0.01 Particle Diameter (mm) MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 02500 02100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.5 3.9 6.8 9.6 11.7 12,4 11.7 9.8 72 4.7 2.6 1.3 0.7 0.6 0.9 1.2 1.4 1.5 1.4 1.3 1.2 1.0 0.9 0.8 0.7 0.7 0.6 0,6 0.5 0.4 0.3 0.2 0.1 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.7 5.6' 12.5 22.1 33.7 46.1 57.6 67.6 74.6 79.5 82.1 83.3 84.0 84.6 85.5 86.6 88.0 89.4 90.8 92.1 93.3 94.3 95.2 96.0 96.7 97.4 98.1 98.6 99.1 99.4 99.7 99.9 100.0 0.0 0.0 0.0 1.7 32.1 41.1 9.1 4.0 5.3 3.5 3.3 ----._---~----~---~- File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4138.50 19AH -r .,. · · 100 @~~y -- 80 o c 603 c ã <" CD --40- :!, - 20 .-,.- 0 0.001 SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 90 95 0.2164 0.1889 0.1667 0.1430 0.0994 0.0617 0.0309 0.0122 0.0057 SURFACE AREA (mA2Icc): STD DEVIATION (mm) : STD DEVIATION (IncheS): GRAVEL PACK : TRASK' MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.1023 0.0994 1.5225 0.8929 0.2301 Inches 0.0085 0.0074 0.0066 0.0056 0.0039 0.0024 0.0012 0.0005 0.0002 FOLK- 3.6441 3.3307 1.4022 0.4792 1.7714 phi 22084 2.4046 2.5848 2.8061 3.3307 4.0189 5.0167 6.3587 7.4506 02560 0.0679 0.0027 20140 MOMENT- 3.9122 3.3307 1.5606 1.6700 5.3365 - COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ";:15 u c CD ::I ~10 II.. GRAVEL VCRS SD CAS so MED SAND FINE SAND VFINE SAND CRS SilT MEO SilT FINE SilT VFINE SilT CLAY ~ ,:&\ Core Lati USI....llf~ EXTENDED RANGE PARTSIZSM ANAL YSIS · · · :~ --~----------._- : @J» :~ · -- .~---~...------------- · · · · · · · · · · · · · · · · · · ~~~J~~ 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ........1 · · · · · Laser Partslz am Distribution GRAlN SIZE DISTRIBUTION PHI ·2.00 ·1.75 ·1.50 ·1.25 ·1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 125 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0238 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo . . . MM 4.??oo 3.3800 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 2.1 4.7 7.8 10.7 12.6 13.1 12.0 9.7 6.8 4.1 2.0 0.7 0.2 0.3 0.6 1.0 1.2 1.3 1.3 1.1 1.0 0.8 0.7 0.6 0.6 0.6 0.5 0.5 0.4 0.3 0.2 0.2 0.1 FileNo. : Date: Depth : Sample: HOU-050167 March 10, 2005 4139.50 21 AH -....~B~;· . 100 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 2.4 7.1 ' 14.9 25.7 38.3 51.3 63.3 73.0 19.8 83.9 85.9 86.6 86.8 87.1 87.7 86.7 89.9 91.2 92.4 93.6 94.5 95.4 96.1 96.7 97.3 97.9 98.4 98.8 99.2 99.5 99.8 99.9 100.0 MEAN MEDIAN SORTING SKEWNESS KURTOSIS . . . . : ~ : ~ : : .~-+~~ ~@J:@1: 4 ~ : ~ : .. Ijl a¡: u ~~ . . u. . . . . . .,¡ - ;..- . 0.1 Particle Diameter (mm) PERCENTILES: 0.0 0.0 0.0 2.4 . u u.J...._r .. 0.01 I I - 80 o c 603 c ã c' ID - 40 .-. £ - 20 o 0.001 SORTING PARAMETERS mm 5 10 16 25 50 75 84 90 95 0.2278 0.1978 0.1743 0.1507 0.1071 0.0705 0.0526 0.0157 0.0071 35.9 SURFACE AREA (m"2Icc): 41.6 STD DEVIATION (mm) : 7.0 STD DEVIATION (inches) : GRAVEL PACK : 3.1 4.6 2.8 2.7 TRASK' 0.1106 0.1071 1.4621 0.9270 0.2203 Inches 0.0090 0.0078 0.0069 0.0059 0.0042 0.0028 0.0021 0.0006 0.0003 FOLK" 3.3314 3.2236 1.1916 0.3762 1.8737 phi 2.1343 2.3377 2.5208 2.7302 3.2238 3.8264 4.2500 5.9897 7.1458 0.2205 0.0608 0.0024 20140 MOMENT'"' 3.7433 3.2238 1.4774 1.8837 6.3548 . COMPUTED USING MilLIMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ....... ~ ';:15 u c CD :I WlO \L GRAVEL VCRSSD CAS so MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SILT CLAY ~, ÜJre laI:Ì .atml1~ File No.: Date: Depth : Sample: HOU-050167 March 10,2005 4140.50 23AH EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partslz am Distribution ~D'lJ®M r.J..~iB~;·· 100 · · ~ · 'ï3I ~ · · ø:ø @Â) · ~ · · @) @) ~ · · ~ ~ · · 80 o c 603 c Pi <. CD 40 .-. £, 5 ~- .1 ~ _: -~-:- - ('-- ~ - 0< . ~ llt.---- d ( .. I It-' ' :. -. . .., . j_ I ..1..1..I... .u 0.1 0.01 Particle Diameter (mm) o 0.001 20 ..=", o 10 ........ ... GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.2339 0.0092 2.0961 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.2025 0.0080 2.3038 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1788 0.0070 2.4838 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1555 0.0061 2.8852 30 0.75 0.0236 0.6000 0.0 0.0 50 0.1104 0.0043 3.1786 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0736 0.0029 3.7640 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0554 0.0022 4.1733 45 1.50 0.0138 0.3500 0.0 0.0 80 0.0168 0.0007 5.8963 50 1.75 0.0117 0.2970 0.4 0.4 95 0.0074 0.0003 7.0856 60 2.00 0.0098 0.2500 2.5 2.9 2.9 70 2.25 0.0083 0.2100 5.2 8.1' 80 2.50 0.0070 0.1770 8.3 16.4 100 2.75 0.0058 0.1490 11.1 27.6 SURFACE AREA (m^2Icc): 0.2120 120 3.00 0.0049 0.1250 12.9 37.5 40.4 140 3.25 0.0041 0.1050 13.1 53.6 170 3.50 0.0035 0.0880 11.8 65.4 200 3.75 0.0029 0.0740 9.4 74.8 STD DEVIATION (mm) : 0.0617 230 4.00 0.0024 0.0620 6.5 40.8 81.3 270 4.25 0.0021 0.0530 3.8 85.0 325 4.50 0.0017 0.0440 1.7 86.7 400 4.75 0.0015 0.0370 0.5 87.2 STD DEVIATION (Inches): 0.0024 500 5.00 0.0014 0.0310 0.1 6.1 87.4 5.25 0.0010 0.0260 0.2 87.6 5.50 0.0009 0.0220 0.6 88.2 GRAVEL PACK : 20140 5.75 0.0007 0.0190 0.9 89.1 6.00 0.0006 0.0160 1.2 2.9 90.3 6.25 0.0005 0.0130 1.2 91.6 6.50 0.0004 0.0110 1.2 92.7 TRASK" FOLK" MOMENT" 6.75 0.0003 0.0093 1.1 93.8 7.00 0.0003 0.0078 0.9 4.4 94.7 MEAN 0.1145 3.2786 3.6883 7.25 0.0002 0.0065 0.8 95.5 MEDIAN 0.1104 3.1786 3.1786 7.50 0.0002 0.0055 0.7 96.2 SORTING 1.4533 1.1784 1.4848 7.75 0.0002 0.0046 0.6 96.8 SKEWNESS 0.9383 0.3718 1.9318 8.00 0.0001 0.0039 0.6 2.7 97.4 KURTOSIS 0.2204 1.8956 6.5871 8.25 0.0001 0.0033 0.5 98.0 8.50 0.0001 0.0028 0.5 98.5 8.75 0.0001 0.0023 0.4 98.9 9.00 0.??oo 0.0019 0.4 99.3 9.25 0.??oo 0.0016 0.3 99.6 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.2 99.8 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.1 99.9 10.00 0.??oo 0.0010 0.1 2.6 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ & ÜJre LZII:Ì Immll .,maunIII File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4141.20 27 AH EXTENDED RANGE PARTS/2SM ANAL YS/S Laser Partslz om Distribution 25 k~lJ~~ , j ~ ~¡.... · @B~; · · 100 · · . .. ~ · .. .. õ~t · · 20 · 80 ~ · · ~ · ~ · 0 · c ;:15 [- 603 u · c c · ã Q · :I · ~ ~10 · · 40 -- IL. · tl ~ ~ · , , ~ , 5 , · ~ , " 20 , ~ , I-~ - , , ¡L. , ~ , .rll, 0 ........ .. . ... . .1 ... . . .. .. . ~ 0 . . 1 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEl 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.2400 0.0094 2.0590 VCRS so 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.2080 0.0082 2.2656 20 025 0.0335 0.8500 0.0 0.0 16 0.1872 0.0074 2.4175 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1636 0.0064 2.6113 30 0.75 0.0236 0.6000 0.0 0.0 50 0.1195 0.0047 3.0652 CRS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0835 0.0033 3.5821 40 125 0.0165 0.4200 0.0 0.0 84 0.0669 0.0026 3.9026 45 1.50 0.0138 0.3500 0.1 0.1 90 0.0281 0.0011 5.1549 MED 50 1.75 0.0117 0.2970 0.7 0.7 95 0.0099 0.0004 6.6540 SAND 60 2.00 0.0098 0.2500 2.8 3.5 3.5 70 225 0.0083 02100 5.9 9.4.' 80 2.50 0.0070 0.1770 9.5 18.9 FINE 100 2.75 0.0058 0.1490 12.7 31.6 SURFACE AREA (mA2Icc): 0.1777 SAND 120 3.00 0.0049 0.1250 14.4 42.6 46.1 140 325 0.0041 0.1050 14.1 602 170 3.50 0.0035 0.0880 12.0 722 VFINE 200 3.75 0.0029 0.0740 8.7 80.9 STD DEVIATION (nvn) : 0.0602 SAND 230 4.00 0.0024 0.0620 52 40.0 86.1 270 4.25 0.0021 0.0530 2.5 88.6 325 4.50 0.0017 0.0440 0.8 89.5 CAS 400 4.75 0.0015 0.0370 02 89.7 STD DEVIATION (Inches) : 0.0024 SILT 500 5.00 0.0014 0.0310 0.2 3.7 89.9 525 0.0010 0.0260 02 90.1 5.50 0.0009 0.0220 0.5 90.6 GRAVEl PACK : 20140 MED 5.75 0.0007 0.0190 0.8 91.5 SILT 6.00 0.0006 0.0160 1.0 2.6 92.5 6.25 0.0005 0.0130 1.0 93.5 6.50 0.0004 0.0110 1.0 94.5 TRASK- FOLK- MOMENT** FINE 6.75 0.0003 0.0093 0.8 95.3 SILT 7.00 0.0003 0.0078 0.7 3.5 96.0 MEAN 0.1236 3.1284 3.5125 7.25 0.0002 0.0065 0.6 96.5 MEDIAN 0.1195 3.0652 3.0652 7.50 0.0002 0.0055 0.5 97.0 SORTING 1.4000 UJ675 1.3544 VFINE 7.75 0.0002 0.0046 0.5 97.5 SKEWNESS 0.9572 0.3449 2.2235 SILT 8.00 0.0001 0.0039 0.4 1.9 97.9 KURTOSIS 0.2228 1.9398 8.2666 8.25 0.0001 0.0033 0.4 98.3 8.50 0.0001 0.0028 0.4 98.7 8.75 0.0001 0.0023 0.4 99.1 9.00 0.??oo 0.0019 0.3 99.4 9.25 0.??oo 0.0016 0.2 99.7 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.2 99.8 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.1 100.0 CLAY 10.00 0.??oo 0.0010 0.0 2.1 100.0 Kerr McGee Oil & Gas Corporation ~\ File No.: HOU-050167 Nikaitchuq 4 Date: March 10, 2005 NW Milne Point ..... . Depth : 4142.80 (or-e Lab Sample: 29AH Imftllll Int111UJ8 EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Parts·z am Distribution 25 ka'~J~R ~ I _ . . 100 · · "@J · 'l31 ~ · ® · ~ 0'Ø--- 20 · 80 ~ · · 19) @ID ~ · ~ · ~ ~ (') · c ;:15 · 60 ~ · u · c · ¡¡¡- II · - ~ · ~. ~ 10 · · 40 .-. · u.. · :!, · · .. · 5 · ..."'"- - - - 20 · ~ 1l-111' I- · .~. · ( ¡. · . _"It-... · I ¡4 0 .... . . . I .. . ..... ¡.. 0 1 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1138 0.0045 3.1358 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0947 0.0037 3.4011 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0802 0.0032 3.6400 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0648 0.0026 3.9475 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0355 0.0014 4.8162 CRS so 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0116 0.0005 6.4270 40 125 0.0165 0.4200 0.0 0.0 84 0.0070 0.0003 7.1566 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0047 0.0002 7.7454 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0030 0.0001 8.3933 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0,1 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.8 0.8 SURFACE AREA (m"2Içe): 0.5735 SAND 120 3.00 0.0049 0.1250 2.1 2.9 2.9 140 3.25 0.0041 0.1050 3.8 6.7 170 3.50 0.0035 0.0880 5.5 12.2 VFINE 200 3.75 0.0029 0.0740 6.9 19.1 STD DEVIATION (mm) : 0.0366 SAND 230 4.00 0.0024 0.0620 7.7 23.9 26.8 270 4.25 0.0021 0.0530 7.9 34.7 325 4.50 0.0017 0.0440 7.4 42.1 CAS 400 4.75 0.0015 0.0370 6.5 48.6 STD DEVIATION (Inches): 0.0014 SILT 500 5.00 0.0014 0.0310 5.5 27.3 54.1 5.25 0.0010 0.0260 4.6 58.7 5.50 0.0009 0.0220 3.9 62.7 GRAVEL PACK: NJA MED 5.75 0.0007 0.0190 3.5 66.2 SILT 6.00 0.0006 0.0160 3.3 15.4 69.5 6.25 0.0005 0.0130 3.3 12.8 6.50 0.0004 0.0110 3.2 76.0 TRASK" FOLK" MOMENT" FINE 6.75 0.0003 0.0093 3.2 79.2 SILT 7.00 0.0003 0.0078 3.1 12.7 82.2 MEAN 0.0382 5.2043 5.3724 7.25 0.0002 0.0065 2.9 85.1 MEDIAN 0.0355 4.8162 4.8162 7.50 0.0002 0.0055 2.7 87.8 SORTING 2.3616 1.6757 1.6531 VFINE 7.75 0.0002 0.0046 2.4 90.2 SKEWNESS 0.5978 0.3459 0.6886 SILT 8.00 0.0001 0.0039 2.1 10.0 92.2 KURTOSIS 0.2955 0.8690 2.5889 8.25 0.0001 0.0033 1.8 94.0 8.50 0.0001 0.0028 1.5 95.5 8.75 0.0001 0.0023 1.2 96.8 9.00 0.??oo 0.0019 1.0 97.8 9.25 0.??oo 0.0016 0.8 98.6 . COMPUTED USING MIlliMETER VALUES 9.50 0.??oo 0.0014 0.6 99.2 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.5 99.7 CLAY 10.00 0.??oo 0.0010 0.3 7.8 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 ~ ~ Core Lab Irsnn..,P'TUQIMIJI' FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4143.50 31 AH EXTENDED RANGE PARTS/ZSM ANAL YS/S Laser Partsiz 1m Distribution , · · · · · --L-__ · · · · · · · · · · · · · · · · · · · · · · · · · o ............ 10 - _ .. . . 100 cç;B~y k[flJ®~ 20-- #: ';:15 u c c ::J tT !! 10 II.. GRAVEL VCRS SO CAS SO MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY · · · - 80 ~:'12J Æ---=--~ @) @I) ~ ~ ~ @1j ~ o c 603 c ã i -- 40 ~ i; 01/: . .... ------r- ' -... ~ ,: .~ : J~- ~. ~ .. . .. , . " : - ' '1 . , 0.1 Particle Diameter (mm) 0.01 5 20 lli L1I.l0'1..- ...... I ... I o 0.001 . . . GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 ·2.00 0.15/5 4.??oo 0.0 0.0 6 ·1.75 0.1323 3.3600 0.0 0.0 7 ·1.50 0.1114 2.8300 0.0 0.0 8 ·1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 ·1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1625 0.0064 2.6215 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1402 0.0055 2.8348 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1224 0.0048 3.0298 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1046 0.0041 3.2573 30 0.75 0.0236 0.8000 0.0 0.0 50 0.0719 0.0028 3.1987 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0418 0.0016 4.5815 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0189 0.0007 5.7234 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0098 0.0004 6.6790 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0052 0.0002 7.5814 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.4 0.4.1 80 2.50 0.0070 0.1770 2.2 2.6 100 2.75 0.0058 0.1490 4.7 7.2 SURFACE AREA (m"2lçc): 0.3041 120 3.00 0.0049 0.1250 7.5 14.7 14.7 140 3.25 0.0041 0.1050 10.0 24.7 170 3.50 0.0035 0.0880 11.6 36.3 200 3.75 0.0029 0.0740 11.8 48.1 STD DEVIATION (nvn) : 0.0518 230 4.00 0.0024 0.0620 10.7 44.1 58.8 270 4.25 0.0021 0.0530 8.7 67.5 325 4.50 0.0017 0.0440 6.2 73.7 400 4.75 0.0015 0.0370 4.0 77.7 STD DEVIATION (Inches) : 0.0020 500 5.00 0.0014 0.0310 2.4 21.3 80.2 5.25 0.0010 0.0260 1.5 81.6 5.50 0.0009 0.0220 1.1 82.8 GRAVEL PACK : 20140 5.75 0.0007 0.0190 1.2 84.0 6.00 0.0006 0.0160 1.4 5.2 85.4 6.25 0.0005 0.0130 1.6 87.0 6.50 0.0004 0.0110 1.7 88.7 TRASK' FOLKH MOMENT*' 6.75 0.0003 0.0093 1.7 90.5 7.00 0.0003 0.0078 1.6 6.7 92.1 MEAN 0.0732 4.1840 4.3629 7.25 0.0002 0.0065 1.4 93.5 MEDIAN 0.0719 3.7987 3.7987 7.50 0.0002 0.0055 1.2 94.7 SORTING 1.5824 1.4249 1.4991 7.75 0.0002 0.0046 1.0 95.7 SKEWNESS 0.8459 0.4772 1.4610 8.00 0.0001 0.0039 0.9 4.5 96.6 KURTOSIS 0.2409 1.5351 4.6596 8.25 0.0001 0.0033 0.7 97.3 8.50 0.0001 0.0028 0.6 97.9 8.75 0.0001 0.0023 0.5 98.5 9.00 0.??oo 0.0019 0.5 99.0 9.25 0.??oo 0.0016 0.4 99.3 . COMPUTED USING MIlliMETER VAlUES 9.50 0.??oo 0.0014 0.3 99.6 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.2 99.9 10.00 0.??oo 0.0010 0.1 3.4 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ~ Con! LaI:i .mlmlll,~ File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4144.50 35AH EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partslz 1m Distribution 25 k~~J®~ · 0 @B~;. · 100 · · · · · · ~ · ~ · · · · · · · ~. · 20 --"- ---"- . -80 0 @j) · . · · · @) · · · ~ · · · l · · [1!1. · · 0 , · · I~ · c · · · · 603 :-.15 - ~,-~ . .- . - ---------------- u , · · · c c , · · · ã GI · · · - r · · :I · · ... · · <" [10 - · · = · · CD · - · ", · 40 - · · -'{r ~ · II.. '>R. , · . . · ~ · · : ~ · · · ~ · · · , ' · 5~ · · , ' · 20 · -------- J ~~i . · · .. · , : J ("'~ · · I · · : ~ · , - nO"_LI · 0 ........ . . . . . ...e~ -:- . r. I . I 0 · · 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1,4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1753 0.0069 2.5121 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1531 0.0060 2.7072 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1359 0.0054 2.8794 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1168 0.0046 3.0980 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0820 0.0032 3.6084 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0540 0.0021 4.2118 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0375 0.0015 4.7382 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0125 0.0005 6.3167 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0065 0.0003 7.2713 SAND 60 2.00 0.0098 0.2500 0.1 0.1 0.1 70 2.25 0.0063 0.2100 1.1 1.2.' 60 2.50 0.0070 0.1770 3.5 4.6 FINE 100 2.75 0.0058 0.1490 6.3 10.9 SURFACE AREA (m"2ICC): 0.2496 SAND 120 3.00 0.0049 0.1250 9.3 20.2 20.2 140 3.25 0.0041 0.1050 11.7 31.9 170 3.50 0.0035 0.0880 12.8 44.7 VFINE 200 3.75 0.0029 0.0740 12.4 57.1 STD DEVIATION (nvn) : 0.0492 SAND 230 4.00 0.0024 0.0620 10.7 47.6 67.8 270 4.25 0.0021 0.0530 8.1 75.9 325 4.50 0.0017 0.0440 5.3 81.2 CRS 400 4.75 0.0015 0.0310 3.0 84.2 STD DEVIATION (Inches): 0.0019 SilT 500 5.00 0.0014 0.0310 1.4 17.8 85.6 5.25 0.0010 0.0260 0.6 86.2 5.50 0.0009 0.0220 0.5 86.7 GRAVEL PACK : 20140 MED 5.75 0.0007 0.0190 0.7 87.4 SilT 6.00 0.0006 0.0160 1.0 2.8 88.4 6.25 0.0005 0.0130 1.3 89.7 6.50 0.0004 0.0110 1.4 91.1 TRASK' FOlK- MOMENT*" FINE 6.75 0.0003 0.0093 1.4 92.5 SilT 7.00 0.0003 0.0078 1.3 5.5 93.8 MEAN 0.0854 3.7420 4.1040 7.25 0.0002 0.0065 1.1 95.0 MEDIAN 0.0820 3.6084 3.6084 7.50 OJl002 0.0055 0.9 95.9 SORTING 1,4711 1.1858 1.4133 VFINE 7.75 0.0002 0.0046 0.8 96.7 SKEWNESS 0.9376 0.3774 1.7390 SilT 8.00 0.0001 0.0039 0.7 3.5 97.4 KURTOSIS 0.2234 1.7513 5.8474 8.25 0.0001 0.0033 0.6 97.9 8.50 0.0001 0.0028 0.5 98.4 8.75 0.0001 0.0023 0.4 98.8 9.00 0.??oo 0.0019 0,4 99.2 9.25 0.??oo 0.0016 0.3 99.5 . COMPUTED USING MilliMETER VAlUES 9.50 0.??oo 0.0014 0.2 99.7 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.2 99.9 CLAY 10.00 0.??oo 0.0010 0.1 2.6 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ;:15 u c: GI :J cr f10 LL. GRAVEL VCRS so CAS so MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT ClAY ~G'~J~R 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 M> 45 50 60 70 60 100 120 1M> 170 200 230 270 325 400 500 A\ Core Lab 'O(IIØtI~ EXTENDED RANGE PARTS/Z8M ANAL YS/S ........¡ ........ Laser Partslz am Distribution :"@ :.~-_.- · · · · · -----....--- ~ (ò)2) @) ~ GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.157ó 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.07M> 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5 2.3 4.8 7.6 10.1 11.6 11.9 10.7 8.7 6.3 4.0 2.3 1.4 1.0 1.1 1.3 1.5 1.7 1.7 1.6 1.4 1.2 1.0 0.9 0.8 0.6 0.6 0.5 0.4 0.3 0.2 0.1 : lï~ ...---: ;: : -1' -~:!~ ~~ ~ ~ : I~~ ~ Il-~ 'I : . . 0.1 Particle Diameter (mm) SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.5' 2.8 7.6 15.2 25.3 36.9 48.8 59.5 68.2 74.5 78.5 80.8 82.2 83.2 84.3 85.6 87.1 88.8 90.4 92.0 93.4 94.6 95.7 96.5 97.3 97.9 98.5 99.0 99.3 99.6 99.9 100.0 0.0 0.0 0.0 0.0 15.2 44.3 21.3 4.8 6.4 4.5 3.5 FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4145.20 37 AH _ _ .. . . 100 ---_._--~..._- , ha.- . II [......:....-.... . PERCENTILES: 0.01 o c: 60 ~ ã ~. 40 - -..e ~ 20 . . - o 0.001 · , · . · . : ~ ~ ___~_u________~_ . ~ : : ~: : · . . -------.----- -----__e_______--_______.- · . · . · . · . · . · . .. . · . · . · . · . ., t -------~- · · · · · SORTING PARAMETERS mm 5 10 16 25 50 75 84 90 95 0.1642 0.1414 0.1234 0.1056 0.0726 0.0431 0.0199 0.0098 0.0052 SURFACE AREA (mA2Ic:c): STD DEVIATION (mm): STD DEVIATION (Inches) : GRAVEL PACK : MEAN MEDIAN SORTING SKEWNESS KURTOSIS TRASK' 0.0743 0.0726 1.5654 0.8620 0.2373 inches 0.0065 0.0056 0.0049 0.0042 0.0029 0.0017 0.0008 0.0004 0.0002 FOLK- 4.1510 3.7830 1.4143 0.4738 1.5813 phi 2.6066 2.8219 3.0183 3.2435 3.7830 4.5366 5.6516 6.6800 7.5958 0.3022 0.0518 0.0020 20140 MOMENT- 4.3423 3.7830 1.5000 1.4889 4.7456 . COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 #: ";:15 u c CD ::J ~10 u. GRAVEL VCRS so CAS so MED SAND FINE SAND VFINE SAND CAS SilT MED SilT FINE SilT VFINE SILT CLAY kD'~J~1 ~ & Core Lab lalflmlØTJ!IIIIAJM EXTENDED RANGE PARTS/Z5M ANAL YS/S Laser Partslz 1m Distribution · · · :~ --"--- · '^"" · '=" :~ · . -_.----.----~.._------- · . · . · . · . · . ._~-_._~+-~--+----+.- · . . It' . I · . I · . . · . . --- !' . · . . · . . · . . · . . · . . 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 60 100 120 140 170 200 230 270 325 400 500 FileNo. : Date: Depth : Sample: , . · . · . : ~ : ~ : _~ øø : ~_____1- · . . :@)'@I)' : ~ : ~ : , u_ -:--t~r --. --- . :- ~J _________~c , , : ..:4.... i . . . . ~ . . . . '- . . . . . . I, - -y - - J... -- roo n"".u .- GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7_50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0_0002 0.0002 0.0001 0.0001 0_0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0-0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.3 3.4 6.1 8.6 11.0 12.1 11.7 10.2 7.8 5.3 3.1 1.6 0.8 0.6 0.8 1.1 1.4 1.5 1.5 1.4 1.3 1.1 1.0 0.8 0.8 0.7 0.6 0.6 0.5 0.4 0.4 0.2 ---+--~~- 0.1 Particle Diameter (mm) 0.01 .- · · · · "-:-'1 HOU·050167 March 10,2005 4146.50 39AH _ _. . . 100 @~"my 80 o c --- 60 ~ i < G 40 ~ ~ 20 I I . o 0.001 SEP SORTING PARAMETERS 0.0 CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.4 .. 4.9 11.0 19.8 30.8 42.9 54.6 64.8 12.6 77.9 81.0 82.6 83.4 84.0 84.8 85.9 87.3 88.8 90.3 91.7 93.0 94.1 95.1 95.9 96.6 97_3 98.0 98.5 99.0 99.5 99.8 100.0 MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.0823 0.0795 1.5370 0.8944 0.2317 PERCENTILES: mm 0.0 5 10 16 25 50 75 84 90 95 0.1764 0.1535 0.1354 0.1156 0.0795 0.0489 0.0220 0.0096 0.0047 0.0 0.1 SURFACE AREA (m^2Icc): 19.7 STD DEVIATION (mm): 45.0 STD DEVIATION (Inches): 17.8 GRAVEL PACK : 3.4 TRASK' 5.8 4.2 inches 0.0069 0.0060 0.0053 0.0046 0.0031 0.0019 0.0009 0.0004 0.0002 FOlKH 4.0150 3.6526 1.4502 0.4881 1.7331 phi 2.5030 2.7038 2.8851 3.1131 3.6526 4.3533 5.5072 6.6967 7.74n 0.3135 0.0567 0.0022 20140 MOMENTH 4.2342 3.6526 1.5666 1.6003 5.0597 . COMPUTED USING MILLIMETER VAlUES -- COMPUTED USING PHI VAlUES 4.1 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ~, Can! Lab IWll'flllttmlltAl'llll FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4147.50 43AH EXTENDED RANGE PARTS/2SM ANAL YS/S Laser Partslz 1m Distribution 25 ~~~J~ - · ~ . ....100 · · -.J..~~~y · · · ~ · "@ '@} · · · · ~ ~ 20 - · . ---._.~~,-~ 80 , @J'» · · · @J @I · ~ · ¡: , · ~ ~ 0 · · c: ';:15 · · ~-60 g --~.- . --------"~ (,) , · I c: · · .., ã Q) · : ~ ;, · ~. ~10 - , ~------¡It , ~-- 40 -- IL ---^-----.-~-- , : 1ft , ,¡e · ~ , · . ' -. , ~ : ~ · · · 5- · · . · - 20 , · . '" 0(- · · . ~ · · . ~ I ¡ J , .. . ~ · : . 3 · I'" I..IJ_r _ -JiU.Jl:sr ' 0 ........ .... .....~ ' ~.. ..., - 0 -r 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.2082 0.0082 22643 VCRS SD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1809 0.0071 2.4664 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1611 0.0063 2.6342 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1390 0.0055 2.8467 30 0.75 0.0236 0.8000 0.0 0.0 50 0.0991 0.0039 3.3353 CRSSO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0656 0.0026 3.9292 40 125 0.0165 0.4200 0.0 0.0 84 0.0458 0.0018 4.4486 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0111 0.0004 6.4977 MED 50 1.75 0.0117 0.2970 02 02 95 0.0050 0.0002 7.6351 SAND 60 2.00 0.0098 02500 1.3 1.4 1.4 70 225 0.0083 02100 32 4.7' 60 2.50 0.0070 0.1770 8.1 10.7 FINE 100 2.75 0.0058 0.1490 9.3 20.0 SURFACE AREA (m^2Icc): 0.2847 SAND 120 3.00 0.0049 0.1250 12.0 30.6 32.0 140 325 0.0041 0.1050 13.4 45.5 170 3.50 0.0035 0.0880 13.0 58.5 VFINE 200 3.75 0.0029 0.0740 11.0 69.5 STD DEVIATION (mm) : 0.0576 SAND 230 4.00 0.0024 0.0620 7.9 45.4 77.4 270 4.25 0.0021 0.0530 4.8 82.2 325 4.50 0.0017 0.0440 2.3 84.5 CRS 400 4.75 0.0015 0.0370 0.8 85.2 STD DEVIATION (Inches) : 0.0023 SILT 500 5.00 0.0014 0.0310 0.3 8.1 85.5 5.25 0.0010 0.0260 02 85.7 5.50 0.0009 0.0220 0.4 86.1 GRAVEL PACK : 20140 MED 5.75 0.0007 0.0190 0.6 86.7 SILT 6.00 0.0006 0.0160 0.9 2.1 87.6 6.25 0.0005 0.0130 1.2 88.8 6.50 0.0004 0.0110 1.3 90.0 TRASK' FOLKti MOMENT'" FINE 6.75 0.0003 0.0093 1.2 91.3 SILT 7.00 0.0003 0.0078 1.2 4.8 92.4 MEAN 0.1023 3.4727 3.9087 7.25 0.0002 0.0065 1.1 93.5 MEDIAN 0.0991 3.3353 3.3353 7.50 0.0002 0.0055 1.0 94.5 SORTING 1.4553 1.2673 1.5668 VFINE 7.75 0.0002 0.0046 0.9 95.4 SKEWNESS 0.9295 0.4142 1.8005 SILT 8.00 0.0001 0.0039 0.9 3.9 96.3 KURTOSIS 0.2160 2.0333 5.6749 8.25 0.0001 0.0033 0.8 97.2 8.50 0.0001 0.0028 0.7 97.9 8.75 0.0001 0.0023 0.6 98.5 9.00 0.??oo 0.0019 0.5 99.1 9.25 0.??oo 0.0016 0.4 99.4 - COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.3 99.7 .. COMPUTED USING PHI VALUES 9.75 0.0000 0.0012 0.2 99.9 CLAY 10.00 0.??oo 0.0010 0.1 3.7 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ~ ÚJre Lab øst"""'~ File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4148.70 45AH EXTENDED RANGE PARTS/Z5M ANAL YS/S Laser Partslz 8m Distribution 25 ~~~J~I · ~~ bõ~t 100 , , , ~ c¡g ~ , , ~ ~: 20 · . 80 · @>1 · · · @) ¡g') · ~ · ~ · · ~ ~ 0 , · c ;:15 , · --60 ~ · · (,) · · · c: , · · ã CII , · · ::I · · · C- O" · , · 111 I!! 10 · , · 40 ~ · · · u. · , · $ · , · · , · · , · 5 · · · nlrJrlUlh~ -------- , · · I I · · , · II · · · · · · , · · · , : J! · · , 0 ............ . . . . . ...-fIr. 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3600 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0764 0.0030 3.7098 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0571 0.0022 4.1298 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0428 0.0017 4.5479 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0297 0.0012 5.0747 30 0.75 0.0236 0.8000 0.0 0.0 50 0.0126 0.0005 6.3098 CASSO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0045 0.0002 7.7884 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0027 0.0001 8.5431 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0018 0.0001 9.1581 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0014 0.0001 9.5257 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 0.2100 0.0 0.0' 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.1 0.1 SURFACE AREA (m^2Icc): 1.2664 SAND 120 3.00 0.0049 0.1250 0.5 0.6 0.6 140 3.25 0.0041 0.1050 1.0 1.6 170 3.50 0.0035 0.0880 1.6 3.2 VFINE 200 3.75 0.0029 0.0740 2.2 5.4 STD DEVIATION (mm) : 0.0200 SAND 230 4.00 0.0024 0.0620 2.8 7.6 8.2 270 4.25 0.0021 0.0530 3.3 11.5 325 4.50 0.0017 0.0440 3.7 15.3 CRS 400 4.75 0.0015 0.0370 4.1 19.4 STD DEVIATION (Inches) : 0.0008 SILT 500 5.00 0.0014 0.0310 4.4 15.6 23.8 5.25 0.0010 0.0260 4.7 28.4 5.50 0.0009 0.0220 4.9 33.4 GRAVEL PACK : NIA MED 5.75 0.0007 0.0190 5.1 38.5 SILT 6.00 0.0006 0.0160 5.2 20.0 43.8 6.25 0.0005 0.0130 5.2 49.0 6.50 0.0004 0.0110 5.1 54.1 TRASK' FOLK- MOMENT'" FINE 6.75 0.0003 0.0093 4.8 58.9 SILT 7.00 0.0003 0.0078 4.5 19.6 63.4 MEAN 0.0171 6.4669 6.5706 7.25 0.0002 0.0065 4.1 67.5 MEDIAN 0.0126 6.3098 6.3098 7.50 0.0002 0.0055 3.7 71.3 SORTING 2.5613 1.8800 1.7798 VFINE 7.75 0.0002 0.0046 3.4 74.7 SKEWNESS 0.8447 0.1119 0.1713 SILT 8.00 0.0001 0.0039 3.1 14.4 77.8 KURTOSIS 0.2271 0.8783 2.1138 8.25 0.0001 0.0033 2.9 80.6 8.50 0.0001 0.0028 2.7 83.4 8.75 0.0001 0.0023 2.6 86.0 9.00 0.??oo 0.0019 2.6 88.6 9.25 0.??oo 0.0016 2.7 91.4 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 2.9 94.2 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 3.5 97.7 CLAY 10.00 0.??oo 0.0010 2.3 22.2 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ð\ ÚJre Lab .m:""'IJ:~ FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4149.70 47 AH EXTENDED RANGE PARTSlzsM ANAL YSIS Laser Partsiz om Distribution 25 ~~~J®I · " · -.. . 100 · · · · · · @~~y · "@j · '13! '13! · · · · · @íð · ~ ~..-: 20~ ---------- ~ ~-80 · @i) · · · @ ) ~ · · ~ · · ~ · · ~ ~ · 0 · · · c ......15 · · · 603 . - · ~ · · · c c · · · ã 41 · · · = · · · <r C7 · · · CD 2!10 · · . 40,... LL. · ~~---.---------.---~ ~ · · · ~ · · · · · · · · ~ --t.i? 5 · · 20 · . . · · · · · . j . . rill · · · · · · · · · .11 ".IU.""_I.-_u ~c ~ 0 ............ 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.2342 0.0092 2.0942 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1968 0.0077 2.3453 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1693 0.0067 2.5620 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1417 0.0056 2.8196 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0919 0.0036 3.4441 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0479 0.0019 4.3847 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0192 0.0008 5.7061 45 1.50 0.0138 0.3500 0.1 0.1 80 0.0099 0.0004 6.6636 MEO 50 1.75 0.0117 0.2970 1.0 1.1 85 0.0048 0.0002 7.7145 SAND 60 2.00 0.0098 0.2500 2.3 3.4 3.4 70 2.25 0.0083 0.2100 4.1 7.5 .. 80 2.50 0.0070 0.1770 6.2 13.7 FINE 100 2.75 0.0058 0.1490 8.3 22.0 SURFACE AREA (m"2Icc): 0.2995 SAND 120 3.00 0.0048 0.1250 9.8 28.4 31.8 140 3.25 0.0041 0.1050 10.4 42.2 170 3.50 0.0035 0.0880 10.1 52.3 VFINE 200 3.75 0.0029 0.0740 8.8 61.1 STD DEVIATION (mm): 0.0751 SAND 230 4.00 0.0024 0.0620 7.0 38.3 68.1 270 4.25 0.0021 0.0530 5.0 73.1 325 4.50 0.0017 0.0440 3.3 76.4 CAS 400 4.75 0.0015 0.0370 2.1 78.5 STD DEVIATION (Inc:hes): 0.0030 SILT 500 5.00 0.0014 0.0310 1.5 11.9 80.0 5.25 0.0010 0.0260 1.3 81.3 5.50 0.0009 0.0220 1.3 82.6 GRAVEL PACK : 20140 MED 5.75 0.0007 0.0190 1.5 84.1 SILT 6.00 0.0006 0.0160 1.6 5.7 65.7 6.25 0.0005 0.0130 1.7 87.4 6.50 0.0004 0.0110 1.6 89.0 TRASK' FOLK- MOMENT- FINE 6.75 0.0003 0.0093 1.5 90.5 SILT 7.00 0.0003 0.0078 1.4 6.2 91.9 MEAN 0.0948 3.9041 4.0703 7.25 0.0002 0.0065 1.2 93.1 MEDIAN 0.0919 3.4441 3.4441 7.50 0.0002 0.0055 1.1 94.2 SORTING 1.7202 1.6376 1.6834 VFINE 7.75 0.0002 0.0046 1.0 95.2 SKEWNESS 0.8032 0.4793 1.3515 SILT 8.00 0.0001 0.0039 0.9 4.2 96.1 KURTOSIS 0.2509 1.4717 4.2546 8.25 0.0001 0.0033 0.8 96.9 8.50 0.0001 0.0028 0.7 97.6 8.75 0.0001 0.0023 0.6 98.3 9.00 0.??oo 0.0019 0.6 98.8 9.25 0.??oo 0.0016 0.4 99.3 . COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 0.3 99.6 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.3 99.9 CLAY 10.00 0.??oo 0.0010 0.1 3.9 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point A Con! tøti Imllftll .rn.r- File No.: Date: Depth : Sample: HOU-050167 March 10.2005 4150.50 51 AH EXTENDED RANGE PARTSIZSM ANAL YSIS Laser Partslz om Distribution 25 kD'lJ~~ · I - -.... 100 · · · @~~y · ~ 'i23 · 'i23 · · · · · ~ · 20 ---"- ---------- -80 · @II · · ~ · ~ · · ~ · · ~ · ~ · [!!1 · · 0 · · · · c: '>:15 · · 'I · · 603 · · . u · j · c: c · · jjj GI · · ... :I · - · i" tT · I · 1!!10- · f- - · 40....... · -=0 u.. · · :i · · · · · 5 · - 20 · .- . , · · · · · · · · · .. " r I.I.·-_IL-__ 0 ........' ........' .. .. 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3S00 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1926 0.0076 2.3762 VCRS so 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1676 0.0066 2.5770 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1475 0.0058 2.7611 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1277 0.0050 2.9693 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0906 0.0036 3.4637 CAS so 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0596 0.0023 4.0683 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0427 0.0017 4.5512 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0135 0.0005 6.2096 MED 50 1.75 0.0117 0.2970 0.0 0.0 85 0.0066 0.0003 7.2433 SAND 60 2.00 0.0098 0.2500 0.3 0.3 0.3 70 2.25 0.0083 0.2100 2.1 2.4 ' 80 2.50 0.0070 0.1770 4.9 7.3 FINE 100 2.75 0.0058 0.1490 8.0 15.3 SURFACE AREA (mA2Icc): 0.2408 SAND 120 3.00 0.0049 0.1250 10.9 25.9 26.2 140 3.25 0.0041 0.1050 12.7 38.0 170 3.50 0.0035 0.0880 13.1 52.0 VFINE 200 3.75 0.0029 0.0740 11.8 63.9 STD DEVIATION (nun) : 0.0524 SAND 230 4.00 0.0024 0.0620 9.4 47.0 73.3 270 4.25 0.0021 . 0.0530 6.5 79.8 325 4.50 0.0017 0.0440 3.8 83.6 CRS 400 4.75 0.0015 0.0370 1.9 85.5 STD DEVIATION (Inches): 0.0021 SILT 500 5.00 0.0014 0.0310 0.7 12.9 86.2 5.25 0.0010 0.0260 0.3 86.5 5.50 0.0009 0.0220 0.4 87.0 GRAVEL PACK : 20140 MED 5.75 0.0007 0.0190 0.8 87.8 SILT 6.00 0.0006 0.0160 1.1 2.7 88.9 6.25 0.0005 0.0130 1.3 90.2 6.50 0.0004 0.0110 1.4 91.6 TRASK' FOLK" MOMENT" FINE 6.75 0.0003 0.0093 1.3 92.9 SILT 7.00 0.0003 0.0078 1.2 5.2 94.1 MEAN 0.0937 3.5920 3.9726 7.25 0.0002 0.0065 1.0 95.1 MEDIAN 0.0906 3.4637 3.4637 7.50 0.0002 0.0055 0.8 95.9 SORTING 1.4636 1.1850 1.4404 VFINE 7.75 0.0002 0.0046 0.7 96.6 SKEWNESS 0.9265 0.3840 1.8184 SILT 8.00 0.0001 0.0039 0.6 3.1 97.2 KURTOSIS 0.2209 1.8150 6.1075 8.25 0.0001 0.0033 0.6 97.8 8.50 0.0001 0.0028 0.5 98.3 8.75 0.0001 0.0023 0.5 98.8 9.00 0.??oo 0.0019 0.4 99.2 9.25 0.??oo 0.0016 0.3 99.5 . COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 0.2 99.7 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.2 99.9 CLAY 10.00 0.??oo 0.0010 0.1 2.8 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ¡¡ >:15 -----~ () c CD ~ tr !!10 u.. 5-- A\ Core lab .œllft1lll'T1lUUnll" EXTENDED RANGE PARTS/28M ANAL YS/S · · · · · o ........þ.. 10 GRAVEL VCRS so CAS so MEO SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 Laser Partslz am Distribution :: J I _~__....100 'ª : l2J: ... ·~t ~ @B~y @ : ~. -=--- ----~ . . . êI:§)): . : ~.æ1.. .. . -~i-~t -+-~-------~- I:. : L~ : -~ : ~ -I ~ " · · · · · _L_ · · · · · · · · · · · · · · · · · · · · · · · · . . . . . '4 GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.G335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo ~~lJ®1 : ~ ~----_........._-_..-. : ~; j ~ ~ · . · . · . · . · . · . · . · . · . It . ., . · . · . · . · . · . · . · . · . MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 2.0 5.1 9.4 13.8 16.0 15.5 12.4 8.1 4.1 1.4 0.3 0.2 0.3 0.4 0.7 1.0 1.2 1.1 1.0 0.9 0.7 0.6 0.5 0.5 0.5 0.5 0.5 0.4 0.3 0.3 0.2 0.1 .. ~ .~ - ~- 0.1 Particle Diameter (mm) SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 2.3' 7.5 16.9 30.5 46.5 62.0 74.4 82.5 86.5 87.9 88.2 88.5 88.7 89.1 89.8 90.8 91.9 93.1 94.1 94.9 95.7 96.3 96.8 97.3 97.8 98.3 98.7 99.1 99.5 99.7 99.9 100.0 0.0 0.0 0.0 0.3 30.2 52.0 6.0 2.3 4.2 2.4 2.7 . ----- I( I _I Ir"r"r-. I 0.01 File No.: Date: Depth : Sample: 'Ii HOU-050167 March 10, 2005 4159.50 75AH 80 o c 60 æ ã <" - 40!. t. -20 o 0.001 SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 90 95 0.1929 0.1695 0.1517 0.1347 0.1011 0.0731 0.0586 0.0183 0.0077 SURFACE AREA (m"2Icc): STO DEVIATION (mm) : STD DEVIATION (IncheS): GRAVEL PACK: TRASK" MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.1039 0.1011 1.3577 0.9629 0.2038 Inches 0.0076 0.0067 0.0060 0.0053 0.0040 0.0029 0.0023 0.0007 0.0003 FOLK" 3.3733 3.3060 1.0470 0.3730 2.1576 phi 2.3743 2.5606 2.7207 2.8920 3.3060 3.7744 4.0931 5.7738 7.0197 0.2169 0.0466 0.0018 20140 MOMENT"" 3.7889 3.3060 1.3758 2.2182 7.8764 . COMPUTED USING MILLIMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ';:15 u c 41 :I ~10 u. GRAVEL VCRS SD CAS so MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY ~0'~J~8 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ~+,. ..... Con! Lab 'ßlanll~ EXTENDED RANGE PARTSIZSM ANAL YSIS Laser Partsiz am Distribution File No.: Date: Depth : Sample: HOU-050167 March 10,2005 4160.50 77AH I ~-i"· · · · · ·~~~t ~ @~~y . 100 · . · . · . :~: ~:~: .. ~ ~._.~.. . · &a: . :~. .êJ:@I: . :~: :~:~: : --t--- ~ --t---i· -1t.--t'I/~---~~ : : : : ~ : · . I . .. . .- . :e -------.---- . -.--" , . .. . · . . . ¡ . .. . . !. . · . .. í .. . . . - ~ · . l' -_______ - _ ~ ... · . . . ~ ,. : : : :~/f, · . . . r# · . . . . .' . . . . . . . . ( .. . . . ..' , ..- GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.6 2.6 6.0 10.4 14.2 16.1 15.1 11.7 7.3 3.5 1.1 0.4 0.2 0.2 0.3 0.7 1.0 1.1 1.1 1.0 0.8 0.7 0.6 0.5 0.5 0.4 0.4 0.4 0.3 0.3 0.2 0.1 0.1 0.1 Particle Diameter (mm) SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.7 3.3' U 19.7 33.9 50.0 65.1 76.8 84.1 87.6 88.7 89.1 89.3 89.5 89.9 90.5 91.5 92.6 93.7 94.7 95.5 96.2 96.8 97.3 97.7 98.2 98.6 99.0 99.3 99.6 99.8 99.9 100.0 0.0 0.0 0.0 0.7 33.3 50.1 5.2 2.2 4.0 2.2 2.3 · · · · · · · --"-~----~-_._---- _._--_..._..~- II .. PERCENTILES: -....r· 0.01 .. -='" - 80 o c - 60 g ã <" CD - 40 ~ i! 20 o 0.001 SORTING PARAMETERS mm 5 10 16 25 50 75 84 90 95 0.2006 0.1752 0.1590 0.1401 0.1050 0.0761 0.0621 0.0213 0.0088 SURFACE AREA (mA2Icc): STD DEVIATION (nvn) : STD DEVIATION (Inches): GRAVEL PACK : MEAN MEDIAN SORTING SKEWNESS KURTOSIS TRASK' 0.1081 0.1050 1.3566 0.9664 0.2079 Inches 0.0079 0.0069 0.0063 0.0055 0.0041 0.0030 0.0024 0.0008 0.0003 FOLK" 3.3044 3.2511 1.0234 0.3524 2.1040 phi 2.3178 2.5132 2.6531 2.8358 3.2511 3.7157 4.0090 5.5499 6.8351 0.1958 0.0484 0.0019 20140 MOMENT" 3.7068 3.2511 1.3327 2.2549 8.2061 . COMPUTED USING MILLIMETER VAlUES -- COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ~ Cere laI:i mtÞII11l1P'1'UlllrAnlll File No.: Date: Depth : Sample: HOU-050167 March 10, 2005 4161.50 79AH EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partsiz 1m Distribution 25 ~ü'~J~8 · · j ~~-_.... 100 · · · · ~ · 'B · .. · --Mt @B~y · · ~. · 20 80 @Ja · @I @} · ~ · ~ ~ ~ ~ 0 c ......15 ~ 603 ~ riJ c c ã GI :I <" f10 · CD J - -40..... u. · ':P. · ,!.. · ll~: · 5 · · 20 · I, : · · ....,- · J"" · · ........ 0 ........1 ...... . I ... , 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -025 0.0469 1.1900 0.0 0.0 5 0.1817 0.0072 2.4602 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1631 0.0064 2.6165 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1464 0.0058 2.7723 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1312 0.0052 2.9299 30 0.75 0.0236 0.6000 0.0 0.0 50 0.1011 0.0040 3.3058 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0757 0.0030 3.7239 40 125 0.0165 O.~ 0.0 0.0 84 0.0628 0.0025 3.9934 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0248 0.0010 5.3330 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0089 0.0004 6.8090 SAND 60 2.00 0.0098 0.2500 0.1 0.1 0.1 70 225 0.0083 02100 1.3 1.4 60 2.50 0.0070 0.1770 4.2 5.6 FINE 100 2.75 0.0058 0.1490 8.8 14.4 SURFACE AREA (m^2Icc): 0.1972 SAND 120 3.00 0.0049 0.1250 14.3 28.6 28.7 140 3.25 0.0041 0.1050 17.4 46.1 170 3.50 0.0035 0.0880 17.1 63.2 VFINE 200 3.75 0.0029 0.0740 13.4 76.6 STD DEVIATION (mm) : 0.0418 SAND 230 4.00 0.0024 0.0620 7.9 55.8 84.5 270 425 0.0021 0.0530 3.6 88.1 325 4.50 0.0017 0.0440 1.0 89.1 CAS 400 4.75 0.0015 0.0370 0.4 89.5 STD DEVIATION (Inches): 0.0016 SILT 500 5.00 0.0014 0.0310 0.2 5.1 89.7 525 0.0010 0.0260 02 89.9 5.50 0.0009 0.0220 0.4 90.3 GRAVEL PACK : 20140 MED 5.75 0.0007 0.0190 0.5 90.8 SILT 6.00 0.0006 0.0160 0.9 2.0 91.7 6.25 0.0005 0.0130 1.1 92.7 6.50 0.0004 0.0110 1.1 93.8 TRASK' FOLKM MOMENTM FINE 6.75 0.0003 0.0093 1.0 94.8 SILT 7.00 0.0003 0.0078 0.8 4.0 95.6 MEAN 0.1035 3.3571 3.7549 7.25 0.0002 0.0065 0.7 96.3 MEDIAN 0.1011 3.3058 3.3058 7.50 0.0002 0.0055 0.5 96.8 SORTING 1.3167 0.9642 1.2919 VFINE 7.75 0.0002 0.0046 0.5 97.3 SKEWNESS 0.9712 0.3686 2.3963 SILT 8.00 0.0001 0.0039 0.4 2.1 97.7 KURTOSIS 0.2008 2.2449 8.8839 8.25 0.0001 0.0033 0.4 98.2 8.50 0.0001 0.0028 0.4 98.6 8.75 0.0001 0.0023 0.4 99.0 9.00 0.??oo 0.0019 0.3 99.3 9.25 0.??oo 0.0016 0.3 99.6 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.2 99.8 ., COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.1 99.9 CLAY 10.00 0.??oo 0.0010 0.1 2.3 100.0 Kerr McGee Oil & Gas Corporation ~ FileNo. : HOU-050167 Nikaitchuq 4 ~~ Date: March 10, 2005 NW Milne Point Depth : 4162.70 Core l.aI::i Sample: 83AH ImJ:ftllImJlltAnll EXTENDED RANGE PARTSIZ 8M ANAL YSIS Laser Partslz om Distribution 25 k~~J~1 ~ --..... 100 ~ ~ · · j · ·~õ~tt @~~y 20 øm 80 @' 7 · @t · ~ · ~ ~ · (') ... c: ';:15 ~' 603 u ).l c: c: ã GI ~ :.¡ <" cr CD I!! 10 · ... 40 -- u.. · iJf. -:R. · ~ · · · 5 · 20 · I« · · lip · · · .......IiI~1It. 0 ........1 ... . . . . . I .. .. ~I" - , 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE lJlSTRIBUTlON SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1966 0.0077 2.3465 VCRSSD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1724 0.0068 2.5358 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1558 0.0061 2.6826 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1379 0.0054 2.8587 30 0.75 0.0236 0.6000 0.0 0.0 50 0.1037 0.0041 3.2689 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0758 0.0030 3.7224 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0625 0.0025 4.0006 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0293 0.0012 5.0907 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0094 0.0004 6.7288 SAND 60 2.00 0.0098 0.2500 0.4 0.4 0.4 70 2.25 0.0083 0.2100 2.3 2.7 80 2.50 0.0070 0.1770 5.7 8.4 FINE 100 2.75 0.0058 0.1490 10.1 18.4 SURFACE AREA (m"2Icc): 0.1908 SAND 120 3.00 0.0049 0.1250 14.2 32.2 32.6 140 3.25 0.0041 0.1050 16.3 48.9 170 3.50 0.0035 0.0880 15.5 64.3 VFINE 200 3.75 0.0029 0.0740 12.2 76.5 STD DEVIATION (nun): 0.0466 SAND 230 4.00 0.0024 0.0620 7.8 51.7 84.3 270 4.25 0.0021 0.0530 3.8 88.1 325 4.50 0.0017 0.0440 1.3 89.4 CAS 400 4.75 0.0015 0.0370 0.4 89.8 STD DEVIATION (Inches): 0.0018 SILT 500 5.00 0.0014 0.0310 0.2 5.6 89.9 5.25 0.0010 0.0260 0.2 90.1 5.50 0.0009 0.0220 0.4 90.5 GRAVEL PACK: 20140 MED 5.75 0.0007 0.0190 0.6 91.1 SILT 6.00 0.0006 0.0160 0.9 2.1 92.0 6.25 0.0005 0.0130 1.1 93.1 6.50 0.0004 0.0110 1.0 94.1 TRASK' FOLK" MOMENT" FINE 6.75 0.0003 0.0093 0.9 95.1 SILT 7.00 0.0003 0.0078 0.8 3.8 95.8 MEAN 0.1068 3.3174 3.7049 7.25 0.0002 0.0065 0.6 96.4 MEDIAN 0.1037 3.2689 3.2689 7.50 0.0002 0.0055 0.5 97.0 SORTING 1.3490 0.9935 1.2958 VFINE 7.75 0.0002 0.0046 0.4 97.4 SKEWNESS 0.9705 0.3447 2.3435 SILT 8.00 0.0001 0.0039 0.4 2.0 97.8 KURTOSIS 0.2170 2.0794 8.7978 8.25 0.0001 0.0033 0.4 98.2 8.50 0.0001 0.0028 0.4 98.6 8.75 0.0001 0.0023 0.4 99.0 9.00 0.??oo 0.0019 0.3 99.3 9.25 0.??oo 0.0016 0.3 99.6 . COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 0.2 99.8 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.1 99.9 CLAY 10.00 0.??oo 0.0010 0.1 2.2 100.0 Kerr McGee Oil & Gas Corporation ~ File No.: HOU-050167 Nikaitchuq 4 ~ Date: March 10,2005 NW Milne Point Depth : 4163.70 Con! lðt:Ì Sample: 85AH 'atmn~ EXTENDED RANGE PARTS/Z5M ANAL YS/S Laser Partslz am Distribution 25 ~~~J®g - ... . 100 ~ @~~y 20 80 #: , 0 c ";:15 603 u c c ã 41 :I · .. < cr · ~. m f10 · 40...... LL " .r $ · "... · . · l-1 · 5 · 20 · " · I t II .... _ ." II. [J _- ..a.u,. I · · · · · · · · 0 ............ ...i1 .... · I . 0 r 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1781 0.0070 2.4892 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1568 0.0062 2.6731 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1388 0.0055 2.8490 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1192 0.0047 3.0685 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0834 0.0033 3.5845 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0530 0.0021 4.2371 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0222 0.0009 5.4952 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0100 0.0004 6.6492 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0049 0.0002 7.6713 SAND 60 2.00 0.0098 0.2500 0.1 0.1 0.1 70 2.25 0.0083 0.2100 1.3 1.3' 80 2.50 0.0070 0.1770 3.8 5.1 FINE 100 2.75 0.0058 0.1490 6.8 11.9 SURFACE AREA (m^2Icc): 0.2976 SAND 120 3.00 0.0049 0.1250 9.7 21.5 21.6 140 3.25 0.0041 0.1050 11.8 33.4 170 3.50 0.0035 0.0680 12.6 46.1 VFINE 200 3.75 0.0029 0.0740 11.9 58.0 STD DEVIATION (nvn): 0.0583 SAND 230 4.00 0.0024 0.0620 9.9 46.3 67.8 270 4.25 0.0021 0.0530 7.2 75.0 325 4.50 0.0017 0.0440 4.5 79.5 CAS 400 4.75 0.0015 0.0370 2.4 81.9 STD DEVIATION (Inc:hes): 0.0023 SILT 500 5.00 0.0014 0.0310 1.1 15.1 83.0 5.25 0.0010 0.0260 0.5 83.5 5.50 0.0009 0.0220 0.5 84.0 GRAVEL PACK: 20140 MED 5.75 0.0007 0.0190 0.8 84.9 SILT 6.00 0.0006 0.0160 1.2 3.1 86.0 6.25 0.0005 0.0130 1.5 87.5 6.50 0.0004 0.0110 1.6 89.1 TRASK" FOLK- MOMENT*" FINE 6.75 0.0003 0.0093 1.5 90.6 SILT 7.00 0.0003 0.0078 1.4 6.0 92.0 MEAN 0.0861 3.9762 4.1733 7.25 0.0002 0.0065 1.3 93.3 MEDIAN 0.0834 3.5845 3.5845 7.50 0.0002 0.0055 1.1 94.4 SORTING 1.4993 1.4467 1.5545 VFINE 7.75 0.0002 0.0046 1.0 95.3 SKEWNESS 0.9096 0.5107 1.6318 SILT 8.00 0.0001 0.0039 0.8 4.2 96.2 KURTOSIS 0.2254 1.8174 5.1024 8.25 0.0001 0.0033 0.8 96.9 8.50 0.0001 0.0028 0.7 97.6 8.75 0.0001 0.0023 0.6 98.2 9.00 0.??oo 0.0019 0.5 98.8 9.25 0.??oo 0.0016 0.4 99.2 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.4 99.6 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.3 99.9 CLAY 10.00 0.??oo 0.0010 0.1 3.8 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ -:!!. !!..,..15 ~ c GI :s 0" f10 u. GRAVEL VCRS SD CAS so MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SilT CLAY ~D'~J~~ 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 .... ~ ~ Core lBI:i 'au,.uI mTJmAnH EXTENDED RANGE PARTS/Z9M ANAL YS/S . . . ~ @J» ~ Laser Partslz sm Distribution "" 11-............ -.... .. ~ I 0.01 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3_50 3.75 4.00 425 4.50 4.75 5.00 525 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo ~, i ~ iJ ~ ~ ¡ ~ : r·~~ - : · "Þ- ¡ ~ ~ JI:¡.; · . · ~ . . . ~ . . . II .; MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 02500 02100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 02 1.7 4.4 7.5 10.5 12.5 13.1 12.1 9.9 7.1 4.3 2.2 0.9 0.4 0.4 0.7 1.0 1.2 1.3 1.3 1.2 1.0 0.9 0.8 0.7 0.6 0.5 0.5 0.4 0.3 0.2 0.2 0.1 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 02 1.9' 6.3 13.9 24.3 36.8 49.9 62.0 71.9 78.9 83.3 85.5 86.4 86.7 87.1 87.8 88.8 90.0 91.4 92.7 93.9 94.9 95.8 96.5 97.2 97.8 98.3 98.7 99.1 99.5 99.7 99.9 100.0 0.0 0.0 0.0 02 24.2 47.5 14.5 2.4 5.1 3.3 2.8 File No.: Date: Depth : Sample: III=", "" - HOU-050167 March 10,2005 4164.50 87 AH _ _ .. . . 100 ©B~y 80 o c 60 ~ ã i' 40...... -:!!. ~ 20 o 0.001 SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 90 95 0.1869 0.1633 0.1441 0.1239 0.0879 0.0580 0.0416 0.0131 0.0064 SURFACE AREA (m"2Ic:c): STD DEVIATION (mm) : STD DEVIATION (Inches) : GRAVEL PACK: TRASK' MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.0910 0.0879 1.4617 0.9303 0.2194 inches 0.0074 0.0064 0.0057 0.0049 0.0035 0.0023 0.0016 0.0005 0.0003 FOLK- 3.6295 3.5078 1.1858 0.3787 1.8230 phi 2.4199 2.6142 2.7950 3.0123 3.5078 4.1076 4.5858 62551 7.2918 02454 0.0512 0.0020 20140 MOMENT- 4.0098 3.5078 1.4353 1.8216 6.1197 . COMPUTED USING MIlliMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation ~ File No.: HOU-050167 Nikaitchuq 4 ð\ Date: March 10,2005 NW Milne Point Depth : 4165.50 ÜJre lðIi Sample: 91 AH Ult....ØI~ EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partslz 8m Distribution 25 ~rr'~J~~ · I - -.... 100 · · · · · ~ · c¡g "@J · · · · ~ ~ 20 · , 80 · @ï» · · ~ @j) · ~ y~ ¡ · ¡§E ~ 0 · c ';:15 · 60 ~ · u · ~ ~- : c · i Q) · ::::I · IP":J' . i go · · '" . 2!10 · · ~-,'" 40 -- · · II.. · · . E $ · · ! -'I"". · · · · 5 · · ~l r~b- "__ 20 · · · · · · · · · · · · ~ U,,..- r'.. 0 ........1 .... . I ... --.- , ~..~-' 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1853 0.0073 2.4320 VCRSSD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1622 0.0064 2.6244 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1432 0.0056 2.8039 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1232 0.0049 3.0205 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0876 0.0034 3.5125 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0586 0.0023 4.0934 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0443 0.0017 4.4968 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0152 0.0006 6.0366 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0071 0.0003 7.1440 SAND 60 2.00 0.0098 0.2500 0.1 0.1 0.1 70 2.25 0.0083 0.2100 1.7 1.8' 80 2.50 0.0070 0.1770 4.3 6.1 FINE 100 2.75 0.0058 0.1490 7.4 13.5 SURFACE AREA (m^2Icc): 0.2313 SAND 120 3.00 0.0049 0.1250 10.4 23.8 23.9 140 3.25 0.0041 0.1050 12.5 36.4 170 3.50 0.0035 0.0880 13.2 49.7 VFINE 200 3.75 0.0029 0.0740 12.4 62.0 STD DEVIATION (nun): 0.0495 SAND 230 4.00 0.0024 0.0620 10.2 48.3 72.2 270 4.25 0.0021 0.0530 7.4 79.6 325 4.50 0.0017 0.0440 4.6 84.1 CRS 400 4.75 0.0015 0.0370 2.4 86.5 STD DEVIATION (Inches): 0.0019 SILT 500 5.00 0.0014 0.0310 1.0 15.3 87.5 5.25 0.0010 0.0260 0.4 87.9 5.50 0.0009 0.0220 0.3 88.2 GRAVEL PACK: 20140 MED 5.75 0.0007 0.0190 0.6 88.8 SILT 6.00 0.0006 0.0160 0.9 2.2 89.7 6.25 0.0005 0.0130 1.2 90.9 6.50 0.0004 0.0110 1.3 92.1 TRASK' FOLK" MOMENT" FINE 6.75 0.0003 0.0093 1.2 93.4 SILT 7.00 0.0003 0.0078 1.1 4.8 94.5 MEAN 0.0909 3.6044 3.9814 7.25 0.0002 0.0065 1.0 95.4 MEDIAN 0.0876 3.5125 3.5125 7.50 0.0002 0.0055 0.8 96.2 SORTING 1.4504 1.1372 1.3845 VFINE 7.75 0.0002 0.0046 0.7 96.9 SKEWNESS 0.9403 0.3521 1.8903 SILT 8.00 0.0001 0.0039 0.6 3.0 97.5 KURTOSIS 0.2200 1.8000 6.5723 8.25 0.0001 0.0033 0.5 98.0 8.50 0.0001 0.0028 0.5 98.4 8.75 0.0001 0.0023 0.4 98.9 9.00 0.??oo 0.0019 0.4 99.2 9.25 0.??oo 0.0016 0.3 99.5 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.2 99.7 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.2 99.9 CLAY 10.00 0.??oo 0.0010 0.1 2.5 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ;:15 () c GI :I 17 !10 LL GRAVEL VCRS SO CAS so MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY ~ S Care Lab .atJlftllI~ FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4166.60 93AH EXTENDED RANGE PARTSIZSM ANAL YSIS Laser Partslz om Distribution k~~J~ @B~;. · 100 80 · , , , , , _---L- , , , , , , · · '@ :"@) @:íL~ . ~:@I ~:Œ!!:. · . ----.---------------- · , · · , · , , · · · · · · · · · · ~ @» ~ o c -60g ã i" - 40 ~ £ /. f : ~- : ----,'_..------ , -, , , , , . , , , 20 5 o 0.001 . OM .. .. . .1 , L- 0.01 o 10 ~ .. , .... . .. t ....... 0.1 Particle Diameter (mm) GRAlN SIZE DISTRIBunON SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -125 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -025 0.0469 1.1900 0.0 0.0 5 0.1781 0.0070 2.4891 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1573 0.0062 2.6688 20 025 0.0335 0.8500 0.0 0.0 16 0.1395 0.0055 2.8419 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1202 0.0047 3.0571 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0852 0.0034 3.5531 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0566 0.0022 4.1422 40 125 0.0165 0.4200 0.0 0.0 84 0.0410 0.0016 4.6078 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0133 0.0005 6.2334 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0065 0.0003 72544 60 2.00 0.0098 02500 0.0 0.0 0.0 70 2.25 0.0083 02100 12 1.3 ' 80 2.50 0.0070 0.1770 3.8 5.1 100 2.75 0.0058 0.1<490 6.9 12.0 SURFACE AREA (1II"2Iec): 0.2450 120 3.00 0.0049 0.1250 10.0 22.0 22.0 140 325 0.0041 0.1050 12.3 34.3 170 3.50 0.0035 0.0880 132 47.5 200 3.75 0.0029 0.0740 12.5 80.0 STD DEVIATION (nvn) : 0.0492 230 4.00 0.0024 0.0620 10.4 48.4 70.4 270 425 0.0021 0.0530 7.7 78.1 325 4.50 0.0017 0.0440 4.8 82.9 400 4.75 0.0015 0.0370 2.5 65.5 STD DEVIATION (Inche.): 0.0019 500 5.00 0.0014 0.0310 1.1 16.1 86.5 5.25 0.0010 0.0260 0.4 86.9 5.50 0.0009 0.0220 0.4 87.3 GRAVEL PACK : 20140 5.75 0.0007 0.0190 0.6 87.9 6.00 0.0006 0.0160 1.0 2.4 88.9 6.25 0.0005 0.0130 1.2 90.1 6.50 0.0004 0.0110 1.4 91.5 TRASK' FOLK" MOMENT" 6.75 0.0003 0.0093 1.3 92.8 7.00 0.0003 0.0078 1.2 5.1 94.0 MEAN 0.0884 3.6676 4.0449 7.25 0.0002 0.0065 1.0 95.0 MEDIAN 0.0852 3.5531 3.5531 7.50 0.0002 0.0055 0.9 95.9 SORTING 1.4565 1.1635 1.4112 7.75 0.0002 0.0046 0.7 96.6 SKEWNESS 0.9376 0.3740 1.8336 8.00 0.0001 0.0039 0.6 3.3 97.3 KURTOSIS 0.2206 1.7998 6.2210 8.25 0.0001 0.0033 0.5 97.8 8.50 0.0001 0.0028 0.5 98.3 8.75 0.0001 0.0023 0.4 98.7 9.00 0.??oo 0.0019 0.4 99.1 9.25 0.??oo 0.0016 0.3 99.5 . COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 0.3 99.7 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.2 99.9 10.00 0.??oo 0.0010 0.1 2.7 100.0 Kerr McGee Oil & Gas Corporation ~, FileNo. : HOU-050167 Nikaitchuq 4 Date: March 10. 2005 NW Milne Point Depth : 4167.70 Core LaIÍ Sample: 95AH Imml!ltrT1Jl1UntW EXTENDED RANGE PARTS/28M ANAL YS/S Laser Partslz am Distribution 25 ~~~J~~ " · b~·· . 100 · · Õ" . Ë ©~~y · · ~ · 'l3I '13J · · · · (1@ ~~~---=-, 20 80 · t9JJ · · -LL · · · · ~ t§D · · @ · · · l · ~ · · ~ [!!1, · 0 · · · · c · · · · 60 g >015 - ------.--~-- " · ~ ----------- u · · · /--- · c · · · · ã GI · · · · :::J · · · · <' f:T · · · CD f10 · · · 40 ~ · · · u.. · · · :! · · ~J · · · · · · · 5 · · · 20 . · ~ --------- " · lll-JH".- _" _ · · · dÎ~ · · · · · · · · · $.....--- 0 ........1 . . .....¡ ' 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAlN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1515 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1601 0.0063 2.6432 VCRS SD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1335 0.0053 2.9047 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1135 0.0045 3.1387 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0924 0.0036 3.4365 30 0.75 0.0236 0.6000 0.0 0.0 so 0.0532 0.0021 4.2333 CAS so 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0200 0.0008 5.6464 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0114 0.0004 6.4608 45 I.SO 0.0138 0.3500 0.0 0.0 80 0.0066 0.0003 7.2418 MED so 1.75 0.0117 0.2970 0.0 0.0 115 0.0035 0.0001 8.1494 SAND 60 2.00 0.0098 0.2500 0.1 0.1 0.1 10 2.25 0.0083 0.2100 0.7 0.8 ! so 2.SO 0.0070 0.1770 2.0 2.8 FINE 100 2.75 0.0058 0.1490 3.7 6.5 SURFACE AREA (11I"2Icc) : 0.4303 SAND 120 3.00 0.0049 0.1250 5.5 11.9 12.0 140 3.25 0.0041 0.1050 7.1 19.0 170 3.SO 0.0035 0.0880 8.1 27.1 VFINE 200 3.75 0.0029 0.0740 8.3 35.4 STD DEVIATION (11IIII) : 0.0511 SAND 230 4.00 0.0024 0.0620 7.8 31.2 43.2 270 4.25 0.0021 0.0530 6.9 SO. 1 325 4.50 0.0017 0.0440 5.9 56.0 CRS 400 4.75 0.0015 0.0370 5.0 61.0 STD DEVIATION (Inches) : 0.0020 SILT 500 5.00 0.0014 0.0310 4.3 22.1 65.3 5.25 0.0010 0.0260 3.9 69.1 5.50 0.0009 0.0220 3.6 72.7 GRAVEL PACK: 40160 MED 5.75 0.0007 0.0190 3.3 76.1 SILT 6.00 0.0006 0.0160 3.1 13.9 79.2 6.25 0.0005 0.0130 2.8 82.0 6.50 0.0004 0.0110 2.5 84.4 TRASK" FOLK- MOMENT- FINE 6.75 0.0003 0.0093 2.2 86.6 SILT 7.00 0.0003 0.0078 1.9 9.3 88.5 MEAN 0.0562 4.6109 4.8210 7.25 0.0002 0.0065 1.7 90.1 MEDIAN 0.0532 4.2333 4.2333 7.50 0.0002 0.0055 1.5 91.6 SORTING 2.1509 1.6648 1.6699 VFINE 7.75 0.0002 0.0046 1.4 93.0 SKEWNESS 0.6524 0.3817 0.9140 SILT 8.00 0.0001 0.0039 1.3 5.8 94.3 KURTOSIS 0.2652 1.0212 3.1843 8.25 0.0001 0.0033 1.2 95.4 8.50 0.0001 0.0028 1.1 96.5 8.75 0.0001 0.0023 0.9 97.5 9.00 0.??oo 0.0019 0.8 98.3 9.25 0.??oo 0.0016 0.7 98.9 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.5 99.4 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.4 99.8 CLAY 10.00 0.??oo 0.0010 0.2 5.7 100.0 Kerr McGee 011 & Gas Corporation Nikaitchuq 4 NW Milne Point 25 ~ ~~ Care Lab 'œJftllIJ'T1~ FileNo. : Date: Depth : Sample: HOU-050167 March 10, 2005 4168.65 99AH EXTENDED RANGE PARTS/28M ANAL YS/S Laser Partslz 8m Distribution , · · '. · · _ .. . . 100 ~ü'lJ~K . 20 __________.L_ ~ ';15 u c c ::J W10 LI. GRAVEl VCRS SO CAS so MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY ~i~~'JI ~ 11 . . ~ ( ~ ] -~I 11 .. .J...~. I! r u _ J......-£_-~. 0.01 @rn~y ~ @JI . ~ -- 80 o c -~- 60 ~ iã ~ -40- £, ~_._~ · · · · · · . · · · · · o ........1 10 5- 20 o 0.001 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1683 0.0066 2.5713 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1443 0.0057 2.7934 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1256 0.0049 2.9935 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1074 0.0042 3.2187 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0733 0.0029 3.7702 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0440 0.0017 4.5061 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0215 0.0008 5.5402 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0097 0.0004 6.6868 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0050 0.0002 7.6341 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 2.25 0.0083 02100 0.8 0.8 .. 60 2.50 0.0070 0.1770 2.7 3.4 100 2.75 0.0058 0.1490 5.1 8.5 SURFACE AREA (m^2Icc): 0.3028 120 3.00 0.0049 0.1250 7.7 162 162 140 325 0.0041 0.1050 10.0 262 170 3.50 0.0035 0.0880 11.5 37.7 200 3.75 0.0029 0.0740 11.7 49.4 STD DEVIATION (nvn) : 0.0520 230 4.00 0.0024 0.0620 10.6 43.8 60.0 270 4.25 0.0021 0.0530 8.7 68.7 325 4.50 0.0017 0.0440 6.3 75.0 400 4.75 0.0015 0.0370 4.1 79.1 STD DEVIATION (Inches) : 0.0020 500 5.00 0.0014 0.0310 2.4 21.5 81.5 5.25 0.0010 0.0260 1.4 82.9 5.50 0.0009 0.0220 0.9 83.8 GRAVEL PACK : 20140 5.75 0.0007 0.0190 0.9 84.8 6.00 0.0006 0.0160 1.1 4.4 85.9 6.25 0.0005 0.0130 1.4 87.3 6.50 0.0004 0.0110 1.5 88.8 TRASK' FOLKti MOMENT*" 6.75 0.0003 0.0093 1.6 90.4 7.00 0.0003 0.0078 1.5 6.0 91.9 MEAN 0.0757 4.1013 4.3202 7.25 0.0002 0.0065 1.4 93.2 MEDIAN 0.0733 3.7702 3.7702 7.50 0.0002 0.0055 1.2 94.5 SORTING 1.5624 1.4038 1.5094 7.75 0.0002 0.0046 1.0 95.5 SKEWNESS 0.8801 0.4582 1.5088 8.00 0.0001 0.0039 0.9 4.5 96.4 KURTOSIS 0.2357 1.6116 4.8265 8.25 0.0001 0.0033 0.8 97.2 8.50 0.0001 0.0028 0.7 97.9 8.75 0.0001 0.0023 0.6 98.4 9.00 0.??oo 0.0019 0.5 98.9 9.25 0.??oo 0.0016 0.4 99.3 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.3 99.6 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.2 99.9 10.00 0.??oo 0.0010 0.1 3.6 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ¡: ""'15 ß' c: GI :;¡ r:T !!!10 u. GRAVEL VCRS so œsso MED SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY ~G'~J~! 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 10 60 100 120 140 170 200 230 270 325 400 500 A\ t:on! lab ImØ81l~ EXTENDED RANGE PARTS/Z5M ANAL YS/S · · · :~ ~ : E»' ~~ . · · · · · · · · · · · · . · · · · · ........~ , · · · · · Laser Partsiz om Distribution ~ @I ~ · · · · · ~ ~-=- ~ ~ · · · · · · ------- · · · · · . Jartf- ~ · · · · · · · · . · · · · · GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -125 -1.00 -a.75 -a.50 -a.25 0.00 025 0.50 0.75 1.00 125 1.50 1.75 2.00 2.25 2.50 2.75 3.00 325 3.50 3.75 4.00 425 4.50 4.75 5.00 525 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 6.25 8.50 8.15 9.00 9.25 9.50 9.15 10.00 INCH 0.1515 0.1323 0.1114 0.0931 0.0187 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0001 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo . · · · · · ..."... MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 02970 0.2500 02100 0.1770 0.1<190 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0018 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.9 2.5 4.6 6.1 8.5 9.6 9.8 92 8.0 6.5 5.1 3.9 3.0 2.4 2.1 2.0 1.9 1.8 1.1 1.6 1.5 1.3 1.2 1.0 0.9 0.1 0.6 0.4 0,4 0.2 0.1 Particle Diameter (mm) SEP CUM U.O 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0" 0.0 0.9 3.5 8.0 14.1 232 32.8 42.6 51.8 59.8 66.3 11.4 152 18.2 80.6 82.8 84.7 86.6 88.5 90.2 91.8 93.4 94.1 95.9 96.9 97.8 98.5 99.0 99.5 99.8 100.0 0.0 0.0 0.0 0.0 3.5 29.4 33.4 14,4 7.8 6.2 5.3 FileNo. : Date: Depth : Sample: . l·~J1Un.._---k- ~ 0.01 SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 90 95 0.1183 0.1000 0.0859 0.0718 0.0458 0.0222 0.0111 0.0067 0.0037 SURFACE AREA (m"2Icc): STD DEVIATION (nvn): STD DEVIATION (Inches) : GRAVEL PACK : TRASK' MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.0410 0.0458 1.1915 0.1611 0.2655 Inches 0.0041 0.0039 0.0034 0.0028 0.0018 0.0009 0.0005 0.0003 0.0001 FOLK" 4.8004 4.4493 1.4124 0.4085 1.2066 . COMPUTED USING MILLIMETER VALUES ., COMPUTED USING PHI VALUES HOU-050167 March 10, 2005 4169.40 101 AH _ _ _ . . 100 80 o c: --- 60 ª ã ~ 40 ~ £. - 20 .. , o 0.001 phi 3.0196 3.3214 3.5405 3.1991 4.4493 5.4911 6.4113 7.2311 6.0609 0.4254 0.0311 0.0015 40160 MOMENT" 4.9801 4.4493 1,4951 1.1213 3.1366 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ';:15 - u C 41 ::I IJ !10 u.. GRAVEL VCRS SO CAS so MEO SAND FINE SAND VFINE SAND CRS SIlT MEO SilT FINE SilT VFINE SilT CLAY ~~lJ~M ~.. ..... . I:on! LaIÍ ta:tllQ1lll~ EXTENDED RANGE PARTS/2SM ANAL YS/S . - ~ : ~ f~ ~-.-' · · · · · · · · · · · · . · · · · · 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ........1 Laser Partslz &m Distribution FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4170.50 103 AH _ _ _. . . 100 · · · · · · ---- · · · · · · -, · · · · · -. : ;. .rrI~;": .. ~\. . ¡-~ '-. ~ -r-=ur - 1 - . . . i . .. ~ I{¡ t - J.- _ b.: JU",,:__- - GRAIN SIZE DISTRIBUTION PHI -2.00 ·1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0185 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.8 2.6 4.9 7.5 9.7 11.1 11.3 10.3 8.4 6.2 4.1 2.6 1.6 1.2 1.2 1.3 1.5 1.6 1.7 1.6 1.4 1.3 1.1 1.0 0.8 0.7 0.6 0.5 0.4 0.3 0.3 0.1 í 0.1 Particle Diameter (mm) 0.01 :,? -80 o c - 60 g ã ;¡:" CD 40...... :t. 20 o 0.001 SEP SORTING PARAMETERS 0.0 CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.8 3.4 8.3 15.8 25.5 38.6 47.9 58.2 66.6 12.8 77.0 19.5 81.1 82.3 83.5 84.8 86.4 88.0 89.7 91.2 92.7 94.0 95.1 96.1 96.9 97.7 98.3 98.8 99.3 99.6 99.9 100.0 MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.0731 0.0715 1.6219 0.8352 0.2442 PERCENTILES: mm 0.0 5 10 16 25 50 75 84 110 95 0.1677 0.1435 0.1245 0.1060 0.0715 0.0403 0.0119 0.0090 0.0047 0.0 0.0 SURFACE AREA (mA2Icc): 15.8 STD DEVIATION (nvn) : 42.4 STD DEVIATION (Inches) : 21.4 GRAVEL PACK : 5.3 TRASK" 6.4 4.8 Inches 0.0066 0.0056 0.0049 0.0042 0.0028 0.0016 0.0007 0.0004 0.0002 FOLK" 4.2058 3.8057 1.4829 0.4763 1.5174 phi 2.5759 2.8008 3.0055 3.2378 3.8057 4.6333 5.8062 6.7984 7.7422 0.3215 0.0533 0.0021 20140 MOMENT"" 4.3842 3.8057 1.5488 1.4138 4.4555 . COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES 3.9 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ --15 ~ c GI ::I ~10 II. GRAVEL VCRS so CAS so MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SILT CLAY ~~~J~I 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ~ ~ Core LaIÌ U'Jt"'lIf~ EXTENDED RANGE PARTS/2SM ANAL YS/S c:¡g¡ @:í.j : t9}t: ~ ~ ~ , , · · · , · -.--- · · , · , . · · · · · " · · · · · . ........¡ Laser Partslz am Distribution ........ 0.1 Particle Diameter (mm) · · · : "@ : 'BI : · -0'J.L~ : · ;§l» :~ · · · · · · · · · · · · · · · · · · · · GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1515 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.0 1.9 3.0 4.0 4.9 5.6 6.2 6.5 6.6 6.5 6.2 5.9 5.4 5.0 4.5 4.1 3.7 3.3 3.0 2.7 2.3 2.0 1.7 1.4 1.1 0.9 0.5 @) [\!1, .....J:.~,.. SEP ~i . ---------. 0.0 CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ' 0.0 0.0 0.0 0.1 1.2 3.1 6.1 10.0 14.9 20.5 26.7 33.2 39.8 46.3 52.6 58.4 63.9 68.8 73.3 77.4 81.1 84.5 87.4 90.1 92.4 94.5 96.2 97.6 98.7 99.5 100.0 0.0 0.0 0.0 0.0 6.1 20.6 25.9 20.8 14.1 12.6 PERCENTILES: 5 10 16 25 50 75 84 90 115 SURFACE AREA (mA2Icc): STD DEVIATION (nvn) : STD DEVIATION (Inches) : GRAVEL PACK : MEAN MEDIAN SORTING SKEWNESS KURTOSIS kõ~t FileNo. ; Date; Depth : Sample: HOU-050167 March 10.2005 4171.50 107 AH . . 100 o c 603 c i <' IV 40 - $ 20 _ .l- _ _-"-11 I.. - 0 0.01 0.001 - ...... SORTING PARAMETERS mm 0.0663 0.0531 0.0426 0.0327 0.0172 0.0073 0.0047 0.0033 0.0022 TRASK' 0.0200 0.0172 2.1189 0.8001 0.2551 Inches 0.0026 0.0021 0.0017 0.0013 0.0007 0.0003 0.0002 0.0001 0.0001 FOLK- 6.0454 5.8590 1.5402 0.1938 0.9323 phi 3.9156 4.2360 4.5516 4.9365 5.8590 7.1031 7.7256 8.2331 8.8440 0.8457 0.0190 0.0007 NlA MOMENT"" 6.2054 5.8590 1.4872 0.4155 2.4454 . COMPUTED USING MILLIMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 ~~~J~I 20 ~ ;:15 u c Q) ::I W10- II. 5- GRAVEL MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 VCRS SO CAS so MED SAND FINE SAND VFINE SAND CAS SilT MED SilT FINE SilT VFINE SilT CLAY ~ S Core LaIÌ Immllll"!UßLU1ll EXTENDED RANGE PARTSlzsM ANAL YSIS . . . Laser Partsiz am Distribution c¡:g¡:"¡3J ~~ · ~i ~ · · 4t:~ . FileNo. : Date: Depth : Sample: / .. . - ---<m - Jt- ....III~· · 0.Q1 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 125 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 o.osao 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0,0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.4 1.6 3.3 5.3 7.3 9.0 10.1 10.4 9.8 8.4 6.7 4.8 3.3 2.1 1.4 1.1 1.0 1.1 1.2 1.3 1.2 1.2 1.1 1.0 0.9 0.8 0.8 0.7 0.6 0.6 0.5 0.4 0.3 0.2 0.1 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.4 2.0 5.3 10.6' 17.9 26.9 37.0 47.4 57.2 65.6 72.3 77.1 80.4 82.5 83.8 84.9 85.9 87.1 88.3 89.5 90.7 91.9 93.0 94,0 94.9 95.8 96.6 97.3 97.9 98.5 99.0 99.4 99.7 99.9 100.0 · · : "@I _~ @R) : @JI: ~ ~ ; ~~- · · · · · · · · · · · · .- · · · · · o ........, 10 0.0 0.0 0.0 5.3 31.7 35.2 11.6 4.4 4.8 3.5 3.4 HOU-050167 March 10,2005 4172.30 109 AH _ _ .. . . 100 ~ ~~~y ~----80 · · · · · .. I _;-11 o c -60 ê i <" ~- 40 .!. £. 20 . ~ -- o 0.001 SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 80 95 0.2545 0.2144 0.1855 0.1550 0.1005 0.0569 0.0303 0.0122 0.0054 SURFACE AREA (m"2ICC) : STO DEVIATION (nvn): STD DEVIATION (Inches) : GRAVEL PACK: TRASK" MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.1060 0.1005 1.6496 0.8738 0.2423 inches 0.0100 0.0084 0.0073 0.0061 0.0040 0.0022 0.0012 0.0005 0.0002 FOLK" 3.5970 3.3149 1.4944 0.4201 1.5739 phi 1.9743 2.2214 2.4302 2.6901 3.3149 4.1343 5.0461 6.3566 7.5209 0.2624 0.0776 0.0031 20140 MOMENT" 3.8751 3.3149 1.6287 1.5091 4.9566 . COMPUTED USING MILLIMETER VALUES ., COMPUTED USING PHI VALUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ¡: .....15 ~ c III ;:, 0- f 10 u. GRAVEL VCRS SD CAS so MED SAND FINE SAND VFINE SAND CRS SilT MED SilT FINE SilT VFINE SilT CLAY k~lJ®~ 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 · · · · · · _I · · · · · · · · · · · · · · · · · · · · · · · · · ~ ð\ Con! LaI:Í """""~ EXTENDED RANGE PARTSIZSM ANAL YSIS . . ~ : ®: ~ : ~~ Laser Partslz am Distribution FileNo. : Date: Depth : Sample: HOU-050167 March 10, 2005 4173.30 111 AH ~~_...100 .. : @~~y . - 80 I~ · . . ------------~---------- · . . · . . .. . . ;t . . · . . : . :l'~~ · fIÏ'!' '". · .. j_. ". ~.~ -~ ~~r_~ . . . . . -n~ ~ _fu-.Ill.--_Ll··_" .I:I--.JI1 ............. 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 225 2.50 2.75 3.00 325 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.8000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.7 2.2 4.1 6.3 8.4 9.9 10.4 10.0 8.6 6.8 5.0 3.4 2.3 1.7 1.4 1.4 1.5 1.6 1.7 1.7 1.6 1.5 1.3 1.2 1.1 1.0 0.8 0,7 0.6 0.5 0.4 0.2 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.8" 3.0 7.1 13.5 21.9 31.8 <42.3 52.2 60.8 67.6 72.6 76.0 78.3 79.9 81.3 82.7 84.3 85.9 87.6 89.2 90.8 92.3 93.6 94.8 95.9 96.9 97.7 98.4 99.0 99.4 99.8 100.0 MEAN MEDIAN SORTING SKEWNESS KURTOSIS PERCENTILES: 0.0 0.0 5 10 16 25 50 75 84 90 95 0.0 0.1 0.01 o c 603 c !ã i - 40 ~ £ ~--20 o 0.001 SORTING PARAMETERS mm 0.1636 0.1382 0.1190 0.0997 0.0647 0.0327 0.0135 0.0072 0.0038 13.4 SURFACE AREA (mA2Icc): STD DEVIATION (mm): 38.7 STD DEVIATION (1nc:heS) : 23.8 GRAVEL PACK: 6.8 6.5 5.6 TRASK' 0.0662 0.0647 1.7452 0.7804 0.2555 Inches 0.0064 0.0054 0.0047 0.0039 0.0025 0.0013 0.0005 0.0003 0.0001 FOLK- 4.4099 3.9510 1.6062 0.4725 1.3836 phi 2.6120 2.8553 3.0706 3.3264 3.9510 4.9332 6.2081 7.1217 8.0363 0.3787 0.0528 0.0021 40160 MOMENT"" 4.5587 3.9510 1.6292 1.2696 3.9520 5.2 . COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 ~ ';:15 u c CD ::I .,. I!! 10 u. GRAVEL VCRS SD CAS so MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SILT CLAY 5- o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ~ ~, Core lzIIÌ unMII ~ EXTENDED RANGE PARTS/Z8M ANAL YS/S · · · · · Laser Partsiz SIn Distribution . · · · · · ........þJ.. FileNo. : Date: Depth : Sample: I .~ . , , . . . ~. JI · · · · · · · · · · · ~ · · · · · · · · · · · · . J - I... - UI.....u..~-~ 0.01 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 125 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.15ft> 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo ~[(~J®r : ~ 20 --~-----------~-- : ~ :~ · . ----------..---~-- · · · · · · · , · · , · . · , · · · MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.9 2.0 3.6 5.5 7.5 9.2 10.2 10.4 9.7 8.2 6.3 4.4 2.8 1.7 1.1 0.9 1.0 1.1 1.3 1.4 1.4 1.3 1.2 1.1 1.0 0.9 0.8 0,7 0.6 0.5 0.4 0.3 0.2 0.1 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.0 3.0 6.7.' 12.2 19.7 28.9 39.1 49.5 59.2 67.4 13.8 78.2 81.0 82.8 83.9 84.8 85.8 86.9 88.2 89.5 90.9 92.2 93.4 94.4 95.4 96.3 97.0 977 98.4 98.9 99.3 99.6 99.9 100.0 0.0 0.0 0.0 3.0 25.9 38.5 15.3 4.1 5.3 4,1 3.7 PERCENTILES: 5 10 16 25 50 75 84 90 95 ~-- - ---,---- HOU-050167 March 10,2005 4174.50 115 AH .. . . 100 @~~y ---- 80 o c ~-60g ã <" CD 40 ~ £ 20 o 0.001 SORTING PARAMETERS mm 0.2283 0.1902 0.1629 0.1352 0.0873 0.0505 0.0255 0.0104 0.0050 SURFACe AREA (1II"2Icc): STD DEVIATION (mm): STD DEVIATION (IncheS): GRAVEL PACK : MEAN MEDIAN SORTING SKEWNESS KURTOSIS TRASK' 0.0928 0.0873 1.6359 0.8958 0.2355 inches 0.0090 0.0075 0.0064 0.0053 0.0034 0.0020 0.0010 0.0004 0.0002 FOLK" 3.8102 3.5179 1.5054 0.4126 1.5930 phi 2.1313 2.3947 2.6183 2.8872 3.5179 4.3074 5.2944 6.5863 7.6515 0.2868 0.0687 0.0027 20140 MOMENT'" 4.0645 3.5179 1.6178 1.4468 4.7128 . COMPUTED USING MILLIMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 20 ~ ~15 ~ c GI ::J c:r I!! 10 II. GRAVEL VCRS SD CASSO MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SILT CLAY ~G'~J~~ 5 o 10 MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 ~ ð\ I:on! Lab larmlll IrmuAJ1II EXTENDED RANGE PARTSIZSM ANAL YSIS ........1 , . . ~~ @J'i : ~~ Laser Partsiz am Distribution · · · · · · · · · · · · · ~ · ~ 11 ~ : --:-- -~.. - · . . · . ~ . .. I . .. ! . ........... .L.;l ~ . GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -125 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 125 1.50 1.75 2.00 2.25 2.50 2.75 3.00 325 3.50 3.75 4.00 425 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 1.3 2.9 4.7 6.4 7.6 8.0 7.7 6.9 5.9 4.9 4.1 3.6 3.3 3.2 3.2 3.2 3.1 3.0 2.8 2.5 2.3 2.0 1.8 1.5 1.3 1.0 0.8 0.7 0.3 0.1 Particle Diameter (mm) SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0" 0.0 0.0 1.3 4.1 8.9 15.3 22.9 30.9 38.7 45.6 51.5 56.3 60.4 64.0 67.3 70.5 73.8 77.0 80.1 83.1 85.8 88.4 90.6 92.6 94.4 95.9 97.2 98.2 99.0 99.7 100.0 0.0 0.0 0.0 0.0 1.3 21.6 28.6 15.8 12.8 10.6 9.4 -- FileNo. : Date: Depth : Sample: HOU-050167 March 10, 2005 4175.50 117 AH . . 100 - 80 o c - 60 g iii ... <" (11 40 ~ £ --20 - JluJi~o 0.01 0.001 SORTING PARAMETERS PERCENTILES: 5 10 16 25 50 75 84 90 95 SURFACE AREA (mA2Icc): STD DEVIATION (nun): STD DEVIATION (Inches): GRAVEL PACK : MEAN MEDIAN SORTING SKEWNESS KURTOSIS mm 0.1019 0.0855 0.0729 0.0596 0.0325 0.0103 0.0062 0.0041 0.0026 TRASK' 0.0350 0.0325 2.4020 0.5832 0.3027 inches 0.0040 0.0034 0.0029 0.0023 0.0013 0.0004 0.0002 0.0002 0.0001 FOLK" 5.3545 4.9427 1.6931 0.3619 0.8579 phi 3.2948 3.5472 3.7780 4.0674 4.9427 6.5958 7.3428 7.9317 8.5874 0.8372 0.0334 0.0013 NlA MOMENT*" 5.5190 4.9427 1.6666 0.6799 2.5038 . COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point A\ ÚJr1! LaIi HStÞlll1n'tJIIUI'a FileNo. : Date: Depth : Sample: HOU-050167 March 10,2005 4176.50 119 AH EXTENDED RANGE PARTS/25M ANAL YS/S Laser Partslz sm Distribution 25 ~O'~J~( I · 'ª~I bõ~t . . 100 · · · · ~ · ~ · · · · ~ · ~ 20 · · 80 @») · · · ¡9J · @) ~ · · ~ ~ · ~ · (!J1 0 · · c ';:15 · · 60 ê · ~ u · · c · · i GI · · :I · · ~ ~10 · · · · · · 40 ~ · · II. · · fJ'. · · -- · · · · 5 · · I 20 -------,~.- · · · llIJIL." n · · · · · · L-r1IC _ ~o · · 0 ............. . . . . . ....JIIt . 10 0.1 0.01 0.001 Particle Diameter (rom) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0795 0.0031 3.6523 VCRS SO 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0648 0.0026 3.9481 20 0.25 0.0335 0.8500 0.0 0.0 16 0.0543 0.0021 4.2029 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0419 0.0017 4.5758 30 0.75 0.0236 0.8000 0.0 0.0 50 0.0201 0.0008 5.6390 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0074 0.0003 7.0844 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0048 0.0002 7.7113 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0034 0.0001 8.2101 MEO 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0022 0.0001 8.8156 SAND 60 2.00 0.0098 02500 0.0 0.0 0.0 70 225 0.0083 02100 0.0 0.0' 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1<490 0.0 0.0 SURFACE AREA (mA2Icc): 0.8062 SAND 120 3.00 0.0049 0.1250 0.0 0.0 0.0 140 325 0.0041 0.1050 0.8 0.9 170 3.50 0.0035 0.0880 2.0 2.9 VFINE 200 3.75 0.0029 0.0740 3.4 6.4 STD DEVIATION (nvn): 0.0248 SAND 230 4.00 0.0024 0.0620 4.7 11.1 11.1 270 4.25 0.0021 0.0530 5.7 16.8 325 4.50 0.0017 0.0440 6.3 23.1 CAS 400 4.75 0.0015 0.0370 6.4 29.5 STD DEVIATION (IncheS) : 0.0010 SILT 500 5.00 0.0014 0.0310 6.2 24.6 35.7 5.25 0.0010 0.0260 5.8 41.5 5.50 0.0009 0.0220 5.3 46.8 GRAVEL PACK : NIA MED 5.75 0.0007 0.0190 5.0 51.8 SILT 6.00 0.0006 0.0160 4.7 20.7 56.4 6.25 0.0005 0.0130 4.5 60.9 6.50 0.0004 0.0110 4.4 65.3 TRASK" FOLK" MOMENT"" FINE 6.75 0.0003 0.0093 4.3 69.6 SILT 7.00 0.0003 0.0078 4.1 17.3 73.7 MEAN 0.0247 5.8511 6.0181 7.25 0.0002 0.0065 3.9 77.6 MEDIAN 0.0201 5.6390 5.6390 7.50 0.0002 0.0055 3.7 81.3 SORTING 2.3855 1.6594 1.6035 VFINE 7.75 0.0002 0.0046 3.4 84.6 SKEWNESS 0.7673 0.2059 0.4181 SilT 8.00 0.0001 0.0039 3.0 14.0 87.7 KURTOSIS 0.2814 0.8435 2.2609 8.25 0.0001 0.0033 2.7 90.3 8.50 0.0001 0.0028 2.3 92.7 8.75 0.0001 0.0023 2.0 94.7 9.00 0.??oo 0.0019 1.7 96.3 9.25 0.??oo 0.0016 1.3 97.7 . COMPUTED USING MilliMETER VAlUES 9.50 0.??oo 0.0014 1.1 98.7 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.9 99.6 CLAY 10.00 0.??oo 0.0010 0.4 12.3 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ &\ Core LðI:Ì .atJM1)~ File No.: Date: Depth : Sample: HOU-050167 March 10,2005 4177.35 121 AH EXTENDED RANGE PARTSIZSM ANAL YSIS Laser Partslz om Distribution 25 k~~J®~ ~ · bõ~t . . 100 · · · · ~ · ~ '19 · · · · (IfRJ (Ilk) · 20 · 80 tSæ · · · @) @I · ~ · · ~ · ~ [!& · (') · · c ;: 15 - · · 603 " Q · C C · · ã 41 · · ::I · · <' ~ 10 · · CD · 40~ · · II. · · · · · · · · 5 , · ~llJlll , --------- . 20 · · ...~...1Jt ···~o · · · · · · · · 0 ............. 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 ·1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.0760 0.0030 3.7179 VCRS so 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.0611 0.0024 4.0332 20 025 0.0335 0.8500 0.0 0.0 16 0.0507 0.0020 4.3013 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0385 0.0015 4.6977 30 0.75 0.0236 0.6000 0.0 0.0 60 0.0181 0.0007 5.7913 CAS so 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0065 0.0003 72687 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0043 0.0002 7.8589 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0031 0.0001 8.3232 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0021 0.0001 8.8943 SAND 60 2.00 0.0098 02500 0.0 0.0 0.0 70 225 0.0083 02100 0.0 0.0' 80 2.50 0.0070 0.1770 0.0 0.0 FINE 100 2.75 0.0058 0.1490 0.0 0.0 SURfACE AREA (m^2Icc): 0.8715 SAND 120 3.00 0.0049 0.1250 0.1 0.1 0.1 140 3.25 0.0041 0.1050 0.8 0.8 170 3.50 0.0035 0.0880 1.7 2.5 VFINE 200 3.75 0.0029 0.0740 2.9 5.4 STD DEVIATION (mm) : 0.0232 SAND 230 4.00 0.0024 0.0620 4.1 9.4 9.5 270 4.25 0.0021 0.0530 5.1 14.5 325 4.50 0.0017 0.0440 5.7 20.3 CAS 400 4.75 0.0015 0.0370 6.0 26.3 STD DEVIATION (Inches): 0.0009 SILT 500 5.00 0.0014 0.0310 6.0 22.9 32.3 5.25 0.0010 0.0260 5.8 38.1 5.50 0.0009 0.0220 5.4 43.5 GRAVEL PACK : NlA MED 5.75 0.0007 0.0190 5.0 48.5 SILT 6.00 0.0006 0.0160 4.7 20.9 53.3 6.25 0.0005 0.0130 4.5 57.8 6.50 0.0004 0.0110 4.4 62.2 TRASK' FOLK" MOMENT'"' FINE 6.75 0.0003 0.0093 4.3 66.6 SILT 7.00 0.0003 0.0078 4.3 17.6 70.8 MEAN 0.0225 5.9838 6.1487 7.25 0.0002 0.0065 4.1 74.9 MEDIAN 0.0181 5.7913 5.7913 7.50 0.0002 0.0055 3.9 78.9 SORTING 2.4377 1.6737 1.6123 VFINE 7.75 0.0002 0.0046 3.7 82.6 SKEWNESS 0.7664 0.1806 0.3320 SILT 8.00 0.0001 0.0039 3.4 15.2 86.0 KURTOSIS 0.2765 0.8251 2.1693 8.25 0.0001 0.0033 3.1 89.0 8.50 0.0001 0.0028 2.7 91.7 8.75 0.0001 0.0023 2.3 94.0 9.00 0.??oo 0.0019 1.9 96.0 9.25 0.??oo 0.0016 1.5 97.5 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 1.2 98.7 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.9 99.6 CLAY 10.00 0.??oo 0.0010 0.4 14.0 100.0 · [ore Lab RESERVOIR DPTIJotIZATIIIN' FIGURES for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES DIVISION 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska 10000 Permeability vs Porosity @ Various NCS . Routine Core Analysis (600 psig NCS) Routine Core Analysis Measurements (1200 psig NCS - Mean Net Effective Stress) Å Routine Core Analysis Measurements (1600 psig NCS) 1000 -= !ill! Routine Core Analysis Measurements (2400 psig NCS) fill Routine Core Analysis Measurements (3000 psig NCS) â Vertically Oriented Samples 100 0 Fractured Samples ê 10 .s >- ~ :õ IU Q) E .... Q) Il. 0.1 0.01 0.001 o 5 10 15 Figure 1 " Porosity (%) 20 . File No.: HOU-050167 Date: May 16, 2005 . £, 25 30 40 35 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska >- := :a !II a¡ E f- a¡ 0.. 0.001 10000 Permeability vs Porosity @ 600 psig NCS . Routine Core Analysis (600 psig NCS) o Fractured Samples 1000 100 10 . 0.1 0.01 o 5 10 15 20 25 Figure 2 Porosity (%) 30 File No.: HOU-050167 Date: May 16, 2005 . . 35 40 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 10000 Permeability vs Porosity @ 1200 psig NCS (Mean Net Effective Stress) Routine Core Analysis Measurements (1200 psig NCS - Mean Net Effective Stress) A Vertically Oriented Samples 10 1000 0 Fractured Samples 100 >- :5 :ë (II G> E .... G> Q. 0.1 0.01 0.001 o 5 10 15 20 25 30 35 40 Figure 3 Porosity (%) 1-- Kerr-McGee Oil &. Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 I'ITr,1!LUjjj ~H~H:rS 10000 Permeability vs Porosity @ 1800 psig NCS " Routine Core Analysis Measurements Ci800 psig NeS) o Fractured Samples 1000 '" A M &. 100 ê 10 .s ;:.. := ~ &. ~ E ... ( ) c.. f. 0.1 0.01 o 5 0.001 10 15 20 Porosity (%) 25 30 35 40 Figure 4 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska 10000 File No.: HOU-050167 Date: May 16, 2005 fnl¡lnrt¡¡¡Sr!)l'l('n Permeability vs Porosity @ 2400 psig NCS I)J Routine Core Analysis Measurements (2400 psig NCS) o Fractured Samples 1000 100 Õ 10 E -- ~ :ë !'II III E .... (! Q. 0.1 - 0.01 0.001 o 5 Figure 5 10 15 20 25 30 40 35 Porosity (%) Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska 10000 Permeability vs Porosity @ 3000 psig NCS II Routine Core Analysis Measurements (3000 psìg NCS o Fractured Samples 1000 100 ê 10 g. ~ :ä :¡¡ E I} ... ( c. ~ I 0.1 I 0.01 0.001 o 5 10 15 20 25 Figure 6 Porosity (%) File No.: HOU-050167 Date: May 16, 2005 . !\!III 30 35 40 ____________________________n_______n___________________---------------------1 Kerr-McGee Oii 8. Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 70 (KlPhi)o.5 vs Water Saturation @ 1200 psig NCS (Mean Net Effective Stress) 60 . . . .. 50 . . · . 40 · ., . · . . --. . . 30 . . ., · · . . . . · . . 20 "" ¡; 10 . .. . 0 0 10 20 30 40 50 60 70 80 90 100 Figure 7 Stw (%) Kerr-McGee Oil 8< Gas Corporation Nikaitchuq 4 NW Milne Point Alaska 10000 Permeability vs Grain Density @ 1200 psig NCS (Mean Net Effective Stress) File No.: HOU-050167 Date: May 16, 2005 1000 .. ~ .... .. .. .. 100 '" '" .. ê 10 .. g . '" ~ .. I :ë .. (\ I E "- II) Il. .. .. 0.1 0.01 0.001 2.65 2.70 2.75 2.80 2.85 2.90 2.95 3.00 Figure 8 Grain Density (glee) 3.05 3.10 Kerr-McGee Oil 8. Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 10000 Permeability vs Mean Grain Size @ 1200 psig NCS (Mean Net Effective Stress) 1000 .. . . 100 .. '" 10 . >- ~ :ö I'!I Q) E ... Q) n. . == 0.0011 ¡f8161 R2 == 0.91 0.1 0.01 o 20 0.001 40 60 80 100 120 140 Figure 9 Mean Grain Size (microns) o -Total Gamma 30 60 90 120 150 0 4100 5 0 10 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 File No : HOU-050167 Spectral Core Gamma Scale 5" = 100' 4110 4120 4130 4140 4150 4160 4170 4180 4190 4200 4210 4220 4230 4240 -Potassium (%) Uranium (ppm) - Thorium (ppm) 1 0 30 CORE ANAL YSIS DA TA Scale 5" = 100' -Kair (mD) -Seo (%) ~"Total Gamma -Stw(%) 100 4100 4110 4120 4130 4140 4150 4160 4170 4180 4190 4200 4210 4220 4230 4240 4250 " " 1 ,1""1,,,,1. 2.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska o Figure 11 File No.: HOU-050167 Date: May 16, 2005 Analysts: RP, MM, MS Core: Conventional -Porosity (%) -Grain Density (glee) " , ¡, " 2.5 3.0 Kerr-McGee Oil & Gas Nikaitchuq 4 NW Milne Point Alaska Figure 12 PROBE PERMEABILITY MEASUREMENTS Scale: 5" = 100 feet 10000 1000 100 10 0.1 0.01 4100 4110 4120 4130 4140 4150 4160 4170 4180 4190 4200 4210 4220 4230 4240 4250 File No.: HOU-050167 Date: March 3, 2005 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska 1200 psig NCS (Mean Net Effective Stress) I~ 100 90 80 70 '>!!. 0 60 ..J ~ z 50 ~ IIJ :::¡¡; W IX: 40 (.) ~ 30 20 10 0 PERMEABILITY HISTOGRAM - - - CUMULATIVE CAPACITY .010-.100 10000-100000 .100-1.00 1.00-10.0 10.0-100 100-1000 PERMEABILITY -Kair 1000-10000 POROSITY HISTOGRAM 100 100 90 90 80 80 70 70 '>!!. 0 ..J 60 g ~ ¡¡¡: z c::: w 50 50 ç :::¡¡; w .... IX: <: (.) 40 40 I'll ~ ¡f. 30 o 5-10 35-40 40-45 20-25 25-30 POROSITY 30-35 10-15 15-20 Figure 13 100 90 80 70 60 g ¡¡¡: c::: 50 ç .... <: 40 I'll ¡f. 30 20 10 o 10 o · [ore Lab RESERVOIR OPTIMIZATION Appendix I (Core Inventory) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entiray upon core samples, soils, solidS, liquidS, or gases, together with raated observational data,provided solely by the client. The concfusions, inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitat>ility or productivity on any well, sand. or drilling activity is at the sofe risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division Fax: 713-328-2567 6316 Wind/ern Houston, TX 77040 USA Tel: 713-328-2565 Kerr-McGee Oil & Gas Corporation . File No : HOU-050167 Nikaitchuq 4 Date: February 16. 2005 NW Milne Point Alaska PruOtru)!sulV1r.rs Core Inventory Core Tube Depth Interval Comments II Core I Tube Depth Interval Preserved No No (ft) No No (ft) Sections 1 1 4120.00 4123.00 1 2 4123.00 4126.00 1 3 4126.00 4129.00 1 4 4129.00 4132.00 1 5 4132.00 4135.00 1 6 4135.00 4138.00 1 7 4138.00 4141.00 1 8 4141.00 4144.00 1 9 4144.00 4145.50 Stabilizer 1 10 4145.50 4147.00 Stabilizer 1 11 4147.00 4150.00 1 12 4150.00 4153.00 1 13 4153.00 4156.00 1 14 4156.00 4159.00 1 15 4159.00 4162.00 1 16 4162.00 4165.00 1 17 4165.00 4168.00 1 18 4168.00 4171.00 1 19 4171.00 4174.00 1 20 4174.00 4177.00 1 21 4177.00 4178.50 Catcher Page 1 Appendix I Core Inventory .. [ore LaI:Ï RESERVOIR OPTIHIZATHlN' Appendix II (Sample Inventory) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data,provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES DIVISION 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 Kerr-McGee 011 & Gas Corporation Start Date: 02-16-05 Nikaitchuq 4 File No: HOU 050167 NW Milne Point Alaska Core Sample Log (Updated 05-09-(5) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Good Fair Poor Failed Vert Len Dia Trims Analysis Star!< LPSA SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 7BV 4120.00 x x 3.00 1.50 2 RCAL Sample Ambient Storage 51912005 8DV 4120.00 x x 2.50 1.50 2 Storage Sample Chilled Storage 2/25/2005 9AH 4120.50 x 2.00 1.50 2 RCAL Sample Ambient Storage 5/9/2005 10CH 4120.60 x 1.75 1.50 2 Chilled Storage 2/2512005 123G 4123.25 x 2.00 1.00 NfA Geology 31212005 11BV 4126.00 x " 3.00 1.50 2 ReAL Sample Ambient Storage 5/9/2005 12DV 4126.00 x " 3.00 1.50 2 Storage Sample Chilled Storage 2/25/2005 13AH 4126.45 x 2.00 1.50 2 ReAL Sample Ambient Storage 51912005 14CH 4126.55 x 2.00 1.50 2 Storage Sample Chilled Stora¡¡e 2/25/2005 124G 41,28.00 x 2.00 1.00 WA Geology Sample Geology 31212005 15BV 4132.00 x x 2.25 1.50 2 RCAL Sample Ambient Storage 5/9/2oo5 16DV 4132.00 x x 2.50 1.50 2 Storage Sample Chilled Storage 2/2512005 17AH 4132.35 x 2.00 1.50 2 RCAL Sample Ambient Storage 51912005 x 2.25 1.50 2 2/25/2005 19AH 4138.50 x 2.00 1.50 2 RCAL Sample Ambient Storage 5/9f2oo5 20CH 4138.60 x 2.00 1.50 2 Storage Sample Chilled Storage 2/25/2005 21AH 4139.50 x 2.00 1.50 2 RCAL Sample Ambient Storage 519/2005 22CH 4139.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/25/2005 4140.50 Bulk 200 g Bulk sample Humble Geochemical 312612005 23AH 4140.50 x 1.25 1.50 2 RCAL Sample Ambient Storage 519/2005 24CH 4140.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 25BV 4140.80 x x 3.00 1.50 2 RCAL Sample Ambient Storage 5/9/2005 28DV 4140.80 x x 3.00 1.50 2 Storage Sample Chilled Storage 2/25/2005 27AH 4141.20 x 1.00 1.50 2 RCAL Sample Ambient Storage 5/912005 28CH 4141.30 x 1.75 1.50 2 Storage Sample Chilled Storage 2/2512005 29AH 4142.80 x 2.25 1.50 2 RCAL Sample Ambient Storage 519/2005 30CH 4142.90 x 1.75 1.50 2 Storage Sample Chilled Storage 2/2512005 31AH 4143.50 x 1.75 1.50 2 Ambient 51912005 132A 4143.70 x 2.00 1.00 NlA Viscosity Sample Ambient Storage 5/9/2005 133B 4143,70 x 2.00 1.00 WA VisCOSity Sample Ambient Storage 519/2005 33BV 4143.80 x x 3.00 1.50 RCAL Sample Ambient Storage 5/912005 34DV 4143.80 x x 2/25/2005 35AH 4144.50 x 1.75 1.50 2 RCAL Sample Ambient Storage 51912005 38CH 4144.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 37AH 4145.20 x 2.50 1.50 2 ReAL Sample Ambient Storage 5/9/2005 38CH 4145.30 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 Page 1 Appendix II Nikaitchuq 4 Sample Inventory 11II -----------------l Kerr-McGee Oil 8. Gas Corporation S1art Date: 02-16-05 Nikaitchuq 4 File No . HOU 050167 NW Milne Point Alaska Core Sample log (Updated 05-09-05) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Good Fair Poor Failed Vert Len Oia Trims Analysis Stark lPSA SCAl Section XRO SEM Remarks location Date Sent Addilional Comments 1200 4146.46 x 2.00 1.00 N/A Geology Sample Geology 31212005 39AH 4146.50 2.00 1.50 2 RCAl Sample Ambient Storage 519/2005 40CH 4146.60 x 2.00 1.50 2 Storage Sample Chilled Storage 2125/2005 41BV 4146.80 x " 1.50 1.50 2 RCAl $ample Ambient Storage 519/2005 42DV 4146.80 x " 2.00 1.50 2 Storage Sam¡>le Chilled 212512005 4$AH x 1.50 2 44CH 4147.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2I25!2005 1200 4146.20 x 2.00 1.00 NlA Geology 3l2f2005 x. !ÍJ(A NlA 45AH 4146.70 x 2.00 1.50 2 ReAL Sample Ambient Storage 5/9/2005 46CH 4146.60 x 1.50 1.50 2 Storage Sample Chilled Storage 2/25/2005 47AH 4149.70 x 2.00 1.50 2 ReAL Semple Ambient Storage 5/9/2005 46CH 4149.80 x 1.75 1.50 2 Chilled 2125/2005 49BV 4150.20 x x 2.00 1,50 2 ReAL Sample Ambient Storage 519/2005 500V 4150.20 x 2.00 1.50 2 Storage Sample Chilled Storage 2/25/2005 51AH 4150.50 x 2.00 1.50 2 RCAlSampie Ambient Storage 519/2005 52CH 4150.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/25/2005 4151.60 Bulk 200 g Bulk sample Humble Geochemical 312612005 53AH 4151.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 519/2005 54CH 4151.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 55AH 4152.50 x 2.25 1.50 2 RCAl Sampie Ambient Storage 5/9/2005 56CH 4152.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2125/2005 57BV 4152.80 x X 3.00 1.50 RCAl Sample Ambient Storage 51912005 58DV 4152.80 x x 3.00 1.50 Storage Sample Chilled StoraQe 2/25/2005 127G 4153.115 x 59AH 4153.50 x 2.25 1.50 2 Ambient Storage 60CH 4153.60 x 2.25 1.50 2 Storage Sample Chilled Storage 61AH 4154.60 x 1.75 1.50 2 RCAl Sample Ambient Storage 519/2005 62CH 4154.60 x 1.75 1.50 2 2/25/2005 67AH 4156.50 x 2.00 1.50 68CH 4156.60 x 1.00 1.50 Storage Sample 134A 4157.40 x 2.00 1.00 N/A Viscosily Sample 519/2005 Page 2 Appendix II Nikailchuq 4 Sample Inventory Kerr-McGee Oil & Gas Corporation Start Date: 02-16-05 Nikaitchuq 4 File No ' HOU 050167 NW Milne Point Alaska Core Sample log (Updated 05-09-05) Smpl Depth Smpl Smpl End Routine Dean Thin No. (It) Good Fair Poor Failed Vert Len Dia Trims Analysis Stark lPSA SCAl Section XRD SEM Remarks location Date Sent Additional Comments 135B 4157.40 x 2.00 1.00 N/A Viscosity Sample Ambient Storage 519/2005 69AH 4157.50 x 1.25 1.50 2 RCAl Sample Ambient Storage 519/2005 70CH 4157.60 x 2.25 1.50 2 Storage Sample Bob Skopec 41112005 71AH 4158.50 x 1.75 1.50 2 ReAL 5/9/2005 73BV 4159.00 x x 3.00 1.50 2 RCAL Sample Ambient Storage 5/912005 74DV 4159.00 x x 3.00 1.50 2 Stora~ Sample Chilled Storage 2/2512005 128G 4159.5$ x 2.00 1.00 NIA Geology S<lmple Geology 3/2/2005 76CH 4159.60 x 2.25 1.50 2 Storage Sample Chilled Storage 212512005 4160.50 Bulk 200 9 Bulk sample Humble Geochemical 3/2612005 77AH 4160.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 519/2005 78CH 4160.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2125/2005 79AH 4161.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 5/912005 SOCH 4161.60 x 2.25 1.50 41112005 81BV 4162.30 x x 3.00 1.50 2 RCAl Sample Ambient Storage 519/2005 82DV 4162.30 x x 2.75 1.50 2 Storage Sample Chilled Storage 212512005 83AH 4162.70 x 2.25 1.50 2 RCAl Sample Ambient Storage 519/2005 84CH 4162.80 x 2.50 1.50 2 Chilled Storage 2/25/2005 85AH 4163.70 x 1.75 1.50 Ambient Stora e 5/912005 88CH 4164.60 x 2.25 1.50 Storage Sample Chilled Storage 2125/2005 89BV 4164.80 x )( 3.00 1.50 RCAl Sample 5/912005 90DV 4164.80 x )( 2.25 1.50 Storage Sample 91AH 4165.50 x 1.00 1.50 ReAL Sample Storage Sample g3AH 4166.60 )( 0.50 1.50 2 ReAL Sample Ambient Storage 5/912005 94CH 4166.80 x 1.00 1.50 2 Storage Sample Chilled Storage 2/2512005 95AH 4167.70 x 2.50 1.50 2 ReAL Sample Ambient Storage 519/2005 96CH 4167.80 x 1.50 1.50 2 Storage Sample 212512005 97BV 4166.30 )( )( 2.50 1.50 2 RCAL Sample Ambient Storage 519/2005 98DV 4166.30 x x 1.75 1.50 2 Storage Sample Chilled Storage 2125/2005 Page 3 Appendix II Nikaitchuq 4 Sample Inventory Kerr-McGee 011 & Gas Corporation Start Date: 02-16-05 Nikaitchuq 4 File No : HOU 050167 NW Milne Point Alaska Core Sample Log (Updated 05-09-05) SmpJ Depth Smpl Smpl End Routine Dean Thin No. (It) Good Fair Poor Failed Vert Len Dia Trims Analysis Stark lPSA SCAl Saction XRD SEM Remarks Location Date Sent Additionai Comments 99AH 4168.65 x 1.75 1.50 2 RCAlSampJe Ambient Storage 5/9/2005 100cH 4168.75 x 1.50 1.50 2 Storage Sampie Chilled Storage 2/2512005 101AH 4189.40 x 2.00 1.50 2 ReAL Sample Ambient Storage 5/9/2oo5 1000H 4169.50 x 2.00 1.50 2 Storage Sample Chilled Storage 2/25/2005 104CH 4170.30 x 2.25 1.50 2 Chilled 2/2512005 105ßV 4171.00 x J( 3.00 1.50 2 ReAL Sample Ambient Storage 51912005 I06DV 4171.00 x x 2.25 1.50 2 Storage Sample Chilled Storage 2/25/2005 107AH 4171.50 x 2.00 1.50 2 ReAL Sample Ambient Storage 5/912005 108CH 4171.60 x 2.t3 1.50 2 Storage Sample Chilled Storage 2/2512005 I09AH 4172.30 x 2.00 1.50 2 ReAL Sample Ambient Storage 5/912005 l10CH 4172.40 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 111AH 4173.30 x 1.75 1.50 2 RCAl Sample Ambient Storage 5/912005 112CH 4173.40 x 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 130G J( 2.00 1.00 N/A Geology Sample Geotogy $1212005 113BV 4174.00 x J( 1.25 1.50 2 RCAL Sample Ambient Storage 5/9/2005 114DV 4174.00 J( " 2.25 1.50 2 Storage Sample Chilled Storage 2/2512005 115AH 4174.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 5/9/2005 IIOCH 4174.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/25/2005 117AH 4175.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 5/912005 IlaCH 4175.60 x 2.25 1.50 2 Storage Sample Chilled Storage 2/25/2005 119AH 4176.50 x 2.25 1.50 2 RCAl Sample Ambient Storage 51912005 120CH 4176.60 x 2.25 1.60 2 Storaqe Sample Chilled Storage 2/2512005 x NiA 121AH 4177.35 x 2.00 1.50 2 5/912005 122CH 4177.60 x 2.00 1.50 2 Chilled 2/2512005 Page 4 Appendix II - Nikaitchuq 4 Sample Inventory I · Core LaIi RESERVOIR OPTIMIZATION Appendix III (Statistical Averages) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data,provided solely by the cJient. The conclusions, inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any weH, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division Houston, TX 77040 USA Fax: 713-328-2567 Tel: 713-328-2565 6316 Wind/ern Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska Core Interval for Statistical AveraQes Net Confining Stress Total Core Footage Footage Included in Statistics PERMEABILITY Arithmetic Mean Geometric Mean Harmonic Mean Flow Capacity POROSITY Arithmetic Mean Storage Capacity Grain Density Oil Saturation Water Saturation Page 1  ,[fRIIUUttUP¡\,Ir[S File No.: HOU-050167 Date: May 16, 2005 Analysts: RP, MM Core: Conventional STATISTICAL AVERAGES 4120.00 - 4178.50 1200 NCS 58.50 Feet 58.50 Feet 337 mD 102 mD 4.25 mD 19,727 mD - feet 31.25 % 1,828 Por.-feet 2.725 glee 46.7 % 45.5 % Appendix III Statistical Averages .. [on! Lab REsrRVOJR OPTIKIZATIDH Appendix IV (Pilot Study Laser Particle Size Analysis) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES DIVISION 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 Kerr McGee Oil & Gas Corporation & File No.: HOU-050167 Nikaítchuq 4 Date: February 23, 2005 NW Milne Point ~ Analyst(s): RP, SR Alaska ptnOUIIKStUICts PARTSIZsM ANALYSIS SMPL DEPTH Kair SAND % SILT % CLAY Vsh Cs MEAN NO (ft) (mD)* GRVL VCRS CRS MED FINE VFIN CRS MED FINE VFIN (%) (%) (m2/cc) (µ) LlTHOLOGY* 1 PS 4138.20 184 0.0 0.0 0.0 0.2 16.3 34.6 17.6 8.4 8.7 7.3 7.0 31 0.47 62 Sd vfg sshy vslty 2 PS 4144.20 126 0.0 0.0 0.0 0.0 10.4 36.1 20.4 7.4 10.0 8.5 7.2 33 0.49 54 Sd vfg sshy vslty 3PS 4150.20 486 0.0 0.0 0.0 0.0 18.1 41.4 15.9 5.2 7.9 6.1 5.5 25 0.39 72 Sd vfg vsshy vslty 4PS 4156.25 1080 0.0 0.0 0.0 0.1 27.5 55.7 4.8 2.1 4.3 2.4 3.1 12 0.23 102 Sd vf-fg cln 5 PS 4162.25 601 0.0 0.0 0.0 0.4 25.0 42.9 11.8 4.1 6.5 4.6 4.7 20 0.33 88 Sd vf-fg vsshy slty 6 PS 4168.25 381 0.0 0.0 0.0 0.0 12.5 40.1 22.2 6.0 7.6 6.3 5.4 25 0.40 64 Sd vfg sshy vslty Footnotes: . Kair & lithology determined using laser particle size distribution. Page 1 Pilot Study LPSA Appendix IV .. [ore LaIÏ RESERVOIR OPTIMIZATION Appendix V (Viscosity I API Gravity Data) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client. and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES DIVISION 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: March 18, 2005 Analysts: RP, MS Cores: Conventional SHEER STRESS VISCOSITY MEASUREMENTS Visible Light Photograph Ultraviolet Light Photograph Protocol: 1 - 1.0" diameter samples were drilled using liquid nitrogen as bit lubricant. Sample locations are listed below: 132A·4143.70 with flw::m\\scence - see photo above) 1338·4143.70 (Edge core with gold fluorescence see photo 2 - Each sample was disaggregated and extracted using methylene chloride in order to remove all hydrocarbon material. 3 - This sample-sOlvent mixture was then filtered to separate all granular & liquid material 4 - The solvent was then allowed to evaporate from the hydrocarbon material until weight stabilization (+1- 0.001 g) was reached. 5 - The sheer stress viscosity & refractive index was measured on remaining hydrocarbon material @ 50° C. Data: Sample 132A 1338 Depth 4143.70 4143.70 Viscosity (cp) 305.7 354.1 Conclusion: There does not appear to be a significant difference between the two (2) samples measured; therefore, it appears the oil properties are constant across the entire profile of the core at this particular depth interval. Page 1 Viscosity Comparison Appendix V Kerr-McGee Oil 8. Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: March 18, 2005 Analysts: RP, MS Cores: Conventional SHEER STRESS VISCOSITY MEASUREMENTS Visible Light Photograph Ultraviolet light Photograph Protocol: 1 - 1.0" diameter samples were drilled using liquid nitrogen as bit lubricant. Sample locations are listed below: 34A - 4157.40 (Center of core with gold fluorescence - see photo above) 1358 - 4157.40 (Edge of core with gold fluorescence - see above) :2 - Each sample was disaggregated and extracted using methylene chloride in order to remove all hydrocarbon material. 3 - This sample-solvent mixture was then filtered to separate all granular & liquid material 4 - The solvent was then allowed to evaporate from the hydrocarbon material until weight stabilization (+1- 0.001 g) was reached, 5 - The sheer stress viscosity & refractive index was measured on remaining hydrocarbon material @ 50° C. Data: Sample 134A 1358 Depth 4157.40 4157.40 Viscosity (cp) 327.5 323.0 Page 2 Conclusion: There does not appear to be a significant difference between the two (2) samples measured; therefore, it appears the oil properties are constant across the entire profile of the core at this particular depth interval. Viscosity Comparison Appendix V Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point North Slope, Alaska SMPL DEPTH NO (ft) R.I. 1 4140.50 1 .495 2 4151.50 1 .492 3 4160.50 1 .489 Footnotes: . 'UIID\U"5UV!Cts File No.: HOU-050167 Date: March 25, 2005 Analyst(s): TW API by Refractive Index °API 22 23 25 * API by refractive index of retorted oil samples Page 3 · [ore Lab RESERVOIR OPTIXIZATIOH Appendix VI Qualitative Spontaneous Imbibition Photography for Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska This report is based entirely Upon core samples. soils, solids, liquids, or gases, together with related observational data,provided solely by the client. The conclusions, inferences, deductions and opinîons rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Arr¡ reliance on the information contained herein concerning the profita[.ility or productivity on any well, sand, or drilling activìty is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division 6316 Windfern Houston, TX 77040 USA . Tel: 713-328-2565 Fax: 713-328-2567 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska File No : HOU-050167 Date: February 23, 2005 Qualitative Spontaneous Imbibition PhotoQraphv Analytical Protocol Three (3) sections of core (4140.00 - 4140.25,4151.00 - 4151.25 & 4164.00 - 4164.25) were selected from sand intervals for qualitative spontaneous imbibition photography. Two (2) fluids were used for this test: a brine solution (35000 ppm) & high gravity mineral oil (420 API). The results of this photographic analysis can be found in this report. One 3/4 section of core (4140.00 - 4140.25) was also selected for spontaneous imbibition photography. These images are included immediatley following the 1/4 section photos. Table of Contents Depth Range (ft) 4140.00 - 4140.25 4140.00 - 4140.25 4140.00 - 4140.25 4140.00 - 4140.25 4140.00 - 4140.25 4140.00 - 4140.25 4140.00 - 4140.25 (3/4 section) 4140.00 - 4140.25 (3/4 section) 4140.00 - 4140.25 (3/4 section) 4140.00 - 4140.25 (3/4 section) 4140.00 - 4140.25 (3/4 section) 4140.00 - 4140.25 (3/4 section) 4151.00 - 4151.25 4151.00-4151.25 4151.00-4151.25 4151.00-4151.25 4151.00-4151.25 4151.00 - 4151.25 4161.00 - 4161.25 4161.00-4161.25 4161.00 - 4161.25 4161.00 - 4161.25 4161.00 - 4161.25 4161.00-4161.25 Time Interval (minutes) o 5 10 20 30 60 o 5 10 20 30 60 o 5 10 20 30 60 o 5 10 20 30 60 Page(s) 1 1 2 2 3 3 4 4 5 5 6 6 7 7 8 8 9 9 10 10 11 11 12 12 Spontaneous Imbibition Report Appendix VI Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4140.00 - 4140.25 o minutes 4140.00 - 4140.25 5 minutes Page 1 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition PhotoQraphv 4140.00 - 4140.25 10 minutes 4140.00 - 4140.25 20 minutes Page 2 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition PhotoQraphv 4140.00 - 4140.25 30 minutes 4140.00 - 4140.25 60 minutes Page 3 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4140.00 - 4140.25 (3/4 section) () minutes 4140.00 - 4140.25 (3/4 section> 5 minutes Page 4 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4140.00 - 4140.25 (3/4 section) 10 minutes 4140.00 - 4140.25 (3/4 section> 20 minutes Page 5 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photo~raphv 4140.00 - 4140.25 (3/4 section) .30 minutes 4140.00 - 4140.25 (3/4 section) 60 minutes Page 6 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil &: Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4151.00 - 4151.25 o minutes 4151.00 - 4151.25 5 minutes Page 7 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23. 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4151.00 - 4151.25 10 minutes 4151.00 - 4151.25 20 minutes Page 8 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoqraphv 4151.00 - 4151.25 30 minutes 4151.00 - 4151.25 60 minutes Page 9 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photo~raphv 4164.00 - 4164.25 o minutes 4164.00 - 4164.25 5 minutes Page 10 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoqraphv 4164.00 - 4164.25 10 minutes 4164.00 - 4164.25 20 minutes Page 11 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 Kerr-McGee Oil & Gas Corp Nikaitchuq 04 NW Milne Point Alaska Qualitative Spontaneous Imbibition Photoaraphv 4164.00 - 4164.25 30 minutes 4164.00 - 4164.25 60 minutes Page 12 Qualitative Spontaneous Imbibition File No : HOU-050167 Date: February 23, 2005 · [ore Lab RESERVOIR OPTIMIZATION Appendix VII (Preliminary Routine Core Analysis Instructions) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 26, 2005 This report is based entirely upon core samples, soils, solids, liquids, or gases, together with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Any reliance on the information contained herein concerning the profitat>ility or productivity on any well. sand, or drilling activity is at the sole risk of the client, and Core Laboratories, LP, neither extends nor makes any warranty or rèpresentation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division . 6316 Windfern . Houston, TX 77040 USA . Tel: 713-328-2565 . Fax: 713-328-2567 CONFIDENTIAL 2/18/05 From: Bob Skopec, Consultant to Kerr McGee (PAl, Inc.) To: Chris Camden, Russ Murphy, Rob Brown, Howard White, et al. Subject: Analytical Program-Nikaitchuq #4-Full-Diameter Core Analyses Surface Core Gamma Rav (Done) All cores should be logged into a master spreadsheet upon their arrival at Core Lab, Houston. A multi-channel (spectral) core gamma ray scan should be performed as soon as the core arrives at Core Lab. The 2/3 slab should remain frozen to preserve in situ fluid saturations and prevent core deterioration during and after processing. Thin Section Fabrication/SEMIXRD (Der Howard White) Plug sample end trims to be designated by Howard White for XRD and SEM by Barry Wawak, Core Lab, Lafayette and thin section fabrication (only). Further petrographic evaluation will be determined by Dr. Howard White after his initial screening of the thin sections. Point counts (300 points minimum), modal analysis (grain size distribution), and diagenetic interpretation. Micro- paleontological objectives will be considered after thin section evaluation. Other techniques such as cathodoluminescence for source rock/provenance studies will be considered. Every attempt should be made to use a single end trim for all mineralogical and petrographic work. Staining will be determined after initial examination and integration of XRD data-carbonate and feldspar stains are likely. . err Scannlna (Done) Axial slices must be taken three per tube section for core orientation and plugging. Each individual core tube image must be marked for tube number, X-ray slice location, and datum for tube orientation, i.e., the uphole direction and a long axis reference point. Longitudinal images should be taken at two orientations. X-ray images are to be included in the final basic core analysis report. The core should be slabbed prior to sample plugging in a single cutting operation (1/3-2/3) using the crr data to maximize bed exposure-- the 1/3 (sedimentological slab) should be photographed. . Selection of 2/3 Slab Core Sections for Rock Mechanics To be conducted after log integration and/or basic core analyses. SamDlina and SamDle PreDaration Basic Core Analysis samples are to be 1.5" diameter cylinders with flat and parallel ends. Pilot Study Sample Group "PS" (a total of six samples to be distributed in sands only) XRD/SEM/EDX and Multiple Permeability Measurements on 1.5" Plugs (to be confirmed on Feb. 21) Single phase oil perm/miscible cleaning/multiple drying protocol (cool solvent/flow through cleaning with two single-phase liquid permeability measurements at net effective reservoir stress 1 if mineralogy suggests routine Dean Stark distillation will damage sands). Avoid high flow rates as migratable clays may be present in this reservoir rock. Standard porosity GV + PV and gas permeability at the estimated net effective reservoir stress of XXXX psig and XXX X psig). Sample Group "AH" (1.5" Inch Horizontal Plugs for Routine Core Analysis) Methods Subject to Pilot Study Results SW(talal) Dean Stark Protocol (horizontal plug orientation)-one sample precisely every foot in the sands. Toluene should be used to maximize water distillation/extraction efficiency-the water distillation/extraction process will be considered complete when no additional water is collected in the Dean Stark trap for 24 hours. All samples are to be measured at XXXX psig and XXXX psig net effective reservoir stress. Every fifth sample should be measured at net confining stresses of XXXX, XXXX, XXXX, and XXXX psig. Follow Dean Stark distillation/extraction with a Soxhlet reflux/salt extraction using chloroform/methanol azeotrope, followed by methanol. Dry samples in a vacuum oven at 10SoC to constant weight. Sample Group "BV" (One Inch Vertical Plugs Twinned to Horizontals for Routine Core Analysis) Methods Subject to Pilot Study Results SW(total) Dean Stark Protocol (vertical plug orientation)-QNE sample precisely every three feet directly adjacent to "AH" sample (ONLY IN RESERVOIR FACIES/SAMPLING DISCUSSIONS MAYBE REQUIRED) to be measured at XXXX psig and the net effective reservoir stress of XXXX psig (same protocol as in Sample Group "AHIJ). Sample Group "CH" 1.5" Diameter Twin Plug (Companion Sample to Group "A") and Group "CV" (Vertical) for Special Core Analyses Fresh State horizontal samples to be processed the same as Group "AH", cataloged, preserved in sealed containers, and refrigerated for future special core analyses (cut immediately after slabbing). Overview of Basic Core Analvsls Protocol 1. Porosity and Grain Denslty-direct pore volume porosity (helium PV + GV approach) at net effective reservoir stress (to be calculated) and XXXX psig. 2. Permeability (Steady-state)-single-phase gas permeability at net effective reservoir stress (to be calculated) and XXXX psig. Samples with sufficient permeability will be considered for single-phase liquid permeability measurements. Selected gas permeabilities are to be Klinkenberg corrected at a minimum of three mean reciprocal pressures in addition to values derived from Klinkenberg's "b" factor. 3. Qualitative Spontaneous Imbibition Test-with time lapse photographs to be performed as soon as operationally feasible. Fresh Core surfaces (two in main sand) using individual "drops" of simulated formation brine and fresh reservoir crude oil or suitable lab oil. Digital photos of the imbibition process should be taken at zero as well as five, ten, twenty, thirty, and sixty-minute intervals after the liquid contacts the core. 7. Core Photography-(Done) general requirements provided by Howard White, minimal requirements call for a box and strip format. 2 8. Probe Permeametry- 10 shots per foot in the potentially productive lithologies immediately after the sedimentological slabs have dried to the point where multi-phase flow effects are minimized. Potential Special Core Analvses (Sand Intervals) Samples to be selected based on geological facies, hydraulics, and CfT screening (three longitudinal scans (0, 45, and 90 degrees) and three axial scans with scan positions marked) from Group AH/CH samples. In the interest of time, the special core analysis program will be divided into two phases: Phase #1 Fast Track Program (four weeks or less-- after or concurrently with basic core analyses) 1. The "PS" single phase liquid permeability and rock characterization study (listed under the basic core analysis program). 2. Formation Factors 3. 100% Sw NMR analyses (if applicable) 4. Mercury Porosimetry 5. Quick turnaround completion and fluid compatibility testing 6. Non-wettability restored Krw/Kro Phase #2 (eight to 16 weeks, possibly longer for porous plate capillary pressure de-saturation) All other analyses. Maior Test Groups 1. Rock Mechanics (Core Lab or TerraTek)-- Uniaxial strain compressibility with concurrent permeability during drawdown (up to 10,000 psi drawdown from net effective reservoir stress· on horizontal sample) and determination of grain compressibility and Biot coefficient. Possible Unconfined Compressive Strength Triaxial Compressive Strength to define Mohr-Coulomb parameters as well as 2MHz acoustics for determination of elastic moduli (if appropriate). Emphasis will be placed on tests suitable for assessing horizontal wellbores, sand control, and stability issues (if warranted). 2. Electrical properties (Core Lab)-routine Archie electrical properties of "a", "m", and "n" at 1 KHz and 20KHz at reservoir net effective stress· using two- and four-electrode methods and concurrent air-brine porous plate de-saturation for capillary pressure. Excess conductivity studies will be considered using the Co-Cw multi-salinity approach if warranted by mineralogy. Rw options to be evaluated. 3. Nuclear Magnetic Resonance (If Warranted-- Core Lab or PTS Labs)-2MHz T2 distributions at 100% Sw and Swir, multiple inter-echo spacings (0.32, 0.6, and 1.2 ms) and SIN of 200/1 and 8/1 at net effective reservoir stress*. Includes multiple permeability and porosity determinations with possible fresh state measurements/liquid re-saturation. 4. Wettability Measurements-- using the modified USBM method on wettability restored samples in combination with complete drainage and imbibition centrifuge capillary pressure determinations. 3 5. Relative Permeability (Core Lab}-Testing at reservoir net effective stress*-- the appropriateness of methods will be determined after routine analyses, e.g., steady state vs. unsteady state. Methodology, fluids, potential for trapped gas measurements, Interfacial Tension (1FT), and imbibition vs. drainage cycles to be determined. End point as well as measured 1FT data may also be of interest. Likely requirements will include Krw/Kro (steady state) and Krg/Kro (unsteady state) on non-wettability restored and wettability restored samples. The same plugs will be used for all relative permeability tests regardless of preparation protocol. 6. Injection Well Studies and Produced Water Compatibility Analyses-To be considered/designed after evaluation of basic core analysis, Phase #1 special core analysis, and assessment of project economics. 7. Extended Range and/or at Stress Mercury Porosimetry-for pore throat radii distribution air-mercury pressure (destructive testing) to quickly build a family of capillary pressure curves. 8. Completion Engineering, Drilling Fluid Evaluation, and Formation Damage Testing (Core Lab/StimLab or Completions Services Vendor}-to be determined. Will be conducted concurrently with other special core analyses. Destructive tests will be conducted on end trims. Possible Tests: a. Capillary Suction Testing (CST) b. Regained permeability to evaluate fluid performance c. Acid solubility/stimulation oriented testing d. Other flow through tests, e.g., evaluation of fines migration/critical velocity if warranted. 6. Other special core analyses as warranted after review of basic core analysis results, e.g. shale top, inter-bedded, and bottom seal analyses such as extended range mercury porosimetry, TOC, and whole rock geochemistry. Detailed procedures and recommendations for special core analysis will be provided after the basic core analysis results are evaluated.' · A full tensor net effective stress calculation will be performed using the overburden gradient, frac gradient, an estimate of intermediate stress, and pore pressure. RAS, PAl, Inc. for Kerr McGee 4 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point File No.: Date: Depth : Sample: HOU-050167 Feb 23, 2005 4138.20 1 PS ;;.. ð\ Con! LaI:Í .ntJ'fOllltr.1JfllAnH EXTENDED RANGE PARTS/Z8M ANAL YS/S Laser Partslz 1m Distribution -1 ~IJ L~·-l-IJ~ j :@: .:êi:@J:.: :~:. .:.~:~: ': · .. . .--. -- II . -'-'-'~---'-------'-----'--.-"-'-- · . . . . · . . . . · . . . . · . .. . . · . . .. .. -~-------_..- ---~----------- --.------------.-- .. · . .. .. . · . .. . · .. .. . · .. .. . · . . .. · II .. . ~---:------- .:~-:-----:-- ~ , . . . ¡,- (~ · . I . , ....~...:...~...'~~ 25 100 k[j~J®~ 20--~ ~. . ~ ';:15 ---- u c Q ;:, tT I!! 10 II.. o c 3 c i <" 40 !. £, _-:---~____~n__ 60 · · , · · · · · · · · · . , · ----~--_..._~_. -- ----,-,---------------._-,- :- -;. 5- - 20 I( ~- Illlll..JL-_--_-..... I o 10 ,. - 0 0.001 0.1 Particle Diameter (mm) 0.Q1 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 60 100 120 140 170 200 230 270 325 400 500 PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 1.25 1.50 1.75 2.00 2.25 2.50 2.75 3.00 3.25 3.50 3.75 4.00 4.25 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0260 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 0.2500 0.2100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.2 1.3 3.0 5.0 7.0 8.5 9.2 8.9 7.9 6.4 4.9 3.6 2.7 2.2 2.0 2.0 2.1 2.2 2.2 2.2 2.1 2.0 1.9 1.8 1.6 1.5 1.3 1,1 1.0 0.8 0.6 0.5 0.2 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.2 1.5' 4.4 9.4 16.4 25.0 34.1 43.1 51.0 57.4 62.3 65.9 68.6 70.8 72.9 74.9 no 79.2 81.4 83.6 85.7 87.7 89.6 91.4 93.0 94.5 95.8 97.0 97.9 98.7 99.3 99.8 100.0 PERCENTILES: GRAVEL 0.0 inches phi mm 0.0068 0.0058 0.0050 0.0041 0.0025 0.0007 0.0004 0.0002 0.0001 0.1738 0.1471 0.1265 0.1049 0.0635 0.0188 0.0090 0.0053 0.0031 2.5242 2.7653 2.9826 3.2527 3.9767 5.7301 6.7938 7.5557 8.3271 5 10 16 25 50 75 84 90 95 VCRS SD 0.0 CAS SO 0.0 MED SAND 0.2 FINE SAND 0.4653 SURFACE AREA (m^2Icc) : 16.3 VFINE SAND 0.0588 $TO DEVIATION (mm) : 34.6 CRS SILT STD DEVIATION (Inches): 0.0023 17.6 40160 GRAVEL PACK : MED SILT 8.4 MOMENT- FOLK~ TRASK' FINE SILT 4,7278 3.9767 1.8237 0.9517 2.9189 4.5843 3.9767 1.6320 0.4889 0.9600 0.0619 0.0635 2.3598 0.4899 0.3036 8.7 MEAN MEDIAN SORTING SKEWNESS KURTOSIS VFINE SILT 7.3 . COMPUTED USING MILLIMETER VALUES .. COMPUTED USING PHI VALUES CLAY 7.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ¿ ~\ Con! LaIÌ Irn1l\'ll1J ummU1P File No.: Date: Depth : Sample: HOU-050167 Feb 23, 2005 4144.20 2 PS EXTENDED RANGE PARTSlzsM ANAL YSIS Laser Partsiz om Distribution 25 ~~lJ®~ "i "I' b ~.''100 o . . · . , õ~t ~ @~ 'yj · . . · . : ~: ..: ~ ~ Loj I(!R)- .1 ßØ- 20 ~-----, _J-____ __-L- .-L 0J& .. ---- .___..L__________ 80 : êJ»: : @) · · . · ~ · . · @. .... · · . '#. o ~. . ~ · ~ · . 0 o . . · · . c ;: 15 ___~___.______:.__~---.--~.---___:._-M--'--~---- --- · . 60 3 - .-..------------------= u 0 · · · · · c c: · · · · · · ã CD 0 · · · · · ::I · · · · · i' c- o · · · · I!! 10 · · · · · I' _._._--------~- 40 .-. IL ..-----------.-.--- · · · · - . ~ $ · · · · · · · · · ~ · · · · · · · · · · "- ' . 5 · · · · ~.. , · 20 · .---4----- ..---.-_~~- L( · · · · · . I- ~ · · o . · hL-JJl"_U--_uJ:!I11 . I · o . · · . ~ . . . ~ .'" · · 0 ........1' . . .. · - - 0 " - I 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 ·1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm Inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1482 0.0058 2.7546 VCRS SD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1268 0.0050 2.9789 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1107 0.0044 3.1753 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0926 0.0036 3.4326 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0580 0.0023 4.1080 CAS SO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0151 0.0006 6.0472 40 125 0.0165 0.4200 0.0 0.0 84 0.0080 0.0003 6.9639 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0051 0.0002 7.6256 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0031 0.0001 8.3389 SAND 60 2.00 0.0098 02500 0.0 0.0 0.0 70 225 0.0083 02100 0.1 0.1' 80 2.50 0.0070 0.1770 1.4 1.5 FINE 100 2.75 0.0058 0.1490 3.3 4.8 SURFACE AREA (mA2Icc): 0.4935 SAND 120 3.00 0.0049 0.1250 5.6 10.4 10.4 140 325 0.0041 0.1050 7.8 182 170 3.50 0.0035 0.0880 9.3 27.5 VFINE 200 3.75 0.0029 0.0740 9.8 37.3 STD DEVIATION (mm) : 0.0513 SAND 230 4.00 0.0024 0.0620 92 36.1 46.6 270 425 0.0021 0.0530 7.7 54.3 325 4.50 0.0017 0.0440 5.9 60.2 CRS 400 4.75 0.0015 0.0370 4.1 64.3 STD DEVIATION (Inches): 0.0020 SILT 500 5.00 0.0014 0.0310 2.7 20.4 67.0 525 0.0010 0.0260 1.9 68.9 5.50 0.0009 0.0220 1.7 70.5 GRAVEL PACK : 40160 MED 5.75 0.0007 0.0190 1.8 72.3 SILT 6.00 0.0006 0.0160 2.0 7.4 74.3 6.25 0.0005 0.0130 2.3 76.6 6.50 0.0004 0.0110 2.5 79.2 TRASK" FOLKH MOMEN'-" FINE 6.75 0.0003 0.0093 2.6 81.8 SILT 7.00 0.0003 0.0078 2.6 10.0 84.4 MEAN 0.0539 4.7491 4.8960 7.25 0.0002 0.0065 2.4 86.8 MEDIAN 0.0580 4.1080 4.1080 7.50 0.0002 0.0055 2.2 89.0 SORTING 2.4748 1.7933 1.7879 VFINE 7.75 0.0002 0.0046 2.0 91.0 SKEWNESS 0.4164 0.5115 0.9144 SILT 8.00 0.0001 0.0039 1,8 8.5 92.8 KURTOSIS 0.3182 0.8753 2.7651 8.25 0.0001 0.0033 1.6 94.4 8.50 0.0001 0.0028 1.4 95.8 8.75 0.0001 0.0023 1.2 97.0 9.00 0.??oo 0.0019 1.0 97.9 9.25 0.??oo 0.0016 0.8 98.7 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.6 99.3 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.5 99.8 CLAY 10.00 0.??oo 0.0010 0.2 7.2 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ ~ Core Lati USIIMIIJ mnmAn1II" File No.: Date: Depth : Sample: HOU-050167 Feb 23, 2005 4150.20 3 PS 25 EXTENDED RANGE PARTS/25M ANAL YS/S Laser Parts'z om Distribution íl _ .. . 100 ~~~J@~ 20 ------- ~ ';::15 u c GI ::J tr f10 IL GRAVEL VCRS SO CAS SO MEO SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY 5 : ~ ..~ '~ : · .. . . ___l__~,· _L_l ~ -,lX· - · ~. . . · 0". ,.~.~ .@. ..r..::2fJ-0ø :~: .:~:~ · .. .. . 1----- ¡---: --- -~--- - ~ 7(--- _u__ -~---_. ~ . ---.. ~-- w -----. . : ~ : ¡ a, I ; -11.. . ... [_ . . . . : . .. ... ...,¡.r ,-.:- - jÜ ~ -..a.JIJL . 0.1 0.D1 Particle Diameter (mm) .e.-...... ,. 0 0.001 · @~~y -~---------- 80 · · · · · _.~._---- o c --60 ~ i <" ID 40~ ~ 20 o 10 GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 ·1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1723 0.0068 2.5366 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1483 0.0058 2.7537 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1309 0.0052 2.9331 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1115 0.0044 3.1643 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0744 0.0029 3.7484 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0322 0.0013 4.9546 40 1.25 0.0165 0.4200 0.0 0.0 84 0.0114 0.0005 8.4486 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0066 0.0003 72416 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0036 0.0001 8.1086 60 2.00 0.0098 02500 0.0 0.0 0.0 70 2.25 0.0083 02100 0.9 0.9' 80 2.50 0.0070 0.1770 3.1 4.1 100 2.75 0.0058 0.1490 5.7 9.7 SURFACE AREA (m"2Icc): 0.3910 120 3.00 0.0049 0.1250 8.3 18.1 18.1 140 325 0.0041 0.1050 10.3 28.4 170 3.50 0.0035 0.0880 112 39.8 200 3.75 0.0029 0.0740 10.7 50.3 STD DEVIATION (mm) : 0.0597 230 4.00 0.0024 0.0620 9.1 41.4 59.4 270 425 0.0021 0.0530 8.9 66.3 325 4.50 0.0017 0.0440 4.6 71.0 400 4.75 0.0015 0.0370 2.8 73.7 STD DEVIATION (Inches): 0.0024 500 5.00 0.0014 0.0310 1.6 15.9 75.3 5.25 0.0010 0.0260 1.1 76.4 5.50 0.0009 0.0220 1.1 77.5 GRAVEL PACK : 20140 5.75 0.0007 0.0190 1.3 78.9 6.00 0.0006 0.0160 1.7 5.2 80.5 6.25 0.0005 0.0130 1.9 82.4 6.50 0.0004 0.0110 2.0 84.5 TRASK" FOLKH MOMENT** 6.75 0.0003 0.0093 2.0 86.5 7.00 0.0003 0.0078 1.9 7.9 88.4 MEAN 0.0719 4.3767 4.4828 7.25 0.0002 0.0065 1.8 90.1 MEDIAN 0.0744 3.7484 3.7484 7.50 0.0002 0.0055 1.6 91.7 SORTING 1.8598 1.7231 1.7295 7.75 0.0002 0.0046 1.4 93.2 SKEWNESS 0.6497 0.5506 1.2338 8.00 0.0001 0.0039 1.3 6.1 94.5 KURTOSIS 0.2799 1.2755 3.5847 8.25 0.0001 0.0033 1.2 95.6 8.50 0.0001 0.0028 1.0 96.7 8.75 0.0001 0.0023 0.9 97.6 9.00 0.??oo 0.0019 0.8 98.3 9.25 0.??oo 0.0016 0.6 99.0 . COMPUTED USING MILLIMETER VAlUES 9.50 0.??oo 0.0014 0.5 99.4 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.4 99.8 10.00 0.??oo 0.0010 0.2 5.5 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point 25 ~~~J®m 20 -~~----- ~ ';:15 -----------.-- () C GI ::I 0- !10 II. 5 ~ ~ Core Lab IDt_1J umnv.nu EXTENDED RANGE PARTSIZSM ANAL YSIS o ........ 10 GRAVEL MESH 5 6 7 8 10 12 14 16 18 20 25 30 35 40 45 50 60 70 80 100 120 140 170 200 230 270 325 400 500 VCRS so CAS so MEO SAND FINE SAND VFINE SAND CAS SILT MED SILT FINE SILT VFINE SILT CLAY @1» ~ Laser Partsiz 8m Distribution . J ~-_.... l ~~._~"-Dt -I @D'!!J~ .~ --;---- ---- ---------- 3'J - : ---- f " · · :~ -~~ · :é9J :~ · · · · · · · · · · · · · ---6-.- . · · · · · · · · · ..¡~ ~ @R) @) [l!1 ~ ~ .. .. ... . ..- · · -----.-- - · · · · · . ._----_.__..__._-_._----------~- · · · : ~ . · ® . -..-----..--------- · · · · · · '---.--.-'.'---~'--- · · · · · · --"--~-'------.---- · · · · · · · · · · · ..... - ~---------_. ~III 111' ... . -- I 0.1 Particle Diameter (mm) 0.01 GRAIN SIZE DISTRIBUTION PHI -2.00 -1.75 -1.50 -1.25 -1.00 -0.75 -0.50 -0.25 0.00 0.25 0.50 0.75 1.00 125 1.50 1.75 2.00 225 2.50 2.75 3.00 325 3.50 3.75 4.00 425 4.50 4.75 5.00 5.25 5.50 5.75 6.00 6.25 6.50 6.75 7.00 7.25 7.50 7.75 8.00 8.25 8.50 8.75 9.00 9.25 9.50 9.75 10.00 INCH 0.1575 0.1323 0.1114 0.0937 0.0787 0.0661 0.0555 0.0469 0.0394 0.0335 0.0280 0.0236 0.0197 0.0165 0.0138 0.0117 0.0098 0.0083 0.0070 0.0058 0.0049 0.0041 0.0035 0.0029 0.0024 0.0021 0.0017 0.0015 0.0014 0.0010 0.0009 0.0007 0.0006 0.0005 0.0004 0.0003 0.0003 0.0002 0.0002 0.0002 0.0001 0.0001 0.0001 0.0001 0.??oo 0.??oo 0.??oo 0.??oo 0.??oo MM 4.??oo 3.3600 2.8300 2.3800 2.??oo 1.6800 1.4100 1.1900 1.??oo 0.8500 0.7100 0.6000 0.5000 0.4200 0.3500 0.2970 02500 02100 0.1770 0.1490 0.1250 0.1050 0.0880 0.0740 0.0620 0.0530 0.0440 0.0370 0.0310 0.0260 0.0220 0.0190 0.0160 0.0130 0.0110 0.0093 0.0078 0.0065 0.0055 0.0046 0.0039 0.0033 0.0028 0.0023 0.0019 0.0016 0.0014 0.0012 0.0010 SEP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.0 3.9 8.5 14.1 17.4 17.1 13.4 7.8 3.5 0.9 0.3 0.2 02 0.3 0.6 1.0 1.2 1.2 1.0 0.9 0.7 0.6 0.6 0.5 0.5 0.5 0.5 0.5 0.4 0.3 0.2 0.1 SEP CUM 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 1.1' 5.0 13.5 27.6 45.1 62.1 75.5 83.3 86.8 87.7 88.0 88.1 88.3 88.6 89.2 90.2 91.3 92.5 93.6 94.4 95.2 95.8 96.3 96.9 97.4 97.9 98.4 98.9 99.3 99.6 99.9 100.0 0.0 0.0 0.0 0.1 27.5 55.7 4.8 2.1 4.3 2.4 3.1 FileNo. : Date: Depth : Sample: SORTING PARAMETERS PERCENTILES: mm 5 10 16 25 50 75 84 90 95 0.1769 0.1605 0.1448 0.1295 0.1001 0.0745 0.0601 0.0165 0.0068 SURFACE AREA (m^2Ice): STD DEVIATION (mm) : STD DEVIATION (Inches) : GRAVEL PACK : TRASK' MEAN MEDIAN SORTING SKEWNESS KURTOSIS 0.1020 0.1001 1.3179 0.9637 0.1908 Inches 0.0070 0.0063 0.0057 0.0051 0.0039 0.0029 0.0024 0.0007 0.0003 FOLK- 3.3882 3.3208 1.0287 0.4049 2.4179 HOU-050167 Feb 23, 2005 4156.25 4PS 100 80 o c 603 c iii .. < CD ------ 40 ~ ~ 20 o 0.001 phi 2.4993 2.6395 2.7882 2.9493 3.3208 3.7457 4.0554 5.9190 7.1982 0.2343 0.0423 0.0017 20140 MOMENT'" 3.8337 3.3208 1.4028 2.2894 7.9704 . COMPUTED USING MILLIMETER VAlUES .. COMPUTED USING PHI VAlUES Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~~ ~, ÚJn! Lab _mtnfllmlØtAftH File No.: Date: Depth : Sample: HOU-050167 Feb 23, 2005 4162.25 5 PS kD'1J~~ 20 ----------~-. 25 -¡: ;: 15 (,) c CP ::¡ cr 2! 10 . IL GRAVEL VCRS so CRS so MED SAND FINE SAND VFINE SAND CRS SILT MED SILT FINE SILT VFINE SILT CLAY EXTENDED RANGE PARTS/ZSM ANAL YS/S Laser Partsiz om Distribution ~~~. . .~..---_. . 100 o 10 , . .. . .. . : ~ : ~ ~: ~@jV: ~ @}J): : êJ): : ~ : :~: :c:s @II: .~. .1"3 ~. · .. . ._M___._.__-----..-.------____________.. . · ... . · ... . · ... . · .. ;¡" - - II! . .. , .. Ii"- /ft.. ~. ------ -~ ., . I · . t )!. : :: -~ I , ". ov-t ¡ ¡ -r J ~ i -- .. ........(..."...4 'U ~ o 0.001 80 o c 603 c i ~. 40 .-. £ 5--- 20 I J . . . Ii III -- r II - -...1:1- 0.01 0.1 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -1.25 0.0937 2.3800 0.0 0.0 PERCENTILES: 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1934 0.0076 2.3701 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1675 0.0066 2.5775 20 0.25 0.0335 0.8500 0.0 0.0 16 0.1469 0.0058 2.7669 25 0.50 0.0280 0.7100 0.0 0.0 25 0.1259 0.0050 2.9894 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0870 0.0034 3.5234 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0507 0.0020 4.3031 40 125 0.0165 0.4200 0.0 0.0 84 0.0164 0.0006 5.9308 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0085 0.0003 6.8813 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0041 0.0002 7.9286 60 2.00 0.0098 02500 0.4 0.4 0.4 70 2.25 0.0083 02100 22 2.6' 80 2.50 0.0070 0.1770 4.8 7.4 100 2.75 0.0058 0.1490 7.7 15.1 SURFACE AREA (m^2Icc): 0.3324 120 3.00 0.0049 0.1250 10.3 25.0 25.4 140 325 0.0041 0.1050 11.8 372 170 3.50 0.0035 0.0880 12.0 492 200 3.75 0.0029 0.0740 10.7 59.9 STD DEVIATION (mm) : 0.0653 230 4.00 0.0024 0.0620 8.4 42.9 68.3 270 425 0.0021 0.0530 5.8 74.1 325 4.50 0.0017 0.0440 3.4 77.5 400 4.75 0.0015 0.0370 1.7 79.3 STD DEVIATION (Inches): 0.0026 500 5.00 0.0014 0.0310 0.8 11.8 80.1 5.25 0.0010 0.0260 0.6 80.7 5.50 0.0009 0.0220 0.8 81.6 GRAVEL PACK : 20140 5.75 0.0007 0.0190 1.2 82.7 6.00 0.0006 0.0160 1.5 4.1 84.2 6.25 0.0005 0.0130 1.7 85.9 6.50 0.0004 0.0110 1.7 87.6 TRASK' FOLK" MOMENT'* 6.75 0.0003 0.0093 1.6 89.2 7.00 0.0003 0.0078 1.5 6.5 90.7 MEAN 0.0883 4.0737 4.1973 7.25 0.0002 0.0065 1.3 92.0 MEDIAN 0.0870 3.5234 3.5234 7.50 0.0002 0.0055 1.2 93.2 SORTING 1.5767 1.6332 1.6784 7.75 0.0002 0.0046 1.1 94.3 SKEWNESS 0.8434 0.5534 1.4802 8.00 0.0001 0.0039 1.0 4.6 95.3 KURTOSIS 0.2366 1.7340 4.4089 8.25 0.0001 0.0033 0.9 96.2 8.50 0.0001 0.0028 0.9 97.1 8.75 0.0001 0.0023 0.8 97.8 9.00 0.??oo 0.0019 0.7 98.5 9.25 0.??oo 0.0016 0.6 99,1 . COMPUTED USING MilLIMETER VAlUES 9.50 0.??oo 0.0014 0.4 99.5 .. COMPUTED USING PHI VAlUES 9.75 0.??oo 0.0012 0.3 99.8 10.00 0.??oo 0.0010 0.2 4.7 100.0 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point ~ â ÜJre LaIÍ un_ )!~ FileNo. : Date: Depth : Sample: HOU-050167 Feb 23, 2005 4168.25 6 PS EXTENDED RANGE PARTS/Z5M ANAL YS/S Laser Partslz om Distribution 25 ~~~J~s i 100 c¡g " "i9J ~ @ " <ï@ -ß@ 20 -~-- "--- 80 §) · · (9J @J ~ · ~ · ~ (l11 0 " c ';:15 · --- 60 ê " u · · · c · · · ã CD · · - ./: · ::I · · <" CT · · CD 2!10 · · 40 .-. · - .... · IL · " , · · £ · ~ · · · JI · · · - · 5 · · · 20 · ~_. ~ - · · · · · · 111.-.I.lUn" _'.I~." · · 0 ........1 . . . ... . 0 10 0.1 0.01 0.001 Particle Diameter (mm) GRAIN SIZE DISTRIBUTION SORTING PARAMETERS MESH PHI INCH MM SEP SEP CUM 5 -2.00 0.1575 4.??oo 0.0 0.0 6 -1.75 0.1323 3.3600 0.0 0.0 7 -1.50 0.1114 2.8300 0.0 0.0 8 -125 0.0937 2.3800 0.0 0.0 PERCENTILES: GRAVEL 10 -1.00 0.0787 2.??oo 0.0 0.0 0.0 12 -0.75 0.0661 1.6800 0.0 0.0 mm inches phi 14 -0.50 0.0555 1.4100 0.0 0.0 16 -0.25 0.0469 1.1900 0.0 0.0 5 0.1564 0.0062 2.6765 VCRS SD 18 0.00 0.0394 1.??oo 0.0 0.0 0.0 10 0.1342 0.0053 2.8976 20 025 0.0335 0.8500 0.0 0.0 16 0.1169 0.0046 3.0967 25 0.50 0.0280 0.7100 0.0 0.0 25 0.0988 0.0039 3.3399 30 0.75 0.0236 0.6000 0.0 0.0 50 0.0650 0.0026 3.9432 CASSO 35 1.00 0.0197 0.5000 0.0 0.0 0.0 75 0.0302 0.0012 5.0474 40 125 0.0165 0.4200 0.0 0.0 84 0.0114 0.0004 6.4549 45 1.50 0.0138 0.3500 0.0 0.0 90 0.0066 0.0003 7.2470 MED 50 1.75 0.0117 0.2970 0.0 0.0 95 0.0037 0.0001 8.0901 SAND 60 2.00 0.0098 0.2500 0.0 0.0 0.0 70 225 0.0083 0.2100 0.3 0.3' 80 2.50 0.0070 0.1770 1.8 2.1 FINE 100 2.75 0.0058 0.1490 3.9 6.0 SURFACE AREA (m^2Içc:): 0.3976 SAND 120 3.00 0.0049 0.1250 6.4 12.5 12.5 140 3.25 0.0041 0.1050 B.7 21.2 170 3.50 0.0035 0.0880 10.3 31.5 VFINE 200 3.75 0.0029 0.0740 10.8 42.4 STD DEVIATION (rnm): 0.0527 SAND 230 4.00 0.0024 0.0620 10.2 40.1 52.5 270 425 0.0021 0.0530 8.5 61.1 325 4.50 0.0017 0.0440 6.4 67.5 CAS 400 4.75 0.0015 0.0370 4.4 71.9 STD DEVIATION (Inches): 0.0021 SILT 500 5.00 0.0014 0.0310 2.8 22.2 74.7 5.25 0.0010 0.0260 I.B 76.5 5.50 0.0009 0.0220 1.4 77.9 GRAVEL PACK : 40160 MED 5.75 0.0007 0.0190 1.3 79.2 SILT 6.00 0.0006 0.0160 1.5 6.0 80.7 6.25 0.0005 0.0130 1.7 82.5 6.50 0.0004 0.0110 1.9 84.4 TRASK' FOLKH MOMENTH FINE 6.75 0.0003 0.0093 2.0 86.4 SILT 7.00 0.0003 0.0078 1.9 7.6 88.3 MEAN 0.0645 4.4982 4.6127 725 0.0002 0.0065 1.8 90.1 MEDIAN 0.0650 3.9432 3.9432 7.50 0.0002 0.0055 1.7 91.B SORTING 1.8072 1.6598 1.6628 VFINE 7.75 0.0002 0.0046 1.5 93.2 SKEWNESS 0.7066 0.5139 1.2212 SILT 8.00 0.0001 0.0039 1.3 6.3 94.6 KURTOSIS 0.2885 1.2994 3.6565 8.25 0.0001 0.0033 1.2 95.7 8.50 0.0001 0.0028 1.0 96.7 8.75 0.0001 0.0023 0.9 97.6 9.00 0.??oo 0.0019 0.8 98.4 9.25 0.??oo 0.0016 0.6 99.0 . COMPUTED USING MILLIMETER VALUES 9.50 0.??oo 0.0014 0.5 99.5 .. COMPUTED USING PHI VALUES 9.75 0.??oo 0.0012 0.4 99.8 CLAY 10.00 0.??oo 0.0010 0.2 5.4 100.0 · [ore Lab RESERVOIR OPTIMIZATION Appendix VIII (Final Report Distribution) for Kerr-McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska File No.: HOU-050167 Date: May 16, 2005 This report is based entirely upon core samples, soits, solids, liquids, or gases, together with related observational data,provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratories, LP. Arry reliance on the information contained herein concerning the profitability or productivity on any well. sand, or drilling activity is at the sole risk of the client, and Core Laooratories, LP, neither extends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Petroleum Services Division . 6316 Windfern . Houston, TX 77040 USA . Tel: 713-328-2565 . Fax: 713-328-2567 Kerr McGee Oil & Gas Corporation Nikaitchuq 4 NW Milne Point Alaska ~ File No.: HOU-050167 Date: May 16, 2005 Drilling Fluid: Oil Based Mud Analyst(s): RP PtTF.OUUK S-tRYIW, Distribution of Final Reports Kerr-McGee Oil & Gas 16666 Northchase Houston, TX 77060 Attn: Rebecca Isbell Petrophysical Applications Inti, Inc. PO Box 130304 The Woodlands, TX 77393-0304 Attn: Dr. Robert Skopec Armstrong Alaska, Inc. 700 17th Street, Suite 1400 Denver Colorado 80202 Attn: Jesse Sommer ConocoPhillips Alaska, Inc. ATO 1470 PO Box 100360 Attn: Justine Boccanera Alaska Oil & Gas Conservative Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian Tim Ryherd, Geologist Dept. of Natural Resources - Division of Oil & Gas State of Alaska 550 W 7th Avenue, Suite 800 Anchorage, AK 99501-3510 Page 1 4 copies / 1 CD-ROM 1 copy / 1 CD-ROM 4 copies / 1 CD-ROM 1 copy / 1 CD-ROM 1 copy / 1 CD-ROM 1 copy / 1 CD-ROM Final Report Distribution Appendix VIII HALLIBURTON Sperry-Sun Kerr McGee Oil & Gas Corporation END OF WELL HEPORT Nikaitchuq 4 & 4PB1 o /) - / .. ~Dc/> z Cp c) I I I I I I I I I I I I I .1 I I I I I spe~~v-sun C R I L..L..I N G 5 e R V I c: E 5 Kerr McGee Oil & Gas Corporation END OF WELL REPORT Nikaitchuq 4 & 4PB1 I I I I TABLE OF CONTENTS I I 1. General Information I 2. Daily Summary 3. Daily Operations (I.A.D.C.) I 4. Morning Reports I 5. Bit Record 6. Mud Reports I 7. Show Reports I 8. Survey Report I 9. Days vs Depth 10. Gas & Lithology ASCII data I 11. Formation Evaluation Logs I I I I I I sperl""'y-sun t:lRIL.L.II'II~ SeFHJlc:es 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 Oil and Gas Corporation Nordic Calisa Rig 3 Nikaitchuq 4 & 4PB1 N. Milne pt. North Slope Alaska United States 50-629-23241-00 AK-AM-0003523133 31 Jan 2005 23 Feb 2005 True 24.43° 80.892° 57594 NT 31 Jan 2005 North 70° 33' 13.99" East 149° 46' 29.28 " Wayne Hermanson Mark Lindloff Tom Mansfield pave Sterns Tavia Bicklein 101/110 Original hole was vertical and drilled to 4310' through the Scharder Bluff objective. It was designated Nikaitchuq 4PB1. The hole was plugged back and kicked-off at 2863' and built angle to laterally drill the Schrader Bluff to a final measured depth of 7577'; 4185' TVD. sperl''Y-5un ¡;;J!"i.IL.L.1 N œ :i=FnJIC=S I I I I I I I I I I I I I I I I I I I Nikaitchuq 4 & PBl - Daily Summary 01 Feb 2005 Pick up bottom hole assembly. Stand back in derrick. Tag up at 40' and ream down to 80'. Condition mud and drill to 215'. Circulate bottoms up. Pull out of hole to pick up MWDIL WD tools. 02 Feb 2005 Drill 12 y,¡" hole from 620' to 2460'. Note: lost ~ hour on weather advisory . 03 Feb 2005 Drill 12 y,¡" hole from 2460' to 2464'. Circulate bottoms up and pump HiVis sweep. Wiper trip to HWDP. Circulate and clean hole. Run carbide lag - approximately 50% washout. Pull pipe and prepare to fun 9 5/8" casing. 04 Feb 2005 Run 9 5/8" casing. Condition mud for cementing. Cement casing lost returns while displacing cement. Reduced pump rate, but did not bump the plug. Run in to close FO tool. Close FO tool and pullout of hole. 05 Feb 2005 Lay down Sperry Sun equipment. Nipple down and nipple up BOP stack. Test BOP's. 06 Feb 2005 Download MWDIL WD. Run in hole with BHA. Shallow test MWDIL WD tools. Trip in, picking up 4" drill pipe. Circulate bottoms up & clean up hole. Rig up to test casing to 2500 psi. Test casing to 2500 psi. Rig down & blow down equipment. Run in hope to drill cement. Wash down to 2464'. Drill 8 W' hole from 2464 to 2484'. Circulate and condition mud for leak-off test. Stand back 1 stand for leak-off test. Perform leak-off test. Pumped 1.3 bbls to leak-off at 655 psi. Continued to pump to establish injection rate of 630 psi @ 0.1 bbls/min - total pumped 3.7 bbls. Shut in for 33 min. Stabilized shut in pressure = 310 psi. EMW = 14.4 ppg @ 2484'. Drill 8 W' hole from 2484 to 3189'Drill12 y,¡" hole. 07 Feb 2005 Drill 8 ~" hole from 3189 to 4120'. Circulate bottoms up twice. Wiper trip to shoe at 2458'. Trip back to bottom. Condition mud and spot a HiVis-pill on bottom. Trip for core barrel. Pick up coring BHA. 08 Feb 2005 Make up coring BHA and run in to 3700'. Ream to bottom at 4120'. Start coring at 4120' to 4180'. Pull core slowly with intermittent stops to let pressure stabilize. I I I I I I I I I I I I I I I I I I I 09 Feb 2005 Finish pulling out of hole with core barrel. Lay down core barrel and pack in dry ice. Pick up new BRA, mud motor/MWDIL WD tools and MIRL. Shallow test tools and run in hole. Pickup 21 singles to 1450' and trip into 4118'. Ream from 4120 to 4180'. Drill 8 Yz" hole from 4180 to 4310'. Circulate and condition mud - circulate two bottoms up. Pull out of hole. 10 Feb 2005 Rack back RWDP, monels, plug in & de-activate MIRL. Break down Sperry BRA. Download L WD. Flush mud motor & break-off bit. Start rigging up to wireline. Install Radio Active sources. Log with Schlumberger "Platform Express", RAIS log, FMI/DSI and CBL. Rig down wireline. Trip in with mule shoe to 4306'. 11 Feb 2005 Trip in hole. Wash down to 4306': Rotate and reciprocate pipe while circulating and conditioning mud. Continue to circulate with cement lines. Pump 1 st stage of cement plug. Rig down circulating lines. Pull 8 stands out of hole at 5 min/std. Pump 2nd stage of cement plug, chase with 23 bbls mud. Pull out 10 stands. Pump wiper ball. Rig down circulating lines. Finish pulling out of hole. NOTE: End of Nikaitchuq 4PBl and beginning of Nikaitchuq 4. Rig up to test BOP's. Test BOP's. Pull test plug. Install wear ring. Pick up BRA. Upload MWDIL WD tools. Shallow test MWD. Trip in to 2663' where cement was tagged. 12 Feb 2005 Circulate bottoms up. Directional drill 8 Yz" hole from kick-off at 2863' to 4423'. Build angle to approximately 70° at an azimuth of 311 0. 13 Feb 2005 Directional drill 8 Yz" hole from 4423' to 4861' (4155' TVD), building angle to a final 78° measured 60' behind the bit. Circulate and condition mud. Pump sweep and three bottoms up. Wiper trip to shoe. Run in hole to bottom. Circulate three bottoms up. Pull out of hole and measure pipe on way out. Download L WD tools. Change out rams to 7" for running casing. 14 Feb 2005 Run 7" casing. Change out bails. Change out float shoe joint. Trip in with 7" casing to shoe and break circulation. Stage pumps up to 5 bbls/min. Circulate pipe volume. Continue to run 7" casing to bottom. Space out and land casing. Circulate and condition mud while reciprocating casing. Cement 7" casing with returns to Vac truck. Blow down and rig down cementing equipment. Set pack-off and test. Change out bails. I I I I I I I I I I I I I I I I I I I 15 Feb 2005 Change out lower pipe rams to 4" and test to 2000 psi. Pull test plug and set wear ring. Lay down casing running equipment. Pick up HWDP & stand back in derrick. Organize pipe shed for picking up BHA. Lay down casing tools. Make up bit and Sperry Sun BHA. Upload MWDIL WD. Shallow test MWDIL WD tools. Pick up Nuke tools. Trip in with flex collars HWDP and 2 DP. Slip & cut drilling line and perform a full service on top drive 16 Feb 2005 Drill out float & shoe equipment plus 20' of new hole to 4881'. Circulate bottoms up and condition mud for Leak-off Test. Perform Leak-off Test. Directional drill 6" hole from 4881' to 5950' - build angle to horizontal and GeoSteer in the Schrader Bluff. 17 Feb 2005 Directional drill 6" hole and continue to GeoSteer in the Schrader Bluff. steer 18 Feb 2005 Directional drill 6" hole from 7197' to 7577', (TVD 4184'). Reciprocate pipe and circulate three bottoms up. Pump sweep and pump out to shoe. Run in hole circulate 2 bottoms up. Pump sweep and spot pill in open hole. Pull out of hole. 19 Feb 2005 Finish pulling out of hole, lay down BHA download L WD and remove nuclear sources. Test BOP's. Run in hole with 3 Yz" slotted liner. 20 Feb 2005 Continue to Run in hole with 3 Yz" slotted liner. Displace well to 9.3 ppg brine. POOH with DP. Begin RIH with ESP. 21 Feb 2005 Run in hole with ESP testing string. Encounter problems with cable. Had to pull testing tubing. 22 Feb 2005 Finish pulling test string. Repair problem with ESP cable. Re-run 27/8" tubing and ESP motor. 23 Feb 2005 Land and test tubing string. Nipple down BOP's. Nipple up test tree and test to 5000 psi. Completion ofNikaitchuq #4. I I DAILY ACTIVITY (I.A.D.C.) Kerr McGee Nikaitchuq 4 & 4PBl 3. DAILY OPERATIONS (I.A.D.C.) I I, Time (hrs) I 01 Feb 05 0000-0630 0630-0900 0900-0930 0930-1030 1030-1100 1100-1200 1200-1300 1300-1315 1315-1330 1330-1345 1345-1800 1800-2400 I I 02 Feb 05 0000-0100 0100-0130 0130-0200 0200-0230 0230-0830 0830-0930 0930-1200 1200-2400 I I 03 Feb 05 0000-0015 0015-0200 0200-0330 0330-0400 0400-0530 0530-0830 0830-1500 1500-1600 1600-1730 1730-1830 1830-2045 2045-2400 I I I 04 Feb 05 0000-0230 0230-0300 0300-0500 0500-1130 I I 1130-1200 1245-1330 1330-1700 I I 1700-1800 1800-2030 2030-2200 2200-2400 I 05 Feb 05 2330-2~00 0000-0030 0030-0700 0700-1730 1730-2230 2230-2330 2330-2400 I I Elapsed Code Time 6.50 6 2.50 6 0.50 2 1.00 5 0.50 2 1.00 5 1.00 2 0.25 5 0.25 7 0.25 6 4.25 21 6.00 2 1.00 2 0.50 5 0.50 6 0.50 6 6.00 2 1.00 2 2.50 2 12.00 2 0.25 2 1.75 5 1.50 6 0.50 1 1.50 6 3.00 5 3.00 6 1.00 12 1.50 21 0.50 12 2.25 12 3.25 12 2.50 12 0.50 5 2.00 12 6.50 5 0.75 12 0.75 12 3.30 12 1.00 12 2.50 12 1.50 12 2.00 12 0.50 14 0.50 21 6.50 14 5.50 14 5.00 15 1.00 21 0.50 14 Operations Breakdown Pick up HWDP, jars & De's - stand back in derrick. PJSM prior to making up BHA. Tag up at 40', break circulation & ream down to 80'. Condition mud. Drill 12 y." hole from 40' to 135'. Circulate & condition mud. Drill 12 y." hole from135' to 215'. Circulate bottoms up. Blow down Top Drive. POOH to rig up MWD tools. Rig up MWD/LWD tools & upload tools. Drill 12 y." hole from 215' to 620'. Drill 12 y." hole from 620' to 635'. Circulate .bottoms up - clean hole. POOH to wait on fluids - weather advisory. RIH to drill. Drill 12 Y." hole from635' to 1015'. Drill 12 y." hole from 1015' to 1035' - Slide. Drill 12 y." hole from 1035' to 1295'. Drill 12 y." hole from 1295' to 2460'. Drill 12 y." hole from 2460' to 2464' - TD 12 y." section. Circulate & clean up hole. Pump HiVis Sweep. P 0 0 H to H W D P . ... . Bring in Franks Fill-up Tool, cement head & box of centralizers. RIH Circulate bottoms up. Pump HiVis sweep. Pump carbide pill. Lay down BHA & MWD/LWD tools. Download LWD tools. Rig up to run 9 5/8" casing. Rig up & make up float collar & float shoe. Dry run for setting landing joint. Make up sliding sleeve. PJSM prior to running 9 5/8' casing. RIH with 9 5/8" casing. Break circulation at 1600'. RIH with 9 5/8" casing. Tag up on hanger. Begin to circulate & condition mud for cement. Rig down Franks tool. Blow down top drive. Rig up cement head. PJSM prior to cementing 9 5/8" casing Pressure test cement lines. Cement 9 5/8" casing with 315 bbls Permafrost cement at 10.7 ppg, plus 40 bbls premium GW, 25 bbls CaCI2 at 15.8 ppg. Loss of returns at 139 bbls pumped. Reduced rate to 3 bbls/min. Did not bump plug. Rig down cement head and lay down test joint. Change out bails & make up shifting tool. Run in hole to open FO tool. Make up Franks tool & run in hole. Pump 15.0 bbls 9.3 ppg KCL to freeze protect. Pick up shifting tool & run in hole. Close FO tool & POOH. Lay down & move closing & opening tools off rig. PJSM to discuss nippling up adaptor on bell n Layout Sperry Sun 8" equipment. Rig down diverter lines. Rig up lines to pull stack. Nipple down stack & "T" hang knife valve in cellar. Nipple up BOP stack. Test BOP's. Pull test plug & set wear bushing. PJSM for nippling up adaptor on bell nipple. 6 I DAILY ACTIVITY (I.A.D.C.) Kerr-McGee Nikaitchuq 4 & 4PBl I Time (hrs) Elapsed Code Operations Breakdown Time I 06 Feb 05 0000-0130 0130-0330 0330-0530 0530-0730 0730-1000 1000-1015 1015-1045 1045-1115 1115-1130 1130-1200 1200-1245 1245-1300 1300-1330 1330-1400 1400-1600 I I I I 1600-2400 I 07 Feb 05 0000-1045 1045-1130 1130-1200 1200-1500 1500-1600 1600-2030 2030-2100 2100-2400 I I 08 Feb 05 0000-0100 0100-0300 0300-0600 0600-1200 1200-1430 1430-1800 1800-1900 1900-2200 2200-2300 2300-2400 I I I 09 Feb 05 0000-0200 0200-0230 0230-0600 0600-0630 0630-0700 I 0700-0900 0900-0930 0930-1030 1030-1130 I 1130-1200 1200-1500 1500-1530 1530-1900 1900-2000 2000-2400 I I 10Feb05 0000-0100 0100-0300 0300-0530 0530-0800 0800-1200 I I 1.50 14 0.50 21 1.50 6 2.00 6 2.00 3 0.25 1 0.75 21 0.25 21 0.25 6 0.50 3 0.75 3 0.25 2 0.50 5 0.50 21 2.00 21 8.00 2 10.75 2 0.75 5 0.50 6 3.00 6 1.00 5 4.50 6 0.50 21 3.00 4 1.00 21 2.00 6 3.00 3 5.00 4 2.50 4 3.50 6 1.00 21 3.00 6 1.00 21 1.00 6 2.00 6 2.00 21 3.50 6 0.50 7 0.50 7 2.00 20 0.50 20 1.00 20 1.00 20 0.50 6 3.00 6 0.50 3 3.50 2 1.00 5 4.00 6 1.00 6 2.00 6 2.50 11 2.50 11 4.00 11 Nippling up adaptor on belli nipple. Download MWD/LWD. RIH with BHA. Shallow test MWD/LWD tools. RIH picking up 4" DP. Circulate bottoms up & clean up hole. Rig up to test casing to 2500 psi. Test casing to 2500 psi. Rig down & blow down equipment. RIH to drill cement. Wash down to 2432'. Wash down to 2464'. Drill 8 Yo" hole from 2464 to 2484'. Circulate & condition mud for LOT. Stand back 1 stand for LOT. PJSM on leak-off & perform LOT. Pumped 1.3 bbls to leak-off at 655 psi. Continued to pump to establish injection rate of 630 psi @ 0.1 bbls/min - total pump~d 3.7 bbls. Shut in for 33 min. Stabilized shut in pressure = 310 psi. EMW = 14.4 ppg @ 2484'. Drill 8 Yo"'hole from 2484 to 3189' Drill 8 Yo" hole from 3189 to 4120'. Circulate 2 bottoms up. Blow down Top Drive. POOH for wiper trip to shoe. POOH to shoe at 2458' & RIH to 4120'. Circulate & condition mud. Spot HiVis pill on bottom & POOH to core. PJSM & clean rig floor for coring. Pick up coring BHA. Make up coring BHA & RIH. RIH with HWDP & run in hole to shoe. Ream from 3700 to bottom at 4120'. Start coring @ 4120' to 4133'. Cut core from 4133' to 4180'. POOH with core to 1946'. Wait 1 hour as directed by Core Hand. POOH with core to 644'. Wait 1 hour as directed by Core Hand. POOH with core barrel at 3 ft/min (present bit depth 407'). POOH with core barrel at 3 ft/min. Break out XO's to core barrel. PJSM on laying down core barrel assembly, as per Core Hand. Lay down core barrel as per Baker Rep. Change out saver sub & lubricate rig. Organize pipe shed to pick up new BHA. Hold PJSM on picking up new BHA. M ak e up M W D / L W D to 0 I s & mud mot 0 r. Plug in & download LWD tool. Shuffle monel collars & make up MIRL tool. Pick up stands of HWDP. Shallow test LWD, MWD & MRL tools. Blow down top drive. RIH with HWDP & jars. RIH with HWDP. Pick up 21 singles to 1450' & RIH to 4118'. Ream from 4120 to 4180'. Drill 8 Yo" hole from 4180 to 4310'. Circulate & condition mud - circulate 2 bottoms up. Blow down top drive. POOH to HWDP. Rack back HWDP, monels, plug in & de-activate MIRL. Break down Sperry BHA. Download LWD. Flush mud motor & break-off bit. Start rigging up to wireline. PJSM on making up wireline tools. Install Radio Active sources. RIH. RIH with HRLA - "Platform Express", POOH. Remove radio active sources, change out wireline tools. 7 I DAILY ACTIVITY (lA.D.C.) I Time (hrs) Elapsed Code Operations Breakdown Time I 0300-0430 0430-0600 0600-0800 0800-1000 1000-1100 I 1100-1200 1200-1400 1400-1700 1700-1830 1830-2030 2030-2130 2130-2200 2200-2300 I I 2300-2400 I 16 Feb 05 0000-0130 0130-0230 0230-0300 0300-1200 1200-2400 I I 17 Feb 05 0000-1200 1200-2400 I 18 Feb 05 0000-0900 0900-1100 I 1100-1400 1400-1430 1430-1600 1600-1930 I 1930-2400 I 19Feb05 0000-0600 0600-0930 0930-1030 1030-1200 1200-1500 1500-1800 I 1800-1830 1830-1900 1900-2400 20 Feb 05 0000-0900 0900-1000 1000-1200 1200-1300 1300-1330 1330-1630 1630-1700 1700-1930 1930-2000 2000-2400 I I I I I 1.50 1.50 6 2.00 21 2.00 20 1.00 20 1.00 6 2.00 7 3.00 6 1.50 2 2.00 6 1.00 21 0.50 2 1.00 5 1.00 2 0.50 2 1.00 5 0.50 21 9.00 2 12.00 2 12.00 2 12.00 2 9.00 2 2.00 5 3.00 6 0.50 7 1.50 6 3.50 5 4.50 6 6.00 6 3.50 6 1.00 15 1.50 15 3.00 15 3.00 1 0.50 1 0.50 21 5.00 6 9.00 6 1.00 21 2.00 5 1.00 5 0.50 7 3.00 6 0.50 1 2.50 1 0.50 22 4.00 6 Kerr~McGee Nikaitchuq 4 & 4PBl Send out spider slips, elevators & rig down 4" tongs. Rig up 3" tongs. Pick up HWDP & stand back in derrick. Organize pipe shed for picking up BHA. Lay down casing tools. Make up bit & Sperry Sun BHA. RIH. Upload MWD/LWD. Shallow test MWD/LWD tools. PJSM on Nuke tools & install Nuke tools. RIH with flex collars HWDP & 2 DP. Prepare to slip & cut. Slip & cut drilling line. Full service on Top Drive. RIH picking up singles DP to ES tool at 2833'. Tag ES tool @ 2836'. Fill pipe, break circulation & drill out plug. RIH to 4761' @ baffle adaptor. Break circulation. Rig up & test casing to 2500 psi. Rig down & blow down test equipment. Break circulation & begin to drill cement. Slow down pump rate. Change shaker screens. Circulate cold mud. Drill out baffle. Drill out float & shoe equipment plus 20' of new hole to 4881'. Circulate bottoms up & condition mud for Leak-off Test. Perform Leak-off Test. Directional drill 6" hole from 4881' to 5295'. Directional drill 6" hole from 5295' to 5950' Directional drill 6" hole from 5950' to 6661'. Directional drill 6" hole from 6661' to 7197'. Directional drill 6" hole from 1197' to 7577' (TVD4184') Work pipe while circulating & conditioning mud. Circulate 3 bottoms up & pump a sweep. Pump out of hole to shoe at 4851' MD. Service top drive, swivel & check saver sub. RIH to Total Depth. Make up top drive, fill pipe, tag bottom, circulate & condition mud for trip out of hole. Circulate 2 bottoms up. Pump sweep, spot pill in open hole & blow down top drive. POOH. POOH. Lay downBHA. Download MWD & remove Nukes. Pull wear ring & set test plug. Rig up to test BOP's & test BOP's. Cont. test BOPE POOH, test plug, set wear ring. Start rigging up to run liner. Organize pipe shed. Continue to rig up floor for liner. PJSM for running liner. RIH with liner. Contuinue to RIH with liner. Drop plug, chase to bottom 760 stks, set liner, set packer. Test to 2500 psi. Release, POOH 30' +1-. Break circ., Unload/ok/load mud & make spacers while clean up surface lines. Displace well to brine, 9.3 ppg. Clean up surface lines. Blowdown top drive, clean up floor, fill trip tank, service rig. Start POOH with DP. Balance weight in derrick for move. Rig up to pull wear ring I pull wear ring. Rig up floor for ESP. PJSM for RIH with ESP. Suck out stack, pick up ESP motor, service pump, RIH with ESP I component string. 9 I DAILY ACTIVITY (I.A.D.C.) Kerr-McGee Nikaitchuq 4 & 4PBl I Time (hrs) Elapsed Code Operations Breakdown Time I 21 Feb 05 0000-0930 0930-1200 1200-1230 I 1230-1530 1530-2130 2130-2330 2330-2400 I 22 Feb 05 0000-0100 0100-0200 0200-0500 0500-0530 0530-0600 0600-0930 0930-1000 1000-1200 1200-1800 1800-1900 1900-2000 2000-2130 2130-2200 2200-2400 I I I I 23 Feb 05 0000-0100 0100-0200 I 0200-0230 0230-0300 0300-0900 0900-1200 9.50 6 2.50 6 0.50 21 3.00 21 6.00 6 2.00 21 0.50 6 1.00 6 1.00 21 3.00 21 0.50 1 0.50 1 3.50 21 0.50 21 2.00 6 6.00 21 1.00 21 1.00 21 1.50 21 0.50 21 2.00 21 1.00 21 1.00 21 0.50 21 0.50 21 5.00 14 3.00 14 RIH with ESP Completion srting. Megger test ESP cable. Test failed. POOH standing back 2 7/8" tubing. Arrive at joint #99 where splice in cable located. Cut cable & megger test. Cable failed test. Splice ESP cable before POOH. POOH standing back tubing. Relieve pressure from drain valve POOH standing back tubing. POOH - stand back tubing. Megger test motor. Re-program down hole sensor gauge. Splice ESP cable. Re-install downhole sensors. Plug in motor & re-service seal. Make splice in cable. PJSM. Plug in cable. Megger test. RIH with stands of tubing. Continue to RIH with stands of tubing. Pick up singles from pipe rack. Rig up SSSU & test same. R I H wit h sin g I e s of tub i n g t 0 j 0 i n t # 1 3 8 . Make up hanger. Install penetrator. Cut ESP cable. Put end penitrator on. Hook up ESP to penetrator. Install SSSV control line in hanger. Land hanger & test to 5000 psi for 10 min. Rig up to pump 4 bbls diesel. , . Pump 4 bbls diesel down 2718"x 7" annulus with test pump. Rig up & test TBG to 1000 psi & charge for 10 min. Nipple down BOP's. Nipple up tree. Test void tree to 5000 psi. I NOTE: End of Nikaitcuq 4 & move to Nikaitchuq 3. I I I I I I I I 10 Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 spe,...,,...,v- sun DRILLING seRVIc::es Mudlogger's Morning Report Current 18 2 14 hr Avg 164 ftIhr ( 2 unit~ ( ( 14 hr Max ftIhr units Deg F 735 5 245 454 Pump 1 Pump 2 Pump SPP ~~~'u",,_.n~~¡;~m~1k~ Mud Wt In Mud Wt Out 8.90 ppg 8.90 ppg Report No.: Date: Depth Ftg last 24h"s Rig Activity: Report For: 1 02/02/2005 620 405 Drilling Lewis / Mosley .,__.._,..,...._,.:.:.JI:" Pump and Flow Data 1 00 spm Flow rate 100 Liner 5.5 x Stk 1458 632 2.84 10 gpm gps in. -- Vise ~ sees FIt ~ ml HTHP m Mud Wt at Max Gas ppg PV 15 cp YP 32 Ibs/100ft2 Gels 12 \ 15 \ 18 pH 8.7 Sd .. 0 % 1 0-30 Type: RPM: GT1 Bit Size: Hrs. On Bit: 121/4 Jets: 1 x 18 \ -- Total Revs on Bit: "--r-[:,:::-,:::,,'" ....::¡.. I:.:nø=.::JL~:::"7"ltr;:-:~::.;:r~:.:.:lt,r:r:=::=: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to 65 % Sand 35 % Cly % Sltst II, L, ,._l._::,:._.JJ,LIX.::.....::..~_,J(.1 ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg units units units .,..Î"~;;..,v~:i.~f~~~~A~.JI 'II ,JI[:lIr',.,l.'lî=::=.:.t:::::·:1:_~IIJ Drilling Breaks Depth Drill Rate during Gas during before after before to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: x 12 \ 2 x 16 TFA: 0.7520 -- Footage for Bit Run 465 1..L.:,:n...:ø::: '-::11" ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft IiI.fL:: ____..1..JL..:..::...1 % % ft units ft units ft units T:'I.. iT.!.II n ppg ppg ppg II after % Lithology Cgl Sst Ls Sh - N/A oz. ;.';¡ 24 hr Recap: Pick up BHA and stand in derrick. Tag up at 40', break eire, Ream to 80', Condition Mud, Drill to. 135', No gas, Continue to drill to 215', No gas, CBU, POOH< rig up MWD tools, RIH, Continue to drill to 620' MD. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Well: Area: Lease: Rig: Job No.: spe.-.r'V- sun I:) R Il.-L...I N G 5 E R V I c: E 5 Mud Jogger's Morning Report Current 128 37 ftIhr units Deg F 14 hr Avg 140 ftIhr ( 25 unit~ ( ( 447 107 Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 14 hr Max @ @ 2 02/03/2005 2464 1840 Drilling Lewis 1 Mosley Pump 1 Pump 2 Pump SPP Pump and Flow Data 105 spm Flow rate 110 Liner 5.5 x Stk 2145 ,. ..' .,iI.",.""I...."",,···,. 1772' 1676' 'if,:.1...~::,..~:¡.;;;¡ç[ ~L:;,.J!.,:~~.~;;~1;J:: II ,fll Mud Wt In Mud Wt Out 9.50 9.50 1 Type: 10-15 RPM: 638 10.63 10 ......' ppg ppg Vise 39 sees PV 12 cp Fit 18.0 ml HTHP m Mud Wt at Max Gas YP 11 Ibs/100ft2 Gels 6 \ 13 \ 19 pH ~ppg 9.2 Sd -1.5 % GT1 80 -- .. ..".~~~_~IWL ~..:l .a:m..:.~_..:..... . II Bit Size: 12 1/4 Hrs. On Bit: Jets: 1 x 18 \ 1 x 12 -- Total Revs on Bit: ~"'_X'"': ~·.¡;!',~,~~~~~..J1¡:J:];::.t'-:f~"î::J::::I:::œ.t=:::'¡(:::::.J::I.C....1-::::.::. ft Trip Gas: ft Short Trip Gas: Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: ..r=-~.Jtl."JI. ..t·- .- IIlL,..__,J to to II ~ iI.f.'ir:C· .1I.~1:":::J"TIrt1 Current Lithology: % Sand 20 % Ii . i!I, ¡q~..~_,..m:::]¡ 1.......,.-:.1::~:~=:::::r...J...:...L..._. ft units ft units ft units .~X::·~_'II.._.__~···-c.. . ..'11 Depth to to to to Cly 80 % .....,i~_.;._:_._::U..L~ Sltst II. .. -. ~~-~~, U.,LIL..LL. ppm ppm ft ,. c:. % 1i"IJLLLL.II,!II Connection Gas and Mud Cut ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg ppg ft units ppg ft units ppg J . ',~_..... ,U..:' >·"'-·i.;-'--~_··~ _~~-'.~ Drilling Breaks Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh % lJ.'" u: --::1 IIL..:II__ N/A oz. 24 hr Recap: Continue to drill F/620 T/635, CBU, POOH to wait on fluid. RIH and contiue to drill to 2464. Max gas was 107 units. Logging Engineer: Mark Lindloff I Wayne Hermanson * """-'["1: units = 100% Gas In Air sper'r'v-sun DR I L.L.I N G 5 E R V I c: E 5 Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 3 02/04/2005 2464 o RIH W/Casing Lewis 1 Mosley .' r "~'!!'~~<YC:;T,J'-'~S;·"^7.Jt~~:£;¡,?c~~;3x:,~,1,~~~"'-Y.:e:::f¡:::U,",ill 'I. Iì·-:;-::,~:C_. ,'II ",I, Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftIhr 0 ftIhr ( 0 @ Pump 1 0 spm Flow rate 0 gpm 0 units 3 unit~ ( 10 @ 2464 Pump 2 0 0 gps - Temp Out Deg F ( Pump Liner 5.5 x Stk 10 in. SPP Mud Wt In Mud Wt Out 9.50 ppg 9.50 ppg Vise 39 sees Fit 18.0 ml HTHP m Mud Wt at Max Gas PV 12 cp YP 11 Ibs/100ft2 Gels 6 \ 13 \ pH 9.2 T-~----:=;=-"::l::,':"T.¡¡'~ - rillJl,~ II. ::ß':-:-iI Bit No.: Type: Bit Size: Wt On Bit: RPM: Hrs. On Bit: 5œ~""'~::,:,:__~._",_'::~::",,=:"::LJJ(H'U -u Trip Depth: Short Trip Depth Tight Spots: Jets: x -- Total Revs on Bit: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to % :'¡¡;;\i,\-J""";~.:,~tJ:Jfi~,~~: ft ft ft units ppg units ppg units ppg :~~,'·::({ff'~';i::~~~:~~~"".,._. Depth before to to to to Wf:}[ Jilt : ,L r:..::J.d,,: :r.x:-:::rr;¡:LJlI..J...". Sand 20 % 80 % Sltst Cly ,J_~~,==':';: ,:.'_,'", " :::·.::::",'L" '1(1 .... Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ":,,~__:"',JU .'"':r.,·,:::",,,'''1C[,n.:::::' I. Drilling Breaks Drill Rate during Gas during after before 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: \ x TFA: -- Footage for Bit Run ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft % 'DL_.J!,,:,....LJIJ.L.·'j" I.. ,,_ % ft ft ft ]][):":.'\\\!ijB .Jilt after N/A oz. II LJI" ppg ppg ppg Ill.. ""'.:.m. ¡ 24 hr Recap: Continue drilling to casing point, F/2360' T/2364' md, Circulate hole clean, POOH to Heavy Weight RIH , CBU with Carbide Pill. Carbide test showed 54% Washout POOH, LD BHA, Rig up to run casing, PJSM to run cas Logging Engineer: Mark Lindloff I Wayne Hermanson units units units "II! .. % Lithology Cgl Sst Ls Sh * 10000 units = 100% Gas In Air IJ spef"""f"""\{- sun DRI LLI N G SERVI t:ES Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Current o o 55 ftlhr units Deg F 14 hr Avg o ftlhr ( o unit~ ( ( Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 o o 14 hr Max @ @ Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: Ì!! .~~_"""____,,,..,, 4 02/05/2005 2464 o UD CMT Equip Lewis / Mosley Pump and Flow Data o spm Flow rate o Liner 5.5 x Stk Mud Wt In Mud Wt Out ppg ppg Vise 39 sees PV 11 cp Fit 9.4 ml HTHP m Mud Wt at Max Gas YP 12 Ibs/100ft2 Gels 4 \ 10 \ 14 pH -ppg 8.7 Sd -0.1 % Pump 1 Pump 2 Pump SPP '" !:;;i¡;;i£~~.'" v:_-,.A.;;;;:;';;'~~;,~ôii~~1:Irt,,1I 11"''':1.. tìU.I'III[: ___U.I{]U-- In...~ ,I 9.35 9.35 . . '" ^ :è¡~'Jf.r::-::::--,ft ",,'-':""..:.i :_:::::_,,"L"~.. ~',I' ·I....L.:]==_L~.: ,JIIC..__ \ x TFA: -- Footage for Bit Run .~_,a:;:..=:.. __"...' _,.,.,.1.,. Bit No.: Type: Bit Size: Jets: _ x _ Wt On Bit: RPM: Hrs. On Bit: Total Revs on Bit: :L::.,J"'!C~~',¡H .r: ·:I,,:...X:=:m...:JL..L.....:.....,::..l' ,'0 "',.,.:,::.____.1:1."1;1'.. "".At...> III Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to -"}~:~-r""?;;:ri~1!,,,~~1:';;;;';¡~ "..,::J:::1,r..:'~. .D\J[ % Sand 20 % % Current Lithology: Mud Cut: Mud Cut: to , ",:.::..C",....I, J, ppg Trip C/: ppg Short Trip CI: Feet of Fill on Bottom: .,.11'" 1IIIi£._.,::I.JIl,~,. ~':"~."f I.. Cly 80 % Sltst ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft ft units ppg ft ft units ppg ft '._..:.:J:;¡;m~~1I.::_.,l-'L,ln-"'IJflL"":,.U.ll [1 units units units .,..:f::..L,..'...::C:::=:::C~~=:;,;;;;;~=,¡::.L..xJ Depth Drill Rate during before to to to to Drilling Breaks after Gas during units units units _I..". .. o o 10 gpm gps in. ~ ppm ppm ft T_ % before 1.1 .... ppg ppg ppg _,.,.,:111II11II after % Lithology Cgl Sst Ls Sh N/A -~ '''T~ 24 hr Recap: Run casing - Tag Bottom. Stage up pumps slowly to circulate and condition mud - 6 units of Ìi TG gas @ bottoms up, prejob meeting - tested lines - cement surface 9 5/8" casing - displace cement with rig pumps, loss of returns -' Slowed pumps to 3 BPM, reestablished circulation. RID cement equipment - rig open Fa tool. 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Logging Engineer: Mark Lindloff I Wayne Hermanson ,.'''"'"f'' oz. * 1 0000 units = 1 00% Gas In Air sperry-sun DRILLING seRVices Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Current o o 55 14 hr Avg o ftIhr ( o unit~ ( ( ftIhr units Deg F o o Mud Wt In Mud Wt Out Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 14 hr Max @ @ Pump 1 Pump 2 Pump SPP Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 5 02/06/2005 2464 o Pick Up Drillpipe Lewis I Mosley o o 10 gpm gps in. Pump and Flow Data o spm Flow rate o Liner 5.5 x Stk 9.35 ppg 9.35 ppg Vise 40 sees Fit 9.6 ml HTHP m Mud Wt at Max Gas ppg PV 12 cp YP 12 Ibs/100ft2 Gels 5 \ 12 \ 15 pH 8.6 Sd -0.1 % 2 Type: Hughes GT-1 RPM: Bit Size: Hrs. On Bit: 81/2 Jets: 16 \ 16 \ -- Total Revs on Bit: 16 \ x TF A: -- Footage for Bit Run -~:L.. JU ~'.'," -, . :;~ÛlZ;;:~;;'·":::C··.~·:.r::r- ..., "'T Lr'f!'m"".J.:":.:..x:rnl ,__..-: 'lr'u,:, --::'.II1._aC,IIILJ Trip Depth: Short Trip Depth Tight Spots: ft ft Trip Gas: Short Trip Gas: to to Mud Cut: Mud Cut: to , .11'1 % Sand 20 % .~';:'f.:-'-:-:' J~':'-::~;;-.,. """.~_,.::t::J~,1:l:;o.~~íìLr-"""~.tt:·tx. ..'::1: :11,:11 Cly 80 % Sltst IflC']UI(. . ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: II ILlif II. II. I, -~:: % 1"i~'::'n "'X..!. if -, .."II! , 'j,f'UIIi1 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg '·:1t.:::::.en::l¡;;!t:':ir:::,::;II:-1't~:c.::-:::L.ilTI1_~._:~,.". ,==-)'!t::.HL... II. .'.. ,,~_lL.:L. Depth Drill Rate during before to to to to Drilling Breaks after Gas during before 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: after ft units ppg ft units ppg ft units ppg ,I" III. II, % Lithology Cgl Sst Ls Sh N/A oz. 24 hr Recap: Layout BHA, RID Diverter Line, R/U BOP Stack, Tested BOPS, Pull test plug. Currently P/U BHA Logging Engineer: Mark Lindloff I Wayne Hermanson 0.5890 % oJ n "" -"'" '\ * 10000 units = 100% Gas In Air spe,...,,...,v- sun I:) RILL I N G 5 e R v I c:: e 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: ..11("" 6 02/07/2005 3190 726 Drilling Lewis I Durkin ;\'þ~c~':1~U.J:..UI;f.:t:.~ð.I:lJ;'i"''1J:JWi~.:=....:.~'''''''·'·..I..::~:j '"': -- 8 1/2 ".:lifi:-J.., ),' ,~J¡J,:1\':.:1~r-:':.:...._~,I:::.: )¡(,,:,_~.: -.- :~_":::"":.."'JL :. I!,Ö,' L:::=..~",L" fil'i Ü'm :'.........:1J._ :! ..'):C:l..c\::I % Mud Cut: Mud Cut: to 50 % Sltst Current Lithology: 50 % Sand 0 .f''f~'{·~-iã~'¡"T.:,Yj ~L ;\y\..-.J.~~:';gr.rrLt:_,-~I_:,=..:'_,~_.,.",K=]:JI ft ft ft units units units ppg ppg ppg Current 14 hr Avg 14 hr Max Pump and Flow Data 207 ftIhr 131 ftIhr ( 582 @ 2466 Pump 1 67 spm Flow rate 460 - 26 units 17 uniÜ ( 31 @ 2996 Pump 2 81 7.667 55 Deg F ( Pump Liner 5.5 x Stk 10 SPP 1718 , T" l~ 'P~~Jm[1~.;';'~, í'::;;;::,;,f:;:"';~~: l:_,i'_,~'::':f;:::'f:ì\~::""f:;J.ltfiJì:li[....:::r:.!ll.....t-' Mud Wt In Mud Wt Out 9.35 ppg 9.35 ppg Vise 40 sees Fit 9.6 ml HTHP m Mud Wt at Max Gas ppg PV 12 cp YP 12 Ibs/100ft2 Gels 5 \ 12 \ 15 pH 8.6 Sd -0.1 % , '-:::ø; -;;xm!,¡..1J'\"l::j"::~L-_L:,,:,-L:;;;;;:¡:\~,JL... ..::::::::t::::::)=r::~(": ,..:uÐL:.Ll.I.. Ju..: 2 4.00 Type: RPM: Hughes GT-1 Bit Size: 78 Hrs. On Bit: Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Jets: 16 \ 16 \ 16 \ x TFA: -- -- Total Revs on Bit: Footage for Bit Run 1 :Jf!.:JL.:..IL::.::::...-:r::: J_ ' . .1::=1 ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Cly .,.1. A_.~'''tr::_c.'',_____,_ Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg % % I ..,.. _ .LIt::.., _I ¡...i\L.....L ft units ppg ft units ppg ft units ppg _~____,....It_ t ICC.::..L, .1.. ~~,~~~r~::~'';'Q;.:;;,';;':¡':;;:~t't',1!l:~J6.¡~'L~~.::G,_::: ~::!~L ,...1 I. .:t. Depth Drill Rate during before to to to to Drilling Breaks after Gas during before 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: after % Lithology Cgl Sst Ls Sh r N/A oz. 24 hr Recap: Continue to RIH with BHA, Shallow test MWD, RIH with Drill Pipe singles, CBU and clean up hole. R/U to test casing to 2500 PSI, Test casing, RID and bleed down equipment, RIH and drill out cement. Wash down to 2464, Drill to 2484 md, Circulat and condition mud for LOT, Stood back a stand and run LOT, Good test. Drilled F/2484 T/3190. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #4PB1 North Slope NW Miline Point Nordic 3 AK-AM- 0003523133 spe....,....,v- sun DRILLING SERVIC::ES Mudlogger's Morning Report Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 7 02/08/2005 4120 930 RIH W/Coring Bit Lewis 1 Durkin .·.:'::::'-1i,··,,,tt"Þ.~~~":.,IL~_ I!ltt....:,'·:1..![..U,=-~,i_~_ .~ '.:...:.........-.::~11·', Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftlhr 137 ftlhr ( 283 @ 3485 Pump 1 0 spm Flow rate 0 gpm - 0 units 37 unit~ ( 526 @ 3960 Pump 2 0 0 gps 80 Deg F ( Pump Liner 5.5 x Stk 0 in. SPP 0 Mud Wt In Mud Wt Out 9.35 9.35 ppg ppg Vise 40 sees Fit 9.6 ml HTHP PV 13 cp YP 12 Ibs/100ft2 Gels 3 \ .g1~:I'~ 2~~~.:,:_L';;;~.......J,~:::t:'-" 3 0.00 Type: -iTC ARC-425 C~ Bit Size: 81/2 RPM: 0 Hrs. On Bit: Jets: \ -- Total Revs on Bit: ~::J1ii:ltiE.!r~~~.;~r.__.__.:..::(~LI¡;¡:::; ~:: Trip Depth: Short Trip Depth Tight Spots: Trip Gas: Short Trip Gas: 46 Mud Cut: Mud Cut: to ft 2464 ft to to ,¡:~.:;r;;:_,,'i'æ~w:;;;:':;¡\~¡i!!I¡j~'à';?;!~'j''r'0X¡"'~'Iot\i!;'z,;~~~:.....;;;.'T__~:':.::=':~::'..I' _~___.II, 80 % Sand 20 % Cly/st o % Sltst 11111' !,j Current Lithology: Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ,_,::~::~t::::~.ì::lel:.L¿¡i~,;;~~_J,_ "., .1 n..L~_,.I, mL.:..:....., Drilling Breaks Depth Drill Rate during before Gas during after before to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: m Mud Wt at Max Gas 6 \ 11 pH ~ppg 9.7 Sd -0.5 % \ x TFA: 0.7500 -- Footage for Bit Run 0 ..-'-nL::::::1!I1, , ppg Trip CI: ppg Short Trip CI: 45000 Feet of Fill on Bottom: ... II I""W 1._. I .....::",::.:",~ !llJiIII % % . '.-, ,11....11... I....: :....lL.~__ '. ft units ft units ft units "'C,'Itt1..IIL....ll.:J!L...a,,1 Ii ppg ppg ppg after % Lithology Cgl Sst Ls Sh N/A oz. 24 hr Recap: Continue to drill F/3190 T/4120" MD, Circulate 2 B\U, Short trip to shoe, RIH to bottom, CBU, . POOH, UD BHA, Currently picking up coring equipment. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Kerr McGee Well: Nikaitchuq #4PB1 Area: North Slope Lease: NW Miline Point Rig: Nordic 3 Job No.: AK-AM- 0003523133 Daily Charges: $3,375.00 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: Cumulative Charges: spe""""""y-sun DRILLI N G SERVICES Mudlogger's Morning Report . K:~l;,.'U'i#~C~:W';:;:;':';";".,...;I, Current R.O.P. 0 Gas* 0 Temp Out 60 14 hr Avg 35 ftIhr ( 1 05 unit~ ( ( 14 hr Max @ @ 8 02/09/2005 4180 60 POOH W/Core Lewis 1 Durkin $47,050.00 ....::..11. Pump 1 Pump 2 Pump SPP Pump and Flow Data o spm Flow rate o Liner 5.0 x Stk o gpm gps in. 4161 4148 ftIhr units Deg F 101 548 o o o Vise 41 sees Fit 5.5 ml HTHP PV 14 cp YP 15 Ibs/100ft2 Gels 5 \ m Mud Wt at Max Gas 8 \ 10 pH Mud Wt In Mud Wt Out 9.35 9.35 ppg ppg -- ~~..J _d_·JI~tè.L~r:'i';;\\1T~;;c~~~~o.....__...:.....:·rA;;:;;;;'::"':"'.r.:___:::xt"::jLln !LL~~~.j;;,~J=_"=__'IL' ".' ~~~.~,!I!.,'''' UlI.l'r II ~ppg 9.0 Sd -0.2 % Bit No.: Wt On Bit: Type: -ITC ARC-425 C~ Bit Size: 81/2 RPM: 0 Hrs. On Bit: Jets: \ -- Total Revs on Bit: \ x TFA: 0.7500 -- Footage for Bit Run 60 ..l:::....c._..L.lU.1 .I 1[:--'·, 1 3 0.00 )II ...:_=~~':;'¡';;'~q"=::::~~W¡;;J,.':"";;',:N:¡;~~;::::"j1::"::':-.., L Trip Depth: Short Trip Depth Tight Spots: to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: I. 'J( .. ft Trip Gas: ft Short Trip Gas: 4120 3794 to % 20 % Clylst 20 % Sltst _ .J::,X:L.U~.::;::::1L"L~-~..1 L":.._Jìl.. , 60 % Current Lithology: Sand m~:"".::.:.:, IUI u:~_ ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg . ,.IC:]!.:. .1...., ".,...._Lll.. units units units .._····~';::~~~i.tt::ï;XJ;.;l¡.I»ì:~~--·-:=J:E:...L:Jl.J:.. 1 Drilling Breaks Gas during Depth Drill Rate during before after after before to to to to N/A 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 50000 ppm ~..,.' ',' ppm .! ft ~1 :"L1i % _":.:':'.:.:111 % Lithology Cgl Sst Ls Sh 24 hr Recap: RIH with core barrel, CBU, Core F/4120 T/4180, Did not CBU. Caught samples up to 4140'. Lag Depth. Currently POOH with core barrel. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Kerr McGee Report No.: 9 Well: Nikaitchuq #4PB1 Date: 02/10/2005 sperry-sun Area: North Slope Depth 4180 DRILLI N G seRVIr=es Lease: NW Miline Point Ftg last 24h"s 130 Rig: Nordic 3 Rig Activity: POH R/Elogs Mudlogger's Morning Report Job No.: AK-AM- 0003523133 Report For: Lewis 1 Durkin Daily Charges: $3,375.00 Cumulative Charges: $50,425.00 " '~~!~~:"~U·~~;;::";:;'X,';Jl:':"'¡;:.',::,:Ji!.I¡¡ 1CJ~~I:~L~..J.J...A,~!JL-,æ, ".' )1\, Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftlhr 75 ftlhr ( 166 @ 4200 Pump 1 0 spm Flow rate 0 - 0 units 40 unit~ ( 240 @ 4170 Pump 2 0 0 - 60 Deg F ( Pump Liner 5.0 x Stk 0 SPP 0 4 0.00 Type: -ITC ARC-425 C~ Bit Size: RPM: 0 Hrs. On Bit: 81/2 Jets: \ -- Total Revs on Bit: \ x TFA: -- Footage for Bit Run 0.5890 130 Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg Vise 40 sees Fit 5.8 ml HTHP PV 10 cp YP 10 Ibs/100ft2 Gels 3 \ m Mud Wt at Max Gas 5 \ 8 pH ~ppg 9.2 Sd - 0 -- '~'"l';,::'::l,,",,~f:,~~;;:, ,~J,"J'I:,~~~.L.":",-~w::r;T'~~:J;;:IÌL._.__:~;(, ,.,,,.r::-=: . .11 I RIl.J-] III . ~'~" 1:::ì;'e~'}\f~" -.::.:.:::r.t::.:nc:';1j::'::"i\~~~i:.:::C:":":::;::.JUl'::¡;:';;;;::;;;¡:LJ:f1L:l~~"",.u" ."'_LU·, ,,'- .n ~..., Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 47000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ·-',:,::¡=;;~:r:::LiL~,'L.i:.r..t:.ì~Jil,~,.....I__, . "'---.I:" II ,...,IILJlJ!L"L,.....I.JL::.., Current Lithology: % Sand 95 % Cly/st 5 % Sltst % % ;'If! '~",~="""L,;=«:~ :r!::....:::::;·.:L:L:iL_L.L_.l."".I........ .1~·,C,:L_..:":-_____.1 . .u.,J;,... I. "':::.jLJ!LIt.ulUL~~ ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units ppg ppg ppg I I ~ ~ ~ , !ll\iIlL;JtJI::,:..".':l.. before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh ~ I Drilling Breaks Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. " 24 hr Recap: Continue POOH, Laydown core barrel, Pick up BHA #3, RIH, Drill F/4180" T/431 0' MD, Circulate 2 B/U, Currently POOH to run Elogs Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Kerr McGee Report No.: 10 Well: Nikaitchuq #4PB1 Date: 02/11/2005 sperrv-sun Area: North Slope Depth 4310 [J RILL I N G seRVices Lease: NW Miline Point Ftg last 24h·s 0 Rig: Nordic 3 Rig Activity: Circulating Mudlogger's Morning Report Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $5,380.00 "·I:IL:a':~~~~;'i.,';i;~~~t:J,;)j:;;!I!ì\I!J!5!'~;,J.::.::JI["U=~.:tC:::!:f!ll;:"1'.(,C"~~~,~¡:;;;Y"'5;:';!\l,·.::,J,I!IJi, JlliI. 'III Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg Vise 40 sees PV 10 cP Fit 5.8 ml HTHP YP 11 Ibs/100ft2 Gels 3 \ m Mud Wt at Max Gas 5 \ 8 pH ~ppg 9.3 Sd ~,O % Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftIhr 0 ftIhr ( 0 @ 0 Pump 1 50 spm Flow rate 250 5 units 0 unit~ ( 0 @ 0 Pump 2 50 0 - 40 Deg F ( Pump Liner 5.0 x Stk 0 SPP 285 .'~ II..._.~_.;¡;_~~'I'-·-rn.:-:": '. 1l.,~.JLI~.':"'~,"': I 1 .L.._"';:'.IUJUIl .,:-':.:::.. ¡ILl .,=.c:r:I.... Type: RPM: Bit Size: Hrs. On Bit: Jets: \ -- Total Revs on Bit: \ x TFA: -- Footage for Bit Run o ¡ .. ·.~.Ji.".xX::¡:L:[':=::".;'::l;}lí:.v:,\~¿~,~~:.!:J::._':~:"';¡~¡;:.~_. ...u....t:-i:,;;::.:::::::-...:~:;:.::-:r .: ! __.........:....... " ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 46000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft ~ :').I;.,~:.I-"';;¡;,;" n; ;lC.. ,III ',11 i ,;;~:lm:ftC::lf..· II:, lit rr.J......;,;"... LL....· ,l.J".l.D.:- ~.::.:r:::::r.::M':X77 \'\, .. L;¡;::~rt.lul .."1 II % Sand 95 % Clylst 5 % Sltst % % ft ft ft units ppg units ppg units ppg 1Ul..l...,::~J.:,.....,.,__~..,. J Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft ft ft units units units ppg ppg ppg . ,. ..,_Tl'!t~.h:r.::tJ,:,,1=~~:!Tr "'Ai. ..JUL.,..... ". Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Continue to POOH. Lay down BHA, Rig up to run logs Toolan one run failed. Lay down Logging Equipment. TIH to cement, Currently circulating and conditioning hole for cement job. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: Kerr McGee Report No.: 11 Well: Nikaitchuq #4 Date: 02/12/2005 Area: North Slope Depth 2363 Lease: NW Miline Point Ftg last 24h's 0 Rig: Nordic 3 Rig Activity: RIH Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $53,755.00 _.;;!::.:t::=r:D(=:;¡x:,:;:~fìŒ.~¡;~~J:iil.i;':',;I..--L!cIIL,...IL_:¡¡~'St~.r:.Jtl.IJ::cr:Jì-:, ~-'..r:::u_ . sper'r'y-sun DRt LLt N G SERVt C:ES ft ft ft units ppg units ppg units ppg :J:~"I1X::I\:~~,~~::1 Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg !I~ .. ._~I1i~:t:'t:-'.-,::::1i.::I.IL:_~:::lli,1!!! ft ft ft units ppg units ppg units ppg - III -.]1..........' Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftIhr 0 ftIhr ( 0 @ 0 Pump 1 0 spm Flow rate 0 5 units 0 unit~ ( 0 @ 0 Pump 2 0 0 60 Deg F ( Pump Liner 5.0 x Stk 0 SPP 0 -·,.,r....,:-~p:r..'J,:=r-.,j"A... -:;::...... _ ....~~JL'-'.":'~_-:::r~~+.:1:-==_.:.."Xr:n.LJn-::::U . L.JI[,::rI: lCd... Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg Vise 40 sees Fit 5.8 ml HTHP m Mud Wt at Max Gas - - PV 10 cp YP 11 Ibs/100ft2 Gels..1- \ ~ \ 8 pH ~ppg 9.3 Sd - 0 , ".. ~,J.h~L~ ~__:J:.;...L~-1f . Ii! I . .. '.. ......_.._..,,~:::';;::¡';~;=~_~"':._L..IL';"".l~ 5 Type: MX-C1 Bit Size: 8 1/2 Jets:...l.... X ~ \ RPM: Hrs. On Bit: Total Revs on Bit: ':"'=¡fI'-,:¡m.r.:...::.':::. ']['r=::..:'_. __..:::ID':",,· :::L:"___~,:::.:;'.I,,.J¡:,;,:..,.,.,;:;xI:. Ii. X 12 x TFA: 0.6280 -- Footage for Bit Run 0 :1';;:;''=''[1._._ U",L:Dln. If" Trip Depth: ft Short Trip Depth ft Tight Spots: to :,r!\À~"¡;.,~:....,JtL.I.:· Trip Gas: Mud Cut: ppg Trip CI: 46000 Short Trip Gas: Mud Cut: ppg Short Trip CI: to to Feet of Fill on Bottom: I.. I. ,_::l=.·"'::~;;(;"h.uAm"..L"=". _~.'~.. __.J::r::;;..., ..::..1'" iiI, .... :.J Current Lithology: % Sand % Clylst % Sltst % % .,w..JX'.~,~'::Tr=~1i: ..J14....:J:::,":.L=:::r.JC . '~, RfI.C¡.!¡.~'~:::::=:¡~.,!I!,~::'"....i._ .,1",1 ,.Al:".L I.W""I Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth to to to to i:'. Jill _ 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. , 24 hr Recap: Continue to recipicate pipe while circulating and conditioning mud. Pump first stage of cement plug. POOH at 5 minutes per stamd. Pump 2nd stage of cement plug. POOH, Rig up to test BOPS, Passed, Rig down test plug. Pick ùp BHA and RIH. Currently RIH. Note: Finish Nikaitchuq #4PB1 at 12:00 hrs 11 feb 05 and begin Nikaitchuq #4 Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air, Customer: Kerr McGee Report No.: 12 Well: Nikaitchuq #4 Date: 02/13/2005 spe...,f""1V- sun Area: North Slope Depth 4420 DRILLI N G SERVICES Lease: NW Miline Point Ftg last 24h's 2057 Rig: Nordic 3 Rig Activity: Drilling .~ Mudlogger's Morning Report Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $57,130.00 "i"""·;~l'J.í;;:;;~'f.~J.Ï!'šf~'::7'!ílfìl:-:;,:¡:;¡;jf:¡':~\j¡i:.~,jííf~;X;;;~.}"~.· IX][~~LL~IiL'2~~1I.. .....,...~.,.___~. œ...~~;, Current 14 hr Avg 14 hr Max Pump and Flow Data 45 ftIhr 161 ftIhr ( 908 @ 4371 Pump 1 80 spm Flow rate 410 gpm - 20 units 32 unit~ ( 373 @ 4222 Pump 2 92 6.833 gps - Temp Out 60 Deg F ( Pump Liner 5.0 x Stk 0 in. ~ SPP 1955 .. .\?\'b"r.S~~5t~~~rL;"':':"~:';:~.J.:.:':':',).T .1.1.....J.J!,..L'....c .. 'y Vise 40 sees Fit 5.8 ml HTHP PV 10 cp YP 11 Ibs/100ft2 Gels 3 \ m Mud Wt at Max Gas 5 \ 8 pH ~ppg 9.3 Sd - 0 % Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg -- 5 Type: 25.00 RPM: 81/2 Jets: 3 X 15 \ X 12 x TFA: -- -- Total Revs on Bit: Footage for Bit Run ,~._....~;,~;;,:I.:,J;__:__ :)lC::r.=X:':::-:liIL I, ......___~EL'lO MX-C1 o Bit Size: Hrs. On Bit: ..,.,.~~..:.::~,.[~ç.:.:.n...:.:::::l.:I:t.(::;,::·.. Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 46000 ppg Short Trip CI: Feet of Fill on Bottom: ,~L."IC.:;;...J ..~~r,~r::t!L.:..·, IUII'II.:'ll.: L~lJl]rC::'U:=."';;';;;:J-.."":L~.Il.. ent Lithology: 65 % Sand % Clylst 35 % Sltst :I;;·::~:;·YjJ'é~<¡¡¡¡j~t::.t::::':U 1...fL_..ÌlIL......... ,. ¡!L..';';~.l 1:.1".. .Ill,...",_. % 1 .IIII,:r ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ft units ppg ft units ft units ppg ft units ~'[;~~';;:fi¡i':]~~:'~,:::::1t::::r''''::':'''''..,"I\:.t:1J:;;;;;D::''1I1 r~ .. 'Ill I units units units Drilling Breaks Gas during ppm ppm ft . It 1I__f % ppg ppg ppg 1.:1 after % Lithology Cgl Sst Ls Sh Depth Drill Rate during before after before to to to to N/A oz. 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 24 hr Recap: Continue to recipicate pipe while circulating and conditioning mud. Pump first stage of cement plug. POOH at 5 minutes per stamd. Pump 2nd stage of cement plug. POOH, Rig up to test BOPS, Passed, Rig down test plug. Pick up BHA and RIH. Currently RIH. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air Customer: Kerr McGee Well: Nikaitchuq #4 Area: North Slope Lease: NW Miline Point Rig: Nordic 3 Job No.: AK-AM- 0003523133 Daily Charges: $3,375.00 Report No.: Date: Depth Ftg last 24h"s Rig Activity: Report For: Cumulative Charges: 13 02/14/2005 4861 441 R/U For Casing Springer 1 Durkin $60,505.00 spe....,....,v- sun DR I LL IN G 5 e R v I c:: e 5 Mudlogger's Morning Report Current o o 90 14 hr Avg 97 ftlhr ( 65 unit~ ( ( 14 hr Max @ @ Pump 1 Pump 2 Pump SPP Pump and Flow Data o spm Flow rate o Liner 5.0 x Stk o ftlhr units Deg F 221 821 4440 4832 Mud Wt In Mud Wt Out 9.50 ppg 9.50 ppg Vise 42 sees Fit 6.6 ml HTHP m Mud Wt at Max Gas PV 11 cP YP 13 Ibs/100ft2 Gels 5 \ 13 \ 18 pH ~ppg 9.5 Sd -0.3 % -- 5 0.00 Type: RPM: MX-C1 o Bit Size: Hrs. On Bit: 81/2 Jets: 3 X 15 \ -- Total Revs on Bit: X 12 x TFA: 0.6280 -- Footage for Bit Run 2798 117 ;,;¡:~.c... ",.~..~_,=1.:>!. . . Trip Depth: ft Trip Gas: Mud Cut: Short Trip Depth 4835 ft Short Trip Gas: 127 Mud Cut: Tight Spots: to to to Current Lithology: 50 % Sand % Clylst 50 % Sltst ppg Trip CI: 45000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft 11111 % ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units !IIi ppg ~ì ft units ppg Ð ft units ppg units units units Drilling Breaks Drill Rate during Depth Gas during % Lithology Cgl Sst Ls before after before after to to to to -"(, "'.'m,,,,,-~,. .'~} 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. o o o % 24 hr Recap: Continue to drill F/4420 T/4861, md, Circulate 3 B/U., Short trip to shoe, RIH to bottom, circulate and conditk~ POOH and lay down BHA, R/U for casing run. . , 1 L M * 10000 units = 100% Gas In Air ì I ! , I , ~ Logging Engineer: Mark Lindloff I Wayne Hermanson '~ ~ <,~.." ..~.,.._- Mudlogger's Morning Report Customer: Kerr McGee Report No.: Well: Nikaitchuq #4 Date: Area: North Slope Depth Lease: NW Miline Point Ftg last 24h·s Rig: Nordic 3 Rig Activity: Job No.: AK-AM- 0003523133 Report For: Daily Charges: $3,375.00 Cumulative Charges: ~·.'-"~:I1,:".;Lt:~~~.=;.,iC:.=t··'.~:::T:·" J.-=t:."lI.·'= spe,..,....,v- sun DRILLI N G SSRVIC:SS 14 02/15/2005 4861 o P/U BHA Springer / Durkin $63,880.00 _ IlL;::' 1 Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftIhr 0 ftIhr ( 0 @ 0 Pump 1 0 spm Flow rate 0 gpm 0 units 0 unit~ ( 0 @ 0 Pump 2 0 0 gps 80 Deg F ( Pump Liner 5.0 x Stk 10 in. SPP 0 ;JU.JIL~:!' ..-.:, ,~.J;~";;~¥;:;:;;:;X;:I:.":"U:.~:--·:, '¡:!IiI.. .,I$,':~. ~"'::X" . ) -I:.:. "'::...:U :ILl.,] Mud Wt In Mud Wt Out 9.50 9.50 Vise 42 sees PV 10 cp Fit YP 14 Ibs/100ft2 ml HTHP m Mud Wt at Max Gas Gels 4 \ 12 \ 18 pH ppg ppg -- IIÐIIL.. ~",It..".. ." ._....IL , .;;.~~¿:"',;J::1t. ..:....:._~.;;i.'1'~;~, 6 0.00 ~ppg 9.5 Sd -0.4 %' Type: See: FM3643 Bit Size: 6118 Jets:.J.!. X.J.!. \ 14 \ _ \ _ TFA: RPM: 0 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ·::~~I:_..I.._..-I[:.:I..._.~,.:L:";;~~~;."J!,L \.Jt..~:Jl:'I..CL1:... . J.,I,.J:_.::tL ",... Current Lithology: 50 % Sand % Cly/st 50 % Sltst % % .".,_",:i::1r:l":1.:':'.u.' I... .l1~":]! .,;, ....JJ..:r:·JIII._~::J:I.:~_~:I:J...IIlJ.LtlL,,'IILIIlll[ LIJIIII, IUII.D...·I "...01,.: ft ft Trip Gas: Short Trip Gas: Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to to Feet of Fill on Bottom: III. Iii l,~IJ l·"Tifi::rr~~~_LIl._1. ,.,.:::rJIL,J:.::I1U, to ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft ft units ppg ft ft units ppg ft .,n.::·", III: 1".::::.l1::,I.I1I."b,..,...J( ..,'",,:...T::~I..JI units units units ~~(:'..;:ï':: ':;:".,,;u.~~;. di'J ,,':\L.::.al Drilling Breaks Drill Rate during Depth Gas during before after before after to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Recap: RIH with 7" casing to bottom, Circulate and condition Mud, Cement according to well plan. Lay down casing and cement tools, Currently picking up BHA #6and swapping over to new MOBM (mineral oil base mud). Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 units = 100% Gas In Air -r 45000 ppm ppm ft . ..IIUII units ppg units ppg units ppg ',1.. II" ._ _ Bill r""'L._,. iI % Lithology Cgl Sst Ls Sh Customer: Kerr McGee Report No.: 15 Well: Nikaitchuq #4 Date: 02/16/2005 spe....,....,y- sun Area: North Slope Depth 4861 DRILLING SEAVIC:ES Lease: NW Miline Point Ftg last 24h's 0 Rig: Nordic 3 Rig Activity: Drilling Cmt Mudlogger's Morning Report Job No.: AK-AM- 0003523133 Report For: Springer 1 Durkin Daily Charges: $3,375.00 Cumulative Charges: $67,255.00 "i~~~f,!;::~:::;,¡;¡;.__::;;:J;~""M~"'41=::~' I.," '~"m,. Current 14 hr Avg 14 hr Max Pump and Flow Data 0 ftlhr 0 ftlhr ( 0 @ 0 Pump 1 55 spm Flow rate 269 gpm - 0 units 0 unit~ ( 0 @ 0 Pump 2 55 4.483 gps Temp Out 80 Deg F ( Pump Liner 5.0 x Stk 10 in. SPP 0 :~'!U'N"I :'.:C~O~;:r1.:~1\k~!3i;.~j¡~:u _:..1 '1,.1) II 1II..~U=l._ Mud Wt In Mud Wt Out 9.35 9.35 ppg ppg Vise 40 sees PV 21 eP YP Fit 1.0 ml HTHP 5.5 m Mud Wt at Max Gas 7 Ibs/100ft2 Gels 4 \ 7 \ 9 pH ~ppg 9.5 Sd ~ 0 % -- 6 Type: 3ec:DBS/FM364' Bit Size: 6118 Jets:.J.Q.... X.J.Q.... \ 10 \ 10 \.J.Q.... \ .J.Q.... TFA: 0.4600 38.00 RPM: 56 Hrs. On Bit: Total Revs on Bit: Footage for Bit Run 0 ~l.:.::n:m·-,,·.:':"\;~'t¡;~~_~~\l:f<;=·......=:..t;:',":I:~:,:::t!1:k._ '" ",.... L.. _.k=:x.t::=:;;I.}í1lL. ,~.J::J:::OC=.=- m:r Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 45000 ppg Short Trip CI: Feet of Fill on Bottom: J:..,1Il 1Il'f.II.,~IL"L ~Z-:<;;1'Tci1~~ry..~;':þ,,_t,rìti.-:-~'¡ ¡_,--~~ ~.:' 'J}d r~ i - ii:;Jii~ ~¡fÏ¡ 1:Q.-~":\~~:',l=~~.I..:~:X<~=_-·-I~~--_-~_~~::,Il;I_] Current Lithology: 50 % Sand % Cly/st 50 % Sltst % ft ft ft units units units Connection Gas and Mud Cut ppg ft units ppg ppg ft units ppg ppg ft units ppg :(,c.,~J;';I!:.~~OC::.::::::;1.!~~~~JL.=: ft ft ft % IL. units ppg units ppg units ppg % Lithology ~ I Cgl Sst Ls Sh Drilling Breaks before Drill Rate during after before Gas during after Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. Logging Engineer: Mark Lindloff I Wayne Hermanson * 10000 kl A [ , , I ¡ . units = 100% G" as In Air~, ,! ~1'~\..., 24 hr Recap: Finished P/U BHA, Slip and cut drill line, Serviced top drive. RIH while P/U 4" drill pipe. Continue to RIH T/2836' md. Drill es plug, continue to RIH, Tested Casing to 3500 PSI, Past, Drilling cemenUfloat equipment at present time. Customer: Kerr McGee Report No.: 16 Well: Nikaitchuq #4 Date: 02/17/2005 spe....,....,v- sun Area: North Slope Depth 5946 DRILLING SERVICES Lease: NW Miline Point Ftg last 24h's 1085 Rig: Nordic 3 Rig Activity: Drilling Mudlogger's Morning Report Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $70,630.00 .. _,.",i\;rH·'!!T--Ir Current 24 hr Avg 14 hr Max Pump and Flow Data 185 ftlhr 109 ftlhr ( 365 @ 4874 Pump 1 60 spm Flow rate 294 - 940 units 330 unit~ ( 1007 @ 5937 Pump 2 60 4.9 Temp Out 80 Deg F ( Pump Liner 5.0 x Stk 10 SPP 3489 Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg Vise 57 sees PV 24 cp Fit 1.0 ml HTHP 5.0 m Mud Wt at Max Gas YP 12 Ibs/100ft2 Gels 5 \ 7 \ 9 pH ~ppg Sd -1.5 % -- 6 Type: 3ec:DBS/FM364' Bit Size: 6 1/8 Jets:...!Q.. X ...!Q.. \ 10 \ 10 \...!Q.. \ ...!Q.. TF A: 0.4600 54.00 RPM: 64 Hrs. On Bit: 14.8 Total Revs on Bit: Footage for Bit Run 1085 n=:::::'~"H",..L!!k~¡:;;,¡;::.;;:,¡;:;;:;;:r,;ì;:::]UC':':_"::·""':r.;w:. . II IH ìU~ I -.-.. 1_ II. Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: 45000 ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft \':;';¡;"~,IJ:L:;;l::ßT~~:;:;::::';:;&J~J>~"\",~¡:;¡;:=:::.:.:!;:\îU,~,,.L.. I _,L'::Il, J G,III!. - .';;:';":_L':'L__.. .11 I I Current Lithology: 70 % Sand 1 0 % sst 20 % ._.:::::~).:r:W:Jm:rL.C':'~,.~,_"':,,:.,I._._,JL:::fj,~~l,., I Sltst % % JÎ_~_:':':.....H. _".,'L,:.;,:C:t:r..".. L~-. :Jl.. ~ ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ft units ppg ft units ft units ppg ft units q:;j,~~!r!'G:_, fiI" Jf=.=t:,:.:.:=ìL..:.=..,.::::t:J~=" ..1!'..~£\.,'" ppg ppg ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth to to to to 1, 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Finished P/U BHA, Slip and cut drill line, Serviced top drive. RIH while P/U 4" drill pipe. Continue to RIH T/2836' md. Drill es plug, continue to RIH, Tested Casing to 3500 PSI, Past, Drilling equipment at present time. Logging Engineer: Mark Lindloff / Wayne Hermanson * 10000 units = 100% Gas In Air :Ii ;M--, " DRI L'-I N G SeRVll::ES Customer: Kerr McGee Report No.: 17 Well: Nikaitchuq #4 Date: 02/18/2005 Area: North Slope Depth 7324 Lease: NW Miline Point Ftg last 24h's 1378 Rig: Nordic 3 Rig Activity: Drilling Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $74,005.00 ~;~:~=';:';:JL'/ûj ...11.1' :I=¡::!!~;t::~:x::r:-~::[::I.:-J.-'::..l:"·r::~,J-IL=::''::C,I· ilL..... ¡ spe....,....,v- sun Mudlogger's Morning Report Current 24 hr Avg 14 hr Max Pump and Flow Data 131 ftlhr 72 ftlhr ( 185 @ 6097 Pump 1 58 spm Flow rate 283 gpm 1095 units 825 unit~ ( 1320 @ 6352 Pump 2 58 4.717 gps - 80 Deg F ( Pump Liner 5.0 x Stk 10 in. SPP 3657 '(ll ~~.::u;:::_:r:.:íII.,..,~'¡,;¡:;;:;;;::l:1!;..~~:>;~~':'r:,l'" .~.'::l. :T!I,JL.,~,:.l_. _~. _:J!Ir_~ 11.1 C. . i..., n Mud Wt In Mud Wt Out 9.3+ 9.3+ ppg ppg Vise 68 sees PV 28 cp Fit 1.0 ml HTHP 1.5 m Mud Wt at Max Gas YP 19 Ibs/100ft2 Gels 8 \ 11 \ 15 pH ~ppg Sd ·1 % -- .. ~:l__II\:1C.JJ~~A::;~,"1"'1';;::;r::i!LJ._II~.. _ l.1.1':';:¡~JI..IL:::J. ::111 BlUJ.. ft ft ft units ppg units ppg units ppg ,JIIIU.:J"~~~IJl,_In.'L.I::'I"!I:;.:r:"·- . Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg . II :__ '-.·:m¡':;;-=tt:.1:..~='::'ll._J[ J[::.:t::...~ ft ft ft JIU.,:__.I n" units units units 6 Type: 3ec:DBS/FM364' Bit Size: 6 1/8 Jets: ~ X ~ \ 50-55 RPM: 68 Hrs. On Bit: 34.2 Total Revs on Bit: JLII'::;..::::::::::,:,J, "":'I'·BIL:uI.,iJ..Jm::J1,,.:·~l:::::::.\Lu:..:..r.t;::;.::L:._. 1 0 \ 1 0 \ 1 0 \ 1 0 TF A: -- Footage for Bit Run III ':11. ¡c:...;:;r.;.-. .Il·,.,.:._~]_ Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: Tight Spots: to to to Feet of Fill on Bottom: =-':;~:I.;JJW.,Q.,~"..=:LI] 1..... . 11::::r=.J(,::L...I~'a'\\L\,"'l.Ù.tU.JL ~,.AL::.J'ä::::~I,I' 11I..._ ,:....1... }"", urrent Lithology: ~ % Sst 20 % Lst % % % :1j;IQ::t.l.JIU.Ø,I.]. ,::-.=:.::r::~""il:_J:t:::n:-':hn '. .~::.I"":'::ht",.,;;;.ulh.a::-:~_ll~,I..I::h' '. _ ,_ fL 1.",[. 1LL:__i.JII. _..,. "':::=:11... II Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. .... 1- ~. .... 24 hr Recap: Drilled and slide ahead. Logging Engineer: Tom Mansfield I Wayne Hermanson * 10000 units = 100% Gas In Air Mudlogger's Morning Report Customer: Kerr McGee Report No.: 18 Well: Nikaitchuq #4 Date: 02/19/2005 Area: North Slope Depth 7577 Lease: NW Miline Point Ftg last 24h's 253 Rig: Nordic 3 Rig Activity: Drilling Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375.00 Cumulative Charges: $77,380.00 ·~'::[;~r,.r4!..;,;L,".':::]IL'C.~:~:.JU:·=X=Œ 'Im='C2t-,,1 ,~ III,!1[1"rr ' sperrv-sun DR I LLI N G SERVI c:e 5 Current Temp Out ftlhr units Deg F 24 hr Avg 52 ftlhr ( 955 unit~ ( ( Pump 1 Pump 2 Pump SPP ·T;,I.. .. kt;';'::t' I Liner 5.0 x Stk gpm gps in. 180 1430 14 hr Max @ @ 7265 7550 Pump and Flow Data spm Flow rate Mud Wt In Mud Wt Out 9.3+ ppg 9.3+ ppg Vise 68 sees Fit 1.0 ml HTHP 1.5 m Mud Wt at Max Gas PV 28 cp YP 19 Ibs/100ft2 Gels 8 \ 11 \ 15 pH ~ppg Sd ~ 1 % .,~;¡;;P;;~~, ;·"X';;;¡:';:l\:,..1i,.~"'!.':5;::'!:"""':_,"":'J:I" III 1L...JI,.",.u.~,.,., ;.. '''1'''[" ,. .. 'II, _.. .11LJìL.UI!!IL...._ 6 Type: 3ec:DBS/FM364' Bit Size: RPM: H~.OnB~ 61/8 Jets: 10 X 10 \ 10 \ 10 \ 10 \ 10 TFA: 0.4600 -- -- 39.1 Total Revs on Bit: Footage for Bit Run 2716 . ""\'t:::j.'~K,,':''';':..=L:._. 'I':::·'-.::.,~=.:.:..nll:"'_-' 1I!r"'-Irir" .. Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: 1310 to to Mud Cut: Mud Cut: to ppg Trip CI: ppm ppg Short Trip CI: ppm Feet of Fill on Bottom: ft .DU ....(...., ~"...JII.L...;,..L.:.._.~'I .. Current Lithology: 100 % Sst % % '¡"¡\l',1.'t.Jiî.L~.i':':_::JD::''':.'=:lr.J:)L~JJ..~,if~.:r:nL I ,_ l.::==:t-:'!'C::(.J__..,~,. ..,.., . I II % % <~:~~,t;'.,~.t:::.::::::I::t:l[;L::J1I':""L1__rr:1rt___I...L,.u, 1.[ [~.,.__.JI-] ·.I._ll.,I.l Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ,,JI,OJ.~t:=.L:;~':"'·l1f1t:::::rr"::I.~IL..:~::"'L;:::.::.:t::::_ T 11., 1'l'1I'Jt1Th:::JI':"':'~, Ì\.:'('''II',..I ft units ppg ft units ppg ft units ppg 111' ilL. .'1. ......"",,;.11IiI11111.1IU1 before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Drilling Breaks Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. R 24 hr Recap: Drilled to 7577' MD, 4185' TVD, TO of well. Circulated BU 3X. Pumped out of hole to shoe @ 4851'. RIH. Circulated BU 3X. Short trip gas of 1310 units. Spotted 130 bbls of new 9.3 ppg mud in open hole. POOH to run 3 1/2" slotted liner. Logging Engineer: Tom Mansfield I Wayne Hermanson * 10000 units = 100% Gas In Air :·2"$7'::-; ....-."- I_~....,<..~,. ',-' :..'.""""""'-""¡(þ" ..:.....,.., '.~ m...... ....... ._...._.,............. ......._ ._".....".,....._~ Customer: Kerr McGee Well: Nikaitchuq #4 Area: North Slope Lease: NW Miline Point Rig: Nordic 3 Job No.: AK-AM- 0003523133 Daily Charges: $3,375.00 Report No.: Date: Depth Ftg last 24h"s Rig Activity: Report For: Cumulative Charges: -I,:..L·:II1~n.l-L::.~.1j, . spef'"'"'.......v- sun DRILLI N G seRVI c:::es Mudlogger's Morning Report 19 02/20/2005 7577 o Run Liner Springer I Durkin $80,755.00 Current 24 hr Avg 14 hr Max Pump and Flow Data ftIhr ftIhr ( @ Pump 1 spm Flow rate gpm units unit~ ( @ Pump 2 gps Deg F ( Pump Liner 5.0 x Stk in. SPP Mud Wt In Mud Wt Out Vise 80 sees Fit PV 29 cP YP 19 Ibs/100ft2 ml HTHP 4.5 m Mud Wt at Max Gas Gels 9 \ 13 \ 16 pH 9.30 ppg 9.30 ppg -- 1...1,. ._."."".,.Jll!îlC.,.L:I ~".JIIa.rI._II'fL~. L Sd ppg ~2 % Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ......J...1U::1 .1!J.1r [,..,. IJ ppm ppm ft Type: RPM: Bit Size: Jets: X -- Hrs. On Bit: Total Revs on Bit: .:::.;;;;~::l:.:.I.::'~t: ,.....:.:.:..:J:...;:;:..:xL__:t· :::1 \ \ TF A: -- Footage for Bit Run I:LIl:t;::;:;::"'; _ ""III .. -.''if' , J;.,...~1J.:~.¡~'lli\l%1J[r~ _~~~;::L._~;;:¡~ -J!~;;,Q,r~1:=::::, nt Lithology: ~ % Sst % % % ",,_. r;:::.::1I-:=·J:::':I:r-:·~~:;;:r:,.L.I:;:'::;::L::..._".JI ..._"I.",..,I.,...,'..~-1.1··,....·=tll. I.... ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg .XJ!'.':!(:-c:.:.:n "IUI ft units ppg ft units ppg ft units ppg .::JtF~:"" -. .. .1..::_: ï. .. ,~lI,,1III units units units Drilling Breaks Gas during Depth Drill Rate during before after after before to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A -' % ..1.. % Lithology Cgl Sst Ls Sh oz. 24 hr Recap: Finished POOH & UD 6 1/8" BHA. Tested BOPE. Cleaned pits for displacing with 9.3 ppg brine. R/U to run 3 1/2" slotted liner. RIH wI slotted liner on DP at report time. * 10000 units = 100% Gas In Logging Engineer: Tom Mansfield I Wayne Hermanson J:J R ILLI N G SERVices Customer: Kerr McGee Report No.: 20 Well: Nikaitchuq #4 Date: 02/21/2005 Area: North Slope Depth 7577 Lease: NW Miline Point Ftg last 24h's 0 Rig: Nordic 3 Rig Activity: Run 2 7/8 tubing Job No.: AK-AM- 0003523133 Report For: Springer / Durkin Daily Charges: $3,375,00 Cumulative Charges: $84,130.00 ¡':;:;;¿;::J'~:-'.=:..:::_);::~:-::,..:::~:,;,,¡;,;~'Wtl.'---_,.__~~~"'=::;::t~~:;:r"Cj JiU.,L....:xc:::=rn UL..I{" spe....,....,v- sun Mudlogger's Morning Report Current 24 hr Avg 14 hr Max Pump and Flow Data ftIhr ftIhr ( @ Pump 1 spm Flow rate gpm units unit~ ( @ Pump 2 gps Deg F ( Pump Liner 5.0 x Stk in. SPP !1!t:~",,:Jìì!"~~~'}~i~' I" ":~,,~~.J::C¡;;;¡¡.;.)I;;;~~~J:J:. ::::,,:.:'tHJ ,.~ ":-_.,IIIII! (':._U .. ,....,..;.:::L:;~Üì ¡Mit::--=-..Uf '..' Mud Wt In Mud Wt Out 9.30 9.30 ppg ppg Vise PV 28 sees cp YP Fit Ibs/100ft2 ml HTHP Gels Sd -- m Mud Wt at Max Gas \ pH ppg .. "C!.tJ.:L~~~..:. ::::::r:;;.t:¡;;::.L, ..:IR:::-:;;;,;;.t';L..:" ;';;:-"J ...IL..L:l:::::::::::::;;:_.. ._::-..J...DI.:_,...LL.," ·-C::..":J.~ 11_. Type: RPM: Bit Size: Jets: X \ \ TFA: -- -- Hrs. On Bit: Total Revs on Bit: Footage for Bit Run ....-Q..;:.".:...I::..:':::::.\..;]I:::::·.:r;.:;:,;IIL ...::l1:..1:T'I!!_':;:" ..·....lr__:c~..:..:..lr·:;;·:Jf:..·....ll..l· II Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: ppg Trip CI: Mud Cut: ppg Short Trip CI: to Feet of Fill on Bottom: .."'W~::::_:~I!:..,:;:·.:L.· ~.._] II· .r I ."L:. .1..:.J.,~,"·~'!'~ft.~':J~~_L__.. ,.....: ':::::X:.L.... Current Lithology: % % % % % .. ,~'!!td:L't;;;c:;::r:::-" . DIL._ 1:Ji.. _...In:", . ,..1 .. JIll... ..iI(......"~n~..-.1...,,..IÏ....._ LI . ,. ft ft ft Connection Gas and Mud Cut units ppg ft units ppg units ppg ft units ppg units ppg ft units ppg 'oI&.\::lIt2î~;')¡;¡¡¡¡1Ii!1f~,~~J:í:j'l~r.::. '"L',~~"";~;::::\I~C--I" n:::J.::.. ft ft ft Il..l-.xn . t > _ .oo units units units F ~ ppg ppg ppg _I., : ~ Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth to to to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. . ,,]I ilLJIIn 24 hr Recap: Finished running 3 1/3" slotted liner. Set hanger/packer and test to 2500 psi. Displace well to 9.3 ppg brine. POOH w/ DP. RIH w/ ESP completion string. Logging Engineer: Tom Mansfield I Wayne Hermanson * 10000 units = 100% Gas In Air I I sper'r'v-sun [J RILL.. I N Gi S E R V I c: E S WELL NAME: OPERATOR: CONTRACTOR: Nikaitchuq 4 Kerr McGee Oil & Gas Corp. Nordic Calisa Rig 3 LOCATION: AREA: STATE: Spy Island North Slope Alaska I BIT RECORD I BIT I # 2 I 3 CORE1 4 RR2 I 5 6 I I I I I I I I I I I I Bit Type Bit Bit Depth Depth Footage TFA Remarks Size Hrs IN OUT 12.25 30.50 115 2464 2349 0.750 8.5" 16.90 2464 4120 1656 0.590 8.5" 7.00 4120 4180 60 na Cut 60' of core in Schrader Bluff 8.5" 2.30 4180 4310 130 0.590 Finish vertical section. 8.5" 25.50 2863 4861 1998 0.628 Plug back & kick-off at 2863' 6.125" 38.20 4861 7577 2716 0.460 Finish lateral 7577' MO; 4185' lVO HTC GT1 HTC GT1 HTC GT1 HTC MX-C1 See DBS FM364 ---------- - -- - _.._~- Sperry-Sun Casing Record Company: Kerr McGee Corporation Lease Drilling Services Well Nikaitchuq 4 Area North Slope - Alaska 13 3/8" CSG 115 ft MD Rig Nordic Calisa Rig 3 Job No: AK-AM-0003523133 95/8" 2464 ft MD Water-based Mud Record Mud Co Baroid Spud Date 01 Feb 2005 7" Liner 7577 ft MD TD Date: 18 Feb 2005 Date Depth Wt Vis PV YP Gels Filt Cake Solids Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft-MD ppg see Ib/100 Ib/100ft" m/30m 32nds % % % ppm(k) Ca++ 31-Jan 115 8.9 84 15 32 12/15/16 13.2 62.0147.0 1 0.7 95.6 7.8 0.02/0.60 44 80 31-Jan 115 8.9 84 15 32 12/15/16 13.2 62.0147.0 1 0.7 95.6 7.8 0.02/0.60 44 80 01-Feb 425 9.4 42 11 19 8/16/21 8.8 41.0/30.0 1 4.7 92.2 4.0 0.10 9.2 6.0 0.08/0.45 39 160 Spud 02-Feb 2042 9.5 43 13 13 11/15/21 10.8 39.0126.0 1 5.8 91.8 2.0 0.10 8.9 5.0 0.04/0.40 30 200 Dill 03-Feb 2464 9.7 43 16 18 9/16/24 7.6 48.0/33.0 1 6.2 90.5 1.3 0.10 8.6 10.0 0.05/0.50 41 39 Dill 04-Feb 2464 9.4 39 11 12 4/10/14 9.4 34.0/23.0 1 4.1 92.3 0.1 8.7 10.0 0.05/0.40 44 400 Run 9 5/8" csg 05-Feb 2464 9.4 39 12 11 6/12/15 9.2 35.0/23.0 1 4.4 92.0 0.1 0.04 "8.5 10,0 0.04/0.44 44 380 Cement 06-Feb 2464 9.4 37 9 10 3/6/1 0 6.8 28.0/19.0 1 4.4 92.0 0.1 0.30 8.8 7.5 0.20/1.70 45 240 BOP's 07 -Feb 3194 9.4 38 10 10 4/8/11 6.2 30.0/20.0 1 4.0 92.2 0.1 0.30 8.6 8.0 0.30/1.60 47 280 Drill 08-Feb 4120 9.4 42 14 15 5/7/9 5.5 43.0/29.0 1 3.9 92.2 0.2 0.26 9.0 5.0 0.1010.70 48 380 Pick up Core bbl 09-Feb 4180 9.3 39 9 7 2/3/5 5.8 25.0/16.0 1 3.6 91.8 0.25 9.3 7.5 0.20/0.65 45 400 Pull Core bbl 10-Feb 4300 9.3 40 10 11 3/5/8 5.8 31.0/21.0 1 3.5 91.8 0.25 9.3 7.5 0.35/0.70 46 380 Drill 11-Feb 4300 9.3 40 10 11 3/5/8 5.8 31.0/21.0 1 3.4 91.8 0.25 9.3 7.5 0.3010.70 47 380 Log NOTE: End of Nikaitcuq #4PB1 & beginning of Nikaitchuq #4 . 12-Feb 3735 9.3 44 9 12 4/12/21 6.4 30.0/21.0 3.5 92.1 0.5 0.90 10.7 6.0 0.2010.85 42 680 Dir'l drill 13-Feb 4861 9.5 42 11 13 5/13/18 6.6 35.0/24.0 4.8 90.5 0.3 0.25 9.5 6.0 0.2010.56 45 600 Trip 14-Feb 4861 9.5 42 10 14 4/12/18 34.0/24.0 4.8 90.6 0.4 Clean pits 15-Feb 4861 9.4 40 21 7 4/7/9 5.5 49.0/28.0 7.9 14.0 0.0 Drill out cmt 16-Feb 4861 9.4 40 21 7 4/7/9 HTHP Enviromljl 17-Feb 7247 9.4 68 28 19 8/11/15 4.8 80.0/50.0 8.4 18.0 1.5 18-Feb 7577 9.3 80 29 19 9/13/16 4.5 77.0/48.0 10.6 16.0 2.0 TDwell 19-Feb 7577 9.3 80 29 19 9/13/16 4.5 77.0/48.0 10.6 16.0 2.0 Test BOP's 20-Feb 7577 9.3 28 4.3 96.0 93 KCL Brine 21-Feb 7577 9.4 28 4.7 96.0 96 KCL Brine . I I I sperry-sun Well Name: NIKAITCHUQ #4 Depth (MD) 4135 to 4148 ft Location: NW MILNE PT (TVD) 4135 to 4148 ft DRILLING SERVICES Operator: KERR MCGEE Show Report No. 1 Show Report - Report Prepared By: Wayne Hermanson / Mark Lindloff DatelTime: # 02/07/2005 Report Delivered To: TAVIA BICKLEIN , a Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sand: clear to translucent, light to dark brown, white, black, very fine to fine grained, occasionally fine to medium grained, poorly sorted, angular to sub angular, chert/quartz! occasionally calcareous, pyritic in part, abundant free oil, mustard yellow florescence, bright yellow cut florescence at shakers. Abundant oil observed at shaker. Samples indicate a good oil show. Note: Bottoms up was not circulated. I I I I I I I I I I , I I I I ~ Depth # 4148 ft Gas.W_~°nit~~39~~d~hlorides (1000'S)--56- ·---Fïõvvañe-------~üctiõ-ñ------l;hõvv----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 40.0 - 0.00 = 40.0 - - 0.3 - 0.00 = 0.27 - - 0.1 - 0.00 = 0.10 0.2 - 0.00 = 0.21 - - 0.1 - 0.00 = 0.09 Hydrocarbon Ratios C1 C2 C3 C4 C5 C1/C2 = C,1/C3 = C1/C4 = C1/C5 = 146.0 396.0 191.4 470.6 - ·--Prõaüclrõñ~-----~-----::::=:::---------------------------------------------- Analysis fXlGas rqOil nwater nNon-producible Hydrocarbons ...!J Depth ft Gas ~~nits _ Mud Chlorides (ppm) = ·---Fïõvviiñe-------~üctiön-----l;hõvv----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = - - - C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - ·--Prõaüclrõñ------::::=:::-----::::=:::----------------------------------------------. Analysis nGas nail nWater nNon-Producíble Hydrocarbons '.2J Depth ft Gas ~~nits Mud Chlorides (ppm) = ·---FTõvvañe-------~üctië)ñ------l;hõvv-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = - - - C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - ·--Prõaüclrõñ------::::=:::-----::::=:::----------------------------------------------. Analysis nGas nail nWater nNon-Producible Hydrocarbons ...±J Depth ft Gas ~~nits Mud Chlorides (ppm) = ·---Fïõvvañe-------~üctië)ñ------l;hõvv----------------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = - - - C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - ·--Prõaüclrõñ------~-----========---------------------------------------------- Analysis '" nGas nail n\iVater__nNon-producible_HYdrocarbons_ C1 C2 Hydrocarbon Ratios C1 C1 C3 C4 C1 C5 1000.0 ------- ~-, _:-~~-~ -_:=~=-- --~~-- -.---- ----~ ----- -- NPH ---- ---..- -- ------- . t --~ --- 100.0 --=~_==:~=;;.~ ~_....:c~__.-= =~~__.~= - - -- --------~-~-- ------------ Gas -- --.------ .--- --~---_..- -.- ---------------- -- ------ ---- ----- 10.0 - --------..--.------ ---.-.----- ~---_. -- --.-----.--" ~._---- -------------------.-.--- ------._- ---"."--..-. --- ----,--- Oil -- -----------,--- ------.----- ---------.-- - ----------- ."-----------_._---_._"-----_.~.. NPH 1.0 C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ' 1000.0 - - ~--_.._-~ ~.._~ -- ~---- --- -..-- -- -- -_._--~----- ~_._---~-- NPH ---------.------ -~-~---- ..._----,----- _______n 100.0 -- -- =~ ~-~~~ ",,-:.~:-:'"._-'---= =--=-=== --- .- ---- Gas ----- - -:;;----....------ - - - - 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 sperry-sun Well Name: NIKAITCHUQ #4 Depth (MD) 4801 to 4853 ft Location: NW MILNE PT (TVD) 4142 to 4153 ft DRILLING SERVICES Operator: KERR MCGEE Show Report No. 2 Show Report - Report Prepared By: Wayne Hermanson I Mark Lindloff Date/Time: 02/13/2005 Report Delivered To: TAVIA BICKLEIN Interpretation: Chromatograph gas in air analysis from gas trap at possum belly. Formation: Sand: medium to dark brown, black clear to opaque, subangular to sbround, moderately sorted, predominately quartz, occasionally chert and lithic fragments, abundant (whole sample) fluoresces mustard yellow, free oil and abundant oil over shaker, good to excellent inferred porosity. Sample indicates a good oil show. ~ Depth # 4831 ft Gas _M~Onits 539MudChIOn~~S(1000'S)uu56 ---FïõŸVnñë-------15üëiiõñ-------Shõvv-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) 42.2 - 0.00 = 42.2 - - 0.3 - 0.00 = 0.31 - -- 0.1 - 0.00 = 0.10 - - 0.2 - 0.00 = 0.18 - - 0.1 - 0.00 = 0.08 C1 C2 C3 C4 C5 Hydrocarbon Ratios C1/C2 = 135.8 C1/C3 = 414.0 C1/C4 = 235.9 C1/C5 = 515.0 - --Prõdü-ëiTõñ------========-----========----------------------------------------------. Analysis fXlGas pqOil nWater nNon-Producible Hydrocarbons ..2J Depth ft Gas ~~nits _ Mud Chlorides (ppm) = ---FïõŸVnñë-------15üëiiõñ-------Shõvv-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = - - - C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - --PrõdüëITõñ------========-----========----------------------------------------------. Analysis nGas nOil nWater nNon-Producible Hydrocarbons '2.1 U Depth ft Gas U~nits Mud Chlorides (ppm) = ---FïõŸVnñë-------15üëiiõñ------lšhõvv-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = - - - C5 - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - --Prõdü-ëiTõñ------========-----========----------------------------------------------. Analysis nGas nOil nWater nNon-PrOducible Hydrocarbons ...iJ Depth ft Gas ~~nits Mud Chlorides (ppm) = ---FïõŸVnñë-------15üëiiõñ------lšhõvv-----------------------------------------------. ppm ppm ppm (Steam Still PPM's in 1000's) C1 - = - - - C2 - = - - - C3 - = - - - C4 - = C5 - - - - = Hydrocarbon Ratios C1/C2 = C1/C3 = C1/C4 = C1/C5 = - - - - --Prõdü-ëiTõñ------========-----~----------------------------------------------. Analysis u nGas nOil [lwater [lNon-Producible Hydrocarbons C1 C2 Hydrocarbon Ratios C1 C1 - - C3 C4 C1 C5 ~ 1000.0 --~--_...__.~-~---- -~------- ----~-_.- ---,~--_...._._- -----~---- -.----.. .-.-------,-..----- ==-=~==--==-=-~- ----=~'~-~~-~_._=---=-=~=- ~------------- -.-. ~_.------ ~-~- ~-- -~--- NPH --- --.--- ---_. - . ~----_._- --------- --.. . - ~ ~ 1 00.0 -~=-~~~:-:::::- ~=~:_=-: - .-._~ -.-'"---------..- ---------- --'--.--.--- Gas -- --'- ---.---.-----------..---...---..--- -------..-- .-..- -...-------- ------.-- ------::..---::.-_.,;;;----~-- ----- ---- - - 10.0 - -------~ - ~-~-~-~---- --------...- --.- ---- --.---.-------.-----.--- -- --------~ ----_._~----- -_._--~------ -----.- --_._~-~----- Oil -- ~ - ---- ---- .. ------------- ._------------ .------------.---- -.---.- NPH 1.0 Hydrocarbon Ratios C1 C1 C1 C1 C2 C3 C4 C5 1000.0 ------~---.._---_." --- - ----- -~- -~-- ---------- -~---~~ ~_. ---- --------~- --------- - . .__m._.._ ______"__.._.__._ NPH ----------------- ---~- --- 100.0 - -. --_'?-=::::~ -- ~~~;:;,;- =-~-'-:::=:-=~== -..--.-.-- ---- -------- -~~-- -~- - ------ Gas -_._--~------ - - --;;;------_----.!I!'" ---- ----- 10.0 --- ------ -- --~ - --- -- ---- - - ~-- - Oil- .--.--- . -_._------~._._----- . .-- --- -----_.~- ---.-.--------- -- ---_.__._--_._..._-_._~ ---------- NPH ~-_.- --------.-.-.-- -~_._--- 1.0 I I OHALLlBURTON° I DIRECTIONAL SURVEY REPORT Kerr-McGee Oil & Gas Corp. Nikaitchuq #4PB1 Nikaitchuq Unit I North Slope Alaska USA AK-AM-0003523133 I I 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 204.13 2.81 82.61 204.05 0.64 N 4.96 E -2.38 1.38 294.31 2.30 74.73 294.14 1.40 N 8.90 E -4.07 0.69 386.47 1.24 69.66 386.25 2.24 N 11.62 E -4.99 1.16 477.59 1.41 75.96 477.35 2.85 N 13.63 E -5.67 0-:-25 I I 1039.73 1.24 68.30 1039.27 8.29 N 27.89 E -9.62 0.86 I 1134.68 1.30 78.64 1134.19 8.88 N 29.90 E -10.32 0.25 1228.46 1.36 92.64 1227.95 9.04 N 32.06 E -11.45 0.35 1324.18 1.47 103.37 1323.64 8.70 N 34.39 E -13.09 0.30 1418.77 1.38 110.56 1418.20 8.02N 36.63 E -14.95 0.21 I I 1989.13 1.59 106.24 1988.35 2.39 N 51.21 E -28.05 0.14 2084.30 1.60 110.18 2083.48 1.56 N 53.73 E -30.20 0.12 I 2179.53 1.63 102.66 2178.67 0.81 N 56.30 E -32.32 0.22 2274.24 1.46 104.19 2273.35 0.22 N 58.78 E -34.25 0.18 2369.41 1.48 106.06 2368.48 0.42 S 61.14E -36.15 0.05 I I 2937.80 1.27 92.64 2936.71 2.50 S 74.60 E -45.71 0.26 3032.57 1.23 86.90 3031.45 2.49 S 76.67 E -46.92 0.14 3128.01 1.47 74.79 3126.87 2.11 S 78.87 E -47.90 0.39 I 3223.00 1.30 76.02 3221.83 1.53 S 81.09 E -48.74 0.18 3317.74 1.44 75.10 3316.54 0.97 S 83.29 E -49.56 0.15 I I 3888.81 1.22 95.55 3887.50 0.50 S 94.64 E -55.83 0.26 3983.27 1.39 91.45 3981.93 0.62 S 96.78 E -57.18 0.21 4058.93 1.27 88.60 4057.57 0.63 S 98.54 E -58.21 0.18 4115.93 1.34 87.42 4114.56 0.58 S 99.83 E -58.94 0.13 I 4211.39 1.13 95.63 4209.99 0.62 S 101.89 E -60.17 0.29 Page 1 of 2 I I <:iHALLlBURTON' I Nikaitchuq #4PB1 I I I I I I I I I I I I I I I I I Date Printed:19 March 2005 Page 2 of 2 I I OHALlIBURTON° I DIRECTIONAL SURVEY REPORT Kerr-McGee Oil & Gas Corp. Nikaitchuq #4 Nikaitchuq Unit I North Slope Alaska USA AK-AM-0003523133 I I 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 204.13 2.81 82.61 204.05 0.64 N 4.96 E -2.38 1.38 294.31 2.30 74.73 294.14 1.40 N 8.90 E -4.07 0.69 386.47 1.24 69.66 386.25 2.24 N 11.62 E -4.99 1:16 I 477.59 1.41 75.96 477.35 2.85 N 13.63 E -5.67 0.25 I 1039.73 1.24 68.30 1039.27 8.29 N 27.89 E -9.62 0.86 I 1134.68 1.30 78.64 1134.19 8.88 N 29.90 E -10.32 0.25 1228.46 1.36 92.64 1227.95 9.04 N 32.06 E -11.45 0.35 1324.18 1.47 103.37 1323.64 8.70 N 34.39 E -13.09 0.30 1418.77 1.38 110.56 1418.20 8.02N 36.63 E -14.95 0.21 I I 1989.13 1.59 106.24 1988.35 2.39 N 51.21 E -28.05 0.14 2084.30 1.60 110.18 2083.48 1.56 N 53.73 E -30.20 0.12 I 2179.53 1.63 102.66 2178.67 0.81 N 56.30 E -32.32 0.22 2274.24 1.46 104.19 2273.35 0.22 N 58.78 E -34.25 0.18 2369.41 1.48 106.06 2368.48 0.42S 61.14E -36.15 0.05 I I 2863.00 1.39 86.32 2861.93 2.52 S 72.87 E -44.71 0.26 2937.44 1.44 322.11 2936.35 1.72 S 73.20 E -44.26 3.36 3032.66 5.13 323.79 3031.40 2.66 N 69.95 E -38.81 3.88 I 3127.98 9.49 326.59 3125.93 12.66 N 63.10 E -26.69 4.59 3223.17 14.31 322.16 3219.04 28.51 N 51.55 E -7.08 5.15 I I 3793.61 . 43.66 311.69 3713.12 210.45 N 149.77 W 258.30 4.53 3887.04 47.79 310.32 3778.34 254.31 N 200.26 W 323.42 4.54 3984.16 52.98 309.42 3840.24 302.24 N 257.67 W 395.89 5.39 4078.31 57.19 309.61 3894.12 351.35 N 317.22 W 470.57 4.47 I 4173.49 62.35 309.77 3942.02 403.85 N 380.48 W 550.17 5.42 I Page 1 of 3 I GHAlLlBURTON' I Nikaitchuq #4 I I I 4743.72 77.49 312.83 4129.84 758.10 N 783.71 W 1073.46 2.00 4801.70 77.69 313.34 4142.30 796.78 N 825.06 W 1129.04 0.93 4899.23 82.88 315.61 4158.75 864.11 N 893.62 W 1223.76 5.79 I 4944.03 88.02 318.39 4162.30 896.76 N 924.06 W 1268.05 13.03 4993.44 88.64 324.70 4163.74 935.42 N 954.76 W 1317.37 12.83 I I 5278.45 93.09 330.76 4164.32 1179.79 N 1101.09 W 1601.14 7.31 5323.22 91.05 330.55 4162.71 1218.79 N 1123.01 W 1645.60 4.58 5373.00 87.96 329.99 4163.14 1262.01 N 1147.70 W 1695.08 6.31 5418.59 89.20 331.05 4164.27 1301.68 N 1170.12 W 1740.38 3.58 I 5464.03 92.22 331.56 4163.70 1341.53N 1191.94 W 1785.45 6.74 I 5749.96 89.26 330.36 4163.90 1591.42 N 1330.83 W 2069.35 1.71 I 5801.31 88.70 330.51 4164.81 1636.08 N 1356.17 W 2120.38 1.13 5851.41 88.58 330.45 4166.00 1679.66 N 1380.84 W 2170.16 0.27 5896.40 89.44 330.90 4166.78 1718.88 N 1402.88 W 2214.85 2.16 5948.19 89.38 330.49 4167.31 1764.04 N 1428.22 W 2266.30 0.80 I I 6234.41 89.75 327.58 4169.34 2009.25 N 1575.70 W 2551.43 1.23 6277.34 89.26 327.74 4169.71 2045.52 N 1598.66 W 2594.28 1.20 I 6326.07 88.52 328.09 4170.65 2086.80 N 1624.54 W 2642.89 1.68 6373.02 87.59 327.64 4172.25 2126.53 N 1649.50 W 2689.72 2.20 6420.47 89.81 329.80 4173.32 2167.07 N 1674.13 W 2737.00 6.53 I I 6706.23 91.48 331.01 4177.26 2414.32 N 1817.26 W 3021.24 5.86 6751.83 89.14 330.24 4177.01 2454.05 N 1839.63 W 3066.55 5.40 6813.37 87.78 329.90 4178.66 2507.37 N 1870.32 W 3127.73 2.28 I 6848.17 . 87.59 329.94 4180.07 2537.45 N 1887.75 W 3162.33 0.56 6896.20 87.90 330.93 4181.96 2579.20 N 1911.43 W 3210.03 2.16 I Date Printed:19 March 2005 Page 2 of 3 I I C%ìHAlllBURTON' I Nikaitchuq #4 I I 7180.29 88.64 331.78 4182.27 2829.18 N 2046.25 W 3491.62 0.42 7226.83 88.46 330.50 4183.45 2869.93 N 2068.71 W 3537.80 2.78 7272.86 90.25 332.65 4183.97 2910.40 N 2090.62 W 3583.44 6.08 7322.64 89.38 332.12 4184.13 2954.51 N 2113.69 W 3632.70 2.05 7372.19 89.32 332.41 4184.69 2998.37 N 2136.75 W 3681.76 0.60 I I I I I I I I I I I I I I I Date Printed:19 March 2005 Page 3 of 3 I I I I I I I I I I I I I I I I I I I · spsr--r--y-sun DR 1L-I..ING.u $Ej:IYjJ;§.~ A IIALLIßURTON COl\-IPANY /--..-_~ EOWRlASCn FILES! //-- ---~\\ SDL LOGS-EMF ~, .~ ~ «¡.~~\ ~ 1~~4!~~r tl1 . É' "_ i~) J ~,..,....../".., \\ .,".'. -' .#-':"';" ,. ,., '" ' \':.."i:rt?Z,~rf·~\~><// '~",~.,::'~",~~=--.,.." "-~' KERR-MCGEE CORPORATION Nikaitchuq #4 & #4 PBI API#: 50-629-23241-00 & 50-629-23241-70 APRIL 10, 2005
