The URL can be used to link to this page

Home My WebLink About204-038a b1-1,- o J Guhl, Meredith D (CED) '31 9 7 4 From: Guhl, Meredith D (CED) Sent: Monday, January 27, 2020 1:23 PM To: ZuberJoshua Cc: Davies, Stephen F (CED); Spadaro Giorgio Subject: RE: Nikaitchuq 2 Core Descriptions and Photos Hi Joshua, Thank you for tracking down the photos. We will add them to the archive for Nikaitchuq 2. The AOGCC does have a copy of the core analysis report from Core Lab, I was just hoping there might be more extensive descriptions available. Thank you for checking through ENI's archive. I appreciate ENI's help in making sure the AOGCC archive is complete. Regards, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.gov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith Guhl at 907-793-1235 or meredith.euhl@alaska.aov. From: Zuber Joshua <Joshua.Zuber@eni.com> Sent: Thursday, January 16, 2020 2:01 PM To: Guhl, Meredith D (CED) <meredith.guhl@alaska.gov> Cc: Davies, Stephen F (CED) <steve.davies@alaska.gov>; Spadaro Giorgio <Giorgio.Spadaro@eni.com> Subject: RE: Nikaitchuq 2 Core Descriptions and Photos Hi Meredith, We have been through Eni data base and storage facility and could not locate any core photos or descriptions for the Nikaitchuq 2 well. We were able to contact core labs and locate core photos, I'll forward them to your office via thumb drive. My assumption is they were never turned over to us but that was before my time with Eni. couldn't locate any core descriptions other than the basic/brief ones in the document titled "Nik_02_Final_Core Analysis Rpt (07-30-04)" From the reports that we do have it looks to me that your office was include on the distribution list of the reports and should have the document. Kerr-McGee Oil & Gas Corporation CL File No.: HOU-040292 Nikaitchuq 2 Well Date: July 30, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Distribution of Final Reports Kerr-McGee Oil & Gas 4 copies 11 CD-ROM 16666 Northchase Houston, TX 77060 Attn: Rebecca Isbell Armstrong Alaska, Inc. 4 copies 11 CD-ROM 700 17"' Street, Suite 1400 Denver, CO 80202 Attn: Jesse Sommer BP Exploration (Alaska) Inc. i copy 11 CD-ROM P.O. Box 196612 900 E_ Benson Blvd. Anchorage, AK 99419-6612 Attn: Brett Chambers Herbaly Exploration LLC I copy 11 CD-ROM 1420 W. Canal Ct. Ste. 150 Littleton, Colorado 80120 Alaska Oil & Gas Conservation Commission 1 copy 11 CD-ROM 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Attn: Librarian Tim Ryherd, Geologist 'I copy f 1 CD-ROM Dept. of Natural Resources — Division of Oil & Gas State of Alaska 550 W. Ph Avenue, Suite 800 Anchorage, AK 99501-3510 Petrophysical Applications Intl, Inc. i copy/ 1 CD-ROM PO Box'130304 The Woodlands, TX 77393-0304 Attn: Dr. Robert Skopec Page 2 Report Dtstdbution Appendix 1' Joshua Zuber Sr. Reservoir Geologist eni us operating 3800 Centerpoint Dr # 300, Anchorage, AK 99503 Office: (907) 865-3388 Cell: (907) 223-6659 Mail: ioshua.zuber@eni.com From: Guhl, Meredith D (CED) <meredith.auhl@alaska.eov> Sent: Wednesday, November 13, 2019 2:55 PM To: Zuber Joshua <Joshua.Zuber@eni.com> Cc: Davies, Stephen F (CED) <steve.davies@alaska.aov> Subject: Nikaitchuq 2 Core Descriptions and Photos Hello Joshua, I have recently completed a review of all core data submitted for wells permitted between 2000 and 2019. In my review of the data submitted for Nikaitchuq 2, 1 was unable to locate core descriptions or core photos. I realize ENI was not the original operator of this well, but I'm hoping you can review the files received from Kerr-McGee and forward core descriptions and photos if found. This is a long term project, and a response would be appreciated before Feb 1, 2020. If you have any questions, please contact me. Thank you, Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Anchorage, AK 99501 meredith.guhl@alaska.aov Direct: (907) 793-1235 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Meredith GuhI at 907-793-1235 or meredith.euhl@alaska.eov. Message for the recipient only, if received in error, please notify the sender and read htto://www.eni.com/disclaimer/ 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 • Maunder, Thomas E (DOA) From: Silfven, Laurie A (DEC) Sent: Wednesday, July 02, 2008 9:55 AM To: Maunder, Thomas E (DOA) Subject: RE: Kerr-McGee -Anadarko Two Bits and NW Milne wells Thank you, Tom! Laurie Silfven Ph: (907) 269-7540 From: Maunder, Thomas E (DOA) Sent: Wednesday, July 02, 2008 8:26 AM To: Silfven, Laurie A (DEC) Cc: Gould, Greg M (DEC); 'Bob Britch'; Foerster, Catherine P (DOA) Subject: RE: Kerr-McGee -Anadarko Two Bits and NW Milne wells • Page 1 of 2 pig ~~ Laurie, et al, As requested, I have competed a file review of 8 Kerr-McGee operated exploration penetrations that were drilled and plugged and abandoned nominally in 2Q 2004 and 2Q 2005. Tota! work accomplished was 6 grass-roots wells and 2 redrills as listed below. Permit # Well Name 204-018 204-249 205-025 2o4-26a 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) ~C~aN JU1, ~ 8 2D08 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 (well abandonment. marker, onshore well Ataruq, 2I2A), 20 AAC 25.170 (onshore location clearance, Ataruq 2i2A) and 20 AAC 25.172 (offshore location clearance, remaining wells). Please contact me if further information is needed. Tom Maunder, PE Sr. Petroleum Engineer AOGCG From: Silfven, Laurie A (DEC) Sent: Thursday, June 26, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Gould, Greg M (DEC); Bob Britch Subject: Kerr-McGee -Anadarko Two Bits and NW Milne wells Hi Tom, We received a request from Anadarko to rescind two Anadarko (formerly Kerr-McGee) exploration oil discharge prevention and contingency plans. The contingency plans are for Two Bits (Ataruq) and Northwest Milne Point (Nikaitchuq). In order to do this, we need AOGCC verification that the wells were properly abandoned. Bob Britch, consultant for Anadarko, let me know that an a-mail request to you would be sufficient. According to 7/2/2008 . Page 2 of 2 Bob, the drilling performed for the two plans essentially covered two exploration wells from the Two Bits (Ataruq) Prospect and six exploration wells from the NW Milne Point (Nikaitchuq) Prospect. At your convenience, please provide confirmation that all wells were properly plugged and abandoned. Thanks! Laurie Laurie Silfven Alaska Department of Environmental Conservation Exploration, Production & Refineries Section 555 Cordova Street Anchorage, AK 99501 Ph: (907) 269-7540 Fax: (907) 269-7687 E-mail: laurie. silfven@alaska. gov 7/2/2008 Permit to Drill 2040380 ) 11001 / TVD MD '1 f1o., À~ ~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 API~.~_62~_~~_~G tf Well Name/No. NIKAITCHUQ 2 Operator KERR-MCGEE OIL & GAS CORP 9508 ./ Completion Date 4/4/2004 Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Yes Directional surv~- Samples No DATA INFORMATION Types Electric or Other Logs Run: E-Line, ,AI, Den, CNL, GR, SP, Caliper, MDT CMR, FMI, Dipole Sonic, Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Num r Name C Lis 520 Induction/Resistivity , k" Report: Final Well R ,(og Mud Log !~g Mud Log Mud Log Mud Log Dls Ìf2590 Induction/Resistivity Las ~591 I nd uction/Resistivity ~ Report: Final Well R Induction/Resistivity Induction/Resistivity Density og Density 1:Ôg Density 16g Density ~ Density Density Induction/Resistivity Log Log Interval . Run OH/ Scale Media No Start Stop CH Received Comments Open 7/2/2004 2 CD's PEX-CMR-FMI-DSI- MDT Includes .PDS & LAS. files Mud Log MD 1" & TVD 1" Engineering Log 1" 5 Col ¡V/ð Open 2 Col f/lj) Open 5 Col rv.fJ Open 2 Col ì~ Open 10200 10954 Open AIT/DENSITY/NEUTRON/ GRlSP + PDS GRAPHICS 0 11020 Open DENSITY + CGM-TIFF- EMF-PDF GRAPHICS DLlS/LAS . 0 0 EOWRlMUDLOG GRAPHICS/DIR SRVYS 5 Col foil /) 371 11001 Open DGR,EWR,ROP,BAT 5 Col Ì'VD 371 11001 Open DGR,EWR,ROP,BAT 5 Col f\/D 371 11001 Open DGR,ROP,EWR,CTN,SLD 5 Col (vb 371 11001 Open DGR,ROP,EWR,CTN,SLD 12 Co I 371 11001 Open ¡ 5 Col 371 11001 Open DGR,ROP,EWR,CTN,SLD 12 Col 371 11001 Open DGR,ROP,EWR,CTN,SLD 12 Col 371 11001 Open DGR,ROP,EWR,CTN,SLD I 25 Col fA]) 5416 10991 Open AITIDENS/NEU/GRlSP/CA J LI-PEX DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040380 Well Name/No. NIKAITCHUQ 2 Operator KERR-MCGEE OIL & GAS CORP API No. 50-629-23199-00-00 MD 11001 TVD 9508 Completion Date 4/4/2004 Completion Status P&A Current Status P&A UIC N ~-- I nd uction/Resistivity 25 Col ìv(:) 5416 10991 Open AIT/DENS/ÑEUlGR/SP/CA I LI-PEX ~ Formation Micro Ima 5 Col 10200 10994 Open GR Formation Tester OTH Col 10457 10862 Open MFDT 27 MARCH 2004 Magnetic Resonance 5 Col 10200 1 0954 Open CMR TOOL-SANDSTONE ~ MODE/EPM - 26 MAR 2004 Sonic 25 Blu 5416 10936 Open DIPOLE SHEAR SONIC . IMAGER BCRtSTONELEY/P&S 26 MAR 2004 ì5et Sample 0 0 8/30/2004 Advanced Core Analysis Study - CoreLab Core CD #12932 included in back ~ pocket 12932 RS3aFl: rirull Well R" t.."I/"-~ 0 0 3/2/2005 Advanced Core Analysis Study - Core Labs-cd # 12932 in back pocket .--1 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 3/5/2004. c ADDITIONAL INFORMATION Well Cored? ~ / N Chips Received? Y / N Analysis GN Received? Daily History Received? QN Formation Tops ~/ N . Comments: Compliance Reviewed By: ~ l Date: ÅC ß-(l)~ . . :#j!J:i)iìt!;nD3 .&i,~ ;¡¡Fjï&'J!J.jras5ai' ill) 'ü:r.n.riF~l'm,j 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. ~ ð04 - J-CøO 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 -()d-.S- earn additional acreage. After completion, Kerr-McGee will operate the well with a 55% working interest. dO'-\-o~<6 ~ 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. ~ JO.\-() \. '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 4\ I:ore Lab IESIRVGIR DPIIMlZATlD1i . . C;:<Oc(~()2 <7 Petroleum Services TRANSMITTAL LETTER TO: Librarian Alaska Oil & Gas Conservation Com. 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 FROM: TITLE: DATE: File #: Mr. Paul Delacoe Project Coordinator February 28th, 2005 HOU-040292 DESCRIPTION Please find enclosed: QUANTITY 1 ITEM DESCRIPTION Bound copy with CD of the FINAL report for the following: ADVANCED CORE ANALYSIS STUDY Kerr-McGee Oil & Gas Corporation Nikaitchuq No.2 Well N. W. Milne Point, Alaska INSTRUCTIONS: REMARKS: ge re 'pt by signing and returning one.copy. DATE: ~ RECEIVED . i To AOGCC Attn: Librarian SC_IPIIP From Aron Kramer - Schlumberger cc file Subject Nikaitchuq #2 - Final CD # I cl )';;' t:J Date June 30, 2004 To Whom It May Concern: Enclosed in this mailing are two CD$ containing field data files, field graphics files and processed graphics/data files for the following well: Kerr McGee Corporation Nikaitchuq #2 NW Milne Point North Slope, Alaska API: 500292319900 AFE: ZTGD1HA14011601 This data was acquired one Schlumberger Wireline logging run on March 26, 2004. The files are organized as per the picture below: eC;IC'¡.. ...........2 e PQJ IillØmIEll spa ____ s·OQJ- ,pa~ OQ ~l.:' 'OGi . . ....---- o ... .......... 0..._.... o . .........~ ONlk.~.. o ;i Nik-...t........~.. O~.. 0:\ft:_...M... _No o:\ft:_.JIt... _No O,\ft:_IIII_"... I'OS no Þ:\1I-.ullll_..... I'OS No Þ,\1I-.uM.JIt... LAS FIo þ,\Tt_IIII_..... _Fio O,\T__"... LAS FIo 22''' en"..... N2:0I PM 2CI.3.. ..."..-N2I11PM 22.'" ..."I2GOI7:f2:'3PM s.ø.. ...,,_7:f2:,IPM 210.. 1f11_7,3I:!lSfIM ,.u.. lfI'I2IJOIN2:CI2fIM , .... II22J2OO4 '2:"':'UM Schlumberger ;;<O~(-O~8 A STATE OF ALASKA ~ ALAS~ AND GAS CONSERVATION COMMISR" WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: OilU Gas 0 Plugged 2.J Abandoned 0 Suspended U WAGTI 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJO WINJD WDSPL 0 No. of Completions nla Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., or . 12. Permitto Drill Number: Kerr McGee Oil & Gas Corporation Aband.: April 1, 2004 204-038 3. Address: 6. Date Spudded: 13. API Number: 3900 C Street, Suite 744, Anchorage, Alaska 99503 March 13,2004 ,¡ 50-629-23199-00 4a. Location of Well (Govemmental Section): 7. Date TD Reached: 14. Well Name and Number: ,I Surface: 1293' FEL & 2240 FNL Section 22 T14N R9E UM ,I March 25, 2004 Nikaitchuq #2 Top of Productive Horizon: 10396' MD (8928' TVO) 8. KB Elevation (ft): 15. Field/Pool(s): 1119' FEL & 2598' FNL Section 15 T14N R9E UM 40ft Exploration Total Depth: I 11001' MD (9508' TVO) 9. Plug Back Depth(MD+ TVD): , 1123' FE." & 2424' FNL Section 15 T14N R9E UM 55 ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. PropertY Designation: Surface: x- 527,462.33' / y- 6,052,263.00' 0/ Zone- 4 0/ 11001' MD (9508' TVO) if ADL 355021 TPI: x- 527,610.44' y- 6,057,184.55' Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 527,605.49' y- 6,057,358.21' Zone- 4 nla 18. Directional Survey: Yes 2.J No U 19. Water Depth, if Offshore: 20. Thickness of Permafrost: MWD surveys with IRF Cazandra verification Oft feet MSL 889' 21. Logs Run: E-Line, Run #1 (BSC - 11001' MD): Array Induction, Density, CNL, GR, SP, Caliper, MDT, CMR, FMI, Dipole Sonic. LWD Logs surf to TO: GR, Resistivity, Neutron, Dendity. Surface hole only: Sonic LWD. 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD CEMENTING RECORD AMOUNT FT. TOP BOTTOM TOP BOTTOM HOLE SIZE PULLED 13-3/8" 68# L-80 33' 112' / 33' 151' Drive Pipe N/A 22' 9-5/8" 47# L-80 33' 5416' \I 33' 4683' 12-1/4" 610 sx of Perafrost "L" 22' followed by 540 sx o~ium CMT + 1 % CaClz 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) ~ None. ~"c,~\~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE "t DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED . -i~!-Qi-1 ~~~~ 11000' to 7028' 4 ea (390 sx) Premium cmt plugs (320 bbl) ¡ 1}':I.6"<; ! EZSV at 5325' with 96 sx (20 bbl) Premium , ' 1__ . _ --..-.; 5560' to 5256' cement below and 24 sx (5 bbl) above. ' " ,..~.~. 240' to 60' 75 sx (13.2 bbl) Permafrost "C" (left in hole) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): n/a Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: IGas-Oil Ratio: Test Period ... Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ... 27. CORE DATA Brief description of lithology, porosity, fractures, (appàte..nt dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none"., ~J ~-....: _ I' Core No. 1 (90 ft): 10,390' - 396': siltstone. 1 O,396~~an tone: clear, fine to very fine grained, moderately sorted, sub-angular grains with light brown stain, traces of pyrite and glaUCO~~ e yellow streaming cut and flourescence. 10,460' - 480': mixed sanstone, shale and fociliferous limestone. ~~ (Core Lab's preliminary permeability data is attached) ~\:>.; 0 .::; f .....0"'\ (Detailed core description to follow when availabl~_ Rfa 200\ 1~ld , _ _ . -. . .. . A . /'\ ~u(IIA I rU,~L I.., 11\1 !1 L J"'" \ Form 1 0-407 Revised 12/2003 CO NT ED , ì _ to~ G NAME GEOLOGIC MARKER M TVD 29. FORMATION TESTS Include and briefly su ·ze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. Top Permafrost Base Permafrost Ugnu West Sak Colville Kalubik Put Marker Kuparuk D Kuparuk C LCU Kuparuk A Kingak Sag River sand Shublik Ivishak 718' 1630' 2420' 4632' 4931' 8366' 8390' 8533' 8671' 8700' 8700' 8790' 10396' 10465' 10704' 718' 1607' 2326' 4060' 4296' 7104' 7125' 7250' 7374' 7400' 7400' 7480' 8928' 8993' 9210' None. 30. List of Attachments: Operation Summary, final well bore diagram, final survey data, E-Line 10 s (Platform Express), LWD Logs, final location plat, core permeability data. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Skip Coyner (907) 339-6269 Printed Name: Todd Durk Signature: ¡ Title: Drilling Superintendent, Kerr McGee Phone: (907)339-6370 Date: 14-Apr-04 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 Injection, 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". i'ft'¡~~ ,)~;~t . Form 10-407 Revised 12/2003 Kerr-McGee Oil & Gas Corporation Níkaitchuq 2 Well NW Milne Point Alaska PROFILE PERMEABILITY 5" '" 100' 100 0.D1 0.001 10350 10 0.1 10360 10460 10480 10500 File No Date: Kerr-McGee Oil & Gas Corporati Nikaitchuq 2 Well NW Milne Point Alaska PROFILE MEASUREMENTS 5"= 100 10 0.1 0.01 e e Kerr-McGee Oil & Gas Corporation File No : HOU 040292 Nikaitchuq 2 Well Date: April 8, 2004 NW Milne Point Alaska Profile Permeabilitv Reoort Smpl Depth Ka KI Remarks Smpl Depth Ka KI Remarks 1 10390.10 0.179 0.090 462 10437.00 0.139 0.067 10 10391.00 0.066 0.026 472 10438.02 0.254 0.140 21 10392.05 0.169 0.086 482 10439.03 0.171 0.087 30 10393.03 0.283 0.159 492 10440.01 0.296 0.168 40 10394.00 0.235 0.127 502 10441.03 0.526 0.328 50 10395.00 0.074 0.030 512 10442.03 0.265 0.147 60 10396.03 0.243 0.132 522 10443.00 1.280 0.900 70 10397.00 0.436 0.264 532 10444.02 0.750 0.495 81 10398.10 0.681 0.443 542 10445.00 1.220 0.853 90 10399.00 2.080 1.540 552 10446.03 0.282 0.158 100 10400.06 1.630 1.180 562 10447.00 0.793 0.528 120 10402.04 3.980 3.130 572 10448.02 0.233 0.126 130 10403.00 0.818 0.547 582 10449.00 0.738 0.486 140 10404.02 4.400 3.480 592 10450.04 0.556 0.350 150 10405.00 1.510 1.080 602 10451.00 0.477 0.293 160 10406.01 3.580 2.770 612 10452.02 0.660 0.428 170 10407.00 5.380 4.310 622 10453.00 0.398 0.238 180 10408.05 4.450 3.510 632 10454.02 0.232 0.125 190 10409.00 14.300 12.200 642 10455.00 0.671 0.435 200 10410.01 4.780 3.800 652 10456.02 0.468 0.287 210 10411.00 0.857 0.574 662 10457.00 0.292 0.165 220 10412.01 0.338 0.197 672 10458.05 0.751 0.496 230 10413.00 1.370 0.973 682 10459.00 0.743 0.490 240 10414.00 3.060 2.350 692 10460.06 0.233 0.126 250 10415.00 1.660 1.200 702 10461.00 0.351 0.205 260 10416.01 0.982 0.670 712 10462.03 0.973 0.662 270 10417.00 0.619 0.397 722 10463.00 0.098 0.043 280 10418.01 0.859 0.575 732 10464.02 0.084 0.036 290 10419.00 1.070 0.742 742 10465.00 0.076 0.031 300 10420.06 8.250 6.790 752 10466.03 0.075 0.031 306 10421.00 1.100 0.760 762 10467.00 0.009 0.002 316 10422.02 0.735 0.484 772 10468.01 0.119 0.055 326 10423.00 0.643 0.415 782 10469.00 0.046 0.017 336 10424.02 0.375 0.222 792 10470.03 0.092 0.040 346 10425.00 0.622 0.399 802 10471.00 0.019 0.005 356 10426.01 0.487 0.300 812 10472.03 0.058 0.022 366 10427.00 0.553 0.348 822 10473.00 0.049 0.018 376 10428.01 0.784 0.521 832 10474.03 0.170 0.086 386 10429.12 0.329 0.186 842 10475.00 0.061 0.023 395 10430.03 0.262 0.145 852 10476.03 0.112 0.051 415 10432.01 0.521 0.325 862 10477.00 0.033 0.010 425 10433.00 14.000 12.000 872 10478.03 0.091 0.039 432 10434.06 3.790 2.970 882 10479.00 0.082 0.035 442 10435.00 0.852 0.570 892 10480.03 0.213 0.113 452 10436.02 1.620 1.170 901 10480.90 0.050 0.018 T~ " E CRIPl10N DESCRIPTION NOTES: 16 15 14 o 1. COORDS SHOWN ARE AK. STATE PLANE ZONE 4, NAD27. 2. DATE OF SURVEY: 2/25/04, F.B. L04-03, pp 31-34. 3. BASIS OF LOCA nON: MON DS3R SOUTH2, BY L.H.D. & ASSOC. 4. LOCATIONS AND ELEVATION DETERMINED WITH LEICA 500 SERIES GPS UNITS, USING GEOID 99. 5. GEOGRAPHIC COORDINATES ARE NAD 27. 6. ALL DISTANCES ARE TRUE. 7. ELEVATIONS ARE B.P.M.S.L. 24 19 20 23 25 30 26 NIKAITCHUQ #2 CONDo AS-BUILT LOCA TED WITHIN PROTRACTED SEC. 22, T 14 N, & R 9 E, UMIAT MERIDIAN. 2240' F.N.L, 1293' F.E.L.'/ LAT = 70' 33' 13.987" LONG = 149' 46' 29.276" "" Y = 6.052,263.00 X = 527,462.33 ~ TOP OF CELLAR ELEV. = 6.57' 36 31 32 33 34 35 T14N OLlK OK int T13N 600 K 2 R , VICINITY MAP 1~4_ 22123 N o '<I- N N NIKAITCHUQ #2 0- 1293' ~~"""" ~...~ c. OF LIt '-. .4ti ~\\....-..........:.~ .A~..a. ~ '\ \ ~.... elt:;}, ~t .,.. .. t ¡ ;:.;.... 49th '1~;;>""~'*~\ SURVEYOR'S CERTIFICATE .,.....;...................................~.....I I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED ,....."'...................................:.....= AND LICENSED TO PRACTICE LAND SURVEYING IN THE ~ ~ \ BRIAN G. MANGOLD ¡ f5: STATE OF ALASKA AND TH A T THI S PLAT REPRESEN TS '..~ ...... LS-8626 ......t; A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION ~ ~ ..... ..... c,.,§'- # AND THAT ALL DIMENSIONS AND t.{ð þ~...............~:"'~<;) ... OTHER DETAILS ARE CORRECT AS OF ._....OF"tssIONP>\. ~..., FEBRUARY 25 2004 ..,,"'''~~ , . ß1 LOUNSBURY Ie ASSOCIATES, INC. SURVEYORS INCINBIRS Pl.AØNIRS ... AREA: MODULE: NIKAITCHUQ #2 CONDUCTOR ASBUIL T UNIT: CADD FILE NO. LK601D548 DRAWING NO: NSK 6.01-d548 PAR~ RE~ 1OF1 0 2424' FNL Nikaitchuq No.2 (Bottom Hoie Location) 15 ADL 355021 (5120 total acres) (includes sec. 14, 15, 22 & 23) Farmout from BP Armstrong 0 & G Kerr McGee 0 & G 2240' FNL 22 Nikaitchuq No.2 (Surface Location) NikaitchuQ No.2 in Section 22 T14N R9E 1293' FEL & 2240 FNL 6052263.' N & 527462.33' E NAD 27, Zone 4 in Sec 15 T14N R9E 1123' & 2424' FNL 6057358.' N & 527605' E NAD 27, Zone 4 14 23 KERR-MCGEE CORPORATION Final Weill Event Summary Page 1 of 1 Legal Well Name: NIKAITCHUQ #2 Common Well Name: NIKAITcHUQ #2 (ALASKA) Event Name: DRILLING DATE TMD 3/1112004 (ft) 3/1212004 (ft) 3/13/2004 370.0 (ft) 3/1412004 2,595.0 (ft) 3/1512004 4,943.7 (ft) 3/1612004 5,430.1 (ft) 3/1712004 5,430.1 (ft) 3/1812004 5,430.1 (ft) 3/1912004 8,002.0 (ft) 312012004 8,653.4 (ft) 3/2112004 9,575.0 (ft) 312212004 10,390.5 (ft) 3/23/2004 10,480.5 (ft) 3/24/2004 10,480.5 (ft) 3/2512004 11,001.0 (ft) 3/2612004 11,001.0 (ft) 3/2712004 11,001.0 (ft) 3/28/2004 11 ,001.0 (ft) 3/2912004 11,001.0 (ft) 3130/2004 11,001.0 (ft) 3/31/2004 11,001.0 (ft) 4/1/2004 11,001.0 (ft) 41212004 11,001.0 (ft) End Date: 4/212004 Start Date: 3/4/2004 24 HOUR SUMMARY MOVE IN AND RIG UP NABORS 27E, BALL MILL AND PIONEER CAMP. RIG UP 27E, NIU BOPE I DIVERTER SYSTEM ON CONDUCTOR PIPE FINISHED RIGGING UP. FUNCTION TESTED DlVERTER SYSTEM, SPUD AT 19:30,3/13/04. DRILLED TO 370'. p/u DRILL PIPE. PIU BHA, PDM, MWD & LWD TOOLS. DRILLED AHEAD. DRILLED TO 2594'. CBU. MADE A WIPER TRIP. DRILLED TO 3689'. CBU. DRILLED AHEAD. DRILLED TO CASING POINT AT 5430'. CBU. POOH. LID TOOLS & MWD. RIU TO RUN CSG. RAN 9-5/8" CASING TO 5416' MD (4683' TVD) AND CEMENTED PER.PROGRAM WITH >200 BBlS OF CEMENT TO SURFACE. SET PACKOFF. TEST BOPE. FINISHED TESTING BOPE. PIU 8-112" BIT & BHA. PIU MORE 5" DP, TESTED CASING TO 3500#. DRILLED OUT SHOE + 20'. RAN LOT (14.7# EMW). DRILLED AHEAD. DRILL TO 7815'. WIPER TRIP. DRILLED TO 8363. POOH & REPLACED FAILED MWD TOOL. RIH. DRILLED AHEAD. DRILLED TO 9217'. POOH FOR WASHOUT. DRILLED AHEAD. DRILLED TO CORE POINT AT 10,390'. CBU. POOH FOR CORING ASSEMBLY. FINISHED POOH. STOOD BACK BHA & DOWN-LOADED SAME. MIU CORE BARREL. RIH. CORED 90': SAG RIVER & SHUBLIK. STARTED POOH. POOH W/CORE BARREL & LID SAME. TESTED BOPE. RIH WITH BIT & BHA, RIH. DRILLED TO TD AT 11,001' MD (9508' TVD) , CIRC & CONDmONED HOLE FOR LOGS.. POOH FOR LOGS. LID BHA. RIU E-LlNE. RAN QUAD-COMBO. ATTEMPTED FMI/DI-POLE SONIC: TOOLS FAILED. RE-RAN FMIID..POLE SONIC. RAM MDT. RID E-LlNE. LID HWDP. PIU 3-1/2" CEMENT STINGER. RIH WI CEMENT STINGER. CIRC & COND THE HOLE. WIO CEMENTERS (12 HRS). SPOTTED 4 X 390 SX (1000') CEMENT PLUGS: 11001' TO 7001'. LOOP WHILE woc. LDDP. RIH. CIRC. TAGGED PlUG #4 AT 7028' MD. POOH. RIH & SET EZSV AT 5325' MD. ESTABLISHED INJECTION. MIXED & PUMPED 120 SX (25 BBl) OF CEMENT. DISPLACED 20 BBL BELOW THE EZSV & LEFT 5 BBl ABOVE. CBU. LDDP. SET 120 SX SURFACE PWG (240' - 60'). LOOP. CUT 9-518" & 1.3-318" CASING. FINISHED P & A. DUMPED 3-1/2 CU-YDS OF READY MIX IN THE CONDUCTOR HOLE. ~ RELEASED THE RIG AT NOON ON 4/01104. RIGGED DOWN 27E & MOVED IT TO "12-ACRE PAD". DUG OUT THE CELLAR BOX & BACK FILLED THE HOLE WITH CLEAN ICE. DE-MOBILlZED EQUIPMENT. FINAL REPORT. ./ Printed: 41612004 7:01:53 PM '" ~ I/) .~..... I ............. - :.~.:~.:.... ..." .......oo. ¿m¿~ ;~~{~~{~{~~~{f{~{~{~{: mm ¿m¿]' ....... J¡!¡~~~ti~¡~ ·~(¡i r~~~~~~¿~~~~~~~~~~~~ž~~ I I I I I 10.6 ppg I I I I Toe = 7028' I I:. -:j.: ..~-:.....:;.,:....::.::. -: .....: :..~:-:I ~~~~t$~~~~~~~~~~~~t~~~1 ~li¡¡¡~~~r~lf ~~~....:.,. ·.:i ............".... "........ ~ imml'i!¡~ ~ 11111111 r~~~~~~~~$~~~$~~~~~~~~~i ~·:¿}::t:;.·.......":;.."::.-:;":.;':':,,";,,,:,,";,"..~ ~."."......."""..""'''''''''..''''''''''. ~~mmmmmm~~ ..........................................., ~mmmmmmm~ .......N.~:.~:~ .....?~ :) ~j .~:~~ 60' RKB 240'RKB 5257' MD 5325' MD 5416' MD 5560' MD e e @ KERR-MCGEE COIIPORAnON Nikaitchuq #2 Plug & Abandon Report (Sundry No.: 304-089) 10.6 ppg 1. MW = 10.6 ppg: surface to TD. 2. P/U 1000' of 3-1/2" DP as a cement stinger. 3. RIH to TD. Spotted 390 sx (80 bbl), balanced cement plug #1: 11,000' to 10,000'. POOH 12 stands. CBU. 4. RIH to TOC. Spotted 390 sx (80 bbl), balanced cement plug #2: 10,000' to 9,000'. POOH 12 stands. CBU. 5. RIH to TOC. Spotted 390 sx (80 bbl), balanced cement plug #3: 9,000' to 8,000'. POOH 12 stands. CBU. 6. RIH to TOC. Spotted 390 sx (80 bbl), balanced cement plug #4: 8,000' to 7,000'. POOH 12 stands. CBU. LDDP. WOC 12 hours. 7. RIH. Tagged plug #4 at 7028' MD (witnessed by Chuck Sheve). CBU. POOH 8. RIH with EZSV and set same at 5325' MD. Tested EZSV and casing to 1500 psi. Established injection rates and pressures: 6 bpm at 900 psi. Down squeezed cement plug #5 with 120 sx (25 bbl). Squeezed 20 bbl below the EZSV and left 5 bbl on top. TOC = 5257' MD. 9. POOH 3 stands. CBU. LDDP. 10. RIH with OEDP to 240' MD. Spotted 120 sx (20.5 bbl) balanced cement plug #6: 240' to surf. POOH to 60' MD. Circulated out excess cement. 11. LDDP. NID BOPE. P/U multi-string casing cutter. RIH. Cut the 9-5/8" and 13-3/8" casing strings at 55' MD (12' below Spy Island ground level). 12. UD tools and DP. Dug out the cellar box. Dumped 3-112 yd3 in the cellar 1 conductor hole. 13. De-Mobilized the rig, etc. Cleaned location. Back filled the cellar with clean ice. Conducted site clearance with John Spaulding on 3/7/04. a) Plugs #1, 2, 3, & 4: Premium cement mixed at 15.8 ppg and 1.15 cf/sx. b) Plug #5: Premium cement + 1% CaCI2 mixed at 15.8 ppg and 1.15 cf/sx. c) Plug #6: Permafrost "C" mixed at 15.6 ppg and 0.99 cf/sx. 11001' MD (9508' TVD) Kerr-McGee Corporation Western North Slope, Alaska NW Milne Point (Spy Island) Nikaitchuq #2 e Job No. AKMW2893109, Surveyed: 25 March, 2004 Survey Report 13 April, 2004 .:-- Your Ref: API 500292319900 Surface Coordinates: 6052263.00 N, 527462.33 E (10" 33' 13.9873" N, 149" 46' 29.2758" WJ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 39.95ft above Mean Sea Level e Survey Ref: svy2073 Kerr-McGee Corporation Survey Report for Spy Island - Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Ke" McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -39.95 0.00 O.OON 0.00 E 6052263.00 N 527462.33 E 0.00 SHL@ 2239.41' FNL & 1293.38' FEL, Sec. 22 - T14N - R9E 343.46 0.230 172.510 303.51 343.46 0.68S 0.09 E 6052262.32 N 527462.42 E 0.067 -0.68 618.38 0.450 28.810 578.43 618.38 0.285 0.68 E 6052262.72 N 527463.01 E 0.236 -0.26 704.42 2.300 344.230 664.44 704.39 1.67 N 0.38 E 6052264.67 N 527462.70 E 2.330 1.69 e 798.60 3.810 350.990 758.48 798.43 6.58 N 0.63W 6052269.58 N 527461.68 E 1.646 6.55 893.63 6.410 353.450 853.13 893.08 14.97 N 1.73W 6052277.97 N 527460.55 E 2.745 14.90 985.99 9.770 354.450 944.56 984.51 27.90 N 3.07W 6052290.89 N 527459.15 E 3.641 27.77 1081.11 11.540 359.970 1038.03 1077.98 45.45 N 3.86W 6052308.43 N 527458.30 E 2.146 45.27 1174.86 12.320 3.290 1129.76 1169.71 64.81 N 3.29W 6052327.80 N 527458.80 E 1.108 64.65 1270.15 13.630 3.870 1222.61 1262.56 86.16 N 1.95W 6052349.15 N 527460.06 E 1.382 86.03 1363.45 15.420 1.230 1312.93 1352.88 109.53 N 0.94W 6052372.53 N 527460.98 E 2.045 109.42 1456.89 17.970 1.360 1402.42 1442.37 136.37 N 0.33W 6052399.37 N 527461.49 E 2.729 136.26 1555.39 18.460 2.050 1495.99 1535.94 167.14 N 0.59 E 6052430.14 N 527462.30 E 0.544 167.05 1649.12 18.790 3.220 1584.81 1624.76 197.04 N 1.96 E 6052460.05 N 527463.56 E 0.532 196.98 1743.64 19.840 3.490 1674.01 1713.96 228.25 N 3.80 E 6052491.27 N 527465.28 E 1.115 228.24 1837.10 19.970 3.350 1761.88 1801.83 260.02 N 5.69E 6052523.04 N 527467.06 E 0.148 260.05 1928.95 19.620 3.440 1848.31 1888.26 291.07 N 7.54E 6052554.09 N 527468.79 E 0.382 291.15 2021.79 22.220 7.170 1935.02 1974.97 324.05 N 10.66 E 6052587.09 N 527471.79 E 3.145 324.22 2115.03 24.410 9.280 2020.65 2060.60 360.56 N 15.97 E 6052623.62 N 527476.96 E 2.513 360.91 2206.52 27.470 9.050 2102.91 2142.86 400.07 N 22.34 E 6052663.15 N 527483.19 E 3.346 400.62 2301.31 30.420 5.800 2185.85 2225.80 445.55 N 28.21 E 6052708.65 N 527488.88 E 3.526 446.28 2395.41 33.780 2.940 2265.56 2305.51 495.39 N 31.96 E 6052758.50 N 527492.45 E 3.918 496.23 2489.54 36.060 3.840 2342.74 2382.69 549.17 N 35.15 E 6052812.30 N 527495.45 E 2.483 550.09 e 2585.72 36.200 2.520 2420.42 2460.37 605.79 N 38.30 E 6052868.93 N 527498.38 E 0.822 606.79 2677.89 36.500 2.300 2494.66 2534.61 660.37 N 40.60 E 6052923.52 N 527500.48 E 0.355 661.42 2772.37 37.700 1.840 2570.01 2609.96 717.33 N 42.65 E 6052980.48 N 527502.32 E 1.304 718.41 2865.83 37.600 1.600 2644.01 2683.96 774.39 N 44.37 E 6053037.55 N 527503.82 E 0.190 775.50 2961.33 37.980 2.210 2719.48 2759.43 832.88 N 46.31 E 6053096.04 N 527505.55 E 0.558 834.02 3055.53 38.730 2.700 2793.35 2833.30 891.28 N 48.82 E 6053154.45 N 527507.84 E 0.859 892.47 3149.45 39.010 2.660 2866.47 2906.42 950.15 N 51.57 E 6053213.34 N 527510.38 E 0.299 951.41 3243.81 39.120 2.670 2939.74 2979.69 1009.55 N 54.34 E 6053272.75 N 527512.93 E 0.117 1010.87 3335.64 39.310 2.670 3010.88 3050.83 1067.55 N 57.04 E 6053330.75 N 527515.42 E 0.207 1068.92 3428.42 39.370 2.500 3082.64 3122.59 1126.30 N 59.70 E 6053389.52 N 527517.85 E 0.133 1127.74 3521.47 39.220 1.690 3154.65 3194.60 1185.19 N 61.85 E 6053448.41 N 527519.79 E 0.574 1186.67 3615.69 39.100 1.090 3227.71 3267.66 1244.67 N 63.29 E 6053507.90 N 527521.01 E 0.422 1246.16 13 April, 2004 - 8:23 Page 2 of7 DrillQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island· Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Ke" McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0110Oft) 3708.94 38.900 0.670 3300.18 3340.13 1303.35 N 64.20 E 6053566.58 N 527521.70 E 0.355 1304.83 3806.01 38.490 359.860 3375.94 3415.89 1364.03 N 64.48 E 6053627.26 N 527521.75 E 0.671 1365.48 3900.72 38.670 359.710 3449.98 3489.93 1423.09 N 64.26 E 6053686.32 N 527521.31 E 0.214 1424.50 3991.91 38.790 359.250 3521.12 3561.07 1480.15 N 63.74 E 6053743.37 N 527520.58 E 0.342 1481.49 4087.21 38.900 358.830 3595.34 3635.29 1539.91 N 62.74 E 6053803.13 N 527519.36 E 0.300 1541.18 e 4180.67 39.000 358.620 3668.02 3707.97 1598.65 N 61.43 E 6053861.87 N 527517.83 E 0.177 1599.83 4273.91 38.970 358.470 3740.50 3780.45 1657.29 N 59.94 E 6053920.50 N 527516.13 E 0.106 1658.37 4368.68 39.190 357.750 3814.07 3854.02 1717.00 N 57.97 E 6053980.20 N 527513.93 E 0.532 1717.97 4463.58 38.700 357.440 3887.88 3927.83 1776.60 N 55.47 E 6054039.79 N 527511.21 E 0.556 1777.44 4556.85 38.140 357.600 3960.95 4000.90 1834.50 N 52.96 E 6054097.69 N 527508.49 E 0.610 1835.21 4651.17 38.310 358.000 4035.05 4075.00 1892.82 N 50.72 E 6054156.00 N 527506.03 E 0.318 1893.40 4746.58 37.830 357.420 4110.16 4150.11 1951.60 N 48.37 E 6054214.77 N 527503.47 E 0.627 1952.06 4840.43 37.720 357.080 4184.34 4224.29 2009.03 N 45.61 E 6054272.18 N 527500.49 E 0.251 2009.34 4935.70 37.930 0.120 4259.60 4299.55 2067.42 N 44.19 E 6054330.57 N 527498.86 E 1.969 2067.64 5026.03 37.680 0.630 4330.97 4370.92 2122.79 N 44.55 E 6054385.94 N 527499.01 E 0.443 2122.99 5121.54 36.810 0.280 4407.00 4446.95 2180.59 N 45.01 E 6054443.74 N 527499.26 E 0.938 2180.77 5215.11 36.970 359.590 4481.84 4521.79 2236.76 N 44.95 E 6054499.91 N 527498.99 E 0.475 2236.90 5308.33 36.580 359.310 4556.51 4596.46 2292.56 N 44.41 E 6054555.71 N 527498.24 E 0.455 2292.64 5430.00 35.261 359.287 4655.04 4694.99 2363.93 N 43.54 E 6054627.08 N 527497.11 E 1.084 2363.94 9-5/8" Csg Pt... Drill out 8-112" Ho : 5430.000 MD, 4694.99ft TVD 5466.07 34.870 359.280 4684.56 4724.51 2384.66 N 43.28 E 6054647.80 N 527496.77 E 1.084 2384.63 5558.53 34.270 359.100 4760.69 4800.64 2437.11 N 42.54 E 6054700.25 N 527495.83 E 0.658 2437.03 5653.10 33.570 358.940 4839.17 4879.12 2489.88 N 41.64E 6054753.02 N 527494.74 E 0.746 2489.72 5746.40 33.200 359.930 4917.07 4957.02 2541.21 N 41.13E 6054804.35 N 527494.04 E 0.706 2541.01 e 5842.20 33.780 3.270 4996.98 5036.93 2594.04 N 42.61 E 6054857.18 N 527495.33 E 2.017 2593.85 5937.09 34.950 5.430 5075.30 5115.25 2647.43 N 46.69 E 6054910.59 N 527499.21 E 1.781 2647.36 6030.00 37.020 6.480 5150.48 5190.43 2701.73 N 52.37 E 6054964.90 N 527504.68 E 2.325 2701.82 6124.27 38.140 7.390 5225.19 5265.14 2758.79 N 59.31 E 6055022.00 N 527511.42 E 1.326 2759.11 6219.20 37.160 7.280 5300.35 5340.30 2816.31 N 66.72 E 6055079.53 N 527518.61 E 1.035 2816.85 6313.35 36.370 7.310 5375.77 5415.72 2872.20 N 73.87 E 6055135.46 N 527525.56 E 0.839 2872.97 6407.88 36.270 7.080 5451.94 5491.89 2927.75 N 80.89 E 6055191.03 N 527532.36 E 0.179 2928.74 6501.45 37.800 6.550 5526.63 5566.58 2983.71 N 87.57 E 6055247.01 N 527538.84 E 1.670 2984.91 6597.05 36.800 6.700 5602.68 5642.63 3041.25 N 94.25 E 6055304.58 N 527545.31 E 1.050 3042.66 6691.78 35.590 6.290 5679.12 5719.07 3096.83 N 10D.58 E 6055360.18 N 527551.43 E 1.303 3098.44 6786.45 34.350 5.630 5756.70 5796.65 3150.80 N 106.22 E 6055414.17 N 527556.87 E 1.369 3152.57 6877.99 36.290 3.870 5831.39 5871.34 3203.53 N 110.58 E 6055466.92 N 527561.04 E 2.393 3205.43 13 April, 2004·8:23 Page 3 of7 DrillQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island - Nikaltchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (·/100ft) 6970.34 37.460 2.200 5905.26 5945.21 3258.87 N 113.51 E 6055522.27 N 527563.76 E 1.668 3260.84 7063.81 36.670 1.880 5979.85 6019.80 3315.17 N 115.51 E 6055578.57 N 527565.55 E 0.870 3317.17 7157.61 36.730 2.110 6055.06 6095.01 3371.19 N 117.46 E 6055634.60 N 527567.30 E 0.160 3373.23 7248.01 35.890 1.570 6127.90 6167.85 3424.69 N 119.19 E 6055688.11 N 527568.82 E 0.994 3426.76 7344.05 36.320 1.750 6205.50 6245.45 3481.26 N 120.83 E 6055744.69 N 527570.25 E 0.461 3483.35 e 7438.85 35.300 1.160 6282.37 6322.32 3536.71 N 122.24 E 6055800.14 N 527571.46 E 1.136 3538.81 7531.73 35.040 0.910 6358.30 6398.25 3590.20 N 123.20 E 6055853.63 N 527572.23 E 0.320 3592.30 7626.20 33.730 0.950 6436.26 6476.21 3643.54 N 124.07 E 6055906.98 N 527572.89 E 1.387 3645.64 7719.85 32.620 0.130 6514.64 6554.59 3694.78 N 124.56 E 6055958.22 N 527573.19 E 1.278 3696.87 7814.64 33.070 0.770 6594.28 6634.23 3746.19 N 124.96 E 6056009.63 N 527573.41 E 0.600 3748.25 7909.05 31.680 0.500 6674.01 6713.96 3796.74 N 125.53 E 6056060.18 N 527573.78 E 1.480 3798.79 8004.11 31.220 0.840 6755.11 6795.06 3846.34 N 126.10 E 6056109.78 N 527574.18 E 0.519 3848.37 8098.23 32.960 2.630 6834.85 6874.80 3896.31 N 127.64 E 6056159.75 N 527575.53 E 2.107 3898.36 8192.41 31.560 1.600 6914.49 6954.44 3946.54 N 129.50 E 6056209.99 N 527577.20 E 1.597 3948.63 8278.08 30.440 1.420 6987.92 7027.87 3990.65 N 130.67 E 6056254.10 N 527578.20 E 1.312 3992.75 8371.34 29.770 1.550 7068.60 7108.55 4037.41 N 131.88 E 6056300.87 N 527579.24 E 0.722 4039.53 8447.63 29.510 1.390 7134.91 7174.86 4075.12 N 132.84 E 6056338.59 N 527580.07 E 0.356 4077.25 8558.62 26.370 2.790 7232.95 7272.90 4127.09 N 134.71 E 6056390.56 N 527581.74 E 2.890 4129.25 8652.83 25.760 0.690 7317.58 7357.53 4168.46 N 135.97 E 6056431.93 N 527582.85 E 1.174 4170.64 8745.97 26.970 1.220 7401.03 7440.98 4209.81 N 136.67 E 6056473.29 N 527583.39 E 1.323 4211.99 8840.53 26.190 1.280 7485.59 7525.54 4252.11 N 137.59 E 6056515.59 N 527584.16 E 0.825 4254.29 8934.61 25.970 2.280 7570.10 7610.05 4293.45 N 138.87 E 6056556.93 N 527585.29 E 0.523 4295.65 9028.30 24.630 2.450 7654.80 7694.75 4333.45 N 140.52 E 6056596.94 N 527586.79 E 1.432 4335.69 e 9122.75 26.380 4.320 7740.04 7779.99 4374.04 N 142.95 E 6056637.54 N 527589.06 E 2.039 4376.34 9217.96 26.570 4.650 7825.27 7865.22 4416.36 N 146.27 E 6056679.87 N 527592.23 E 0.252 4418.75 9310.53 26.930 6.860 7907.93 7947.88 4457.81 N 150.45 E 6056721.33 N 527596.25 E 1.143 4460.32 9405.24 27.050 5.340 7992.33 8032.28 4500.54 N 155.01 E 6056764.09 N 527600.66 E 0.739 4503.20 9498.92 26.580 3.340 8075.93 8115.88 4542.68 N 158.22 E 6056806.23 N 527603.71 E 1.086 4545.42 9592.65 27.370 3.580 8159.47 8199.42 4585.11 N 160.78 E 6056848.68 N 527606.12 E 0.851 4587.93 9686.40 28.290 2.450 8242.37 8282.32 4628.82 N 163.08 E 6056892.39 N 527608.25 E 1.131 4631.69 9780.78 26.690 0.340 8326.10 8366.05 4672.36 N 164.16 E 6056935.94 N 527609.17 E 1.984 4675.24 9874.38 27.050 1.060 8409.59 8449.54 4714.66 N 164.68 E 6056978.24 N 527609.53 E 0.518 4717.53 9970.38 24.030 0.190 8496.20 8536.15 4756.04 N 165.15 E 6057019.62 N 527609.85 E 3.170 4758.90 10063.60 23.490 2.150 8581.52 8621.47 4793.59 N 165.91 E 6057057.17 N 527610.47 E 1.026 4796.45 10157.60 23.390 359.820 8667.76 8707.71 4830.97 N 166.55 E 6057094.55 N 527610.98 E 0.992 4833.83 13 April, 2004 - 8:23 Page4of7 DrlllQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island· Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 10252.04 23.150 1.140 8754.52 8794.47 4868.28 N 166.86 E 6057131.86 N 527611.15 E 0.608 4871.12 10346.05 20.790 358.400 8841.70 8881.65 4903.44 N 166.76 E 6057167.02 N 527610.92 E 2.736 4906.25 10396.00 20.328 358.889 8888.47 8928.42 4920.97 N 166.35 E 6057184.55 N 527610.44 E 0.988 4923.76 Target (Top / Sag River) @ 10396 MD, 8928' TVD (2598' FNL & 111! FEL, Sec. 15-T14N -R9E) e 10440.15 19.920 359.340 8929.93 8969.88 4936.16 N 166.11 E 6057199.74 N 527610.15 E 0.988 4938.93 10532.36 18.830 357.300 9016.91 9056.86 4966.73 N 165.23 E 6057230.31 N 527609.15 E 1.391 4969.45 10627.04 16.980 359.200 9107.00 9146.95 4995.82 N 164.32 E 6057259.40 N 527608.13 E 2.049 4998.48 10720.03 15.300 358.000 9196.33 9236.28 5021.66 N 163.70 E 6057285.23 N 527607.42 E 1.842 5024.28 10815.53 15.160 359.270 9288.47 9328.42 5046.74 N 163.10 E 6057310.31 N 527606.73 E 0.379 5049.32 10906.35 14.910 358.550 9376.18 9416.13 5070.30 N 162.66 E 6057333.86 N 527606.19 E 0.344 5072.85 ......-11001.00 14.910 358.550 9467.65 9507.60 5094.64 N 162.04 E 6057358.21 N 527605.49 E 0.000 5097.15 Projected BHL : 11 001.0ft MD. 9507.602 TVD (2424' FNL & 1123 FEL. Sec. 15-T14N-R9E) All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB Est @ 35' MSL. Northings and Eastings are relative to 2440 FNL, 1293 FEL. 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 2440 FNL, 1293 FEL and calculated along an Azimuth of 2.1 09° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 11001.00ft., The Bottom Hole Displacement is 5097.22ft., in the Direction of 1.822° (True). The Along Hole Displacement is 5104.90ft. The Total Accumulated Dogleg is 121.478° The Measured Tortuosity is 1.166°/1 OOft. The Directional PifficUlty Index is 5.4. e 13 April, 2004· 8:23 Page 50f7 DrillQuest 3.03.06.002 Western North Slope, Comments Measured Depth (ft) 0.00 5430.00 10396.00 11001.00 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 0.00 4694.99 8928.42 9507.60 0.00 N 2363.93 N 4920.97 N 5094.64 N 0.00 E 43.54 E 166.35 E 162.04 E Kerr-McGee Corporation Survey Report for Spy Island· Nlkaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Comment SHL @ 2239.41' FNL & 1293.38' FEL, Sec. 22 - T14N - R9E 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5430.00ft MD, 4694.99ft TVD Target (Top / Sag River) @ 10396' MD, 8928' TVD (2598' FNL & 1119' FEL, Sec. 15-T14N -R9E) Projected BHL: 11001.0ft MD, 9507.602 TVD (2424' FNL & 1123' FEL, Sec. 15-T14N-R9E) Kerr McGee 13 April, 2004· 8:23 Page 60f7 DrillQuest 3.03.06.002 e e Kerr-McGee Corporation North Reference Sheet for Spy Island - Nikaitchuq #2 Western North Slope, Coordinate System is NAD27 Alaska state Planes, Zone 4, US Foot Source: Snyder, J.P., 1987, Map Projections - A Working Manual Datum is North American Datum of 1927 (US48, AK, HI, and Canada) Spheroid is Clarke - 1866 Equatorial Radius: 6378206.400m. Polar Radius: 6356583.800m. Inverse Flattening: 294.978698213901 Projection method is Transverse Mercator or Gauss Kruger Projection Central Meridian is -150.000· Longitude Origin: 0.000· Latitude Origin: 54.000· False Easting: 152400.00m False Northing: O.OOm Scale Reduction: 0.99990000 Grid Coordinates of Well: 6052263.00 N, 527462.33 E Geographical Coordinates of Well: 70· 33' 13.9873" N, 149· 46' 29.2758" W Surface Elevation of Well: 39.95ft Grid Convergence at Surface is +0.212· Magnetic Declination at Surface is +24.893· (13 March, 2004) Ke" McGee e e 13 April, 2004 - 8:23 Page 70f7 DrillQuest 3.03.06.002 e ~ spar'r'ly-sun DRILLING SeAVIE::E:S A Halliburton Company Well Data Transmittal To: Alaska Oil & Gas Conservation Commission Attn: Librarian 333 West 7th Avenue, Suite 100 Anchorage AK 99501 RE: Mud Logs, End of Well Summaries, and Digital Data for: (;¿O ( L - 0 3:3 Nikaitchuq #2 T April 5, 2004 Nikaitchua 2 Final: 511 MD Mud Log: 1 Color Set Separate Envelope 511 1VD Mud Log: 1 Color Set Separate Envelope 2" MD Mud Log 1 Color Set Separate Envelope 2"1VD Mud Log 1 Color Set Separate Envelope 1" MD Mud Log 1 Color Set Bound l"1VD Mud Log 1 Color Set Bound End of Well Report and Summary 1 Bound SDL/ML ASCII Data, EOWR, ML and Eng. Logs Dif. Survey Reports Log Viewers (EMF-TIF- CGM) 1 CD ROM PLEASE ACKNOWLEDGE THE RECEIPT OF THIS WELL DATA BY SIGNING AND RETURNING A COPY OF THE TRANSMmAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Steve Carroll 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~- 7-Ci 1 -~ ~~. Signed: ~" Q) \^-..\. /Y'....~ __~~~~... Print: e 20 ý-03;;t Weekly Operations Report Nikaitchuq #2 Permit No.: 204-038 Week of March 13th through March 19t\ 2004 3/13/04 Conitnued to move in and rig up Nabors 27E. Function tested the diverter system (waived by field inspector). Worked on berming, spill containment, communications, fuel, etc. 3/14/04 Finished R/U Nabors 27E. PIU drill pipe & BRA. Spudded well #2 at 19:00 hours on 3/13/04. Drilled to 372'. POOR & P/U LWD tools. 3/15/04 Finished P/U LWD tools. Rill and drilled 12-114" hole to 2595' MD. MW = 9.1 ppg. 3/16/04 Drilled 12-114" surface hole to casing point at 5430' MD (4695' TVD). MW = 9.5 ppg. 3/17/04 Conditioned the hole to run surface casing. POOR. Down-loaded LWD's. R/U casing tools. Started running 9-5/8" casing. 3/18/04 Finished running 9-5/8" surface casing. Set casing at 5416' MD (4695' TVD). Cemented per program. Circulated + 200 bbl cement to surface (calculates to be a 12-314" avg hole size like well # 1 was). Set and tested the packoff. Tested BOP's (witnessed by AOGCC). 3/19/04 PIU BRA, mud motor, MWD & LWD. P/U additional drill pipe. Tested casing to 3500 psi. Drilled out 9-5/8" casing + 20' of new hole. Conducted LOT to 14.7 ppg EMW. Drilling ahead in the Colville this morning. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 · Weekly Operations Report Nikaitchuq #2 Pennit No.: 204-038 Week of March 20th through March 26th, 2004 3/20/04 Drilled to 7910' MD. Made a wiper trip: OK. Drilled to 8002' MD. MW = 10.4 ppg. 3/21/04 Drilled to 8363' MD. LWD failed. Circulated & tripped for LWD. Drilled to 8653' MD: hole breathing with MW = 10.4# & ECD = 11.5#. Monitor seepage while drilling & pumped LCM sweeps. Possible fault in Kuparuk / LCU section. Phase 1 - 2 conditions throughout the day. 3/22/04 Drilled 8-1/2" hole to 10,050' MD. MW = 10.3 ppg. ECD = 11.3 ppg. Hole "breathing" is minimal. No shale problems in the Kingak. Phase 1 - 2 conditions throughout the day. 3/23/04 Drilled 8-1/2" hole to core point at 10,390' MD. Conditioned hole for coring. MW = 10.3 ppg. POOH. Phase 1 - 2 conditions throughout the day: winds diminishing. 3/24/04 P/U core barrel. RIH. Cut 92 ft core: 10,390' -10,482' MD. POOH. MW = 10.3 ppg. 3/25/04 LID core and core barrel: full recovery. Tested BOPE. Picked up bit and BHA. RIH to continue drilling. MW = 10.3 ppg. 3/26/04 Drilled 8-1/2" hole to TD of 11,001' MD (9508' TVD). Increased MW to 11.6 ppg due to high BGG. Circulated and conditioned the hole foe logs. Made a wiper trip: ok. Circulated bottoms up x 3 while W.O Schlumberger. Flow Check. POOH for open hole logs. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 e -L 2.0 q ~.. ð3<6 Weekly Operations Report Nikaitchuq #2 Pennit No.: 204-038 Week of March 27th through April 2nd, 2004 3/27/04 Finished POOH. R/U E-Line. Ran "Platform Express + CMR". Ran "FMI/Di-Pole Sonic": tool Failed. Re-ran "FMI/Di-Pole Sonic". 3/28/04 Finished running "FMI/Di-Pole Sonic". Ran "MDT's" RID E-Line. LID HWDP. PIU 3-1/2" cementing stringer. Preparing to P & A. 3/29/04 Rlli with cement stinger on 5-1/2" DP. Circulated and waited on Halliburton cement unit from well #1. 3/30/04 R/U Halliburton. Mixed and spotted 4 x 390 sx cement plugs as programmed: 11001' -7000'. LDDP while WOC. Preparing to "tag test" plug #4. 3/31/04 Tagged plug # 4 at 7028' MD: witnessed by AOGCC. POOH. RIH with EZSV and set same at 5325' MD. Tested EZSV to 1500 psi: OK. Established injection rate. Mixed and pumped 120 sx (25 bbl) of Premium cement. Squeezed 20 bbl below the EZSV and left 5 bbl above: TOC = 5295' MD. CBU. LDDP. 4/1/04 POOH to 240' MD. Mixed and pumped 120 sx (20.5 bbl) cement plug. POOH to ± 60' MD. Circulated. PIU multi-string casing cutter and cut 9-5/8" and 13-3/8" casing at ± 55' MD. Pulling the casing stubs this am. 4/2/04 To follow next week. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 · ZD:¡~6'"$ Weekly Operations Report Nikaitchuq #2 Pennit No.: 204-038 Week of April20d through AprilSth 2004 4/2/04 LID the casing stubs. Released the rig at noon 4/1/2004. Started de-mobilizing the rig to 12-acre pad. Continued de-mobilizing personnel and equipment. 4/3/04 Dug out the cellar box. Dumped 3.5 cu- yds of ready mix in the conductor hole. Continued de- mobilizing the rig, personnel and equipment. 4/4/04 Continued de-mobilizing the rig. Scraped and removed dirty ice from location. Stock piled dirty ice on 12-acre pad where Kuparuk will melt it for disposal. 4/5/04 Scraped and removed dirty ice from location. Stock piled dirty ice on 12-acre pad where Kuparuk will melt it for disposal. 4/6/04 Scraped and removed dirty ice from location. Stock piled dirty ice on 12-acre pad where Kuparuk will melt it for disposal. 4/704 Site clearance by AOGCC (John Spaulding). Also DNR made a site inspection: OK. 4/8/04 Closed the ice road. Final Report. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 e e MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg <7 A\~oA P.I. Supervisor 'f,~q DATE: March 30, 2004 FROM: Chuck Scheve Petroleum Inspector SUBJECT: Plug & Abandonement Nikaitchuq #2 Kerr McGee Exploration 204-038 CONFIDENTIAL Section: Lease No.: Operator Rep.: Gary Gorlich Township: Drilling Rig: Range: Rig Elevation: Meridian: Total Depth: CasinQlTubinø Data: Conductor: O.D. Shoe@ Surface: 0.0. Shoe@ Intermediate: 0.0. Shoe@ Production: 0.0. Shoe@ Liner: 0.0. Shoe@ TUbing: O.D. Tail@ CasinQ Removal: Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Casing Cut@ Feet Bottom Bottom of Cement 11010 PluøøinQ Data: Top of Cement ~ Verified? 7028 Drillpipe Tag Mud Weight above plug Pressure I Te~ ~:~i"l Type PluQ (bottom up) Open Hole Founded on Type PluQ Open Hole Perforation Annulus Casing Stub Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag No Surface I traveled to the Kerr McGee Nikaitchuq #2 location to witness the integrity test of the bottom cement plug in this well. A cement plug had been spotted in four stages from TO (11010) to an estimated top of cement at 7010. After 12 hours WOC drill pipe was run in the hole to 7028 where solid cement was tagged with 20K DP weight. ~ Attachments: Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c -Inspector Rev.:5128/00 by L.R.G. P&A Nikaitchuq #2 3-30-04 CS.xls 4/6/2004 e e @ KERfl.M&6EE CORPIJRATII1N March 23,2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq #2 Kerr McGee Oil & Gas Corporation Permit to Drill 204-038 ~AR 2 ~1 20L f¡! £~ . Application for Sundry Approval Plug and Abandon Attached for your review is our Application for Sundry Approval to plug and abandon the Nikaitchuq #2 exploration well located four (4) miles north of Oliktok Point. Be advised that we are still drilling, however, we expect to finish with our open hole evaluation over the upcoming weekend. At this point in time, the TD proposed in the APD is still the intended target total depth: 11,010' MD (9450' TVD). This operation will be conducted prior to releasing the drilling rig. Your timely review of our Application for Sundry Approval and the accompanying data is greatly appreciated. Sincerely, sM?~ ASRC Energy Services Project (Drilling) Mngr. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 OR\G\NAL ... a STATE OF ALASKA a ALA_ OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 280 ; l'.r·· A JrAR 2 3 20lw,~ ~~l, ~, z: f'.',:; ',' "", ":,,, .. 1. Type of Request: Abandon ~ Suspend U Operational shutdown U Perforate U Wai",~rh-r . Al1nûfarIJi%þ'ðw.'U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extensio~D ' Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Kerr McGee Oil & Gas Corporation Development 0 Exploratory 0 204~ 0'3 ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: 3900 C Street, Suite 744, Anchorage, AK 99503 50-629-23199-00 7. KB Elevation (ft): 9. Well Name and Number: 38.8 ft Nikaitchuq #2 8. Property Designation: 10. Field/Pools(s): ADL 355021 Exploration 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11,010 ft 9450 ft Casing Length Size MD TVD Burst Collapse Structural Conductor 80 ft 13-3/8" 112ft 112ft 5020 psi 2260 psi Surface 5416 9-5/8" 5378 ft 4683 ft 5750 psi 3090 psi Intermediate Upper Liner Lower Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 27, 2004 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Skip Coyner 907-339-6269 Printed Name Charles Summers Title Drilling Manager, Kerr McGee Oil & Gas Corp. Signature (I JL,.IJ fL. L_ , ......L / hv .s ~one 907-339-6370 Date March 23, 2004 // COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 ~- lJ8,? Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance g Other: c.o~.\-û.(:..\" L~~~~\-Q' ..\C)'~~ o~ "?\~~ L\ f} -\.<:c.~ ~~Or- +0 c::...v \\ '\.......S o..C;.\,,~ '=:> 2'1 .' ' ;) ORIGINAL BY ORDER OF Date:~hbl #' Approved' l,' I COMMISSIONER THE COMMISSION V ..r~, ' INSTRUCTIONS ON REVERSE I "Ii .l te Form 10-403 Revised 12/200 .... BFL .11 O~ e e @ KERll-Mt:tiEE COIPORAlIOI Abandonment Program Well Name: Nikaitchuq #2 Classification: Exploration AOGCC Permit: 204-038 API No.: 50-629-23199 Anchorage No.: 907 -339-6269 Rig Number: 907 -646-8021 Estimated Start Date: March 27 2004 Prepared By: S. Coyner HSE OBJECTIVES FOR ABANDONMENT OPERA TIONS: 1. No Lost time Accidents. 2. No Spills. 3. No environmental damage Notify the AOGCC Field Inspector prior to commencing operations. Abandonment Program 1 3/23/2004 - e Formation Markers: Formation Tops MD TVD T/Colville 4931' 4296' 9-5/8" Casing 5416' 4683' T/Kalubik 8366' 7104' T/Kuparuk zone 8533' 7250' No sand Kingak 8790' 7480' TISag River 10390' 8922' PTD 11010' 9450' Cementina Proaram: Cement PluQs: Plug Length Top Bottom Sacks BBL Excess Displacement 1 1000' 10,010' 11,010' 390 80 15% 175 BBL of mud 2 1000' 9,010' 10,010' 390 80 15% 157 BBL of mud 3 1000' 8,010' 9,010' 390 80 15% 139 BBL of mud 4 1000' 7,010' 8,010' 390 80 15% 121 BBL of mud 5 320' 5,250' 5,560' 122 25 15% 89 BBL of mud 6 240' Surf 240' 120 20.5 0% 2.5 BBL of mud · Use E-Line caliper + 15% for actual cement volumes. · Cement is "Premium" with retarders as/if needed: 1.15 cf/sx & 15.8 ppg. · After displacing each plug, pull .:!. 15 stands and circulate bottoms up. · The four plugs (above) must cover all hydrocarbon bearing zones by ~ 100 ft. · Catch and save samples of each cement plug. Abandonment Procedure: 1. After logging, RIH with a 3-1/2" "cement sub" and ~ 12 stands of 3-1/2" DP (or tubing) on 5" drill pipe. Break circulation at the shoe. RIH. Circulate and condition the mud at TO prior to pumping the abandonment plugs. R/U Halliburton. 2. Test lines to 3000 psi. Mix and pump balanced cement plugs to cover all hydrocarbon bearing zones in the 8-1/2" hole starting at TO. Spot the abandonment plugs as per the table above. Catch wet samples of each plug. Displace with mud as per the table above. 3. While WOC after setting plug #4. LID excess DP. RIH and tag plug #4. POOH. 4. RIH with an EZSV on 5" DP. Set the EZSV at ~ 5325' MD. Establish injection below the EZSV. Release from the EZSV and test to 1500 psi. Tag the EZSV to confirm its depth. Sting back in to the EZSV. R/U Halliburton. Abandonment Program 2 3/23/2004 e e 5. Test lines to 3000 psi. Mix and pump 122 sx (25 bbl) of "Premium" cement mixed at 15.8 ppg and 1.15 cf/sx. Displace plug #5 through the EZSV with 95 bbl of mud. Pull out of the EZSV and dump the final 5 bbl of cement on top of the EZSV. Rack back one (1) stand of DP and circulate until clean. LID all 5" DP remaining in the hole. (catch wet samples) To 5,258' 6. RIH with the final 3 stands of 3-1/2" DP (+ 240'). R/U Halliburton. Test Lines to 2000 psi. Spot plug #6 from 240' back to surface. Mix and pump 120 sx of type "C" Permafrost cement: 15.6 ppg & 0.99 cflsx. POOH to.±. 60 ft (.±. 25 ft below the mud line). Circulate out excess cement. LID all 3-1/2" DP. (catch wet samples) Plu Len th To BBL 6 240' Surf' 20.5 7. P/U a casing cutter. Cut and pull the 9-5/8" casing.±. 20 ft below the mud line. N/D the wellhead. Cut and pull the 13-3/8" casing.±. 15 ft below the mud line. 8. RIH with OEDP to the TOC from step 26 above. R/U Halliburton. Test lines to 1000 psi. Mix and pump 25 sx (5 BBL) of class "G" % 2% CaCI2 and spot same over the casing stubs. LID DP. Clean the pits. 9. Release the rig. RID and MORT. 10. Clean location. Remove and dispose of all dirty I tainted ice and snow. Conduct a "post drilling" site inspection with the AOGCC field inspector. š!/kn~ ~"ASRC Energy Services \ fit-' EQPTM:hncIIøøY ;> /.2 ~h Sf Daté Attachments: 1. Wellbore diagrams 2. Cementing Program 3. LWO: GR 1 Res, 8-1/2" open hole to T/Sag River Abandonment Program 3 3/23/2004 + 500' MD 3910' MD 5416' MD o 0 J-_____~ e Port Collar - @KERR-IICSEE CDRI'DBATlDM Nikaitchuq #2 Surface Casing Permafrost "L" lead slurry 1500' of "Premium" tail slurry 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) 8-1/2" Hole into the Ivishak 11010' MD e + 500' MD o 0 5416' MD Port Collar e @ KERR-IfC6EE CIJIPOIIATlIIN Nikaitchuq #2 Plug Back 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) Plua #1: 390 sx of class "G" 11010' MD '. + 500' MD o 0 5416' MD Port Collar e @ KEIUl-MCSEE CØllPDRAßDII Nikaitchuq #2 Plug Back Cont'd 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) Plua #2: 390 sx of class "G" Plua #1: 390 sx of class "G" 11010' MD + 500' MD 5416' MD . o 0 Port Collar e @ KERll-lfctiEE CllllPDRA7Ø Nikaitchuq #2 Plug Back Cont'd 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) Plua #3: 390 sx of class "G" Plua #2: 390 sx of class "G" Plua #1: 390 sx of class "G" 11010' MD e + 500' MD o 0 5416' MD I I I I I I 7010' MD I Port Collar e @ KEIlII-MCSEE CtJRPDRAßDN Nikaitchuq #2 Plug Back Cont'd 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) \\r-."\ '-> p\ ~ 'J ~o \:> ~ -\Gs" 'J E.'iJ · Plua #4: 390 sx of class "G" Plua #3: 390 sx of class "G" Plua #2: 390 sx of class "G" Plua #1: 390 sx of class "G" 11010' MD 5250' MD 5325' MD 5416' MD 5560' MD e e @ KERR-IfCBEE CIJIIPORAlJOM Nikaitchuq #2 Casing Shoe Plug <..c.. s '\ II'-- ~ ?\Iè'S ":>~ -k <, \-~ o.\o'>$ê ~.!¿II( r Plua #5: 122 sx of class "G" wI EZSV 9-5/8", 40#, L-80, BTC PIUQ #4: (1000') 390 sx of class "G" Plua #3: (1000') 390 sx of class "G" Plua #2: (1000') 390 sx of class "G" PluQ #1: (1000) 390 sx of class "G" 11010' MD -- 60'RKB 240' RKB (8 joints) 5250' MD 5325' MD 5416' MD 5560' MD e @ KERR-MCGEE CORPORATlOtI Nikaitchuq #2 Surface Plug & Abandon Plua #6: 122 sx of type "C" Permafrost · Spot a cement plug from 240' to suñace · POOH to ± 60' RKB and circulate clean · Cut off 9-5/8" & 13-3/8" just above TOC Plua #5: 122 sx of class "G" wI EZSV 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) 11010' MD e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA 8 ~" Open Hole Cement Abandonment Plugs Revision #3 Prepared for: Skip Coyner Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 150 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Abandonment Cement Recommendation (Pln~ #1. PIne #2. Pln~3. Pln~ #4) Recommendation: Preflush I Spacer: 10 bbl Water, Plug Slurry: 80 bbls - 390 Sks. (450 Ft3) Premium Cement + 0.2% CFR-3, (Friction Reducer), + 0.3% Halad-344 (Fluid Loss Additive), + est. 0.2% HR-5 (Retarder) as required 4 plugs: 320 bbls - 1560 sxs Density (ppg) Yield (cu ft I sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Plug Slurry 15.8 1.15 5.00 <100 o +1- 3:00 >1,300 @ 190°F >2,400 @ 190°F Volume based on: Plug Slurry: Each: 1000 ft of 8 \!zoo Open hole + 15 % excess I ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Abandonment Cement Recommendation Surface Casin2 Shoe œlU2 #5) Recommendation: Preflush I Spacer: 10 bbl Water, Plug Slurry: 25 bbls - 122 Sks. (140 Ft3) Premium Cement + 1 % Calcium Chloride Density (ppg) Yield (cu ft I sk) Water requirements (gaUsk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12hr(est.) 24 hr (est.) PlUff Slurrv 15.8 1.15 5.00 >250 o +/- 3:00 >1,300 @ 80°F >2,400 @ 80 of Volume based on: Plug Slurry: 160 ft of 8 W' Open hole + 15% excess plus 90 ft of9 5/8" 40#/ft Casing + 70 ft on top of EZSV packer + 0% excess (TOP: 5250 ft MD) LI 150 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Abandonment Cement Recommendation Surface (Plu~ #6) Recommendation: Preflush I Spacer: Plug Slurry: 10 bbl Water, 20.5 bbls - 120 Sks. (115 Fe) Type C Permafrost Density (ppg) Yield (cu ft / sk) Water requirements (gal/sk) Fluid Loss (cc130 min.) Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Plug Slurrv 15.6 .99 3.75 >250 +1- 2:30 >500 @ 40 of >1,150 @ 40 of Volume based on: Plug Slurry: 270 ft of9 5/8" 40#IFT Casing+ 0% excess 150 14001 Certified Alaska Green Star Certified HALLIBURTON mwd EWR Elctromagnetlc Wave Restivity DGR Dual Gamma Ray SLD Stabilized Litho...Density RIG MONITORING Applied Drilling Technology I: ~ :¡! ~ i ~ (0 ~ ð (\J, I: ~ I w ~ ~ f .... .... ~ .= N ..; ~ i t!! ,¡ II ~ .. J r."J II:L II ~ .. ::;) Jj ~ i ~ :I .... . . . . . . . . . . .. ~ ~ ~ e 0 C! [ - .... l- t: fl ~ - ~ (J ~ .;¡¡ iij .2' f'I !1.! f'I f'I A <3 .... ~ <3 u. ..:5 ~ :¡ Company Rig WeU Fietd CoI.Jntry DOE NI.Jmœr LatitlJde LønQitlJde UTM E~-üng UTM PEfmsne:nt Datum Me.sn Sea U=\l'et Log MeSiíured Frøm rKiU Ftø..or rKiUing Measured Frøm rKiU Ftø..or Depth Logg.ed 311.00 It Date Logg.ed 13--Jan-10 Tøtst Depth MD: 11010.00 It Spud Date 13...1an-10 It RI.Jn Nø. '1 .:l Si7'¡;:' 1.2 25 in R 5 in Tø: 11010.00 It To: 13...1an-10 TVD: fM94.23 It ¡:~nm 37·tO ft f\.A. ':!.fi n it .£10 54? .0 ft O'".¡A. ^ it Kerr M~ Cørpøratl.oo N.abøra 21E Nik.aitnhuq #2 Exptøratiøo 0. EtA. 10 40 33" 13.99'" N 149 "' 4$" 29.26'" W 160110.52 m ...... A A"^^ 7.'" In Elev sti,¡)n 0.00 It 39.95 It Abøve PEfm DstI.Jffi I MO lOG I Unit Nø. 114 Plot Type:Fiekt Plot Date 23.-Mar-04 RI.Jn Nø. Si2'¡;:' Si2'¡;:' 1':¡,r.t7¡;:¡. in 9.6.25 in c~..·........ ~ ....7.0 toof e Oth!=r Selviœ:Þ Elev. KB 0.00 DF33.38 GL 6.57 WD 0,00 e Job Nø. AK...uw..ooo2893169 ¡:,nm Tn ¡:,nm OOit O.Oft Tn H:l 0 it 5....·16.0 ft MD 1 div 5600 5750 ::::: 5850 5900 5950 6000 6050 6100 6200 6450 6900 6950 7000 7050 7200 7250 9850 1 10250 ~3!11!2004 15:18 9072757542 AOGCC PAGE 01 ,/ /lJ ~ r{:A Sfl1 ~ýv1. . 10. ION COMMISSION 907~276-7542 < ' 907~279-1433 ~"" \\ - \ ~ \. FACS]:M1LE ~RANSMITTAL SHEET, TO, FIl0M~ "\ t:- """- I ~ "F t') , h, ~~~t-- ~~\""~~ /\)G.t--.~~~r>o..~ ~C ~Q ~~~~':J~' COMPANY: PArE: \.A . \.. \. ;}Ö 0 4 \- \.a..., l " TOT ÅL'NO, OF PAGES JNa.UDlNG COVER: t-! SE.NDE.R'S REPEJŒNC£ NUMBER.: ~A:X NUMS~R: dO a - <O~ ~ --'-\"'\5(,0 , PHONE NUMBER: It!::: YOUR REfEÎU¡NCI£ NUMBER: . ~~, )!LVRGENT ,1J;.rOJl. K~V1EW [J PLEII.SE· COMMENT 0 PLEASE RE.PL Y 0 PLEASE :RECYCLE NOTES/'CONMENTS: ,.~~\\ ;)1'.<¿)u.j«\ \. , l\ I--\\~ "::>\--,\\ \~\-~<r' s.~ "~~~ ~~\>~~~ ~ /S" __lÅ.- \(1(.." M-,~ ~C\. ~ ~~c,.,,~ --\"'-(C. \ o::.~-\~ ~\-\L ""-o.S 't-'\C~'0 .~ ~SOO' \«.G..s:2. T'Nt C\\~~ \ ~{'",. .. \c.c ~ \,~ ~~..à-"\ S, ",¿j ',,,,, ~~l 7". { l ~ _ þ,~ ú..~ ~ ~W"=>'-'Q\ \.'ê~\ ,g~,,\k.CL~ CQ~t ~ ~ ~ .\. ~ 'fJ-=> ~~~~ \ kCJ-~~ ~~~ "~(Ó ~~ . . t't ~ ~-\<.. \ c>~\<.\.\c,,\ \,~o..~ Çù~,'t",<\ (t\\~' \;:¡ ",..,,-\ù.y "5\ G"~' '- <c \ ,\,..,~ >""'-...1\- '1<:>....1 ~<t\~ 'cl \:"-".... \œ....,. """- "> '€r'\ 'T t~.lJ'\. ~'O.j AOGCC 3:n WEST 7TH AVENUE, SUJTE 100 ANCHORAGE, AX 9!1::;01.393S 03/11/04 THU 19: 19 [TX/RX NO 8221] !41 001 ,....',., ...." '," -~.. -.' .. ,-, ........... -, - _'_ ..', ,_ .. .. .0" '0. .-' "0' .......~ 03/12/2004 FRI'08:52FAx 202 6~456 133!11 1213134 15: 18 913727.2 . .. i LOWES BUSINESS CENTE.. AOGCC 141003 PAGE 03 . ~Tr lM 1rfE f~) 1] Ln} ulb SS3 1M"'" AVENUE. SUlT~ 100 ANCHOIWiE, ALASKA 995OHl5$ PJ.ONE .. (907) 278-14a3 FAX (907) 276-75412 ~œ,~~'~.~I~~ FRANK H. MlJRKOWSKt, GOII£RNOFr Chm,..s_~8~:: Drilling Manager Kerr-McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage. Alaska 99503 Re: Nikaitchuq'#2 (revisèd) ~:;~~~2~~~~bS Corporat~n Sudàce Location: 1293' FEL &. 2240' FNL, Sec. 22, T14N~ R9E, UM Bottomholc Location: 1091' FET... &. 2245' fNL, Sec- J5, T14N, R9~ UM Dear Mr. Sumrriers: Enclosedisthea.pproved appliçation ror permìftödrill/the aboverererenced exploration well. This revision was necessary due to a change of mote than. 500' lâterál1y in the proposed bottomhole location. This permìttodrilJ does not~empt y~ from obtaining additional permits or approvals required by law :t'rom otber governmental agencies, and does not. authorize conducting drillina operations untü all other required permits and appTovéds ha,ve been . issued. In addition, the Commission reserves the rlaht to withdraw the permit in the event.it was. erroneously issued. A weekly status report is required fi-om the time. the. well is spuddeduntifitIssuspend£d or p1ugsed and. abandooed.The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's inte.mal use. An dry ditch sfimple sets.subtmtted to the Commission must be in 00 greater than30'sampleintervals frQtT1 below the permafi-ostOT from. where sll:ßlPles are first caught and .1 O'sample intervalsthTough target zones. In your application spec;f\C8iions for proposed abandonment plugs were presented. It is not possible to approve tbe P&Aproposa] prior to the we)) being driHed. When itbøs been determined to P&A the we1l, Kerr-McGee should file a Sundry NotIce (Form 403) providing the determIned forr.natioo ìnformatjon and planned p'1ug depths. Operations must be conducted in accordance with AS 31.05 and Tnle 20. Chapter 25 of the Alaska Administrative Code unless the Commission speç,ifically authorizes a variance. Pailure to comply with an applicable provìsion of AS 3) ,OS, Title 20, Chapter 25 of Alaska Administrative Code, or a Commission order, or the terrns and conditi.ons (¡{this perm' ma result in the revocation or suspension of the permit. Please pro....ide at least twen -four notice for a representative of the Commission 10 witness any required Cant t 'ssion's North Slope petroleum field inspector a1659-3607 (pager). BY ORDER OF THE COMMISSION DATED tlri$..1l day of Mareh, 2004 cc: Department ofFish & Game, Habîtat Section w/<J encl. Department of Environmental Cönservation w/o encl. 03/11/04 THU 19: 19 [TXlRX NO 8221] ¡g¡ 003 1a,Typs of Work: Crill IilRedriU U 113. Current Well Class: Exploratory 0 =~-=:~~,~:~::.~:~ng REVISED Re-en\IYD Stratigraphic reJt 0 Service n 2. OÞerator Name: 5. Bond: BI$/'iketlt) Single WeliU 11. Well Nan'le and Numbllc Kerr McGee Oil.&. GI!Is OorponiÍtlQn Bond Nô. 3--798-381 Nii<âïtcfiuq #2 3, Address: 6. PropøSéd Depltc 12. rieldIPOO/(S): ......... 3900 C Street, Ste 744.Mõhofags.AI<99503 MD: 11010' TVD:94~' .. 4a. Location of Well (Govemmental Ser;:toh); 7.Pl'Oþerty Designation: El\Ptoratlcn ·iÄ Surface: 1293' FE!. & 2240' FNL, Seç,22,T14NR9E.UM Nikaltchuq '. .. Toþ of ProcJlJctlve Horizon: 8. Land Use Permit 13. Approximate Spud Date: ;;'< 1102' Fe!. & :2548·FNI....Sec.. 15.T14NRSE, UM ADL 355021 3112/2004 Total Depth: 9. Acres in ProPêrty: ... 14. Distance to N~t 1.001' FeL& 2245' FNL.SEa:, 15.T14N Rge,l1M 5120 Property: 1 091' Norltt FI BHL 4b. Loc$tÌoo of Well ($tate f3aSé PIaJ'Ie Coordinates); 10.K6 Eleva1lon 15. Dlatal1te to Nearest Well --:. Surface:(- .·S27462 'f- 60.522.63 Zcrie-4 1IIA[)...27 (Height aboVe GI..): s8.éfeet \Nith¡'Þoot; .... MPF-33A > 20000f 16. DeViated wells; ..Klckoff ~~: . 800 :feet 17. Maxl/TIl,lm Antic/patedPl'e$Sûr8sln pSig(see20 AÄC25,035)C- ..~ Maximum HoI& Mere; . 36 'degrees Downhole: 40440 psi Surface: 3376 þsl i 18. Casing Pragr.IIrI: .. Setting Deplh Quantity of Cement ......... Size S~flons Top Botlom Co f. 01' $<Icks Hole CasIng Waight Grade CoupPng Length MD TVD MD TVD (Including stage data) nIa 13-3/8" 68# N--SO PIE, 80 32 32 112 112 Drive Pipe cc::· 12-1/4" 905!S" 40# L-80 BTC 5378 32 32 $410 4861 610 !IX Permafrost "1.",10.7 PlIO 540 is)/, "G", 15.8 ppg & 1.15 yld '.. 7 19. PRESENT Wl!LJ.. CONDITION SUMMARY (To be completed for Redrill end Re-Entry O~l'8tions) Total Oepth MD (ft): Total Deþth TVO (ft): P1US$ (measured): Effect De)th MO (ft); ESffect. Depth TVD (ft); Junk (measured):. Casing Length S~e Coment VOlume MD 1VD S1ructural Conductor SOft 13-3fS" Drive Pipe 112 ft 112ft Surface . Intermedlatê ..' Produçtlon .' -: Liner Perforation Depth MD (ft); Perforation Depth TVD (ft): 20. AttFJQÌmen!$; RUng Fee BOP SketchW lJii1ling Procram ~ Timl!!v. Depth Plot 1.:1 SfotaJlow HIi:1.:ard Analysi& lJ Property Plat fJl Dlverter Sketch 0 Seabed Report D Drilling Fluid Program 0 2!1 MC 25.O!:iO l'eCuiréments 0 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the roregong i$ true and correct to the best of my knowledge.. Contact Skip Coyner 339-6269 Printed Name Charles Summers frtle DI116n9 Man.g9/', Kerr McGee 011 & Gas Corporation Signature (U), ,1- l, .... /;"..,.<L Phone 907-339-6370 rJate Marçh 11. 2004 ... / / Commission Use Only Permit to Drill 1:1 Number: Permit Approval See cover letter for o!ner Number: 204.Q38 so. 629"23199.00 Date: March 5, 2004 requlrl!lmen~$, eo"";,.,,, "'.,,...,at : ~ ~ ..'" .. y", I No 0 Mucllog requIred Yes J No 0 Hj roge~ tld me¡¡sures Y. s No 0 Dil'éCtional survey required Y~ No 0 Oth", - ':/I71lfi;J:< "<,.~ ~~~ 6Y ORDE~ OP J~ 1/,./)'1 Approv:ly7 '}/U/ A -' THE COMMISSION Date; ~ ~ '--"'" IE FOn'J11Q.401 Revi~d 1212003 Submit ¡nDuplicate oS: 51 FAX 202 646 4456 LOWES BUSlNESSCÈNTER . . .·/i @ 002 15:1898127... STA[ÉOF=I<A. .. ~E.l~Jt.flt4~ ALASKAOILANDGASCONSERVATIONCOMMISSJON ..'-<. \.J'4yVEL: . j PER::~I~~~ILL \4ARll.200' 03/12/2004 FRI 03/11/213134 DUPL\ CA 03/11/04 THU 19:19 [TX/RX NO 8221] @ 002 , , , w ~ '1 ".! o S10,OOO I a . March 11, 2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 t::' . ......_ t' 0-"-' -, \1AR 11 200 Re: Nikaitchuq #2 Permit No.: 204-038 (3/5/2004) Kerr McGee Oil & Gas Corporation Amended Application for Permit to Drill (10-401) Attached for your review is our Amended Application for Permit to Drill the Nikaitchuq #2 exploration well located approximately four (4) miles north ofOliktok Point. The original APD was approved on March 5, 2004. Since that date, we have received v- an "as built" plat and we have moved the bottom hole location in excess of 500 ft. As of today (3/11/04), drilling has not commenced./All necessary attachments have been revised. ./' Our anticipated spud date is now March 13th, 2004. If you have any questions or concerns about the Amended APD or the drilling plan, please call me at 339-6269 or via cell phone 748-3689 and I will do my best to address your questions or concerns. Sincerely, ~~ ASRC Energy Services Project (Drilling) Mngr. 3900 C Street Suite 702, Rm 744 Anchorage, AI( 99503 (907)-339-6370 ORtG'NAL e e Nikaitchuq #2 Revised Drilling Program (' Co .":>~ <è.\-\Q.- c..\-. -\ \-. '\ ~ .\ '\ ~ Type of Well: "Modified Build & Hold" Drill, core, log and Abandon Suñace Location: Bottom Hole Location: 1293' FEL & 2240' FNL of Section 22, T14N, R9E UM yo' 1091' FEL & 2245' FNL of Section 15, T14N, R9E UM ./ ., AFE Number: 1 I Rig: I Nabors 27E I Estimated Spud Date: 13/13/04 I Operating Rig days: 119 I PTD: 111,010 r I TVD: 19,450' It 1 Pad Elev: 16.6' I 1 DF: 138.8' Geologic Objectives: Sag River Sandstone Mud Proaram: S ud - 2500' 2500' - 5410' 9.0-9.5 9.5 -10.0 8.5-9.5 8.5-9.5 8-1/2" Production Hole 5410'-11010' : PV c 10-15 15 - 20 15 - 25 5410' - 8200' 8200' - 9500' 9500' - 11010' 8.5-9.5 8.5-9.5 8.5-9.5 e e Bit Program: Interval Size Type Footage Hours ROP RPM WOB Surf - 5,410' 12-1/4" 1-1-7 5300' 42 126 200/300 5-30 5,410' - 10,355' 8-1/2" PDC 4945' 43 115 200/300 5-25 10,355' -10,445' 8-1/2" CORE 90' 20 4.5 50160 5-10 10,445' - 11,010' 8-1/2" PDC 565' 9 62 200/300 5-25 Directional Surveys: While Drilling: Surface to TMD: MWD surveys every 90 ft Corrections & verifications using IFR Cazandra Mud Logging: Surface Hole [12-1/4"]: Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. (Samples: 30' /10') Mud loggers from surface to casing point. Production Hole [8-1/2"]: Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. (Samples: 30' /10') Mud loggers from casing point to total depth. v ,/ Formation Markers: Formation Tops MD TVD B/Permafrost 1833' 1783' TlWest Sak 3929' 3483' Possible Heavy Oil Zone T/Colville ~, 5332' 4618' 9-5/8" Suñace Casing 5410' 4681' L. Brookian Fan 7518' 6387' Hydrocarbon Bearing, 8.5 ppg EMW T/HRZ 8231' 6987' T/Kalubik 8287' 7037' T/Kuparuk 8434' 7167' Hydrocarbon Bearing, 9.8 ppg EMW LeU/Kingak 8580' 7297' T/Nuiqsut 9032' 7697' Hydrocarbon Bearing, 9.6 ppg EMW T/Sag River 10354' 8869' Hydrocarbon Bearing, 9.8 - 6.2 ppg EMW T/Shublik 10468' 8970' T/lvishak 10705' 9180' Possible Hydrocarbons 9.4 ppg EMW PTD 11010' 9450' " ,/ 2 e e ProDosed Loaaina Proaram: Surface Hole: MWD 1 LWD: MWD/GRlRES/NEU/DEN/Sonic Open Hole: Gas Detection, Mud Logging & samples E-Line: None planned Production Hole: MWD 1 LWD: MWD/GRlRES/PWD/NEU/DEN/Sonic Open Hole: Gas Detection, Mud Logging & samples E-Line: Quad-Combo + Sonic + MDT's + SWC's FMII CMR + Velocity Check Shot v ./ V' CasinalTubina Proaram: Hole Casing WtlFt Grade Cplg Length Top Bottom Size OD MD MD n/a 13-3/8" 68.0# L-80 PIE 80' GL 112' 12-1/4" 9-518" 40.0# L-80 BTC 5378' 32' 5410' 8-1/2" n/a Cement Calculations: Hole Size: 12-114" Casing Size: 9-5/8" Basis for Lead: 200% excess through the Permafrost to 1830' MD and 25% excess Calculations: Below the Permafrost. Lead slurry to fill from 3910' MD to Surface. Tail: Based on 1500' of annular fill + 25% excess + 80' shoe track volume. Tail TOG: at +/- 3910' Volumes: Lead 610 sx of Permafrost L: 10.7 ppg, 4.15 cf/sx Tail 540 sx of Premium cement + additives Intearitv Testina: Test Point Depth Test Type LOT: EMW Surface Casing Shoe 20' of new hole LOT 13.2 ppg Minimum expected 3 e e Well Control: The casing head will be installed on the 13-3/8" drive pipe along with a 13-5/8" (5M) diverter spool. The 13-5/8" (5M) BOP stack will be installed above the diverter spool. The 16" diverter valve and 16" diverter line will be tied in to the diverter spool outlet. The 12-1/4" surface hole will be drilled with the 13-5/8" annular configured as a diverter. After setting and cementing the 9-5/8" surface casing, the diverter line will be removed and'a 13-5/8" (5M) blind flange will be installed on the diverter spool outlet. The 13-5/8" BOP stack will be re-configured to act as BOPs. The production hole will be drilled with well control equipment consisting of 13-5/8" (5000 psi) working pressure pipe rams (2), blind rams, and annular preventer capable of handling maximum potential surface pressures. Based upon offset well data, the rams, valves and manifold will all be tested to 5000 psi and the annular will be tested to 3500 psi. The maximum anticipated Surface Pressure based on the pressure in the Sag River formation: 4440 psi at -8869' SS (8830' TVD) and a 0.12 psilft gradient to surface is: 4440 psi - (8869 ft x 0.12 psi/ft) = 3376 psi Disposal of Drillina Waste: · Cuttings Handling: Cuttings generated from drilling operations will be ground ./ and liquefied on location using the "245 Ball Mill". Liquefied cuttings, mud, etc. will be hauled to Kuparuk's disposal well: 1 R-18 for underground injection. Any solid drilling waste not suitable for injection into 1 R-18 will be hauled to G & I #3: v located on DS-04, Prudhoe Bay. · Fluid Handling: Haul all drilling and completion fluids wastes to 1 R-18 for disposal. Oil and water produced during well test(s) will be hauled to CPF-3 where it will be processed. · Sewage (grey/black water): Camp waste water will be hauled to the sewage treatment plant at Kuparuk where it will be treated and injected along with Kuparuk's camp waste water, etc. H2S: · H2S has not been seen or reported from any of the offset wells that produce from the Sag River and/or Ivishak formations. As a precaution, however, H2S ...../ monitors will be used at all times in accordance with State Regulations. 4 e e DRilLING AND COMPLETION PROCEDURE Pre-Rig Work: 1. The 13-3/8" non-insulated conductor has been driven to refusal at 112' RKB. 2. NU the multi-bowl 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 notify sign in at the security guard post near the spine road AND check in with the camp boss (medic) upon arrival at location. Travelers must check out with the camp boss (medic) when leaving location AND sign out at the security guard post. 3. A Pre-Spud meeting will be held with all rig personnel and service personnel in Anchorage. A second Pre-Spud meeting will be held in the rig camp with all field personnel involved. 4. A planning meeting will be held at the camp prior to each major phase of the operation: surface hole, surface casing, production hole, logging, running liner, running completion. 5. A daily operations meeting will be held to plan out the day's work and a written "Plan of the Day" will be prepared and distributed to key rig and service personnel. 6. All tools and equipment to be checked, strapped and callipered before they are needed. 7. 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. 8. Pit drills/kick drills will be conducted one with each crew in each hole section. 9. 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. 10. 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. Rig Operations: 1. MIRU Nabors Rig 27E, Pioneer camp, the ball mill, the medic skid, rig instrumentation, directional drilling equipment, LWD equipment, gas detectors, PVT, Flo-Show, etc.. 2. Take on water and mix spud mud. Make sure all solids control equipment if operating at capacity. P/U 55 additional stands of 5" drill pipe and rack it in the derrick. 3. N/U the BOP's on the wellhead with the diverter spool in between. RU the diverter valve and diverter lines. Function test the diverter system. Note: the AOGCC field inspector must witness the function test. 5 e e ¡ 4. P/U a 12-1/4" and BHA with MWD/GRlRES/NEUlDEN/Sonic tools. Rotary drill to KOP at 800'. Then build angle at 3°/100' as per the attached directional drilling plan. While drilling the surface hole, stop and circulate the hole clean as/if needed. Rotary drill as much as possible with rotary speed ~ 100 rpm. The flow rate should be at least 700 gpm but not ~ 850 gpm. Control drill if necessary as limited by the solids control equipment and the ball mill. Use Super Suckers if needed to keep up with the waste generated while drilling. Drill the surface hole +/- 100' into the Colville and set casing at +/- 5410' MD. Drill the hole to fit the casing including 10'-20' of rat hole: we are using a mandrel casing hanger. 5. At casing point, circulate the hole clean. Rotate the drill string at ~ 100 rpm to help clean the hole. Make a wiper trip up to the BHA. RIH to bottom and circulate bottoms up again. POOH for logs. UD LWD tools as required. 6. Run and cement the 9-5/8",40# surface casing. A port collar will be run in the casing string at +/- 500' to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. The depth decision will be made prior to running the casing: dependant on the hole conditions. 7. After cementing the 9-5/8" casing, drain and wash out the BOP stack. SeUtest the 9-5/8" packoff. N/D the diverter valve and diverter lines. N/U the 13-5/8" blind flange and test the BOPE to 250 psi /5000 psi. Test the annular to 250 psi /3500 psi. 8. M/U 8-1/2" directional drilling assembly with MWD/GRlRES/NEUlDEN/Sonic/PWD and a bent-housing motor. P/U +/- 55 additional stands of 5" drill pipe. RIH to the float collar. Test the 9-5/8" casing to 3500 psi: same as the annular. 9. Drill out shoe joints and 20' of new formation. Displace well to clean mud (per program). Pull up into the shoe and perform a Leak Off Test. 10. Drill the 8-112" hole to TD as directed following the directional drilling plan. Adjust the mud weight as dictated by hole conditions and in accordance with the attached mud program. Stop and circulate bottoms up as/if needed and rotate the drill pipe at ~ 90 rpm as much as possible to aid hole cleaning. Before drilling into the HRZ, make a wiper trip AND ensure that the mud is conditioned to as per program. 11. Drill ahead to the core point as directed. At core point, circulate bottoms up. Make a wiper trip above the HRZ and return to bottom. Circulate bottoms up. POOH. 12. Make up the coring assembly and RIH. Break circulation, drop the ball and cut the core. POOH and UD the core barrel, etc. 13. RIH with the bit, LWD's & BHA. Drill ahead to TD as directed. At TD, circulate and condition hole for logs, MDT's, etc. Make a wiper trip through the "new hole", RIH to bottom and circulate bottoms up. POOH. 14. RlU E-Line and log the hole as directed. RD E-Line. 15. After logging, RIH with an 1100' x 3-1/2" stinger on 5" DP. Circulate and condition the mud. 16. A Sundry Notice will be submitted with a P & A program for AOGCC approval as per the approved, original permit to drill. JIi~ kyn .. 1!fJ:.... ASRC Energyt;¡ervlceì!l Kt:~Ii:a:II::TØlltWlàkI8Y".."......""..:-:_::-""_"""""_"-_- 6 e e Attachments: · Original, approved Permit to Drill · As Built Survey plat · Directional/Area plat · Well bore Schematic · Drilling Curve: Days -v- Depth · Planned Well Profile · Frac Gradient Plot · BOP and Diverter Schematic · Directional Drilling program · Drilling Mud Program · Cementing Program · Shallow Hazard Survey - Previously submitted · Predicted Abnormal Pressure Study - Previously submitted 7 e ~1r~1rŒ ffiJ~ ~~~~[(~ AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Charles Summers Drilling Manager Ken--McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage, Alaska 99503 e FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nikaitchuq #2 Ken--McGee Oil & Gas Corporation Permit No: 204-038 Surface Location: 1290' FEL & 2240' FNL, Sec. 22, T14N, R9E, UM Bottomhole Location: 1211' FWL & 2373' FNL, Sec. 14, T14N, R9E, UM Dear Mr. Summers: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was en-oneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 3D' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application specifications for proposed abandonment plugs were presented. It is not possible to approve the P&A proposal prior to the well being drilled. When it has been determined to P&A the well, Kerr-McGee should fIle a Sundry Notice (Form 403) providing the determined formation information and planned plug depths. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Çode 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 (2 urs notice for a representative of the Commission to witness any required test. t 'ssion's North Slope petroleum field inspector at 659-3607 (pager). BY ORDER <l& THE COMMISSION DATED this~ day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type ofWOl1<: Drill 0 Redrill !J 1b. Type of well. Exploratory 0 . Stratigraphic Test 0 Development 011 U Re-entry []Deepen 0 Service o Development Gas 0 Single Zone 0 Multlpte Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Kerr McGee 011 & Gas Corporation 33 feet 3. Address 6. Property Designation Exploration 3900 "C" Street, Room 744, Anchorage, AK 99503 ADL 3550211 4. L.ooatlon of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) 1290' FEL & 2240' FNL, Sec 22 T14N R9E UM NlkaltchUQ Statewide At top of productive Interval 8. Well number Number 1142' FWL & 2516' FNL, Sec 14 T14N R9E UM 8938'TVD 2 3-798-381 At total depth 9. Approximate spud date Amount 1211' FWL & 2373' FNL, See 14 T14N R9E UM March 6, 2003 $200,000 12. Distance to nearest property line 13. DIstance to nearest well 14. Number of acres In property 15. Proposed depth (MD and 1VO) 3040 Feet FSL of Section 22 BPXA, MPF-33A, > 17,600 Feet 5120 11211' MD 19368' TVD 16. To be compteted for deviated wells 17. AntIcipated pressure (see 20 MC 25.035 (e)(2» KIckoff depth: 400' MD Maximum hole angle 40° Maximum surface 3367 pslg At Sag River Depth (8938' TVD) = 4440 psi 18. Casing program Settina Depth size Sœ ficatlons Top Bottom Quantitv of Cement Hole Casino WeIoht Grade CouDllno LenoIh MD TVD MD TVD (Include staae data) 13-3/8" 68# K-55 PE 80 32 32 112 112 Drive Pipe 12-1/4" 9-5/8" 40# L-80 BTC 5708 30 30 5740 4697 670 sx Pennafrost L & 560 sx G 8-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Elfecllve Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth RECE\VEO fEB '! S 2004 commiSS\01\ \n & Gas Cons. Perforation depth: measured ~\a,~a \ . þ.1\cbotage true vertical 20. Attachments Fßlng fee 0 Property Plat 0 BOP Sketch 0 Dlverter Sketch 0 Drilling program 0 DrIlling fluid program 0T1me VB depth ptot ~efractIon analysis 0Seabed report 020 MC 25.050 requirements 0 21. I hereby certify that the forego1ng Is true and correct to the best of my knowledge HJr quesuons call ;;;KIP voyner Slgned~~~ ~ . Title: KelT-McGee 011 & Gas Corp Date 1/2312004 C 6S Summers commission Use Onlv F I PermtN~¥ ---D3ð I API:~:z.,9~Z.3(99-c::ð I Approvaldate ~/4!ó4 See cover letter for other requirements ........."'- ~ .81 v.. 0 ... .............' ~ !f v.. U ... ~rogen sulfide measures Yes 0 No Directional survey required Yes 0 No RequIred working OPE 2M; 0 3M; IiJ 5M; ~ 10M; 0 0 Othor. 50 /~'! 7.' ~~ 0..'7 V\<:>- ,,<,<,- by order of ð;~ ()Jf IDY ¡Jr~ ~~ A Commissioner the commission Date \.. ~.~'- LtCATE I , , Form 10-401 Rev. 12/1/85 . OUP DESCRIPTION 14 NOTE S: D 1. COORDS SHOWN ARE AK. STATE PLANE ZONE 4, NAD27. 2. DATE OF SURVEY: 2/25/04, F.B. L04-03, pp 31-34. 3. BASIS OF LOCATION: MON DS3R SOUTH2, BY L.H.D. & ASSOC. 4. LOCA nONS AND ELEVATION DETERMINED WITH LEICA 500 SERIES GPS UNITS, USING GEOID 99. 5. GEOGRAPHIC COORDINATES ARE NAD 27. 6. ALL DISTANCES ARE TRUE. 7. ELEVATIONS ARE B.P.M.S.L. 23 26 NIKAITCHUQ #2 CONDo AS-BUILT LOCA TED WI THIN PROTRACTED SEC. 22, T 14 N, & R 9 E, c/ UMIAT MERIDIAN. 2240' F.N.L, 1293' F.E.L." LA T = 70' 33' 13.987" LONG = 149' 46' 29.276" Y = 6,052,263.00 X = 527,462.33 TOP OF CELLAR ELEV. = 6.57' 36 31 32 33 34 35 T14N int T13N 2 , VICINITY MAP 1~4_ 22123 N o .q- N N NIKAITCHUQ #2 -0 1293' ~~~"1t..., ....~ 'S OF 11 / ..... .. h\ ............ z.../I \\ -. · -< í' ..' '..; 'V.L~. .. ( ____ '" .11 ..... .: - J,.... *........ . ,- -. ~ : ~i 49th '\ J} ~ "'.....:...............II.......I...........~.....~ - = ~.................................I..............- "'?)~ :Q::. ~ '2>~. BRIAN G. MANGOLD .: f? ~/. 'w- ,....... ú',.A .... LS-8626 .... ¡¡s. - 'II':. ('; '. .' -3'-. . ~Á' .... .... C) .- . "() .... ..-". . j:J ........... ~v. ..... i?OF'[SS ION!'.\.. \..Þ'-....... '..1t.",~~~ SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 25, 2004. ~ LOUNSBURY & ASSOCIATES, INC. S~EYORS ENGINEERS PLANNERS ConocJPhillips Alaska, Inc. CADD FILE NO. DRAWING NO: LK601D548 AREA: MODULE: NIKAITCHUQ #2 CONDUCTOR ASBUIL T UNIT: OF 1 REV: o NSK 6.01-d548 PART: · ()\V ~\-- \d- \ \ t-\\) '-- J'S') <-, ç-~ \.- ~c\~ Nikaitchuq No.2 (Bottom Hole Location) 15 22 I I I I I I I I I I I I I I I I ADL 355021 (5120 total acres) (includes sec. 14, 15,22 & 23) Farmout from BP Armstrong 0 & G Kerr McGee 0 & G Nikaitchuq No.2 (Surface Location) Nikaitchuq No.2 Suñace Loc'n in Section 22 T14N R9E / 1293' FEL & 2240 FNL ,/ 6052263.' N & 527462.33' E NAD 27. Zone 4 v v Bottom Hole Loc'n in Sec 15 T14N R9E v'. 1091' FEL & 2245' FNL '" 6057538.' N & 527637' E NAD 27, Zone 4 14 23 BPXA NW Milne Point No.1 BHL: Kuparuk ~47'FEU 1000 2000 3000 4000 5000 .c - Q. (þ C 6000 "C e ; 7000 ca (þ :! 8000 9000 10000 11000 12000 13000 e e Nikaitchuq #2 __!__~1_l__~____j__i__~ _:-- --~--~--i---i-- : : :: :::: :::: I I : I : I : I :: I : : : I: I I I I I I I I - -1- - -I - ~ - - I ~ - - - --t - - ~ - - í - -;- - ~ - - 1 - - j- - - -I - - I I I I : I : I I I I I I I I I I I I: I : I I I II : 1 II I I I - _:_ : I I I I I I :::: I ì-- --i-----i-- - r--I-- --1--+---1---1-- I I I I I 1 I I I I I I Ii: I I: I: I : - _:- - j __l\~ - -- L - L -l--:-- - - L ~ --:-- L- : I I: I: I I I I : I I I : I : I I: I: I : . H \ n Set a~d ce~ent g.~8" . I I " Casing at 5410' MD : :: I: I I -~--~--I- I I I : I o -r I I I --¡--.l-.- I I I I I : : : : - - ~ - -1- - -:- - ~ -- I I I I I I I I I I I I I : : I - - ~ - -1- - -:- - ~ -- I I I I I I I I I I I I I I : [ I - - ~ - - 1- - -; - - ~ - - I I I I I I I I I I __L_ I I I I I I I 1- - -I - - I I I I I I I - I I I I - - I I : I : I I : I I --'----1----1--- I I I I I I t I I I I : I : I I : I I --¡-----ì---L-- I I I I I I I I I I I : I : I I : I I --[-----î--..1-- I I I I I I I I I I I : I : I I I I I --1-'- -î--..L-- I I I I I I I I I I : I : I I I I I --1-- -Î~-.L-- I I I I I I 1 I I I I : I : I I I I I __1__ _¡__..1__ I I I I I I I I I I I : I : I I I I I --~- .--t---1-- I I I I I I I I I I _-j__-1__ I I I I I I I I I I --t---.L-- I I I I I I I I I I _-1__1__ I I I I I I I : : : : - -:-. - -: - - ~ - - + - - I I : I IP&A1 : I I I : I I I - -1- - -1- - T -- I : I I I I I : : : : - - 1- _ _1_ _ -I _ _ ~ _ _ I I I I I I I I I I I I : : : - - } - - 1- - -: - - I : I I I : : : : _ _ L _ _ :_ _ _I _ _ ~ _ _ I I I I I I I I I I I ~. I r- : I : I I I I I I I I I I : I: : I : I - Î - -- ~ - - I - - - - ~ - - + - - r - -:- : I I : I : I I I I I I I : I: : I : 1 [ : I I: I I -~-----I----~-----~- I : I I: I I I 1 I I I 1 I I I I I I I I I : I I I _ ~ _ _ ~ _ _ ~ _ _ _ _ ~ Kuparuk : :: : I : I I 1 I : ': I Nuiqsit I : I I I I -~--I--r----~--T--~- I I I: I: I I I I I I I 1 : I: I I I : I Sag River _1_ ---1-----r----- I : I I I I I I I I I I I --1----1-- I I I I I I I I I I I --1---1-- I I I I I - -I-- I I I I I I I I I I ~ I I : I : I __~--~--:---:-- __L__~--I--~-- I I I I : I : : I : I: I I I I I I 1 I I I I I 1 : I : I I 1 I I I - \:u:u:___:u u:u:_u:u~u u I I I 1 I: I I - -\:...) :--i:-- J-... ~ -~ :-_~_·_:u L- I I I I : I : I I : I: I: I I -~~\: ~X-j ~ ~-~~~-L--:uL- I I I : I : I I : I: I: I I : 1'1 I I: I : -,- .... """'----.... - - '7 -,- . I I - - l' - {- - - 1- - -I - ~NI - - [- - -: - - Î - - - _1_,. -1- _ _ .... _,_ "\ I : I I: I: I I : I : I : I I : I : I I - - -t - - - - -,-1 Logs SWC's MDT's, etc. I : II ' , I I I I I : I : I I : I 1 - - -+ - - - - - 1- - -I - - I I I I I : I : - - - - - - - : Ivishak I : I:: I I I I --I----.J--T--I-- I : I : I I I I I I I I I I I : I I : I _ _ ¡-- _ _ _ _ .....I _ _ ~ _ _ 1- _ _1_ _ I I I I I I I I I o 5 I I -=- I=-_ I I I :-- I - - -,- - 10 Rig Days I I I I I I I --1--1-- I I I I I I I -i-- I I 15 - --~- I I I I I - _I__ I I I 20 25 -- + 500' MD 3910' MD 5410' MD o 0 1------... e Port Collar Nikaitchuq #2 Revised Surface Casing Permafrost "L" lead slurry 1500' of "Premium" tail slurry 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) ... 'ðv.1I-*" '> ,~'" \ "> ~ 8-1/2" Hole into the Ivishak 11010' MD 2000 3000 - 4000 c > t- 5000 6000 7000 8000 9000 10000 -1000 . e Nikaitchuq #2 o : I I I I I I I :: I : I : - í _1- -I - - + - ~ - - ....¡ - T - L - - -I - I - t- - -1- -I - I - I : I I I : I: I I I I: I -: - ~ - ~ - -:- -: - ~ - -:- -:- -: - - ~ - ~ -:- - - ~ - : - ~ - - _l_f--- _--4-~_L_-_I_J_·r_ -I-~- _1-_1__:_ :: ::: I: I : I : I I I : I ::: : I: I: I ::: -:- -: - ~ - - ~ -:- -: - -_:,_-_:_-~-_- -_:_-_~,_-_:_- - -1-1- +-- ~-+-~---I-ì-L- , I I : I: I: I ::: _1- _I - - - - f- - - - - --I- - T _ L - -I - -. - + - : I I I: I I I I I I I : I -I- _1_ -:- I I I -~ - T - I I I -1- -I- I I _J_+_ I I I I - ì -.1- - I I I I I _1- -+_ I I I I -T-I- I I -1- -I-- I I I I I I -¡-I- I I -I- _I_ I I _1- -j_ I I I I I I I --1--r- I I -1- - I I I -¡-I- I I I - , I -I I I I I 1000 I I - ~ - 1- - I I I I -1-1- _ ~ _ ~ _ _ _ _ ~ _ 9-5/8" at : I I I 5410' MD o 1000 2000 3000 4000 5000 6000 7000 Vertical Section 3000 .c - c. G) Q Cã U 4000 1:: G) > G) ~ ~ I- 5000 sc e e Offset LOT's (Frac Gradient) o : : :: ~:: J :::: : i :: J:: ~ :::: _:__:_ ~ _l_ _ ~ _:__:_ J_ -1--1--1-1- -I ~:--I- 1- -~-ï~I--:- -1-1 -r--I--- I~Î-I-I ---I-i-...L-r- I I I I I : I :: I I : I I: I I : I :: I I I I I I I I I I I 1 - " - ~, -:- -',- - +,' - ~ - ,,- -,:- - - -;i ,- ~ - ~ - - -,- ~ - T -, Note: the offset wells in this block :- 1.1 I I I I : I I - ~ - ~ - ~ -~ -- -:-: = 7 - ~ - -,-.,.- ~ -,- -~ -:--,- ~ were all drilled through the Kingak r- ¡ 1 I I I ,.1 I : 1_..1: I I : I : , , ',' ,',", ',_' , " & Sag River with < 11.1# mud. c-,-- I I I I. I I I t I I: I I : -1- -1 - ~ - Î - - 1- -:- -1. J - - ~ -:- -..~ - - ~ - 1-:- -: 1- : ; I: : I :.~ I I 1 'fI I 1 I I I - r -,--:- r -,- ~ -,- -.- - ~ - T - ~ -;.- --,- ~ - + - Note: Nikaitchuq #1 was drilled :- I I I I I i- I J . : ¡ : : I - ~ - L ~ -'- -- -' - ~ - -'- - L·_ --:--'- L ~ -, - --,-..., -- with 10.7# mud and ECD's < 12#. L_ : I ': I I : I ~ I : t I .: : I : I 1 I I ¡ I I I I I I I I -.1 I I I : It: I 1 : I ,. t : I I -. I J: 1 I : I I: t I : !: :::: -:-~-:-7- -:--:-~-~- ~-:--:-:- -~.¡¡-:--:- -~-:-~-:---:-:-~-:---:-~-:-:- -:--,-~-~- _~-:-_I_~- _~_L_:__:_ _Y_~_~_I___~_~_L_~___:_~_~_~_ _1__I_~_-1_ _~_:__I_~_ _~_~_:___ I I ~ r ¡ ~ I :.. I I: I 1-.: I I: r I : I I: ¡ I : I 1: : -~NWMilnePoint.#1 ~__I_~_~_L_ _:~_I_~_~_ I, I I ,__~_I___ _~_!..._L-_:___J_J._~_I__ : , " "" : ~ :: :: \: Thetis Is. #1 ::: :::: :::: I : I: : I :: 1-: ¡ I: I 7' : 1 I: I 1 : 1 I: I I : I r : I 1 I _1__:~J_.1_ _~_I_~_~_ _~_L_:__I~ _J._~_I__I___~_-!._L_~___I_..l_~_~_ _I_~_J_J._ ~i---r rr - ~ -~ -i--i- - ~ - ~ -~:-- - ~ - ~- ~ -i- ~ .~- ~ - ~ - ~ - -:- -i- J - ~ - -:--:--:- L - ~ -~ -:- L I 1 : I 1: I I ; I I -. I!: 1 -.: I I : I :: :: I: : : : -¿-r-¡--:---;-T-L-I----r-J-t--.-- _1_-;_,_.1_ _1j._1_--.J_;_ -1-:--1--1- -..l-ï-:--I- _;_+_L_I_ I 1 I I :! I: I I_ : r I: I. I : I I I ¡ I : l I: I,': " I ! I I I I I I I_ ¡ I I -I ¡ 1 ¡ I 1 I , , ' , NW Milne Point. #1}[' ., ' , :' '~." :,,' ":' ':" I 1 I ¡ 1 ' r.1 I t I. I 1 I r 1 I ~-'-7-~- Jones Island #1 _L ~-r-,--:-...,- -,-~.,--,- -~-:-,T--:-'-7-r---,-~--r-,- I : I I .. I I 1 I ¡ · I ¡ 0 kt k S #1 I I I I I -,--,---<-,- _L_,__;__'_I_+_~_,__,_ ~-f--'---.J-4-1~L__-,-- Ii 0 tate ~_ _L_,__'_.J_ 1-1 I ~ I: 1 I 1.1 'I ' ¡ 'I I I : 1 I I I 'I I I..~ ~ I I r 1 1 I. I!! 1 ! I I 1 r 1 1 , ~ :' ~ ÎNikaitchuq#1 , ~ .~-~-,- -:--:-,-~; -~-,--:-~- -,-~-:--,- -~-~-,-:- : 1 I: ) MPE-13 ~~..... 1 I: ! 1 : r. ! : I 1 : I ¡: I 1 : ' : I 1: ¡ I. ;: I;: 1 ¡.: : 1 j : ¡ I: ! 1 : I 1 1 1 1 I,'l! .. 1 1 1 I. ¡ 1 1 ¡I I 1 . I - ~ - -of- - 1 - ~ - - -1- I - t)J. - r - -1- -: - "1 - .1L- - -1-- -¡ - ~ - - r - 1- -:- -I - ~ - ~ - I -1- - - ~ - Î - ! - ~ - - -1- 1 - ~ - I - ! '! "..y... - I . _~.' \J-.J'- t l ".- k,.""IF- I .. 'I I I liT I 1 1 II! I 1 , 1 -1- -:- ~ m~~.,_~ ~~ ~ -f - I-I~~:--:- ... - ~ ~ -,- -- ~ - {- f- -~ - - -:~-4 - ~- I- - -,--:- ~ - + - -~ -:- -,- ~- ! I ! 1~ - It 1 I_,.s.-_t.... 1 1 1 'r: 1 I 1 1 1 I.I! I 1 1 I I 1 I ! 1 _~-I-_I_-:~ _L~ -~y\~-L_- _J_J...~_ _I_-I_~_-!._ _L_~._I_J_ _~_I__I__:_ _-!._L_~_I_ I : I I : 1 I: ¡ 1 : : r _I : I I: 1 1_: I I: 1 1 : I 1 : I ) I) 1 1 I ¡ 1 1 I I I I. ! I I I 1 1.1 I II! t 1 I 1 1 ) I 1 1 ¡ I 1 I! 1 1 P_ I 1 liT. 1 I I ¡ 1 I 1 1 : I I: 1 I : I I:!! 1 1 :-. ¡ 1 :! I:!" r : I I: ! I : 1 - 1 - ~ - ~ - 1- - - -: - ~ - T - ~ - - ~:- -I - ~ - ~ - - -:- -: - I -. - ~ -:- -1- ~ - - ~ - 1 -:-..- - 1 - ~ - ~ - ,- - - ~ - ~ - T - ~ - : I I: 1 1 : 1 I: I I I 1 :. ! I : I I: I I_ : 1 I: ! I : 1 - - ~ - ì - - - - 1- -1- - - --.. - - r - - -1- -I - - - I- -1- - - - -+ - T - - -1- - - ì - - - + - r" - - - - - ï - - - -1- -1- - - -+ - : I I: 1 1 : 1 I: j I I I : -. I I : 1 I: I ~~ : 1 I: I ¡ : I -~-:--:-~- -~-~-:--:- -~-7-~-:113 21+-~--·';-~-~-~- -:--:-~--·Th..;L-I~--#'-1-J- -~-~-:--:- 1 : : 1 ::!: : 1 ::1 . : I f.: I: : I: e..s s. : : 1 : I 1 I I 1 1 I I I I .1 ¡ I I ¡ I I_ I 1 I I I 1 : I 1 : 1 I: ! ¡ : I : I I :., 1; I I : 1 I _I ¡ I : 1 I : - ~ - T - ~ -:- - - -1- ~ - ~ -,- - -:- ~-I- ~ - - -1- ~- ~ - -1- ..~- -:-1- - ~ -~~¡- -:- - ~ -, - ~ -:- - - -1- ~- ~ -¡-- I I 1 1 1 I ¡ 1 I I I fit I ¡ 1 I I. I 1 I I -: - J - -+ - ~ - -1- _I - ~ _ 1 - - f- _;_ _I _ ~ _ _ _ L _1_ _: _ _ 1 _ 4-'" ~ _1_ _ _ --i _ ~ _ L _ f- _ _ _: _ .J __-+ _ ~ _ _ 1_ _I _ ~ _ 1. _ 1 : ¡ I : 1 I: It: 1 : It: I ): I I : ¡ I: ~ I : I I : ! 1 I 1 I I! I 1 1 I 1 I I 1 I I I I -,--:--1-1- ~~-r--I--;- -1"-I-~-I--- -~-,-,---:-"1-f-~- -I-~I-~-Î- -1--:--1-1- -~-r--I--:- : I : ¡ I: I ¡ : 1 I: I: I I: ¡ I : 1 I: I 1 : I: I 1 1000 2000 6000 7000 8000 10.0 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 EMW (ppg) 9/02 e ~- f-----.-- r . 11M" I r IIDDOf am: ww: ~.,ø..-- , "-IFfY ±-~ r"lM" '.,..6 .~ .'~.~~_._------'.. e Nabors 27E 13 Sir IIIIIIII HVDRIL ANNWR ... BOL'IID F1NfGE ~ 13 s¡r IIIGOf HYDRL MPL PIPE IWI BOLD F1NfGE SINII.E 13 s¡r 5IIOOf HYDRL MPL IIJfI) !WI IOL1ED F1NfGE 4- IOCIOI HCR YIüE ... .- CHOICE LINE .- IOCIOI am: w.w; IOL'IID F1NfGE SINII.E 13 s¡r IIIGOf HYDRL MPL PIPE !WI . Ç.:.:.. 13-5/8" x 5000# Diverter "T" IOL1ED F1NfGE " . I " i \. BOP MODE · Annular: Normal Operation · Rams: Normal Operation · 13-5/8" Blind Flange over the outlet DIVERTER MODE · Annular: Diverter Operation · Rams: Locked Open · 13-5/8" X 16" Adapter, 16" Knife Valve & 16" Diverter Line I-- f- 16" Diverter Line <, Kerr McGee Oil & Gas Corp. Western No NW Miln -- Proposal Report 10 March, 2004 Surface Coordinates: 6052263.00 N, 527462.33 E (70· 33'13.9873" N, 149· 46' 29.2758" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 38. 77ft above Mean Sea Level e Proposal Ref: pro2068 1IpBI"'"..-.y-l!lLJl1 Kerr McGee DRILLING A~":'=~~: North 510 e Alaska BHL @ See 15 - T 14N - R9E, 2245' FNL & 1091' FEL Scale~~~~nJ~OOOft Total Depth: 11009.71ft MD, 9450.00ftJVD 0 TARGET: 10363.91ft MD. 8868.77ft TVD See 15 - T14N - R9E 2548.14' FNL & 1102.31' FEL 0- Surface @ Sec. 22 - T14N - R9E, 2239.41' FNL & 1293.38' FEL 2000 KOP Begin Dir @ 3.00/100ft 800.000 MD, 800.00ft TV Nlk4ilcIulq #1 T1 Œrcle,1/tuI/ns: 100.00jl 886& 77 TVD, 4970.76 N. 185.09 E KOP Begin Dir @ 3.00/100ft : 800.00ft MD, 800.00ft TVD End Dir, Start Sail @ 27.59° 8215.69ft MD, 6973.700 TVD End Dir, Start Sail @ 36.0° : 2000.00ft MD, 1922.59ft TVD - - - - - - - ~,)f¡.\.~ (181~) Section Azimuth: 2.109° (True North) Begin Dir @ 1.5°/1 OOft 7655.02ft MD, 6497.59ft TV Well; Current Well Properties Nikaitchuq #2 '§' o ¡¡: 4000 C> ¡g. ;; Co CD Q 13 'E CD >6000 - --Y;p{;j'·fj~ihiTIï\Vt,;;!S&k, g:¡K:~'} Horizontal Coordinates; Ref. Global Coordinates: 6052263.00 N, 527462.33 E Ref. Geographical Coordinates; 70' 33' 13.9873" N, 149' 46' 29.2758" W Sec. 22-T14N-R9E, 2239.41' FNL & 1293.38' FE 57'f' 9-5/8" Csg Point ! 5410.00ft MD 5000 4681.34ft TVD I Begin 8-1/2" Hole 1 r I 9-5/8" Csg Point@5410.00ftMD. 4~81.34ft ~~:::'3.e.gi~.~:.1/2" Hole RKB Elevation; North Reference ; Units; 38.77ft above Mean Sea Level True North Feet (US Survey) m .....Begin Dir.@ 1..5°/100ft: 7655.02ft MD, 6497.59ft TVD 00.00 End Dir, Start Sail @ 27.59° : 8215.69ft MD, 6973.70ft TVD .....--- - - - ---- 8000 iš 8 N II {j .¡; NikalU:huq #2 Tl CIrcle, Radius: ¡oo.OOft ; 886& 77 TVD, 4970. 76 1\; 183.09 E '~¡~~i{~åt~~\~ir\t)97~¡}~~TV~31~:771l-~ ~ -. . T('~{)t1\'á¡,h:lk, 9JBo.mtYrVD MM'" ......... ,............__.._ ... TARGET: 10353.91ft MD, 886S.77ft TVD ~ee 15· T14N - R9E. 2548.14' FNL & 1102.31' FEL V End Dir, Start Sail @ 36.0° 2000.00ft MD, 1922.59ft TVD ~ ~ (J) 1000.00 Total Depth: 11009.71ft MD, 9450.00ft TVD c 1 - T 4 - R9E, 2245' FNL & 1091' FEL o Surface @ Sec. 22 - T14N - R9E, 2239.41' FNL & 1293.38' FEL 2000 4000 Scale; 1 Inch = 2000ft DriIlQuest 3.03.08.002 Section Azimuth: 2.109" (True North) 5000 e 4000 3000 tJ) C> c:: :ï: 1:: o Z 2000 e iš 1000 ê II 1; ~ .!i ~ (J) o Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) V (ft) ~ 0.00 0.000 0.000 -38.77 0.00 0.00 N O.OOE 6052263.00 0.00 Surface@ Sec. 22 - T14N - R9E 2239.41' FNL & 1293.38' FEL 100.00 0.000 0.000 61.23 100.00 O.OON 0.000 0.00 200.00 0.000 0.000 161.23 200.00 O.OON 0.000 0.00 300.00 0.000 0.000 261.23 300.00 0.00 N 0.000 0.00 400.00 0.000 0.000 361.23 400.00 O.OON 0.000 0.00 500.00 0.000 0.000 461.23 500.00 527462.33 E 0.000 0.00 e 600.00 0.000 0.000 561.23 600.00 527462.33 E 0.000 0.00 700.00 0.000 0.000 661.23 700.00 527462.33 E 0.000 0.00 800.00 0.000 0.000 761.23 800.00 527462.33 E 0.000 0.00 KOP Begin Dir @ 3.0°/1000 : 800.00ft MD, 800.000 TVD 900.00 3.000 2.110 861.18 899.95 0.10 E 6052265.62 N 527462.42 E 3.000 2.62 1000.00 6.000 2.110 0.39 E 6052273.46 N 527462.68 E 3.000 10.46 1100.00 9.000 2.110 0.87E 6052286.50 N 527463.11 E 3.000 23.51 1200.00 12.000 2.110 1.54E 6052304.71 N 527463.71 E 3.000 41.74 1300.00 15.000 2.110 2.40E 6052328.04 N 527464.48 E 3.000 65.08 1400.00 18.000 2.110 3.44E 6052356.42 N 527465.43 E 3.000 93.48 126.77 N 4.67E 6052389.78 N 527466.53 E 3.000 126.85 165.00 N 6.08E 6052428.03 N 527467.80 E 3.000 165.12 208.02 N 7.66 E 6052471.05 N 527469.22 E 3.000 208.16 255.70 N 9.42 E 6052518.73 N 527470.80 E 3.000 255.87 272.22 N 10.03 E 6052535.25 N 527471.35 E 3.000 272.40 Base of Permafrost 190 1801.41 1840.18 307.91 N 11.34 E 6052570.95 N 527472.53 E 3.000 308.12 200 1883.82 1922.59 364.50 N 13.43 E 6052627.55 N 527474.41 E 3.000 364.75 End Dir, Start Sail @ 36.0· : e 2000.000 MD, 1922.59ft TVD 2.110 1964.72 2003.49 423.24 N 15.59 E 6052686.30 N 527476.35 E 0.000 423.53 2.110 2045.62 2084.39 481.98 N 17.76 E 6052745.04 N 527478.30 E 0.000 482.31 2.110 2126.52 2165.29 540.72 N 19.92 E 6052803.79 N 527480.25 E 0.000 541.09 2400.00 36.000 2.110 2207.42 2246.19 599.46 N 22.09 E 6052862.54 N 527482.19 E 0.000 599.86 2500.00 36.000 2.110 2288.33 2327.10 658.20 N 24.25 E 6052921.28 N 527484.14 E 0.000 658.64 2600.00 36.000 2.110 2369.23 2408.00 716.94 N 26.41 E 6052980.03 N 527486.09 E 0.000 717.42 2700.00 36.000 2.110 2450.13 2488.90 775.67 N 28.58 E 6053038.77 N 527488.03 E 0.000 776.20 2800.00 36.000 2.110 2531.03 2569.80 834.41 N 30.74 E 6053097.52 N 527489.98 E 0.000 834.98 10 March, 2004 - 13:45 Page2of9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 2900.00 36.000 2.110 2611.93 2650.70 893.15 N 32.91 E 6053156.27 893.76 3000.00 36.000 2.110 2692.83 2731.60 951.89 N 35.07 E 6053215.01 952.54 3100.00 36.000 2.110 2773.74 2812.51 1010.63 N 37.23 E 6053273.76 1011.31 3200.00 36.000 2.110 2854.64 2893.41 1069.37 N 39.40 E 6053332.51 1070.09 3300.00 36.000 2.110 2935.54 2974.31 1128.11 N 41.56 E 6 .25 N 1128.87 3400.00 36.000 2.110 3016.44 3055.21 7501.66 E 0.000 1187.65 e 3500.00 36.000 2.110 3097.34 3136.11 527503.60 E 0.000 1246.43 3600.00 36.000 2.110 3178.24 3217.01 527505.55 E 0.000 1305.21 3700.00 36.000 2.110 3259.15 3297.92 527507.50 E 0.000 1363.99 3800.00 36.000 2.110 3340.05 3378.82 527509.44 E 0.000 1422.76 3900.00 36.000 2.110 3420.95 54.55 E 6053743.73 N 527511.39 E 0.000 1481.54 3928.78 36.000 2.110 3444.23 55.17 E 6053760.64 N 527511.95 E 0.000 1498.46 Top of Schrader Bluff/West Sak 4000.00 36.000 2.110 3501.85 56.71 E 6053802.48 N 527513.34 E 0.000 1540.32 4100.00 36.000 2.110 3582.75 58.88 E 6053861.22 N 527515.28 E 0.000 1599.10 4200.00 36.000 2.110 3663.65 61.04 E 6053919.97 N 527517.23 E 0.000 1657.88 4300.00 36.000 1715.49 N 63.20 E 6053978.72 N 527519.18 E 0.000 1716.66 4400.00 36.000 1774.23 N 65.37 E 6054037.46 N 527521.12 E 0.000 1775.44 4500.00 36.000 1832.97 N 67.53 E 6054096.21 N 527523.07 E 0.000 1834.21 4600.00 36.000 1891.71 N 69.70 E 6054154.95 N 527525.01 E 0.000 1892.99 4700.00 36.000 1950.45 N 71.86 E 6054213.70 N 527526.96 E 0.000 1951.77 4149.06 4187.83 2009.19 N 74.02 E 6054272.45 N 527528.91 E 0.000 2010.55 4229.97 4268.74 2067.92 N 76.19 E 6054331.19 N 527530.85 E 0.000 2069.33 4310.87 4349.64 2126.66 N 78.35 E 6054389.94 N 527532.80 E 0.000 2128.11 4391.77 4430.54 2185.40 N 80.52 E 6054448.69 N 527534.75 E 0.000 2186.88 e 4472.67 4511.44 2244.14 N 82.68 E 6054507.43 N 527536.69 E 0.000 2245.66 5300. 0 36.000 2.110 4553.57 4592.34 2302.88 N 84.85 E 6054566.18 N 527538.64 E 0.000 2304.44 5331.71 36.000 2.110 4579.23 4618.00 2321.51 N 85.53 E 6054584.81 N 527539.26 E 0.000 2323.08 Top of Colville Mud Stone 5400.00 36.000 2.110 4634.47 4673.24 2361.62 N 87.01 E 6054624.92 N 527540.59 E 0.000 2363.22 5410.00 36.000 2.110 4642.57 4681.34 2367.49 N 87.23 E 6054630.80 N 527540.78 E 0.000 2369.10 9-5/8" Csg Point @ 5410.00ft M[ 4681.34ft TVD ... Begin 8-1/2" Hole 9-5/8" Casing 5500.00 36.000 2.110 4715.38 4754.15 2420.36 N 89.17 E 6054683.67 N 527542.53 E 0.000 2422.00 10 March, 2004 - 13:45 Page30f9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nlkaitchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northin9s Eastin9s Northin9s Eastin9s (ft) (ft) (ft) (ft) (ft) (ft) (ft) 5600.00 36.000 2.110 4796.28 4835.05 2479.10 N 91.34 E 6054742.42 2480.78 5700.00 36.000 2.110 4877.18 4915.95 2537.83 N 93.50 E 6054801.16 2539.56 5800.00 36.000 2.110 4958.08 4996.85 2596.57 N 95.67 E 6054859.91 2598.33 5900.00 36.000 2.110 5038.98 5077.75 2655.31 N 97.83 E 6054918.66 2657.11 6000.00 36.000 2.110 5119.89 5158.66 2714.05 N 99.99 E 6 .40N 2715.89 6100.00 36.000 2.110 5200.79 5239.56 7554.21 E 0.000 2774.67 e 6200.00 36.000 2.110 5281.69 5320.46 527556.16 E 0.000 2833.45 6300.00 36.000 2.110 5362.59 5401.36 527558.10 E 0.000 2892.23 6400.00 36.000 2.110 5443.49 5482.26 527560.05 E 0.000 2951.01 6500.00 36.000 2.110 5524.39 5563.16 527562.00 E 0.000 3009.78 6600.00 36.000 2.110 5605.30 112.98 E 6055329.88 N 527563.94 E 0.000 3068.56 6700.00 36.000 2.110 5686.20 115.14 E 6055388.63 N 527565.89 E 0.000 3127.34 6800.00 36.000 2.110 5767.10 117.31 E 6055447.37 N 527567.84 E 0.000 3186.12 6900.00 36.000 2.110 5848.00 119.47 E 6055506.12 N 527569.78 E 0.000 3244.90 7000.00 36.000 2.110 5928.90 121.64 E 6055564.87 N 527571.73 E 0.000 3303.68 7100.00 36.000 3360.18 N 123.80 E 6055623.61 N 527573.67 E 0.000 3362.46 7200.00 36.000 3418.91 N 125.96 E 6055682.36 N 527575.62 E 0.000 3421.23 7300.00 36.000 3477.65 N 128.13 E 6055741.10 N 527577.57 E 0.000 3480.01 7400.00 36.000 3536.39 N 130.29 E 6055799.85 N 527579.51 E 0.000 3538.79 7500.00 36.000 3595.13 N 132.46 E 6055858.60 N 527581.46 E 0.000 3597.57 7518 6387.00 3605.89 N 132.85 E 6055869.36 N 527581.82 E 0.000 3608.34 Top of L. Brookian Fan 760 6453.08 3653.87 N 134.62 E 6055917.34 N 527583.41 E 0.000 3656.35 765 6497.60 3686.19 N 135.81 E 6055949.67 N 527584.48 E 0.000 3688.69 Begin Dir@ 1.5°/100ft: 7655.Ch MD, 6497.59ft TVD e 2.110 6495.37 6534.14 3712.39 N 136.78 E 6055975.87 N 527585.35 E 1.500 3714.91 2.110 6577.70 6616.47 3769.10 N 138.87 E 6056032.59 N 527587.22 E 1.500 3771.66 7900.00 32.325 2.109 6661.50 6700.27 3823.64 N 140.87 E 6056087.13 N 527589.03 E 1.500 3826.23 8000.00 30.825 2.109 6746.69 6785.46 3875.96 N 142.80 E 6056139.47 N 527590.76 E 1.500 3878.59 8100.00 29.325 2.108 6833.22 6871.99 3926.04 N 144.64 E 6056189.55 N 527592.42 E 1.500 3928.70 8200.00 27.825 2.108 6921.04 6959.81 3973.84 N 146.40 E 6056237.35 N 527594.00 E 1.500 3976.53 8215.69 27.590 2.108 6934.93 6973.70 3981.13 N 146.67 E 6056244.65 N 527594.25 E 1.500 3983.83 End Dir, Start Sail @27.59° : 8215.69ft MD, 6973.70ft TVD 10 March, 2004· 13:45 Page4of9 DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· N;ka;tchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Ke" McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8230.92 27.590 2.108 6948.43 6987.20 3988.18 N 146.93 E 6056251.70 3990.88 Top of HRZ 8287.11 27.590 2.108 6998.23 7037.00 4014.18 N 147.89 E 6056277. 70 4016.91 Top of Kalubik Shale 8300.00 27.590 2.108 7009.65 7048.42 4020.15 N 148.11 E 6056283.67 4022.88 8400.00 27.590 2.108 7098.28 7137.05 4066.43 N 149.81 E 6056329.96 4069.19 8433.79 27.590 2.108 7128.23 7167.00 4082.07 N 150.39 E 60 .60N 4084.84 Top of Kuparuk Sands 8500.00 27.590 2.108 7186.91 7225.68 598.60 E 0.000 4115.51 e 8580.47 27.590 2.108 7258.23 7297.00 527599.83 E 0.000 4152.77 LCU / top of Kingak Shale 8600.00 27.590 2.108 7275.54 7314.31 527600.13 E 0.000 4161.82 8700.00 27.590 2.108 7364.17 7402.94 527601.66 E 0.000 4208.13 8800.00 27.590 2.108 7452.80 7491.57 527603.20 E 0.000 4254.45 8900.00 27.590 2.108 7541.43 158.33 E 6056561.40 N 527604.73 E 0.000 4300.76 9000.00 27.590 2.108 7630.05 160.03 E 6056607.69 N 527606.26 E 0.000 4347.08 9031.79 27.590 2.108 7658.23 160.57 E 6056622.41 N 527606.75 E 0.000 4361.80 Top of Nuiqsit Sand 9099.49 27.590 2.108 7718.23 161.73 E 6056653.75 N 527607.78 E 0.000 4393.15 Base of Nuiqsit Sand 9100.00 27.590 2.108 7718.68 161.74 E 6056653.98 N 527607.79 E 0.000 4393.39 9200.00 4436.70 N 163.44 E 6056700.27 N 527609.32 E 0.000 4439.70 9300.00 4482.98 N 165.14 E 6056746.56 N 527610.86 E 0.000 4486.02 9400.00 4529.26 N 166.85 E 6056792.85 N 527612.39 E 0.000 4532.33 9500.00 4575.54 N 168.55 E 6056839.14 N 527613.92 E 0.000 4578.65 9600.00 4621.83 N 170.25 E 6056885.43 N 527615.45 E 0.000 4624.96 9700 8250.45 8289.22 4668.11 N 171.96 E 6056931.71 N 527616.98 E 0.000 4671.28 980 8339.08 8377.85 4714.39 N 173.66 E 6056978.00 N 527618.52 E 0.000 4717.59 990 8427.71 8466.48 4760.67 N 175.36 E 6057024.29 N 527620.05 E 0.000 4763.90 1000 8516.34 8555.11 4806.96 N 177.07 E 6057070.58 N 527621.58 E 0.000 4810.22 e 10100 8604.97 8643.74 4853.24 N 178.77 E 6057116.87 N 527623.11 E 0.000 4856.53 10200. 0 27.590 2.108 8693.59 8732.36 4899.52 N 180.47 E 6057163.16 N 527624.64 E 0.000 4902.85 10300.00 27.590 2.108 8782.22 8820.99 4945.81 N 182.18 E 6057209.45 N 527626.17 E 0.000 4949.16 10353.91 27.590 2.108 8830.00 8868.77 4970.76 N 183.09 E 6057234.40 N 527627.00 E 0.000 4974.13 TARGET: 10353.91ft MD, 8868.77ft TVD @ See 15 - T14N R9E,2548.14'FNL&1102.31' FEL Top of Sag River Sandstone Target - Nikaitchuq tr2 T1, 100.01 Radius., Current Target 10400.00 27.590 2.108 8870.85 8909.62 4992.09 N 183.88 E 6057255.74 N 527627.71 E 0.000 4995.47 10468.13 27.590 2.108 8931.23 8970.00 5023.62 N 185.04 E 6057287.27 N 527628.75 E 0.000 5027.03 Top of Shublik 10 March, 2004· 13:45 Page50f9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· Nlkaitchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Ke" McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings omment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10500.00 27.590 2.108 8959.48 8998.25 5038.37 N 185.58 E 6057302.02 5041.79 10600.00 27.590 2.108 9048.11 9086.88 5084.65 N 187.29 E 6057348.31 5088.10 10700.00 27.590 2.108 9136.74 9175.51 5130.94 N 188.99 E 6057394.60 5134.42 10705.07 27.590 2.108 9141.23 9180.00 5133.28 N 189.08 E 6057396.95 5136.76 Top of Ivashak 10800.00 27.590 2.108 9225.37 9264.14 5177.22 N 190.69 E 6 .89N 5180.73 10900.00 27.590 2.108 9313.99 9352.76 635.37 E 0.000 5227.04 e 11000.00 27.590 2.108 9402.62 9441.39 527636.90 E 0.000 5273.36 V11009.71 27.590 2.108 9411.23 9450.00 ....... 527637.05 E 0.000 5277.86 Total Depth: 11009.71ft MD. 9450.00ft TVD '-. All data is in Feet (US Survey) unless otherwise stated. Directions and co Vertical depths are relative to RKB Est @ 35' MSL. Northings and Easti Global Northings and Eastings are relative to NAD27 Alaska State P The Dogleg Severity is in Degrees per 100 feet (US Surve Vertical Section is from 2440 FNL. 1290 FEL and calculat Based upon Minimum Curvature type calcula The Bottom Hole Displacement is 5277. Accumulated Dogleg is 44.410° Directional Difficulty Index is 5.2. Com Station Coordinates TVD Northings Eastlngs (ft) (ft) (ft) Comment tit 0.00 800.00 2000.00 5410.00 7655.02 0.00 800.00 1922.59 4681.34 6497.59 O.OON O.OON 364.50 N 2367.49 N 3686.19 N O.OOE 0.00 E 13.43 E 87.23 E 135.81 E Surface @ Sec. 22 - T14N - R9E. 2239.41' FNL & 1293.38' FEL KOP Begin Dir@3.00/100ft: 800.000 MD. 800.00ft TVD End Dir. Start Sail @ 36.0° : 2000.00ft MD, 1922.59ft TVD 9-5/8" Csg Point @ 5410.00ft MD, 4681.34ft TVD ... Begin 8-1/2" Hole Begin Dir @ 1.5°/1000: 7655.02ft MD. 6497.59ft TVD 10 March, 2004 - 13:45 Page 60f9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #2 (wp09) Revised: 10 March, 2004 Western North Slope, Comments (Continued) Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8215.69 10353.91 11009.71 11009.71 146.67 E 183.09 E 194.27 E 194.27 E End Dir, Start Sail @ 27.59° ; 8 TARGET: 10353.91ft MD, BHL @ See 15 - Total Dep 6973.70 8868.77 9450.00 9450.00 3981.13 N 4970.76 N 5274.28 N 5274.28 N Formation Tops Formati on Plane Pro f i I (Below Well Origin) Measured Verti Sub-Sea Dip Up-Dip Depth D Northings Eastings Formation Name (ft) Angle Dirn. (ft) (ft) (ft) 1744.23 1744.23 272.22 N 10.03 E Base of Permafrost 3444.23 3444.23 1497.44 N 55.17 E Top of Schrader Bluff/West Sak 4579.23 4579.23 2321.51 N 85.53 E Top of Colville Mud Stone 6348.23 6348.23 3605.89 N 132.85 E Top of L. Brookian Fan 6948.43 6948.43 3988.18 N 146.93 E Top of HRZ 8287.11 7037.00 6998.23 4014.18N 147.89 E Top of Kalubik Shale 8433.79 7167.00 7128.23 4082.07 N 150.39 E Top of Kuparuk Sands 8580.47 7297.00 7258.23 4149.96 N 152.89 E LCU / top of Kingak Shale 9031.79 7697.00 7658.23 4358.84 N 160.57 E Top of Nuiqsit Sand 9099.49 7757.00 7718.23 4390.18 N 161.73 E Base of Nuiqsit Sand 8830.00 0.000 0.000 10353.91 8868.77 8830.00 4970.76 N 183.09 E Top of Sag River Sandstone 8931.23 0.000 0.000 10468.13 8970.00 8931.23 5023.62 N 185.04 E Top of Shublik 9141.23 0.000 0.000 10705.07 9180.00 9141.23 5133.28 N 189.08 E Top of Ivashak Kerr McGee e e 10 March, 2004 -13:45 Page 70'9 DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· Nikaitchuq #2 (wP()9) Revised: 10 March, 2004 Western North Slope, Casino details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> 5410.00 4681.34 Taroets associated with this welløath Target Name Nikaitchuq #2 T1 Casing Detail 9-5/8" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape Ke" McGee e Target Type Current Target e 10 March, 2004· 13:45 DrillQuest 3.03.05.005 a Level/Global Coordinates: Geographical Coordinates: Target Radius: 8868.77 4970.76 N 183.09 E 8830.00 6057234.40 N 527627.00 E 70034' 02.8778" N 149046' 23.8670" W Circle 100.00ft Page8of9 e e Nikaitchuq #2 Revised Mud Program Baroid Drilling Fluids General Discussion This exploration well will be drilled from an off-shore ice pad on Spy Island, basically due north of Oliktok Point on the North Slope of Alaska. The well will be drilled as a modified "Build & Hold" shaped hole building to 260 in the 12-1/4" surface hole and drilled to.:!:. 5,410' TMD where 9-5/8" casing will be run and cemented. An 8-1/2" hole will then be drilled holding this angle to 6755' MD where a gradual drop to 27.60 will begin. This angle will be then be held to TD at.:!:. 11 ,010' TMD. Primary target for this well is the Sag River sand with other possible oil bearing sands being present. An inhibited KCI/Polymer mud will be used to drill this well from spud to TD. If time allows, the Sag River sand will be cored. Finally, the well will be abandoned in accordance with AOGCC regulations. 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 surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for efficient hole cleaning. This spud mud is formulated with mechanisms to provide effective wellbore stabilization and to reduce drilling waste, Le., ionic inhibition (KCI) and polymer encapsulation (PHPA). From the surface shoe to the core point, the continued use of the inhibited 9.6 ppg KCI/Polymer mud is suggested. When drilling this interval of the well a certain amount of new mud will be required coming out of the surface casing to re-adjust the low gravity solids content to within acceptable limits for continued drilling operations. The mud weight for this interval of the well will range from 9.6 ppg at drill-out of the surface casing to 10.4-10.6 ppg by the top of the HRZ. This weight is needed to help stabilize the HRZ and Kingak shales at this angle and direction as per the Baroid/Sunbury HRZ and Kingak shale studies. 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 60K-90K ppm range when drilling the other target sands on this well. The KCI concentration is deDendent UDon MWD and loaaina restrictions and could varv from this recommendation. Special Considerations 1. Waste minimization is critical to the success of this well. 2. Maintain a sufficient quantity of Driltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. 3. Lime and zinc carbonate should be on location for H2S contingency (@1 pallet No Sulf and 2 pallets lime). 4. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@2000 sxs barite on location at all times). 5. Due to the remote nature of this location, maintain an adequate supply of LCM and the other materials, which may be required to support this drilling program. e Formation Tops/Casina Proaram Spud Base Permafrost Top West Sak Top Colville Muds 9 5/8" casing point L. Brookian Top HRZ Kalubik Kuparuk Top LCU/Kingak Top Nuiqsut Top Sag Top Shublik Top Ivishak TD TMD 0' 1833' 3929' 5332' 5410' 7518' 8231' 8287' 8434' 8580' 9032' 10354' 10468' 10705' 11010' TVD 0' 1783' 3483' 4618' 4681' 6387' 6987' 7037' 7167' 7297' 7697' 8869' 8870' 9180' 9450' e Comments 9.0 ppg density String in LCM Condition for casing occasional shale instability occasional shale instability String in LCM shale instability occasional shale instability target sands String in LCM Mud Wt 9.0-9.3 9.0-10.0 9.0-10.0 9.0-10.0 9.0-10.0 9.6-9.8 10.4-10.6 10.4-10.6 10.4-10.6 10.4-10.6 10.4-10.8 10.4-10.8 10.4-10.8 10.4-10.8 10.4-10.8 12·1/4" Hole to 95/8" Casin Point at 5410' TMD YP PV 10 S. Gel API FL cc's/30 min <15 6-8 9.0-9.3 9.0-10.0 35 - 45 15 - 30 13 - 21 15 - 23 10 -15 10 -15 Surface Interval (12-1/4" Hole to 5.410' TMD) The surface interval will be drilled with a 12% KCI/Polymer mud as formulated below: 9.0 PPQ Formulation Fresh Water KCI EZ Mud DP PAC-UR Barazan-D KOH Aldacide-G Baracor 700 Barascav D .95 bbl 37 ppb .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb 1.0 ppb .5 ppb (ionic inhibition/50.5K ppm chlorides) (polymer encapsulation) (API filtrate of 6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) ( X-Cide 207 for rig maintenance) (corrosion inhibitor) (to be added at rig) Spud the well with maximum flow rates (600-800 gpm assuming 12-1/4 hole w/5" 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'ed 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. Once the angle has been built to 400, weighted/high vis or Barolift sweeps can be utilized. e e With an initial mud density of 9.0 ppg, please note the other issues of concern as listed below: 1. Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. 2. A mud weight of 9.6 ppg range is currently programmed for drilling the gas hydrate interval of the well, if encountered. 3. If gas hydrates are noted, treat the system with 2.0 ppb of Driltreat (Lecithin) and ~% by volume BDF-263. 4. Maintain the mud as cool as possible (~60°F). 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 for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. 3. Hold the pH in the 8.5-9 range with KOH. 4. By material balance, maintain the EZ Mud DP in the .75-1.0 ppb range. 5. Control penetration rates based upon the ability of the surface system to process the drilling mud. 6. Daily additions of X-Cide 207 are needed to control bacterial action. 7. Corrosion inhibitors should be run with this mud system (1 ppb Baracor 700 / .5 ppb Barascav D). 8. Keep MBT as low as possible (generally <12 ppb). While drilling the Schrader Bluff sands, 2-3 ppb of Barofibre should be constantly strung into the system. This should seal the under pressured zone and prevent differential sticking and losses. Heavy amounts of clay may be present below the permafrost that could require additions of BDF-263 and/or ConDet 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, reduce the fluids rheology to <20 YP after the casing is on bottom prior to starting the cement job. Production Hole 8-1/2" Hole f/Base Surface Casin to Well TD at 11,010' TMD Mud Density YP PV 10 S. Gel API FL PH Pro erties cc's/30 min Initial 9.6 10-15 6-12 2-5 6-10 9-9.5 Final 10.4-10.8 15-25 15-25 2-6 <6 <10 THP 9-9.5 Production Interval (8-1/2" Hole to 11.010' TMD) Prior to drilling out the surface casing, condition the spud mud to a 9.6 ppg density with <4% LGS and an MBT of <6 ppb (a certain amount of new mud could be considered in terms of re- adjusting the properties of the mud to insure a quality fluid for the initial drill out below casing. e e As in the suñace hole, 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 60,000- 90,000 ppm range so as to allow maximum application of centrifuge support to optimize solids control efforts. A minimum of 60,000 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 9.6 ppg with a YP in the 10 to 20 range and maintain until out of the sticky clays often found within this interval of the well. Then, adjust the YP as required with Barazan-D polymer for efficient hole cleaning. If screen blinding from heavy clays is a problem, use BDF-263 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 400 to 500 GPM range will provide ample flow to clean the hole. The 9.6 ppg density will be maintained down to ± 8700' (top HRZ) where the weight will be increased to 10.4 ppg with as much KCI as allowable and then barite for controlling the HRZ then to 10.6 ppg to control the Kingak shale at 9080'. While drilling to TD, maintain the API filtrate <6 with PAC's and Dextrid. The HTHP filtrate should be reduced to <10 with a 4-6 ppb Baranex addition prior to entering the HRZ at 8,700' TMD and maintained there until TD of the well. String in 2-3 ppb of Baracarb 50 while drilling the Kuparuk to help bridge/seal this zone. 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 MBT as low as possible «8 ppb). Maintain Barascav D and Baracor 700 specs to aggressively treat for corrosion. Spot a Hi-Vis, LCM pill on bottom (if necessary) prior to POOH for logs. Risks and Continaencies: Lost Circulation: Preventing the initiation of lost returns should be a primary goal of the drilling fluid in the well. To that end the rheology of the system has been reduced while still providing ample hole cleaning. Maintaining a low ECD while circulating, and eliminating high pressure spikes while tripping, will both go a long ways toward reducing the risk of lost returns. Should lost returns occur check with MWD personnel prior to pumping any pills to assure that no plugging will occur. This well is near Milne point so several of the zones may be under-pressured. LCM will be strung into the mud while drilling the Schrader Bluff, Kuparuk, and Sag River sands to help prevent losses and/ or differential sticking tendencies. Wellbore Instability: The HRZ and Kingak can be problematic. Ensure the mud weight is 10.4 ppg prior to entering the HRZ (as per the HRZ polar plot a minimum of 10.2 ppg is needed) and reduce the HTHP to less than 10 cc. The weight will then need increased to 10.6 ppg for the Kingak (as per the Kingak polar plot). Should any signs of shale splintering be seen immediately raise the mud weight a minimum of .4 ppg. Keep instantaneous surge/swab limited. Awareness by the rig crews as to the fragility of these shales to mechanical disturbance is of great importance. e e 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. Sackreaming 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. Note: keep a pallet (8 drums) of "Pipe-Lax" on location at all times. Corrosion Mitigation Sarascav D and Saracor 700 will be run in this fluid system to mitigate the 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 S shaped profile of this well it is likely lubes will be required. If so, it is recommended to add 2% of the lube cocktail (0.5% SDF-263, 1% EZ Glide, 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 Sarofibre (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 are essential to a 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 a weighted high viscosity sweeps in the pay sands. The returns at surface of all pills should be monitored at the shakers and documented to gauge their effectiveness. When circulating bottoms up prior to POH, it is advisable to pull one stand every half hour to reduce the hole washout effects of circulating over one short interval. Long circulation times should be avoided if the bitlSHA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. Hiah sDeed DiDe rotation is the most critical factor for hole cleanina. e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA OptiC em 9 5/8" Cement Surface Casing Revision #2 Prepared for: Skip Coyner Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 H LI RTClN ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Well Conditions Casing Size & Wt. Hole Size MD TVD Top of Lead (MD) 9 5/8" 40#/ft 12 1/4" 5,410' 4,681' 0' Volume Excess Mud Wt. BHST BHCT Previous Casing Depth 200% 125% 9.5 ppg 90°F 80°F 200' Slurry Recommendation: Preflush I Spacer 10 bbl Water, 75 bbll0.5 ppg NSCI Spacer Lead Slurry: 610 Sks. (2,526 Fe) PERMAFROST L Tail Slurry: 540 Sks. (618 Fe) Premium Cement, 1 % Calcium Chloride Displacement: (2,268 Ft3) Mud (450 bbl) (110 bbl) (404 bbl) Density (ppg) Yield (cu ft I sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Spacer 8.34 /10.5 Lead Slurry 10.7 4.15 20.3 Tail Slurry 15.8 1.15 5.00 6:00+ 3:30 (48 Hr.) 25 1650 (72Hr.) 260 1800 Volumes based on: Lead slurry: Top of Lead cement @ Surface 200 feet 13-3/8" 61 #/ft cased hole + 0% excess, 1633 ft of open hole + 200% excess through base of PermafÌ"ost at 1833 ft MD plus 3577 ft MD open hole below PermafÌ"ost + 25% excess. Top of Tail slurry 1500 feet above shoe - TOC 3,912' 1500' calculated annulus volume +25% excess + 80 ft shoe joint. Tail slurry: HALLIB.U TON ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Parameters Fracture Zone Measured Depth 5410.0 ft Fracture Zone Gradient 12.50 lbl gal Reservoir Measured Depth 5410.0 ft Reservoir Pore Pressure 8.65 lb/gal Safety Factor 0.0 psi Additional Pressure to Seat Plug 1000.0 psi Wellbore Annulus-Casing; Depth Orientation Hole Casing; True Excess Diameter OD ID Weig;ht Measured Vertical Dev. Az. Build % in in in lb/ft ft ft ° ° o/(loo*ft) 0.0 0.0 0.0 0.0 0.0 12.515 9.625 8.835 40.00 32.2 32.2 0.0 0.0 0.000 0.0 12.515 9.625 8.835 40.00 200.0 200.0 0.0 0.0 0.000 200.0 16.276 9.625 8.835 40.00 800.0 800.0 0.0 0.0 0.000 200.0 16.276 9.625 8.835 40.00 1833.0 1783.4 31.0 1.8 3.000 25.0 12.823 9.625 8.835 40.00 2000.0 1922.6 36.0 2.1 3.000 25.0 12.823 9.625 8.835 40.00 5410.0 4681.3 36.0 2.1 0.000 Pumpin2 Schedule Stag;e Liquid Number Description Density Rate Volume Tracer Shutdown lb/gal bpm bbl min 1 Spud Mud 9.50 5.00 0.0 0 2 Fresh water 8.34 5.00 10.0 0 3 NSCI Spacer 10.50 5.00 75.0 0 4 0 5.00 5 Permaftost L 10.70 5.00 450.9 0 6 Surface Tail 15.80 5.00 104.5 [g 7 Surface Tail 15.80 5.00 6.1 0 8 0 5.00 9 Spud Mud 9.50 8.00 404.1 0 HALLI.E:I.U.RTC.N ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Pumpin2 Schedule - Modified Rates Stage liquid Number Description Density Rate Volume Shutdown lb/gal bpm bbl min 2 Fresh water 8.34 5.00 10.0 3 NSCI Spacer 10.50 5.00 75.0 4 5.00 5 Permafrost L 10.70 5.00 450.9 6 Surface Tail 15.80 5.00 104.5 7 Surface Tail 15.80 5.00 6.1 8 5.00 9 Spud Mud 9.50 8.00 375.0 10 Spud Mud 9.50 1.00 29.1 Final Position of Staees Cumulative Annular Top of Fluid Stage Description Liquid Volume Measured Length Measured Depth bbl ft ft Spud Mud 0.0 0.0 0.0 Fresh water 10.0 0.0 0.0 NSCI Spacer 85.0 0.0 0.0 Permafrost L 535.9 3912.1 0.0 Surface Tail 640.4 1497.9 3912.1 HALLI URTON ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA OptiC em 9 5/8" Surface Casing - Top Job Contingency Revision #2 Prepared for: Skip Coyner Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 HALLIBU.RTO.N ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Top Job Contin~encv Mix & pump Permafrost L via DP thru the port collar tool at 500 ft until it reaches surface & then displace with mud. Well Conditions Casing Size & Wt. Port Collar Depth Hole Size TVD Drill Pipe: Previous Casing Size Previous Casing Depth 9 5/8" 40#/ft 500'MD 12 114" 4,681' 3.5" 13 .3O#/ft 13-3/8" 61 #/ft 200' BHST BHCT Mud Wt. 60°F 40°F 9.5 ppg Slurry Recommendation: Preflush I Spacer 10 bbl Water Cement Slurry: 90 Sks. (374 Fe) PERMAFROST L Displacement: 3.7 bbls. Mud (67 bbl) (3.7 bbl) Density (ppg) Yield (cu ft I sk) Water requirements (gallsk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Tail Slurry 10.7 4.15 20.3 6:00+ (48 Hr.) 25 (72Hr.) 260 HALLIBUR:TO.N ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Parameters Fracture Zone Measured Depth 500.0 ft Fracture Zone Gradient 12.50 lb/gal Reservoir Measured Depth 500.0 ft Reservoir Pore Pressure 8.65 lb/gal Safety Factor 10.0 pSI Additional Pressure to Seat Plug 50.0 psi Pumoin!!: Schedule Number Description Density Rate Volume Tracer Shutdown lb/gal bpm bbl mm 1 Spud Mud 9.50 5.00 0.0 0 2 Water Spacer 8.34 5.00 10.0 0 3 Permafrost L 10.70 5.00 66.8 ~ 4 Spud Mud 9.50 5.00 3.7 0 Annular Measured Len ft 0.0 0.3 499.7 Top of Fluid Measured De th ft 0.0 0.0 0.3 HALLI URTON ISO 14001 Certified Alaska Green Star Certified e e NW Milne Point Exploration Project 2004 Cementing Services (Revision #2) Parameters Fracture Zone Measured Depth 500.0 ft Fracture Zone Gradient 12.50 lb/gal Reservoir Measured Depth 500.0 ft Reservoir Pore Pressure 8.65 lb/gal Safety Factor 10.0 pSI Additional Pressure to Seat Plug 50.0 psi Pumpin2 Schedule Number Description Density Rate Volume Tracer Shutdown lb/gal bpm bbl min 1 Spud Mud 9.50 5.00 0.0 E5 2 Water Spacer 8.34 5.00 10.0 3 Pennafrost L 10.70 5.00 66.8 ~ 4 Spud Mud 9.50 5.00 3.7 0 Top of Fluid Measured D th ft 0.0 0.0 0.3 HALLI u ON ISO 14001 Certified Alaska Green Star Certified . ~"" \\- \ b \ FACSIMILE TRANSMITTAL SHEE'r. TO,· .. no),! "\t:. '"'\.. /~ "f t') .' ~ \-\, ~ð"i'. ~~t;t-.4C'o.It)~~t4QQ~~. .~O~~ ~~~"-..I<C f;QMPANY¡ . DA't"B:: \1,0.., \. '-t ;).CO Y . I"AX NUMBs.: TOTÌlL'No. 01" "PAGE51NCLl!rJING COVS1t! øQ~~~~~-~~~. ~ 1>HONBNU~ . £ßNÐEa'S~CENOMBIikI !llt1 YOUR RE~Nw.mER1 . ~~\ )st¡.iRGBN1' ' ~Op. ØY1EW [J PLEASE' COMM1lNT [j PLEAD RBPI.Y [J PLEAS5 QCYCLE NOTES /'CONN!!M'%'S: .':11I1 [-IJQa~.~ ~,d... \L.~,\\--\.,,~ ~~~ ~c,.~~..\;~~ \~ ,.~~\\ ;)'1'.<a.v.j~\.\ t ~\-\L ~ø.~ ~~'ù .~ t)saal Q\ I--\~...;.~\\ \~\-""<l" ~ \«.c...'òR. T""" O\"'l.<::}....... \.~tc' ......:>e:.. "" ~""~'-3i0 ~ liS .'1.[+ . \ex) ~ ~}.~ ~ ~ 'S~ ",'¿j '\ '.:> ~~l -., II ~ . ~~ ù.~ ~ (\~'a'-K'-\ \<è~, ,g-:.,,\~~~ . REC~& ~'(ê~ ~~~~\ ~Cl~Ç~~~ . ,·~(Ó %~ . % \40\<.. \ c~,,:ro,-\c:;,," \ \,~(]..<;.<ë Cù~'\"~ ~\\~. \;¡ ""\',,~'¥- ~ ()t"'~\ <...<è \'I",~ :>"~'i"""" ~'-Yt:'cl \:"-...... ~"'- ""'-....., \~ , T~ ~Jö"¡ AOGCC 3U WEST 7TH "VENUE. SUITE \00 ....NCHORACië. M~ ~',)03.3!)35 HAD¡~) ~ '. .' !y, r\ "'~. ··i - 03/11/04 THU 19: 19 [TX/RX NO 8221] ~OOl Well Name: NI 2 Program EXP Well bore seg D Initial ClassfType EXP /1-0IL GeoArea Unit _ On/Off Shore Off Annular Disposal D - - Administration Pe~mitfee attached · NA Revised perrnit to.dJi[l before .spud, 2 Lease .number apprOPJiat~ · . . . . Y~$ . Wellließ witbio 6P Lease ADLQ355Q2; De~ignationof Operatorforrn. reGeiv~d 3/5/04. SFD. - - - - - - 3 .Unique well.n.arn~ .aod ou.mb~~ . . . . . . . . . Ye$ . . I;xplora.tQry wellJoc.ated witbio th~ .affecte.d.area.of the Miloe !?Qint jJnit, KUParyk. River Pil PoollGO 432.B).. . . . . 4 WeJI Jo.cated in.a d.efined pool. · Ye$ . !?rimary tar.get.s .are. Sag Hjver an.dlllÍ~halç.. - - - - - 5 WeJI Jo.cated proper dista!lGe. from. driJli!l9 unitboundary. · . Ye$ . Nearest property line.is 1Q9j feet to.the.nortb.. . . 6 WeJI located proper ~jsta!lGefrom otbeJ wells. . . . . . . - - - - - · . Ye$ . OOly wellio Section 15. . - - - - - - - - - - -- - - - - - 7 Sufficient acreage .available in.drilJiog u.nit. . . . . . · . Y~$ . - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 If.d~viated, is.weJlboJe plaUncJuded . . . . . . . . . . . · Ye$ . - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 Operator only affected pa.rty. . . . . . . . . . . . . . . . · . . . . Ye$ . 3/5/04: . Received. d.esigoation ofoper<lto~ forms JrornKerr-Mc.G.ee.. Sf=D . - - - - - - - - - - 10 .o.per.ator bas.appropriate.b90d in Jorce. . . . . . . . . . . . . . . . . . . . Yes. . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 11 P~~mitcalJ be i.ssu.ed witbout co.n$ervation order. . · . . . . Ye$. - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 PermitcalJ be i.s$u.ed witho.ut admini$tratille.apprOllal . . - - - - - · . Ye$ - - - -- - - - - - - - - - - - - - - - - - - e 3/11/2004 13 Can permit be approved before 15-day wait Yes e· 14 WellJoc<lted within area and.strata autborized. by.lojectioo OrdeUl (puUO# in.comm~ots).{for. NA - - - - - - - - - - - - - - - - - - - - 15 AU wells.wit/lin.1l4.mile.are.a.oheview id~otlfjed (Fo~s.ervice.welJ only). . . . . . . . . . . . . . . NA . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - -. 16 Pre.-prod.uçed iojeGtor; dyratio.n .of pre-prodyctionless. than 3 months (for .seryiçe well only) . . NA - - - - - - - - - - - - ~ - - - - - - 17 ACMP .finding of Gonßi!>t~o<;y .ha$ been Js.suedfor.tbis proieçt . - - - - ~ · Ye$. . K<lye. Laughlio, .JPOc NikaitchYQ exploration proje<;t W<lS determined t.o .be J:;onsistent. with ACMP.. . . . - - - - - - Engineering 18 Gooduçtor strjn.g.provided . . . . . . . . . . . . . - - - - - - ~ - - - - - · Ye$ . . - - - - - -- - - - - - - - - ~ - - - - - ~ - - - - - - - - - ~ - - - ~ - - - - - 19 .surface J::asJng.protects. aILk!lown_ USQWs . . . - - - ~ - - - - - - - NA Altaquife.1'S ex~rnpt~d,.40CFR.147.102.(b)(3).. _ . - - - - -- ~ - - - - - - - - - 20 CMT.voladequ.ate.to circulate.oflconduGtor.& su.rf.C$g . . . . . . . . - - - - · _ Y~s . - - - ~ - - - - - - - - - - - - - - - - - - 21 GMT. vol adeQu.ate.to tie-in .long .stri09 to .surf CS-9. . . . . . . . - - - - - .. N9.. No produ.ctJon.c<lsiog is plaoned. ProposaU$ to.drill, .core .a!ld <lbandon. . . . . . - - -- - - - - - 22 CMT. will coverall known pro~uctive bori¡!:onß. . . . . . . . . - - - - - ~ - .Y~$ Surfa~ Gem.e!lt will <;over.poteotiaJ WestS.aklS6 ß<lnds. PM plUgs. wi/] coYer.a.ny bydro.carbonsjo 8-1/2" hole. . 23 .CasilJg de.si.g!ls. ad.equate. for C,T, 6.&.p.ermafrost. . . . - - - - - ~ - - - . . . Ye$ . . - ~ - - - - - - ~ - - - - - ~ - - - - ~ - - - - - ~ - - - - - ~ - - - ~ - 24 AdeQuatetanl<age.or re.serye pit . - - - - - - - - ~ - - - - - - - - · . .Yes. Rig is.e.quippe~ witb steelpit$. No.re$erve.pjt pla!loe.d. Wa.ste to an aPproved d.i$posal welt . . . . 25 Jfare-drjll, has.a to:4.03 for aba.ndonme!lt beeo approved . . - - - - - .. NA. - - - - - - ~ - - - - ~ - - - - - -- - - - - - - 26 Adequate .w.ellbore. s.eparatjon propO$ed. . . . . . . . . . . . . . . . . . . . . . . . . . .Ye$ . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - ~ - - - - - - - - - - - - - . 27 If.diver1e.r required. does it m.eetregulaìions. . . - - - - - · Y~$. . - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- Appr Date 28 .DriUiog fluid program $cJ1ematlc .&. equip li$t.adequate. . - - - - - - - - - _ Y~s . . Max. expecte.dBHP 9.8 I;MWin rnultiple formations, PJa.n!led MW 10..4 .-11.0 ppg from 9~00'.to TO. . 29 BOPEs,do they meetregula.tion . - - - -- - - - - - - - - - - - · . .Yes. + - - - - - - - - . 30 .BOPE press ratilJg approp~iate; test to (put p$ig in.comrnent$). . . . . . Y~$ . MAS!? calculate~.at 33.67 P$i. Plao is.to teßUo 5QOOpßi. . 31 Choke manifold complies w/.APIRP-53 (May 84). . . . . . . . · . .Y~$. - - - - - - - - - - - - - - - - 32 WOJk will OCCJJ~ withoyt.oper<ltio!l.sbutdown. . . . . . . . . . . · . .Y~$ . - - - - - - - - - - - - - - - - - - - 33 Js Rres.eoGe 0.1 H2S gas. probable. . . .. N.o Myd $hould pœclYde.H2S o.n the rig, Rig i$ equipped with s.e!ls.ors. and .alarms_ . 34 MechanicaLcoodjtioo of well$ withJn AOR verified (For.service wel! only) . NA - - - - - -- - - - - ~ - - - -- I Geology 35 Permiì.cao be i.ssu.ed wlo. hydrogen_s.ulfide meaSur.es. . . . . . . - - - - ~ · No.. 1:128 potential of Sa.g-Ivi$hal< !lot.klJown.at this.tim.e. H2S measures.reQuired.. . - - - - - 36 Data .presented. on. Rote.nlial o\{erpres.syr~ zones. . Yes Abno~maJ pre$su~ej$ oot expected. . Wen will be mydJogged. from $u.rface.to TO. Appr Date 37 .sei.srnic.a!lalysis.ofshallow gaszooes . . . . . . · .Y~s. . Gas. hydrates ~xpected from 600' - 2700' TYD$s; !l0 evJd.e!lGe of aoy. other shallow baz<lrd$. SFD 3/11/2004 38 S~abed çonditioo $u.rvey(if oft-shore) . . . NA N/A; we/] iß Þeiog drilled. from oa.turally.oc<;urring offshoreJsJand. ~ - - - - 39 Go.ntaçl nam.elp/loneJorweelçly progres.s.reRort$ [e1<plor<ltoryo!lly] _ . . . . · . Ye$ Sk.iR Goyner. 90.7-339-6269, - - - Geologic Date: Enginéering Date Public Date Commissioner Commissioner: Commissioner DTS JKN · 4 FRANK H. MURKOWSKI, GOVERNOR A I"ASIiA. OIL AND GAS CONSERVATION COMMISSION Charles Summers Drilling Manager Kerr-McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage, Alaska 99503 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nikaitchuq #2 Kerr-McGee Oil & Gas Corporation Permit No: 204-038 Surface Location: 1290' FEL & 2240' FNL, Sec. 22, T14N, R9E, UM Bottomhole Location: 1211' FWL & 2373' FNL, Sec. 14, T14N, R9E, UM Dear Mr. Summers: Enclosed is the approved application for permit to drill the above referenced exploration well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application specifications for proposed abandonment plugs were presented. It is not possible to approve the P&A proposal prior to the well being drilled. When it has been determined to P&A the well, Kerr-McGee should file a Sundry Notice (Form 403) providing the determined formation information and planned plug depths. 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 (2 urs notice for a representative of the Commission to witness any required test. t t ission's North Slope petroleum field inspector at 659-3607 (pager). BY ORDER <m. THE COMMISSION DATED this.a.. day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~., ï~~ . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work: Drill D Redrill [J 1b. Type of well. Exploratory D Stratigraphic Test 0 Development Oil 0 Re-entry DDeepen 0 Service o Development Gas 0 Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Kerr McGee Oil & Gas Corporation 33 feet 3. Address 6. Property Designation Exploration 3900 "C" Street, Room 744, Anchorage, AK 99503 ADL 355021/ / 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 MC 25.0251) 1290' FEL & 2240' FNL, See 22 T14N R9E UM ./ Nikaitchuq Statewide At top of productive interval ~ f.1I number t:< Number 1142' FWL & 2516' FNL, See 14 T14N R9E UM 8938' TVD I A/-rc..h ~ 3-798-381 "'. At total depth . 9. Approximate spud date Amount 1211' FWL & 2373' FNL, See 14 T14N R9E UM / March 6, 2003 $200,000 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ,,;' 3040 Feet FSL of Section 22 BPXA, MPF-33A, > 17,600 Feet 5120 . 11211'MD/9368'TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Kickoff depth: 400' I MD Maximum hole angle 40° Maximum surface 3367 psig yI At Sag River Depth (8938' TVD) = 4440 psi ",. 18. Casing program Setting Depth size Soecifications Top Bottom Quantitv of Cement Hole CasinQ WeiQht Grade CouplinQ LenQth MD TVD MD TVD (include stage data) 13-3/8" 68# K-55 PE 80 32 32 112 112 Drive Pipe 12-1/4" 9-518" 40# L-80 STC 5708 30 30 ,/ 5740 4697 ,I 670 sx Permafrost L & 560 sx G 8-1/2" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth ~CEr IE KE .-,\ :'. FEB '2 3 2004 Perforation depth: measured Alaska i;~ Cons. COFni:1¡~Slon Ar1chorag~ true vertical 20. Attachments Filing fee D Property Plat D BOP Sketch D Diverter Sketch D Drilling program D Drilling fluid program DTime vs depth plot Befraction analysis D Seabed report D 20 MC 25.050 requirements D 21. I hereby certify that the foregoing is true and correct to the best of my knowledge. ror questIons call ~Klp (joyner !:/Uf-;j;j!:/-óLO!:/ Signed ,,,,,~....~~~~~:::::::::..,,,,,,._ Title~:e~;-~~:e J~~~as Corp Date 1/23/2004 Charles Summers Commission Use Onlv ^ Permit Number .2£Y-!-{) 38 AP~~_l'¡;Zq _ ;23/99-tx) Approval date l ~t; 0(,; See cover letter for other requirements Co""tio~"'pp~1 5~ ,~y~ D No Mud log required II J.~ Yes U No Hydrogen sulfide measures Yes No Directional survey required ~Yes 0 No ""'O''"''ffi'' p. 2M; D ,.; .~,.; 0 10M; 0 0 Other: .5 a <;.\ r v(. ~<:::.s \- (¡." <;,. p ~ ~'-\'.~ ~ J.~ by order of ð/Sí'ð¥- Approve j ~/ ~ A Commissioner the commission Date UJV1 OR / , { IGINAL Form 10-401 Rev. 12/1/85· Nlkaitchua No.2 in Section 22 T14N 70° 33' 13.985" N & 149° 46' 29.177" W 1290' FEL & 2240 FNL ~ in See 14 T14N 1211' FWL & 2373' FNL 6057418.62' N& 529938,82' E NAD 15 2240' FNL 1290'FEL 22 2 Location) 1211' FWL 2373' FNL Nikaitchuq No.2 (Bottom Hole Location) 14 ADL (5120 total acres) sec. 14, 22 & 23) BP G Kerr 0 8. G BHL: . . ® KEIIII-IfCSEE CØIIPORA1ØI Nikaitchuq #2 Drilling and Abandonment Plan Type of Well: "S-Curve" Drill, log, sidetrack, core and Abandon ,\,ç. -\,~(¿ G. ,\.C~ ~ 1290' FEL & 2240' FNL of Section 22, T14N, R9E UM 1211' FWL&2373' FNLofSection 14, T14N, R9E UM Suñace Location: Bottom Hole Location: 1 AFE Number: 1 I Rig: 1 Nabors 27E 1 Estimated Spud Date: 13/6/04 I Operating Rig days: 125 PTD: 111,211 1 "ITVD: 19,368' 1/ I Pad Elev: 12.5' 1 I DF: 133' Geologic Objectives: Sag River Sandstone, Ivishak, Nuiqsit and Kuparuk S ud - 2500' 2500' - 5740' 8.5-9.5 8.5-9.5 8-1/2" Production Hole 5740'-11211' : Density PV c 10-15 15 - 20 15 - 25 5740' - 8700' 8700' - 9500' 9500' - 11211' 9.6 - 10.0 10.0 -10.6 10.4-11.0 KCL-Pol 8.5-9.5 8.5-9.5 8.5-9.5 . . Bit Proaram: Interval Size Type Footage Hours ROP RPM WOB Surf - 5,700' 12-1/4" 1-1-7 5600' 50 112 200/300 5-30 5,740' - 11,211' 8-1/2" PDC 5190' 78 70 200/300 5-25 Surveys & MWD: While Drilling: 12-114" & 8-112" Holes: MWD surveys every 90 to 300 ft At Suñace Casing Point: Drop a Magnetic Multi-Shot Survey Before POOH AtTD: Drop a Magnetic Multi-Shot Survey Before POOH Mud Loaaina: Surface Hole [12-114"]: Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. ,/ (Samples: 30' 1 10') Mud loggers from BIPermafrost to casing point. r' Production Hole [8-1/2"]: Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. I (Samples: 30' 1 10') Mud loggers from casing point to total depth. ¥ Formation Markers: Formation Tops MO TVO B/Permafrost 1936' 1783' TlWest Sak 4155' 3483' Possible Heavy Oil Zone T/Colville 5637' 4618' 9-5/8" Suñace Casing 5740' 4697' L. Brookian Fan 8059' 6473' Hydrocarbon Bearing, 8.5 ppg EMW T/HRZ 8769' 7073' T/Kalubik 8822' 7123' T/Kuparuk 8960' 7253' Hydrocarbon Bearing, 9.8 ppg EMW Miluveach 8996' 7283' LCU/Kingak 9099' 7383' T/Nuiqsit 9525' 7783' Hydrocarbon Bearing, 9.6 ppg EMW T/Sag River 10754' 8938' Hydrocarbon Bearing, 9.8 - 6.2 ppg EMW T/Shublik 1 0881 ' 9058' T/lvishak 11105' 9268' Possible Hydrocarbons 9.4 ppg EMW PTO 11211' 9368' ;I 2 . . ProDosed Loaaina Proaram: Suñace Hole: MWD I LWD: MWDI GRI RES Open Hole: Gas Detection, Mud Logging & samples E-Line: Quad-Combo + Sonic + MDT's + SWC's Production Hole: MWD 1 LWD: MWD I GR I RES I PWD Open Hole: Gas Detection, Mud Logging & samples E-Line: Quad-Combo + Sonic + MDT's + SWC's FMI I CMR + Velocity Check Shot Cased Hole: GRISCMT/CCL ./ ,/ CasinalTubina Proaram: Hole Csg 1 Lnr WtlFt Grade Cplg Length Top Bottom Size Tbg OD's MD MD n/a 13-3/8" 68.0# L-80 PIE 80' GL 112' 12-1/4" 9-518" 40.0# L-80 BTC 5707' 33' 5740' 8-1/2" n/a Cement Calculations: Hole Size: 12-1/4" Casing Size: 9-5/8" Basis for Lead: 225% excess through the Permafrost to 1950' MD and 30% excess Calculations: Below the Permafrost. Lead slurry to fill from 4240' MD to Surface. Tail: Based on 1500' of annular fill + 30% excess + 80' shoe track volume. Tail TOC: at +/- 4240' Volumes: Lead 670 sx of Permafrost L: 10.7 ppg, 4.15 cf/sx Tail 560 sx of Premium cement + additives ,,\, \5'Vt~{~y." Intearitv Testina: Test Point Depth Test Type LOT: EMW Surface Casing Shoe 20' of new hole LOT 13.3 ppg Minimum expected 3 . . Well Control: The casing head will be installed on the 13-3/8" drive pipe along with a 13-5/8" (5M) diverter spool. The 13-5/8" (5M) BOP stack will be installed above the diverter spool. The 16" diverter valve and 16" diverter line will be tied in to the diverter spool outlet. The 12-1/4" surface hole will be drilled with the 13-5/8" annular configured as a diverter. After setting and cementing the 9-5/8" surface casing, the diverter line will be removed and a 13-5/8" (5M) blind flange will be installed on the diverter spool outlet. The 13-5/8" BOP stack will be re-configured to act as BOPs. The production hole will be drilled with well control equipment consisting of 13-5/8" (5000 psi) working pressure pipe rams (2), blind rams, and annular preventer capable of handling maximum potential surface pressures. Based upon offset well data, the rams, valves and manifold will all be tested to 5000 psi and the annular will be tested to 3500 psi. The maximum anticipated Surface Pressure based on the pressure in the Sag River formation: 4440 psi at -8700' SS (8733' TVO) and a 0.12 psilft gradient to surface is: 4440 psi - (8938 ft x 0.12 psi/ft) = 3367 psi if Disposal of Drillina Waste: · Cuttings Handling: Cuttings generated from drilling operations will be ground and liquefied on location using the "245 Ball Mill". Liquefied cuttings, mud, etc. ,/ will be hauled to Kuparuk's disposal well: 1R-18 for underground injection. Any solid drilling waste not suitable for injection into 1 R-18 will be hauled to G & I #3: located on OS-04, Prudhoe Bay. · Fluid Handling: Haul all drilling and completion fluids wastes to 1 R-18 for'/ disposal. Oil and water produced during well test(s) will be hauled to CPF-3 where it will processed. · Sewage (grey/black water): Camp waste water will be hauled to the sewage treatment plant at Kuparuk where it will be treated and injected along with Kuparuk's camp waste water, etc. H2S: · H2S has not been seen or reported from any of the offset wells that produce from the ~ Sag River and/or Ivishak formations. As a precaution, however, H2S monitors will be ... used at all times in accordance with State Regulations. 4 . . DRilLING AND COMPLETION PROCEDURE Pre-Rig Work: 1. The 13-3/8" non-insulated conductor has been driven to refusal at 112' RKB. 2. NU the multi-bowl 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 notify sign in at the security guard post near the spine road AND check in with the camp boss (medic) upon arrival at location. Travelers must check out with the camp boss (medic) when leaving location AND sign out at the security guard post. 3. A Pre-Spud meeting will be held with all rig personnel and service personnel in Anchorage. A second Pre-Spud meeting will be held in the rig camp with all field personnel involved. 4. A planning meeting will be held at the camp prior to each major phase of the operation: surface hole, surface casing, production hole, logging, running liner, running completion. 5. A daily operations meeting will be held to plan out the day's work and a written "Plan of the Day" will be prepared and distributed to key rig and service personnel. 6. All tools and equipment to be checked, strapped and callipered before they are needed. 7. 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. 8. Pit drills/kick drills will be conducted one with each crew in each hole section. 9. 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. 10. 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. Rig Operations: 1. MIRU Nabors Rig 27E, both camps, the ball mill, the medic skid, rig instrumentation, directional drilling equipment, LWD equipment, gas detectors, PVT, Flo-Show, etc.. 2. Take on water and mix spud mud. Make sure all solids control equipment if operating at capacity. P/U +/- 55 stands of 5" drill pipe and rack it in the derrick. 3. N/U the BOP's on the wellhead with the diverter spool in between. RU the diverter valve and diverter lines. Function test the diverter system. Note: the AOGCC field inspector must witness the function test. 5 . . I 4. P/U a 12-1/4" and BHA with MWD/GR/RES tools. Rotary drill to KOP at 400'. Then build angle at 3°/100' as per the attached directional drilling plan. While drilling the surface hole, stop and circulate the hole clean as/if needed. Rotary drill as much as possible with rotary speed ~ 100 rpm. The flow rate should be at least 650 gpm but not ~ 750 gpm. Control drill if necessary as limited by the solids control equipment and the ball mill. Use Super Suckers if needed to keep up with the waste generated while drilling. Drill the surface hole +/- 100' into the Colville and set casing at +/- 5700' MD. Drill the hole to fit the casing including 10'- 20' of rat hole: we are using a mandrel casing hanger. 5. At casing point, circulate the hole clean. Rotate the drill string at ~ 100 rpm to help clean the hole. Make a wiper trip up to the BHA. RIH to bottom and circulate bottoms up again. Drop a magnetic multi-shot and POOH for logs. UD LWD tools as required. 6. RU E-Line, riser and packoff. Log the hole as directed: Quad-Combo with optional RFT's 0/ and SWC's in the West Sak / Schrader Bluff section. Run the SWC's last. Make a wiper trip between E-Line runs only if needed. RD E-Line. 7. After logging, RIH to bottom and circulate bottoms and condition the mud as required. Make a wiper trip only if needed. POOH to run surface casing. 8. Run and cement the 9-5/8", 40# surface casing. A port collar will be run in the casing string between 500' and 1000' to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. The depth decision will be made prior to running the casing: dependant on the hole conditions. Use PDC drill-able float equipment. Make up the port collar "Combo-Tool" on a stand of drill pipe before running casing. 9. After cementing the 9-5/8" casing, drain and wash out the BOP stack. Set/test the 9-5/8" packoff. NID the diverter valve and diverter lines. N/U the 13-5/8" blind flange and test the BOPE to 250 psi /5000 psi. Test the annular to 250 psi /3500 psi. / 10. M/U 8-1/2" directional drilling assembly with MWD/GR/RES/PWD and a bent-housing motor. P/U +/- 50 additional stands of 5" drill pipe. RIH to the float collar. Test the 9-5/8" casing to 3500 psi: same as the annular. 11. Drill out shoe joints and 20' of new formation. Displace well to clean mud (per program). Pull up into the shoe and perform a Leak Off Test. 12. Drill the 8-1/2" hole to TD as directed following the directional drilling plan. Adjust the mud weight as dictated by hole conditions and in accordance with the attached mud program. Stop and circulate bottoms up as/if needed and rotate the drill pipe at ~ 90 rpm as much as possible to aid hole cleaning. Before drilling into the HRZ, make a wiper trip to the shoe, AND ensure that the mud is conditioned to as per program. Maintain at least 5000 ppm free potassium in the system to inhibit the reactive clays. Adequate potassium concentrations will help minimize the MBT, mud weight, LGS, PV, surge, swab and ECD. Add lubricants as needed for torque but pilot test with lubricants before making wholesale additions. 13. At TD, circulate and condition hole for logs, cores and RFT's. Make a wiper trip through the T/HRZ, RIH to bottom and circulate bottoms up. Drop a magnetic multi-shot, circ., POOH. 14. RU E-Line, riser and packoff. Log the hole as directed: Quad-Combo, FMI, CMR, MDT's t/ and SWC's are expected along with velocity check shot(s). Run the SWC's last. Make a wiper trip between E-Line runs only if needed. The MDT will be DP conveyed. RD E-Line. 15. If time Dermits, the well will be sidetracked and cored. If not. skiD ahead to SteD #21 below. RIH with a 3-1/2" "cement sub" and 11 stands of 3-1/2" DP (or tubing) on 5" drill pipe. Break circulation at the shoe. RIH. Condition the mud at TD prior to pumping the sidetrack plug. R/U Halliburton. 6 . . / 17. POOH 15 stands (slowly). Circulate bottoms up. POOH. Rack back the 3-1/2" DP. 18. RI H with sidetrack BHA: (bit, 1.22° bent housing motor, MWD, GR, RES.). Dress off the sidetrack plug in rotary mode to .!. 10400' MD. Orient "high Side" and "time drill" .!. 60 ft to start the sidetrack. Then add weight cautiously while sliding to sidetrack. Slide and drill the sidetrack to the top of the Sag River or as directed by the geologists: 15'-20' of separation is enough. At core point, circulate the hole clean, backream up through the KOP and then return to bottom. Circulate the hole clean. Spot a 50 bbl, Hi-Vis pill on bottom. POOH. LID directional tools, etc. 19. RIH with the Baker-Inteq coring assembly on 5" DP. Break circulation at the shoe then continue RIH. Carefully work through the KOP and wash to bottom if necessary. Drop the ball and core the Sag River as directed. Once the core is cut, POOH and lay it down. 20. If addition coring is required and time allows, repeat step 19 above. 21. After coring, RIH with 12 stands of 3-1/2" DP (or tubing) on 5-1/2" DP. Wash to bottom and circulate to cool the hole. R/U Halliburton to pump abandonment plugs. 22. Test Halliburton lines to 3000 psi. Mix and pump balanced cement plugs to cover all hydrocarbon bearing zones in the 8-1/2" hole starting at TD: (catch wet samples) Plug Length Top Bottom Sacks BBL Excess Displacement 2 1100' 9,700' 10,800' 435 89 15% 176 BBL of mud 3 1100' 8,600' 9,700' 435 89 15% 157 BBL of mud 4 1100' 7,500' 8,600' 435 89 15% 137 BBL of mud J J ./ . Use caliper + 15% for cement volumes. . Cement is "Premium" with retarders as/if needed: 1.15 cf/sx & 15.8 ppg. · After displacing each plug, pull:t 15 stands and circulate bottoms up. · The three plugs must cover all hydrocarbon bearing zones by 100 ft. · Plug #4 above covers the L. Brookian by :t 150 ft. · Catch and save samples of each cement plug. 23. While WOC after setting plug #4. LID excess DP. RIH and tag plug #4. POOH. 24. RIH with an EZSV on 5" DP. Set the EZSV at .!. 5650' MD. Establish injection below the EZSV. Release from the EZSV and test to 1500 psi. Tag the EZSV to confirm its depth. Sting back in to the EZSV. R/U Halliburton. 25. Test lines to 3000 psi. Mix and pump 122 sx (25 bbl) of "Premium" cement mixed at 15.8 ppg and 1.15 cf/sx. Displace plug #5 through the EZSV with 95 bbl of mud. Pull out of the EZSV and dump the final 5 bbl of cement on top of the EZSV. Rack back one (1) stand of DP and circulate until clean. LID all 5" DP remaining in the hole. (catch wet samples) Bottom Sacks Dis lacement 5,900' 122 96 BBL of mud V . . v 27. P/U a casing cutter. Cut and pull the 9-5/8" casing .:t 20 ft below the mud line. NID the wellhead. Cut and pull the 13-3/8" casing .:t 15 ft below the mud line. UD the casing cutter. 28. RIH with OEDP to the TOC from step 26 above. R/U Halliburton. Test lines to 1000 psi. Mix and pump 15 - 20 sx of class "G" neat. UD DP. Clean the pits. Release the rig. 29. RID and MORT. 30. Clean location. Remove and dispose of all tainted ice and snow. When appropriate, conduct a "post drilling" site inspection with the AOGCC field inspector. dizn~ ~ASRC Energy Services \ 1Iifr-" E & P Teahnøtøsw Attachments: · We II bore Schematics · Drilling Curve: Days -v- Depth · Frac Gradient Plot (from offset data) · Planned Well Profile · Diverter & BOP Schematics · Directional Drilling program · Drilling Mud Program · Cementing Program · Shallow Hazard Survey · Predicted Abnormal Pressure Study 8 + 500' MD 4240' MD ¡ 5740' MD o 0 I-_____~ . . @ KEJlR..IfCflEE CIJIIPORATlIJII Nikaitchuq #2 Surface Casing Tam Port Collar Permafrost "L" lead slurry 1500' of "Premium" tail slurry 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) 8-1/2" Hole into the Ivishak 11211' MD + 500' MD 5740' MD o 0 1\ . . ~ KEIIII-.CSEE CllllPMAlI,. Nikaitchuq #2 Plug Back Tam Port Collar 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ Plua #1: 390 sx of class "G" ,I 11211' MD 8-1/2" Sidetrack wi Sag River core . 5580' MD 5650' MD 5740' MD 5900' MD . @mIIUICSEE CllBl'lJRA1Ø Nikaitchuq #2 Plug & Abandon PIUQ #5: 122 sx of class "G" wI EZSV 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) Plua #2: (1100') 435 sx of class "G" Plua #3: (1100') 435 sx of class "G" PluQ #4: (1100') 435 sx of class "G" 11211' MD TMD = 10,800' 60'RKB 240'RKB (8 joints) 5600' MD 5650' MD 5740' MD 5840' MD 11211' MD . . @ KERll-w:BEE CtIRPOBAßIJII Nikaitchuq #2 Plug & Abandon PIUQ #6: 122 sx of type "C" Permafrost · Spot a cement plug from 240' to suñace · POOH to .:!: 60' RKB and circulate clean · Cut off 9-5/8" & 13-3/8" just above TOC PluQ #5: 122 sx of class "G" wi EZSV 9-5/8", 40#, L-80, BTC (Pi = 5750 psi) .. .~" I I I I I 4000 5000 .c ....., c. CD C 6000 "'C CD a... :::2 7000 tn m CD :æ 8000 9000 10000 11000 12000 13000 Nikaitchuq.#2 o 1000 2000 3000 o 5 10 15 Rig Days 20 25 o et LOT's (Frac Gradient) 2000 1000 o 3000 C1:S .~ 4000 1: CI) > 5000 6000 7000 EMW (ppg) sc 4000 c > 5000 I- 10000 -1000 o 1000 2000 3000 6000 7000 8000 9000 8-1/2" Hole to 11211' MD Nikai huq #2 o 1000 2000 3000 4000 5000 6000 7000 Vertical Section . .+-~--- '~ rlt/lf' +..~--- ~- t 10 .,.. ~~-- },..- r . '/If' .~---------- .........-_... BOP MODE · Annular: Normal Operation · Rams: Normal Operation · 13-5/8" Blind Flange over the outlet . - - . Nabors 27E '3 air aoaDf IMJRL ANNIIM lOP 8OL1ED FIMGE SINGLE '3 SIr BODDf HVDRL MPL PIPE !WI 8OL1ED FUNCIE SINGLE '3 s¡r 5IIDOf HYDRI. MPL IIJII) IN 8OL1ED FlANGE 4- ~ HCR VM.VE II · 4- CHOICE LINE 4- ~ M1E _VE 8OL1ED F1NfGE SINGLE '3 SIr 8IXIDI HYDRI. MPL PIPE IN 13-5/8" x 5000# Diverter "T" IOI.'IED FUNCIE .. DIVERTER MODE · Annular: Diverter Operation · Rams: Locked Open · 13-5/8" X 16" Adapter, 16" Knife Valve & 16" Diverter Line 16" Diverter Line ,::"" ~j!f:f:;~ Halliburton Sperry-Sun Western Norlb S NW Mil,!: \t f\Jikå c{ . Revi$~ 17 February, 2004 Proposal Report 17 February, 2004 v Your Ref: Per Russell Murphy (1-21-04) Surface Coordinates: 6052262.78 N, 527465.68 E (70033' 13.9850" N, 149046' 29.1770" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 33.00ft above Mean Sea Level Proposal Ref: pro2073 Begin Dir @ 3.0'/100ft : 400.00ft MD, 400.00ft TVD ~d' 'iF End Dir, Start Sail @ 40.000' : 1733.33ftMD,1627.63ftTVD 1500 3000 ,./ ~ t () > 6000 Begin Dir@4.000'/100ft 8223.70ft MD, 6599.54ft TVD End Dir, Start Sail @ 20.000' / : 8723.70ftMD,7030.36ftTVD 9~ 7500 § <:) I.() '"" II .I::. .Š 9000 ~ à) ro : 11211.3611 MD, 9368.00f! TVD (1211' FWL & 2373' FNL, Sec. 14 - T14111 . R9E) o 3000 4500 6000 1500 Scale: 1 inch::: 1500ft 5000 1000 2000 Eastings Scale: 1 inch;: 1000ft PBHL: 11211.36ft MD, 9368.00f! TVD (1211' FWL & 2373' FNL, Sec. 14 . T14N . R9E) 5000 4000 4000 3000 3000 2000 Csg pt ... Drill out 8·112" Hole: 5740.00ft MD, 4696.920ft TVD 2000 1000 1000 End Dir, Start Sail @ 40.000' : 1733.33ftMD,1627.63ftTVD Begin Dir @ 3.0'/100ft : 400.00ft MD, 40b.00ft TVD o 1000 2000 Scale: 1inch ::: 1000f! A H¡¡liIburtM Company Halliburton Sperry-Sun Proposal Report for Spy Island· Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Comment (ft) (ft) (ft) (ft) (ft) (ft) .~ 0.00 0.000 0.000 -33.00 0.00 0.00 N 0.00 E 6052262.78 ~. 0.00 . SHL (1290' FEL & 2240' FNL, 6052262.78 N¡¡l;; Sec. 22 - T14N - R9E) 100.00 0.000 0.000 67.00 100.00 0.00 N 0.00 E .68 E 0.000 0.00 200.00 0.000 0.000 167.00 200.00 0.00 N 0.00 E 6052262.78 N ,~; 527465.68 E 0.000 0.00 300.00 0.000 0.000 267.00 300.00 0.00 N 0.00 E ,§O:522~2;78 N " §~]465.68 E 0.000 0.00 .~. 400.00 0.000 0.000 367.00 400.00 0.00 N ' 26Z.{'8 N 527465.68 E 0.000 0.00 Begin Dir @ 3.00/100ft: 400.0. v~ MD, 400.00ft TVD 500.00 3.000 25.840 466.95 499.95 N 527466.81 E 3.000 2.62 600.00 6.000 25.840 566.63 599.63 6052272.21 N 527470.21 E 3.000 10.46 700.00 9.000 25.840 665.77 698.77 6052283.98 N 527475.85 E 3.000 23.51 800.00 12.000 25.840 764.08 797.08 6052300.41 N 527483.73 E 3.000 41.74 900.00 15.000 25.840 861.31 894.31 6052321.45 N 527493.83 E 3.000 65.08 1000.00 18.000 25.840 40.74 E 6052347.06 N 527506.11 E 3.000 93.48 1100.00 21.000 25.840 55.29 E 6052377.15 N 527520.55 E 3.000 126.85 1200.00 24.000 25.840 71.97 E 6052411.65 N 527537.10 E 3.000 165.12 1300.00 27.000 25.840 90.73 E 6052450.46 N 527555.71 E 3.000 208.16 1400.00 30.000 25.840 111.52 E 6052493.48 N 527576.35 E 3.000 255.87 1500.00 40 1440.18 277.31 N 134.30 E 6052540.59 N 527598.95 E 3.000 308.12 1600.00 40 1522.59 328.28 N 158.98 E 6052591.65 N 527623.44 E 3.000 364.75 1700.00 4O; 1601.91 383.06 N 185.51 E 6052646.53 N 527649.77 E 3.000 425.62 1733..33 40 1594.63 1627.63 402.15 N 194.75 E 6052665.65 N 527658.94 E 3.000 446.82 End Dir, Start Sail @ 40.0° : t~ 1733.33ft MD, 1627.63ft TVD 180q~()Ò 1645.70 1678.70 440.71 N 213.43 E 6052704.28 N 527677.47 E 0.000 489.67 1900.00 25.840 1722.31 1755.31 498.57 N 241.45 E 6052762.24 N 527705.28 E 0.000 553.95 . 1936·1ß 40.000 25.840 1750.00 1783.00 519.48 N 251.57 E 6052783.19 N 527715.33 E 0.000 577.19 Base of Permafrost 2000.00 40.000 25.840 1798.91 1831.91 556.42 N 269.46 E 6052820.19 N 527733.08 E 0.000 618.23 2100.00 40.000 25.840 1875.52 1908.52 614.27 N 297.48 E 6052878.15 N 527760.88 E 0.000 682.51 2200.00 40.000 25.840 1952.12 1985.12 672.12 N 325.50 E 6052936.10 N 527788.68 E 0.000 746.79 2300.00 40.000 25.840 2028.73 2061.73 729.97 N 353.51 E 6052994.06 N 527816.48 E 0.000 811.07 2400.00 40.000 25.840 2105.33 2138.33 787.83 N 381.53 E 6053052.01 N 527844.29 E 0.000 875.35 2500.00 40.000 25.840 2181.93 2214.93 845.68 N 409.54 E 6053109.97 N 527872.09 E 0.000 939.63 2600.00 40.000 25.840 2258.54 2291.54 903.53 N 437.56 E 6053167.92 N 527899.89 E 0.000 1003.90 2700.00 40.000 25.840 2335.14 2368.14 961.38 N 465.58 E 6053225.88 N 527927.69 E 0.000 1068.18 17 February, 2004· 14:17 Page 2 of 9 DrlllQuest 3.03.05.005 Halliburton Sperry-Sun Proposal Report for Spy Island - Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Section Comment (ft) (ft) (ft) (ft) (ft) (ft) {ft 2800.00 40.000 25.840 2411.75 2444.75 1019.23 N 493.59 E 6053283.84 '52 0.000 1132.46 2900.00 40.000 25.840 2488.35 2521.35 1077.08 N 521.61 E 6053341 .79 5?7... E 0.000 1196.74 3000.00 40.000 25.840 2564.96 2597.96 1134.94 N 549.63 E 6053399.75 528~11 .1'0 E 0.000 1261.02 3100.00 40.000 25.840 2641.56 2674.56 1192.79 N 577.64 E 605~¡¡7.70 N 528038.90 E 0.000 1325.30 3200.00 40.000 25.840 2718.17 2751.17 1250.64 N 605.66 E 6053515.66 N ~~066.70 E 0.000 1389.58 ,...." . 3300.00 40.000 25.840 2794.77 2827.77 6053573:61 N 528094.50 E 0.000 1453.86 3400.00 40.000 25.840 2871.37 2904.37 6.D53631.57 N 528122.30 E 0.000 1518.13 3500.00 40.000 25.840 2947.98 2980.98 6053689.52 N 528150.11 E 0.000 1582.41 3600.00 40.000 25.840 3024.58 3057.58 6053747.48 N 528177.91 E 0.000 1646.69 3700.00 40.000 25.840 3101.19 3134.19 6053805.43 N 528205.71 E 0.000 1710.97 3800.00 40.000 25.840 3177.79 3210.79 773.76 E 6053863.39 N 528233.51 E 0.000 1775.25 3900.00 40.000 25.840 3254.40 3287.4Q 801.78E 6053921.34 N 528261.31 E 0.000 1839.53 4000.00 40.000 25.840 3331.00 3~i4. 829.79 E 6053979.30 N 528289.12 E 0.000 1903.81 4100.00 40.000 25.840 3407.61 341p· 857.81 E 6054037.25 N 528316.92 E 0.000 1968.09 4155.34 40.000 25.840 3450.00 34.~~. 873.31 E 6054069.33 N 528332.30 E 0.000 2003.66 Top of Schrader Bluff/West Sak 4200.00 25.840 3464.21 3517.21 1829.16 N 885.83 E 6054095.21 N 528344.72 E 0.000 2032.36 4300.00 25.840 ·3~Q~:.~1 3593.81 1887.01 N 913.84 E 6054153.16 N 528372.52 E 0.000 2096.64 4400.00 25,iß4.0 363~¡42Y 3670.42 1944.86 N 941.86 E 6054211.12 N 528400.32 E 0.000 2160.92 4500.00 2SJ!40 ·.3714.02 3747.02 2002.71 N 969.88 E 6054269.08 N 528428.12 E 0.000 2225.20 4600.00 ý3790.63 3823.63 2060.57 N 997.89 E 6054327.03 N 528455.93 E 0.000 2289.48 470Q,QO; 3867.23 3900.23 2118.42N 1025.91 E 6054384.99 N 528483.73 E 0.000 2353.76 4800;00; 3943.84 3976.84 2176.27 N 1053.92 E 6054442.94 N 528511.53 E 0.000 2418.04 4900,00 4020.44 4053.44 2234.12 N 1081.94 E 6054500.90 N 528539.33 E 0.000 2482.32 5000:.00 4097.05 4130.05 2291.97 N 1109.96 E 6054558.85 N 528567.13 E 0.000 2546.60 . 5100.g0 4173.65 4206.65 2349.82 N 1137.97E 6054616.81 N 528594.94 E 0.000 2610.87 5200.00 40.000 25.840 4250.25 4283.25 2407.68 N 1165.99 E 6054674.76 N 528622.74 E 0.000 2675.15 5300.00 40.000 25.840 4326.86 4359.86 2465.53 N 1194.01 E 6054732.72 N 528650.54 E 0.000 2739.43 5400.00 40.000 25.840 4403.46 4436.46 2523.38 N 1222.02 E 6054790.67 N 528678.34 E 0.000 2803.71 5500.00 40.000 25.840 4480.07 4513.07 2581.23 N 1250.04 E 6054848.63 N 528706.14 E 0.000 2867.99 5600.00 40.000 25.840 4556.67 4589.67 2639.08 N 1278.06 E 6054906.58 N 528733.95 E 0.000 2932.27 5636.98 40.000 25.840 4585.00 4618.00 2660.48 N 1288.42 E 6054928.01 N 528744.23 E 0.000 2956.04 Top of Colville Mud Stone 5700.00 40.000 25.840 4633.28 4666.28 2696.94 N 1306.07 E 6054964.54 N 528761.75 E 0.000 2996.55 5740.00 40.000 25.840 4663.92 4696.92 - 2720.08 N 1317.28 E 6054987.72 N 528772.87 E 0.000 3022.26 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5740.00ft MD, 4696.920ft TVD 9-5/8" Casing 17 February, 2004·14:17 Page 3 0'9 DrlllQuest 3.03,05.005 Halliburton Sperry-Sun Proposal Report for Spy Island - Nikaltchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) 5800.00 40.000 25.840 4709.88 4742.88 2754.79 N 1334.09 E 6055022.49 ~. 3060.83 5900.00 40.000 25.840 4786.49 4819.49 2812.64 N 1362.11 E 6055080.45 .8' 3125.10 6000.00 40.000 25.840 4863.09 4896.09 2870.49 N j~j;j528845.15 E 0.000 3189.38 6100.00 40.000 25.840 4939.69 4972.69 2928.34 N '·~?j~872.96 E 0.000 3253.66 6200.00 40.000 25.840 5016.30 5049.30 2986.19 N 528900.76 E 0.000 3317.94 . 6300.00 40.000 25.840 5092.90 5125.90 3044.05 N 528928.56 E 0.000 3382.22 6400.00 40.000 25.840 5169.51 5202.51 3101.90 528956.36 E 0.000 3446.50 6500.00 40.000 25.840 5246.11 6055428.18 N 528984.16 E 0.000 3510.78 6600.00 40.000 25.840 5322.72 6055486.14 N 529011.96 E 0.000 3575.06 6700.00 40.000 25.840 5399.32 6055544.09 N 529039.77 E 0.000 3639.33 6800.00 40.000 25.840 5475.93 6055602.05 N 529067.57 E 0.000 3703.61 6900.00 40.000 25.840 5552.53 6055660.00 N 529095.37 E 0.000 3767.89 7000.00 40.000 25.840 5629.13 1670.29 E 6055717.96 N 529123.17 E 0.000 3832.17 7100.00 40.000 25.840 5705.74 1698.30 E 6055775.91 N 529150.97 E 0.000 3896.45 7200.00 40.000 25.840 5713~·3~ 1726.32 E 6055833.87 N 529178.78 E 0.000 3960.73 7300.00 40.000 25.840 75858.95",> 1754.34 E 6055891.82 N 529206.58 E 0.000 4025.01 7400.00 40.000 25.840 .., 5935.55 5968.55 1782.35 E 6055949.78 N 529234.38 E 0.000 4089.29 "'<;tj;..}) ,¡¡012.16 6045.16 3738.27 N 1810.37 E 6056007.73 N 529262.18 E 0.000 4153.56 "6088.76 6121.76 3796.12 N 1838.39 E 6056065.69 N 529289.98 E 0.000 4217.84 6165.37 6198.37 3853.97 N 1866.40 E 6056123.64 N 529317.79 E 0.000 4282.12 6241.97 6274.97 3911.82 N 1894.42 E 6056181.60 N 529345.59 E 0.000 4346.40 6318.57 6351.57 3969.68 N 1922.44 E 6056239.55 N 529373.39 E 0.000 4410.68 8000.. 25.840 6395.18 6428.18 4027.53 N 1950.45 E 6056297.51 N 529401.19 E 0.000 4474.96 . 8058.5.1 40.000 25.840 6440.00 6473.00 4061.38 N 1966.85 E 6056331.42 N 529417.46 E 0.000 4512.57 Top of L. Brookian Fan 8100.00 40.000 25.840 6471.78 6504.78 4085.38 N 1978.47 E 6056355.47 N 529428.99 E 0.000 4539.24 8200.00 40.000 25.840 6548.39 6581.39 4143.23 N 2006.49 E 6056413.42 N 529456.79 E 0.000 4603.52 8223.70 40.000 25.840 6566.55 6599.55 4156.94 N 2013.13 E 6056427.16 N 529463.38 E 0.000 4618.75 Begin Dir @ 4.0o/100ft: 8223.7( MD, 6599.54ft TVD 8300.00 36.948 25.839 6626.27 6659.27 4199.66 N 2033.81 E 6056469.95 N 529483.91 E 4.000 4666.21 8400.00 32.948 25.838 6708.22 6741.22 4251.21 N 2058.77 E 6056521.59 N 529508.68 E 4.000 4723.49 8500.00 28.948 25.836 6793.97 6826.97 4297.48 N 2081.18 E 6056567.95 N 529530.92 E 4.000 4774.90 8600.00 24.948 25.834 6883.09 6916.09 4338.27 N 2100.93 E 6056608.80 N 529550.51 E 4.000 4820.21 8700.00 20.948 25.831 6975.16 7008.16 4373.35 N 2117.91 E 6056643.95 N 529567.37 E 4.000 4859.19 17 February, 2004· 14:17 Page 4 of 9 DrlllQuest 3.03,05.005 Halliburton Sperry-Sun Proposal Report for Spy Island - Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Comment (ft) (ft) (ft) (ft) (ft) (ft) 8723.70 20.000 25.830 6997.36 7030.36 4380.81 N 2121.53 E 6056651.43 4867.48 End Dir, Start Sail @ 20.0° : 8723.70ft MD, 7030.36ft TVD 8769.29 20.000 25.830 7040.20 7073.20 4394.85 N 2128.32 E 6056665.49 0.000 4883.08 Top of HRZ 8800.00 20.000 25.830 7069.06 7102.06 4404.30 N 2132.90 E 6056674.96 N 0.000 4893.58 8822.29 20.000 25.830 7090.00 7123.00 4411 .16 N 2136.22 E '¡~º566Q~.83 N 0.000 4901.20 Top of Kalubik Shale 8900.00 20.000 25.830 7163.03 7196.03 4435.09 N 2 0 '. ... 70~0 N 0.000 4927.78 . 8960.63 20.000 25.830 7220.00 7253.00 724.50 N 529605.99 E 0.000 4948.52 Top of Kuparuk Sands 9000.00 20.000 25.830 7257.00 7290.00 6056736.64 N 529611.81 E 0.000 4961.98 9098.97 20.000 25.830 7350.00 7383.00 6056767.16 N 529626.45 E 0.000 4995.83 LCU / top of Kingak Shale 9100.00 20.000 25.830 7350.97 7383.97 6056767.48 N 529626.60 E 0.000 4996.19 9200.00 20.000 25.830 7444.94 7477.94 6056798.32 N 529641.39 E 0.000 5030.39 9300.00 20.000 25.830 7538.91 7571.91. 2207.40 E 6056829.16 N 529656.17 E 0.000 5064.59 9400.00 20.000 25.830 7632.87 76q5.' 2222.31 E 6056860.00 N 529670.96 E 0.000 5098.79 9500.00 20.000 25.830 7726.84 77~·Sft .ir 2237.21 E 6056890.84 N 529685.75 E 0.000 5132.99 9524.64 20.000 25.830 7750.00 /~: 77&3.00 :Jjj:rf;i" 2240.88 E 6056898.44 N 529689.39 E 0.000 5141.42 Top of Nuiqsit Sand 9588.49 20.000 25.830 '7:~~.00 2250.39 E 6056918.13 N 529698.83 E 0.000 5163.26 Sase of Nuiqsit Sand ,¡.;þ'" 25.830 7853.81 4650.58 N 2252.11 E 6056921.68 N 529700.54 E 0.000 5167.20 2 30 7947.78 4681.37 N 2267.01 E 6056952.52 N 529715.32 E 0.000 5201.40 30 8041.75 4712.15 N 2281.91 E 6056983.36 N 529730.11 E 0.000 5235.60 . 30 8135.72 4742.94 N 2296.81 E 6057014.20 N 529744.90 E 0.000 5269.80 2tj,ß30 8196.69 8229.69 4773.72 N 2311.72E 6057045.04 N 529759.69 E 0.000 5304.00 \i~' 1010 25.830 8290.66 8323.66 4804.51 N 2326.62 E 6057075.88 N 529774.47 E 0.000 5338.21 1020 25.830 8384.63 8417.63 4835.29 N 2341.52 E 6057106.72 N 529789.26 E 0.000 5372.41 10300; 25.830 8478.60 8511.60 4866.08 N 2356.42 E 6057137.56 N 529804.05 E 0.000 5406.61 . 10400. 25.830 8572.57 8605.57 4896.86 N 2371.32 E 6057168.40 N 529818.84 E 0.000 5440.81 10500.ÒO 25.830 8666.54 8699.54 4927.65 N 2386.23 E 6057199.24 N 529833.62 E 0.000 5475.01 10600.00 20.000 25.830 8760.51 8793.51 4958.43 N 2401.13 E 6057230.08 N 529848.41 E 0.000 5509.22 10700.00 20.000 25.830 8854.47 8887.47 4989.22 N 2416.03 E 6057260.92 N 529863.20 E 0.000 5543.42 10753.77 20.000 25.830 8905.00 8938.00 5005.77 N 2424.04 E 6057277.50 N 529871.15 E 0.000 5561.81 TARGET: 10753.77ft MD, 8938.00ft TVD (1142' FWL & 2516' FNL, Sec. 14-T14N-R9E) Top of Sag River Sandstone Nikaitchuq #2 Target WP06, 100.00 Radius., CurrentTarget 10800.00 20.000 25.830 8948.44 8981.44 5020.00 N 2430.93 E 6057291.76 N 529877.99 E 0.000 5577.62 10881.47 20.000 25.830 9025.00 9058.00 5045.08 N 2443.07 E 6057316.88 N 529890.03 E 0.000 5605.48 Top of Shublik 17 February, 2004·14:17 Page 5 of9 DrlllQuest 3.03.05.005 Halliburton Sperry-Sun Proposal Report for Spy Island - Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Western North Slope, Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 10900.00 20.000 25.830 9042.41 9075.41 11000.00 20.000 25.830 9136.38 9169.38 11100.00 20.000 25.830 9230.35 9263.35 11104.95 20.000 25.830 9235.00 9268.00 11200.00 20.000 25.830 9324.32 9357.32 11211.36 20.000 25.830 9335.00 9368.00 Local Coordinates Northings Eastings (ft) (ft) 5050.79 N 5081.57 N 5112.36 N 5113.88N 5143.14N 2445.83 E 2460.73 E 2475.64 E 2476.37 E 2490.54 E Global Coordinates Northings (ft) (ft) 6057322.60 t4' 6057353.44 N. 6057384.28 Ñ 60 85.80 N ,~i22 N þ~;*, ~7418:g2 N "¡I' 529938.82 E 0.000 All data is in Feet (US Survey) unless otherwise stated. Directions and coo Vertical depths are relative to RKB Est @ 33' MSL. Northings and Eastin Global Northings and Eastings are relative to NAD27 Alaska State Plan tes are '« ive to True North. relative\9f240 FNL, 1290 FEL. ''#-' The Dogleg Severity is in Degrees per 1 00 feet (US Survey)! Vertical Section is from 2240 FNL, 1290 FEL and calculatea"al ,,:¡;~~" ¥{ Based upon Minimum Curvature type calculati8ps¿~t a'M~~wed Depth of 11211.36ft., The Bottom Hole Displacement is 5718.31 ª.,JQ the Qirectiònóf 25.838° (True). The Along Hole Displacement iS~(J8.31~, The TótåfAccumulated Dogleg is 60.000° The Planned Tortuosity is 1.Q20oI10Qft. T~~ Directional Difficulty Index is 5.4. ': . w· j;¡; Me.asured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 0.00 400.00 1733.33 5740.00 8223.70 0.00 400.00 1627.63 4696.92 6599.54 0.00 N 0.00 N 402.14 N 2720.08 N 4156.94 N 0.00 E 0.00 E 194.75 E 1317.28 E 2013.13E SHL (1290' FEL & 2240' FNL, Sec. 22 - T14N - R9E) Begin Dir @ 3.00/100ft: 400.00ft MD, 400.00ft TVD End Dir, Start Sail @ 40.0° : 1733.33ft MD, 1627.63ft TVD 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5740.00ft MD, 4696.920ft TVD Begin Dir @ 4.00/100ft: 8223.70ft MD, 6599.54ft TVD 5611.82 5646.02 5680.23 5681.92 5714.43 5718.31 Kerr McGee Top of Ivashak PBHL: 11211.36ft MD, 9368.. TVD (1211' FWL & 2373' FNL, Sec. 14 - T14N - R9E) . 17 February, 2004·14:17 Page 6 of 9 Drl/lQuest 3.03,05.005 Western North Slope, Comments (Continued) Halliburton Sperry-Sun Proposal Report for Spy Island· Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Measured Depth (ft) Station Coordinates TVD Northlngs Eastings (ft) (ft) (ft) 8723.70 10753.77 "11211.36 7030.36 8938.00 9368.00 Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dirn. 1750.00 3450.00 4585.00 6440.00 7040.20 7090·QP 7220.00 . . 7350.00 7750.00 7810.00 0.000 8905.00 9025.00 9235.00 0.000 0.000 0.000 0.212 0.212 0.212 4380.81 N 5005.77 N 5146.64 N Profile Measured Vertiçal Depth DelitÞ (ft) , . 19 41 563 8058.51 8169.29 8822.29 7123.00 8960.63 7253.00 9098.97 7383.00 9524.64 7783.00 9588.49 7843.00 10753.77 8938.00 10881.47 9058.00 11104.95 9268.00 2121.53 E 2424.04 E 2492.23 E 1750.00 3450.00 4585.00 6440.00 7040.20 7090.00 7220.00 7350.00 7750.00 7810.00 8905.00 9025.00 9235.00 Comment Kerr McGee . . 17 February, 2004·14:17 End Dir, Start Sail @ 20.0° : 8 TARGET: 1075 PBHL : 112 V~D, TVD(1142' FWL & 2516' FNL, Sec. 14-T14N-R9E) 1)10 (1211' FWL & 2373' FNL, Sec. 14 - T14N - R9E) Poi n t Northings Eastings Formation Name (ft) (ft) 519.48 N 251.57 E Base of Permafrost 1803.32 N 873.31 E Top of Schrader BlufflWest Sak 2660.48 N 1288.42 E Top of Colville Mud Stone 4061.38 N 1966.85 E Top of L. Brookian Fan 4394.85 N 2128.32 E Top of HRZ 4411.16 N 2136.22 E Top of Kalubik Shale 4453.75 N 2156.83 E Top of Kuparuk Sands 4496.34 N 2177.45 E LCU / top of Kingak Shale 4627.38 N 2240.88 E Top of Nuiqsit Sand 4647.04 N 2250.39 E Base of Nuiqsit Sand 5005.77 N 2424.04 E Top of Sag River Sandstone 5045.08 N 2443.07 E Top of Shublik 5113.88N 2476.37 E Top of Ivashak Page 7 of 9 DrlllQuest 3.03.05.005 Western North Slope, Casino details From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) <Surrace> <Surrace> 5740.00 4696.92 Taroets associated with this welloath Target Name Nikaitchuq #2 Target WP06 Halliburton Sperry-Sun Proposal Report for Spy Island - Nikaitchuq #2 (wp06) Your Ref: Per Russell Murphy (1-21-04) Revised: 17 February, 2004 Casing Detail 9-5/8" Casing Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Target Shape 8938.00 5005.77 N 2424.04 E 8905.00 6057277.50 N 529871.15 E 70" 34' 03.2160" N 149" 45' 17.5679" W Circle Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: 100.00ft Kerr McGee . Target Type Current Target . 17 February, 2004·14:17 DrlllQuest 3.03,05.005 Page 8 of 9 Halliburton Sperry-Sun North Reference Sheet for Spy Island - Nikaitchuq #2 Western North Slope, Coordinate System is NAD27 Alaska State Planes, Zone 4, US Foot Source: Snyder, J.P., 1987, Map Projections - A Working Manual Datum is North American Datum of 1927 (US48, AK, HI, and Canada) Spheroid is Clarke - 1866 Equatorial Radius: 6,378,206.400m. Polar Radius: 6,356,583.800m. Inverse Flattening: 294.97869821388m. Projection method is Transverse Mercator or Gauss Kruger Projection Central Meridian is -150.000· Longitude Origin: 0.000· Latitude Origin: 54.000· False Easting: 500,000.000ft. False Northing: O.OOOft. Scale Reduction: 0.99990000 Datum is North American Datum of 1927 (US48, AK, HI, and Can a Spheroid is Clarke - 1866 Equatorial Radius: 6,378,206.400m. Polar Radius: 6,356,583.800m. Grid Coordinates of Well: 6052262.78 N, 52746&..66E Geographical Coordinates of Well: 70· 33:13.9å50~ N. 149· 46' 29.1770" W Surface Elevation of Well: 33.00ft, .... ... " Grid Convergence at Surface is 0.Ž12° Magnetic Declination at ~l.IrfaGe is?4.924~,(17 February, 2004) ,-",}(," Yv'. True North Grid North Magnetic Model: Date: Declination: Inclination/Dip: Horizontal Component: Northerly Component: Easterly Component: Vertical Component: Total Field Strength: Kerr McGee . BGGM2003 17-Feb-04 24.924 80.906 9096 n T 8249 nT 3833 nT 56826 n T 57550 nT e 17 February, 2004· 14:17 DrlllQuest 3.03.05.005 Magnetic North Hole Direction Grid North is 0.212° East of True North (Grid Convergence) Magnetic North is 24.924· East of True North (Magnetic Declination) Magnetic North is 24.712· East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.212 degrees To convert a Magnetic Direction to a True Direction, Add 24.924 degrees To convert a Magnetic Direction to a Grid Direction, Add 24.712 degrees Page 9 of 9 . . @ KERR-w:sEE ClJRPORAlItJII Nikaitchuq #2 Mud Program Baroid Drilling Fluids General Discussion This exploration well will be drilled from an off-shore ice pad on Spy Island, basically due north of Oliktok Point on the North Slope of Alaska. The well will be drilled as an liS" shaped hole building to 40° in the 12-1/4" surface hole and drilled to ± 5,740' TMD where 9-5/8" casing will v be run and cemented. An 8-1/2" hole will then be drilled holding this angle to 8224' MD where a drop to 20° will begin. This angle will be then be held to TD at ± 11,211' TMD. Primary targets for this well will include the Sag River and Ivishak sands with other possible oil bearing sands ,/ being present. An inhibited KCI/Polymer mud will be used to drill this well from spud to TD. If time allows after reaching TD, the hole will be plugged back, sidetracked and the Sag River will'" be cored. Finally, the well will be abandoned in accordance with AOGCC regulations. As a general drilling fluids plan, spud the well with inhibited 9.0 ppg 12% KCI/Polymer mud. The mud weight will then be held between 9.0-10.0 ppg mud weight to the surface hole TD unless hole conditions dictate otherwise. Our primary focus for surface hole drilling operations will be adequate mud weight for well control and sufficient mud viscosity for 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 surface shoe to the core point, the continued use of the inhibited 9.6 ppg KCI/Polymer mud is suggested. When drilling this interval of the well a certain amount of new mud will be required coming out of the surface casing to re-adjust the low gravity solids content to within acceptable limits for continued drilling operations. The mud weight for this interval of the well will range from 9.6 ppg at drill-out of the surface casing to 10.4-10.6 ppg by the top of the HRZ. This weight is needed to help stabilize the HRZ and Kingak shales at this angle and direction as per the Baroid/Sunbury HRZ and Kingak shale studies. 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 60K-90K ppm range when drilling the other target sands on this well. The KCI concentration is dependent upon MWD and loaaina restrictions and could vary from this recommendation. Special Considerations 1. Waste minimization is critical to the success of this well. 2. Maintain a sufficient quantity of Driltreat (lecithin) to accomplish a 2 ppb treatment in the event gas hydrates are noted. 3. Lime and zinc carbonate should be on location for H2S contingency (@1 pallet No Sulf and 2 pallets lime). 4. Maintain an adequate barite supply (and other necessary products) to increase the mud weight of the current circulating volume by 1.5 ppg at any time (@2000 sxs barite on location at all times). 5. Due to the remote nature of this location, maintain an adequate supply of LCM and the other materials, which may be required to support this drilling program. . . Formation Tops/Casina Proaram TMD rvD Comments Mud Wt Spud 0' 0' 9.0 ppg density 9.0 Base Permafrost 1936' 1783' 9.0-10.0 Top West Sak 4155' 3483' String in LCM 9.0-10.0 Base West Sak 5637' 4618' Stop LCM treatment 9.0-10.0 95/8" casing point 5740' 4697' Condition for casing 9.0-10.0 L. Brookian 8059' 6473' 9.6-9.8 Top HRZ 8769' 7073' occasional shale instability 10.4 Kalubik 8822' 7123' occasional shale instability 10.4 Kuparuk 8961' 7253' String in LCM 10.4 Top LCU/Kingak 9099' 7383' shale instability 10.6 Top Nuiqsit 9525' 7783' occasional shale instability 10.6 Top Sag 10754' 8683' target sands 10.6 Top Shublik 10881' 8803' 10.6 Top Ivishak 111 05' 9053' String in LCM 10.6 TD 11211' 9368' Spot STEELSEAL 10.6 Suñace Hole Mud Pro Mud Density Pro erties Initial 35 - 45 13 - 21 10-15 Final 15 - 30 15 - 23 10-15 Surface Interval (12-1/4" Hole to 5.740' TMD) The surface interval will be drilled with a 12% KCI/Polymer mud as formulated below: 9.0 PPQ Formulation Fresh Water KCI EZ Mud DP PAC-LIR Barazan-D KOH Aldacide-G Baracor 700 Barascav D .95 bbl 37 ppb .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb 1.0 ppb .5 ppb (ionic inhibition/50.5K ppm chlorides) (polymer encapsulation) (API filtrate of 6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) (X-Cide 207 for rig maintenance) (corrosion inhibitor) (to be added at rig) Spud the well with maximum flow rates (600-750 gpm assuming 12-1/4 hole w/5" 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'ed 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. Once the angle has been built to 40°, weighted/high vis or Barolift sweeps can be utilized. . . With an initial mud density of 9.0 ppg, please note the other issues of concern as listed below: 1. Make sure all members of the drilling team are aware of the potential of encountering gas hydrates. 2. A mud weight of 9.6 ppg range is currently programmed for drilling the gas hydrate interval of the well, if encountered. 3. If gas hydrates are noted, treat the system with 2.0 ppb of Driltreat (Lecithin) and ~% by volume BDF-263. 4. Maintain the mud as cool as possible (~60°F). 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 for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface hole TD. 3. Hold the pH in the 8.5-9 range with KOH. 4. By material balance, maintain the EZ Mud DP in the .75-1.0 ppb range. 5. Control penetration rates based upon the ability of the surface system to process the drilling mud. 6. Daily additions of X-Cide 207 are needed to control bacterial action. 7. Corrosion inhibitors should be run with this mud system (1 ppb Baracor 700 / .5 ppb Barascav D). 8. Keep MBT as low as possible (generally <12 ppb). While drilling the Schrader Bluff sands, 2-3 ppb of Barofibre should be constantly strung into the system. This should seal the under pressured zone and prevent differential sticking and losses. Heavy amounts of clay may be present below the permafrost that could require additions of BDF-263 and/or ConDet 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, reduce the fluids rheology to <20 YP after the casing is on bottom prior to starting the cement job. Production Hole 8-1/2" Hole fIBase Surface Casin to Well TD at 11,211' TMD Mud Density YP PV 10 S. Gel API FL PH Pro erties cc's/30 min Initial 9.6 10-15 6-12 2-5 6-10 Final 10.4-10.6 15-25 15-25 2-6 <6 <10 THP 9-9.5 9-9.5 Production Interval (8-1/2" Hole to 11.211' TMD) Prior to drilling out the surface casing, condition the spud mud to a 9.6 ppg density with <4% LGS and an MBT of <6 ppb (a certain amount of new mud could be considered in terms of re- adjusting the properties of the mud to insure a quality fluid for the initial drill out below casing. . . As in the surface hole, 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 60,000- 90,000 ppm range so as to allow maximum application of centrifuge support to optimize solids control efforts. A minimum of 60,000 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 9.6 ppg with a YP in the 10 to 20 range and maintain until out of the sticky clays often found within this interval of the well. Then, adjust the YP as required with Sarazan-D polymer for efficient hole cleaning. If screen blinding from heavy clays is a problem, use SDF-263 and/or ConDet treatments. Regular sweeping of the hole with weighted/high viscosity or Sarolift sweeps is recommended every 4-6 hours while drilling to supplement the hole cleaning ability of the fluid. Flow rates in the 400 to 500 GPM range will provide ample flow to clean the hole. The 9.6 ppg density will be maintained down to :!:. 8700' (top HRZ) where the weight will be increased to 10.4 ppg with as much KCI as allowable and then barite for controlling the HRZ then to 10.6 ppg to control the Kingak shale at 9080'. While drilling to TD, maintain the API filtrate <6 with PAC's and Dextrid. The HTHP filtrate should be reduced to <10 with a 4-6 ppb Saranex addition prior to entering the HRZ at 8,700' TMD and maintained there until TD of the well. String in 2-3 ppb of Saracarb 50 while drilling the Kuparuk to help bridge/seal this zone. 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 MST as low as possible «8 ppb). Maintain Sarascav D and Saracor 700 specs to aggressively treat for corrosion. After circulating and short tripping at TD, 15-20 ppb of SteelSeal should be spotted from TD to above the Sag River sands. This product will help bridge micro fractures and does not dehydrate the drilling fluid therefore the fluid will remain thinner while logging, etc. Risks and Continaencies: Lost Circulation: Preventing the initiation of lost returns should be a primary goal of the drilling fluid in the well. To that end the rheology of the system has been reduced while still providing ample hole cleaning. Maintaining a low ECD while circulating, and eliminating high pressure spikes while tripping, will both go a long ways toward reducing the risk of lost returns. Should lost returns occur check with MWD personnel prior to pumping any pills to assure that no plugging will occur. This well is near Milne point so several of the zones may be under-pressured. LCM will be strung into the mud while drilling the Schrader Sluff, Kuparuk, and Sag River sands to help prevent losses and/ or differential sticking tendencies. Wellbore Instability: The HRZ and Kingak can be problematic. Ensure the mud weight is 10.4 ppg prior to entering the HRZ (as per the HRZ polar plot a minimum of 10.2 ppg is needed) and reduce the HTHP to less than 10 cc. The weight will then need increased to 10.6 ppg for the Kingak (as per the Kingak polar plot). Should any signs of shale splintering be seen immediately raise the mud weight a minimum of .4 ppg. Keep instantaneous surge/swab limited. Awareness by the rig crews as to the fragility of these shales to mechanical disturbance is of great importance. . . 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. Note: keep a pallet (8 drums) of "Pipe-Lax" on location at all times. Corrosion Mitigation Barascav D and Baracor 700 will be run in this fluid system to mitigate the 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 S shaped profile of this well it is likely lubes will be required. If so, it is recommended to add 2% of the lube cocktail (0.5% BDF-263, 1 % EZ Glide, 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 are essential to a 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 a weighted high viscosity sweeps in the pay sands. The returns at surface of all pills should be monitored at the shakers and documented to gauge their effectiveness. When circulating bottoms up prior to POH, it is advisable to pull one stand every half hour to reduce the hole washout effects of circulating over one short interval. Long circulation times should be avoided if the biUBHA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. Hiah speed pipe rotation is the most critical factor for hole cleanina. . . Product Usaae: The following represents an estimate of the quantities of products to be used on each interval. Product Surface Interval Production Interval Total Well Aldacide G Aquagel Baracor 700 Baradefoam Baranex Barascav 0 Barazan 0+ Barofibre Baroid Barolift Barotrol BDF-263 Bicarb Citric Acid Condet Dextrid EP Mudlube EZ Glide EZ Mud DP KCI KOH Mixing Charge Mud Lab PAC-L SAPP Soda Ash Tech Serv Therma Thin X-Cide 207 7 1 28 2 o 30 120 30 100 8 o 8 20 10 6 65 o 8 170 2900 18 600 8 75 10 15 16 20 28 8 o 34 2 110 28 98 30 350 7 60 12 10 8 4 88 10 20 80 2800 22 600 14 64 6 5 28 14 30 15 1 62 4 110 58 218 60 450 15 60 20 30 18 10 153 10 28 250 5700 40 1200 22 139 16 20 44 34 58 '. . @ KERR-MCBEE CORPORATION NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA OptiC em 9 5/8" Cement Surface Casing Revision #1 Prepared for: Skip Coyner February 17, 2004 Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . ~ KEIlR-MCGEE CORPORAnl1ll NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1 ) Well Conditions Casing Size & Wt. Hole Size MD TVD Top of Lead (MD) 9 5/8" 40#/ft 12 114" 5,740' 4,697' 0' Volume Excess Mud Wt. BHST BHCT Previous Casing Depth 225% 130% 9.5 ppg 90°F 80°F 200' Slurry Recommendation: Pre flush I Spacer 10 bbl Water, 75 bb11O.5 ppg NSCI Spacer Lead Slurry: 670 Sks. (2,779 Ft3) PERMAFROST L (495 bbl) (115 bbl) (429 bbl) Tail Slurry: 560 Sks. (645 Fe) Premium Cement, 1 % Calcium Chloride Displacement: 429 bbls. Mud Density (ppg) Yield (cu ft I sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Svacer 8.34 I 10.5 Lead Slurry 10.7 4.15 20.3 Tail Slurry 15.8 1.15 5.00 6:00+ 3:30 (48 Hr.) 25 1650 (72Hr.) 260 1800 Volumes based on: Lead slurry: Tail slurry: Top of Lead cement @ Surface 200 feet 13-3/8" 61 #/ft cased hole + 0% excess, 1750 ft of open hole + 225% excess through base of permafrost at 1950 ft MD plus 3790 ft open hole below permafrost + 30% excess. Top of Tail slurry 1500 feet above shoe - TOC 4,240' 1500' calculated annulus volume +30% excess + 80 ft shoe joint. HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . ~ KERII-Mt:6EE CORPORATION NW Milne Point Exploration Project 2004 Cementing Services (Revision # I) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA OptiC em 9 5/8" Surface Casing - Top Job Contingency Revision #1 Prepared for: Skip Coyner February 17, 2004 Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . ~ KERR-MCBEE CORPORATlOII NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1) Top Job Contin!!encv Mix & pump PeI1llafrost L via DP thru the port collar tool at 500 ft until it reaches surface & then displace with mud. Well Conditions Casing Size & Wt. Port Collar Depth Hole Size TVD Drill Pipe: Previous Casing Size Previous Casing Depth 9 5/8" 40#/ft 500' MD 12 114" 4,697' 3.5" l3.30#/ft 13-3/8" 61 #/ft 200' Volume Excess BHST BHCT Mud Wt. 225% 60°F 40°F 9.5 ppg Slurry Recommendation: Preßush I Spacer 10 bbl Water Cement Slurry: 90 Sks. (374 Fe) PERMAFROST L (67 bbl) (3.7 bbl) Displacement: 3.7 bbls. Mud Density (ppg) Yield (cu ft 1 sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Tail Slurrv 10.7 4.15 20.3 6:00+ (48 Hr.) 25 (72Hr.) 260 Volumes based on: Lead slurry: Top of Lead cement @ Surface 200 feet 13-3/8" 61 #/ft cased hole + 0% excess, 1750 ft of open hole + 225% excess through base of peI1llafrost at 1950 ft MD plus 3750 ft open hole below peI1llafrost + 30% excess. Top of Tail slurry 1500 feet above shoe - TOC 4,240' 1500' calculated annulus volume +30% excess + 80 ft shoe joint. Tail slurry: HALLIBURTON ISO 14001 Certified Alaska Green Star Certified · e @ KERR-MCBEE CORPORATION NW Milne Point Exploration Project 2004 Cementing Services (Revision # I ) Kerr-McGee Corporation Nikaitchuq #2 Alaska; USA 8 ~" Open Hole Cement Abandonment Plugs Revision #1 Prepared for: Skip Coyner February 17,2004 Prepared by: Rafael Hernández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 HALLIBURTON ISO 14001 Certified Alaska Green Star Certified · e @ KERR-MCBEE CDIIPORATlOII NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1 ) Cement Sidetrack & Abandonment Plugs Assumptions for cement plugs: Plug #1 (Sidetrack plug) P&A plug length: 1000 ft MD with bottom of plug at 11211 ft MD to 10211 ft MD. Plug #2 (After coring Sag River) P&A plug length: 1100 ft MD with bottom of plug at 11211 ft MD to 10111 ft MD. Plug #3 (After coring Sag River) P&A plug length: 1100 ft MD with bottom of plug at 10111 ft MD to 9011 ft MD. Plug #4 (After coring Sag River) P&A plug length: 1100 ft MD with bottom of plug at 9011 ft MD to 7911 ft MD. Plug #5 (Surface Casing Shoe) P&A plug(s) length: +or- 320 ft (MD) with approx. 160 ft below casing shoe and 90 ft inside bottom of surface casing and 70 ft above 9 5/8" EZSV packer Plug #6 (Surface Abandonment Plug) P&A plug(s) length: +or-270 ft MD with top of cement at Surface HALLIBURTON ISO 14001 Certified Alaska Green Star Certified · e @s KERR-MCSEE CORPORAßOII NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1) Abandonment Cement Recommendation (PIll!! #1) Recommendation: PreOush I Spacer: 10 bbl Water, Plug Slurry: 80 bbls - 390 Sks. (450 Fe) Premium Cement + 0.2% CFR-3, (Friction Reducer), + 0.3% Halad-344 (Fluid Loss Additive), + est. 0.2% HR-5 (Retarder) as required Density (ppg) Yield (cu ft / sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) PIUf! Slurrv 15.8 1.15 5.00 <100 o +/- 3:00 >1,300 @ 190°F >2,400 @ 190°F Volume based on: Plug Slurry: 1000 ft of 8 Yz" Open hole + 15 % excess HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . @ KERR-MCGEE CORPORATlOII NW Milne Point Exploration Project 2004 Cementing Services (Revision # I ) Abandonment Cement Recommendation (PIll!! #2. PIll!!#3. PIll!! #4) Recommendation: Preflush I Spacer: 10 bbl Water, Plug Slurry: 89 bbls - 435 Sks. (500 Ft3) Premium Cement + 0.2% CFR-3, (Friction Reducer), + 0.3% Halad-344 (Fluid Loss Additive), + est. 0.2% HR-5 (Retarder) as required 3 plugs: 267 bbls - 1305 sxs Density (ppg) Yield (cu ft / sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Plue Slurrv 15.8 1.15 5.00 <100 o +/- 3:00 >1,300 @ 190°F >2,400 @ 190°F Volume based on: Plug Slurry: Each: 1100 ft of 8 Yz" Open hole + 15 % excess HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . @ KERR-MCBEE CORPORATlOII NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1 ) Abandonment Cement Recommendation Surface Casin!! Shoe (Plu!! #5) Recommendation: Preflush I Spacer: 10 bbl Water, Plug Slurry: 25 bbls - 122 Sks. (140 Ft3) Premium Cement + 1 % Calcium Chloride Density (ppg) Yield (cu ft 1 sk) Water requirements (gaVsk) Fluid Loss (cc/30 min.) PluJ! Slurrv 15.8 1.15 5.00 >250 o +1- 3:00 Free Water % Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) > 1,300 @ 80°F >2,400 @ 80 of Volume based on: Plug Sluny: 160 ft of 8 Yz" Open hole + 15% excess plus 90 ft of 95/8" "40#/ft Casing + 70 ft on top of EZSV packer + 0% excess (TOP: 5580 ft MD) HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . @ KERR-MCGEE ClJRPDRATlBN NW Milne Point Exploration Project 2004 Cementing Services (Revision # 1) Abandonment Cement Recommendation Surface (Plu!! #6) Recommendation: Preflush I Spacer: Plug Slurry: 10 bbl Water, 20.5 bbls -120 Sks. (115 Ft3) Type C Permafrost Density (ppg) Yield (cu ft 1 sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) Plu!! Slurrv 15.6 .99 3.75 >250 +1- 2:30 >500 @ 40°F >1,150@40°F Volume based on: Plug Sluny: 270 ft of9 5/8" 40#/FT Casing+ 0% excess HALLIBURTON ISO 14001 Certified Alaska Green Star Certified . . WELL SITE SURVEY SHALLOW DRILLING HAZARDS EVALUATION PROPOSED NIKAITCHUQ #2 ALASKA STATE LEASE 355021 SPY ISLAND, ALASKA Summary Pursuant to 20 AAC 25.061 all available CDP geophysical, velocity, and proximal well data have . been examined and evaluated for shallow to intermediate depth drilling hazards. Data from offset wells suggest that natural gas hydrates are likely~to be encountered in sands and gravels of the Sagavanirktok Formation (600 to 2200' TVD). Our well plan is designed with this potential hazard in mind. The Nikaitchuq #2 well will be drilled ITom an ice pad located approximately 4.0 miles northeast of Oliktok Point on Spy Island. The proposed surface hole location will be 2240' SNL & 1290' WEL of Section 22, Township 14 North by Range 9 East (6054984.32' North Latitude by 519667.62' East Longitude NAD27, Zone4). The associated bottom hole location will be 2516 SNL & 1142' EWL of section 14, Township 14 North by Range 9 East (6057227.50' North latitude by 529871.15' East Longitude NAD 27, Zone 4). /' .) ~: . Geology Throughout Quaternary and possibly late Tertiary time sedimentation in this region has been dominated by the Colville River Delta. Spy Island, the location of the proposed drillsite, is part of the Jones Island chain. These islands are the last reworked remnants of the drowned Pleistocene coastal plain. Superficial sediments include coarse sand, gravel, and boulder lag depositS of Quaternary age. The underlying Pleistocene section, referred to onshore as the Gubik Formation, consists of channelized marine and nonmarine muds, sands, gravels, and low grade coals. Locally the entire Quaternary sequence is less than 900'thick. Underlying the Gubik Formation is the Sagavanirktok Formation, which ranges in age ITom Upper Cretaceous through Tertiary. The Sagavanirktok Formation consists of complexly interbedded marine and nonmarine shelf and delta plain deposits composed of unconsolidated sand, shale, and conglomerate. Locally the Sagavanirktok Formation is approximately 2,000' thick and gently dips to the northeast at 10 to 20. The Colville Group lies conformably below the Sagavanirktok Formation. Deposition of the Colville Group spans the interval of time between the Late Cretaceous through Lower Tertiary . This group is comprised of three formations in the prospect area. From youngest to oldest they are the Ugnu Formation, West SakFormation, and the Colville Mudstone. Sandstones of the West Sak and Ugnu formations, locally in excess of2200' gross thickness, contain significant reserves of heavy oil in the ne~by Milne Point ~d Kuparuk units. However, / there are no hydrocarbon indicators in wells proximal to the Nikaitchuq location. Consequently, these formations are not anticipated to be hydrocarbon-bearing within the prospect area. } . . Geophysics A BP acquired 3-D OBC seismic grid covering the proposed Nikaitchuq #2 well location was analyzed for potential shallow and intermediate depth drilling hazards (see enclosed seismic/well base map). These same data were correlated with all publicly available shallow hole log data to produce an integrated shallow hazards assessment for the Nikaitchuq #2. Specifically as part of this analysis correlations have been made with the Conoco Northwest Milne #1, BP MPU #F-33, MPU F-33a, MPU F-85, MPU F-79, MPU F-10 and MPU F-42 which are within the same structural fault segment and directly offset the Nikaitchuq #2 location. Illustrated inline 244, crossline 169 (both intersect the Nikaitchuq #2) and arbitrary line 1 that parallels the Nikaitchuq #2 wellbore path are enclosed for your reference. A Nikaitchuq #2 interval velocity/pressure profile exhibit, constructed by integrating all available offset logs, subsurface pressures and seismic data is also attached for reference. Potential Shallow Drilling Hazards ) Permafrost Seismic reflection data in proximity to the Nikaitchuq #2 well show a unique response to the laterally varying permafrost thickness in the near subsurface from the mainland and across Harrison Bay. This response is manifested by high quality reflection continuity onshore where permafrost thickness is at a maximum, in contrast to the shallow offshore areas of Harrison Bay where reflection quality degrades due to permafrost thinning. The thinning offshore is caused by the influx of relatively warm sea water since the latest Holocene sea level transgression. Resultant permafrost thinning within Harrison Bay has been recorded to as little as 210' in the Northwest Milne #1 well. The velocity effect seen in the seismic data is a pronounced broad "push-down" of reflection time roughly parallel to the coastline, which progressively increases moving away from land. Conversely seismic reflections show a uniform "pull-up" directly beneath the shoreline indicating permafrost thickening as you move back onshore, as evidenced by the 1850' thick permafrost layer in the MPU F-30 and F-70 wells. The Exxon Thetis # 1 well, located 7 miles west of the Nikaitchuq #2 location, serves as a good analog. The surface location of the Thetis well, like the Nikaitchuq wells, occurs on a low-relief barrier island. Permafrost in the Thetis well was approximately 450' thick. Interpretation of all available seismic and well log data translates to an expected permafrost thickness of 400' and an .". anticipated permafrost base at the Nikaitchuq #2 location of approximately 370' subsea. Shallow Gas/Oil Accumulations There is no geophysical or geological evidence for any significant accumulation of shallow gas ./ beneath the Nikaitchuq #2 location. No amplitude anomalies, velocity sag or frequency attenuation indicators are present from 3-D seismic covering the location. Mudlogs and open hole logs from offset wells show no evidence of natural gas trapped below the permafrost in the - sands or gravels of the Sagavanirktok Formation, though such a phenomenon occurs in the Milne Pdint Field updip to the south. There is some chance of penetrating several natural gas hydrate zones in the sands of the U gnu Formation. Gas hydrates were detected in the Exxon Thetis #1 well (1050 to 1550' TVDss). These highly resistive zones are easily correlated on openhole logs into the Nikaitchuq prospect v area. . . No drilling hazards associated with shallow gas or natural gas hydrates are anticipated in the / operations of the proposed wells. Specifically, the Conoco Northwest Milne #1 and MPU F-79, MPU F-90 and MPU F-42 were all drilled and did not encounter any significant amo~ts of gas or experienced any notable drilling operational issues associated with shallow gas. In addition to the offset well data, there are no other geophysical velocity indicators of any shallow ftee gas v beneath the well or any faulting interpreted to extend into the shallow sedimentary section that could create any significant migration pathways for minor shallow gas/hydrates accumulations below the base of permaftost. Regardless, minor elevated background gas levels within and ./ immediately below the permaftost interval are being planned for in the proposed Nikaitchuq #2 well. The composite Ugnu-West Sak interval is present in the MPU F-30 (2412 to 8880' MD, -2264 to -4554' TVDss), and the Northwest Milne #1 (2910 to 6538' MD, -2327 to-4461 'subsea). Minor background gas and no oil shows are seen in association with these sands. This is consistent with the known limit ofUgnu and West Sak oil-bearing sands located to the southeast in the Kuparuk River Unit. This interval is anticipated to occur at a depth ranging ftom approximately -2300 to - 4500' subsea in the Nikaitchuq #2 well. Any sands present will most likely be water-bearing or v contain only minor accumulations of solution gas. The previously referenced vertical pressure profile, which incorporates all pertinent engineering, geological and geophysical data, served as the basis for design and development of all operational and safety plans for the Nikaitchuq #2 well. \) Summary We have not identified ftom seismic or offset well data any conditions beneath the Nikaitchuq #2 location which could pose a prohibitive shallow or intermediate depth drilling hazard to the planned drilling operations. Natural gas hydrates are likely in t1).e sands and gravels of the v Sagavanirktok Formation (600 to 2200' TVDss),and the drilling plan has been adjusted accordingly. A copy of all pertinent data to shallow geological and drilling safety conditions has been supplied to operations and engineering personnel in the preparation of the Nikaitchuq #2 well design and operational plan. · . Well Site Survey Abnormal Formation Pressure Evaluation State Lease ADL 355021 WELL SITE SURVEY ABNORMAL FORMATION PRESSURE EVALUATION NIKAITCHUQ # 2 LOCATION ALASKA STATE LEASE ADL 355021 SPY ISLAND, ALASKA Pursuant to 20AAC 25.033 (e) (1) available geophysical data and proximal offset well data to the Nikaitchuq #2 (surface hole location is 2240' SNL & 1290' WEL of Section 22, Township 14 North by Range 9 East /6054984.32' North Latitude by 519667.62' East Longitude NAD27, Zone4, and the associated bottom hole location will be 2516 SNL & 1142~ EWL of section 14, Township 14 North by Range 9 East! 6057227.50' North latitude by 529871.15' East Longitude NAD 27, Zone 4) have been examined and evaluated for potentially overpressured strata. Examination and interpretation of these data suggest that formation pore pressure increases at a normal gradient with depth and abnormal formation pressure is not anticipated to the proposed total depth of9335 ft SSTVD. Reference is hereby made to the proposed Nikaitchuq #2 seismic/well base map and several seismic interval velocity exhibits previously submitted to the DNR Oil and Gas Conservation Commission in February, 2004. A seismic/well base map highlighting the area of 3-D coverage, 2'-D coverage, key seismic transects, key offset wells and the Nikaitchuq #2 well location is included for reference. Also included is a pressure versus depth plot generated for the Nikaitchuq #2 from available geologic, petrophysical, engineering and geophysical information. The plot depicts increasing formation pressure along the "x" axis versus true vertical depth on the "y" axis. Examination of all available velocity, density and pressure data show a general increase of interval velocity and pressure with depth to the limit of penetrated formations below 9800 ft within the area. Minimal discrete velocity reductions on an overall increasing trend are observed in the data, with a slight "breakback" in velocities at the top of the Lower Brookian through the Triassic section. This section has been penetrated in numerous offset wells within the same fault compartment, the "breakback" has been shown to be caused by local variations in formation density, fluid density, velocity, and lithology. Based on our analysis of the formations to be " penetrated by the Nikaitchuq #2, no overpressure is anticipated above the proposed total depth of ..I 9335 ft SSTVD. . This overpressure evaluation is supported by all available geophysical and petrophysical data. Those wells considered key offsets for well planning purposes are highlighted on the aforementioned seismic/well base map. Of all the key offset exploration and production wells, the BP NW Milne #1, the BP Milne #1, the BP Milne #2, the BP MPU F-33, F33a, F73 were considered the best and most representative wells in constraining our analysis. The total depth of these wells ranged from 7416 ft to 9189 ft TVD. All six of these wells were drilled with maximum mud weights ranging from 9.9 ppg to lOA ppg. As it is general practice to drill slightly overbalanced, in situ pore pressures are likely less than there observed mud weights. 1 : .\ ~~-J . Well Site Survey Abnormal Formation Pressure Evaluation State Lease ADL 355021 . In summary, abnormal formation pressure is not anticipated beneath the proposed Nikaitchuq #2 well location. All operations and engineering personnel have been advised of the anticipated geological drilling conditions. .X. Furi Vice President of Geoscience Armstrong Oil & Gas February 17,2004 2 . AK 99501 COMMISION ,,- ¡ ¡ I, 3 2 ? ,,- I: ¡ 2 5 2000 5 ? I: 3? II. ? B 2 ? ¡ ¡ ,,_ . RECEI FEB 2'3 2004 Alaska 011 E. Gas Com; Aochoragf:i . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,// 'k<'-//cL«f} 2- PTD# 2D t/ ~ 038 Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) BOLE // SPACING EXCEPTION /. . V .' DRY DITCH SAMPLE ~ploration Stratigraphic ~'CLUEn Tbe permit is for a new we1Jbore segment of existing well, . Permit No, . API No. Production sbould continue to be reported as a function· of tbe original API number. stated above. In accordance witb 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated In botb nl\me ("jD~ on permit plus PH) ,AA/ici.u añõ¡vf API number (50'(o-¿c¡- 3f'l7-7ð rom records, data and logs acquired c.4t. ~ well(...e 8B ~c)~1t~., bor<L. dr:11< ~ CP'r/n ~,. e permit is a prov subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate 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 that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater tbaD 30' sample intervals from below the permafrost or from wbere samples are first caught and 10' sample intervals through target zones. PTD#: 2040380 Administration Well bore seg Annular Disposal Appr e Engineering Appr Date ~ _ .~./2~/2004 !ftM ?tJ,,\ ·?¡t S Geology Appr SFD Date 2/24/2004 Geologic Commissioner: ú)~ Date 3/5/2004 Field & Pool Well Name: NIKAITCHUQ 2 Company KERR-MCGEE OIL & GAS CORP Initial ClasslType EXP / PEND GeoArea 973 Unit 1 Pe(mitfe~ attached. . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . 2 .Lease numb~r apprOPJiate. . . . . . . . . . . . . . . . . . . . . . . Yes. . . Well lies withilJ 6P Lease ADL035502; Des.ignatio.n.of Operatorform.need~d, Received 3/5/04.SfD. 3 .U.ni~l,Je well.n.ame .a[1C;! lJu.mber . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . .Yes . . . . . . . Exp[ora.tory welUoc.ated wjthilJ the .affecte_d.are.a.ofthe MjllJ~ Point jJnit, Kuparl,Jk. Riv~r Oil Pool.(CQ ~32.B).. . . . . 4 WeJIJocatedin.ad.efinedpool........ ........................... YesPrimarytar~ets.are.SagRjve[andlllÍs.ha~... ........... 5 WeJI Jocated prop~r dista[lcefrom driJli[lQ I,Jnitbpl,Jndal"Y. . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 WeJI Jo.cated prpper dista[lce.from otheJ wells. . . . . . . . . . . . . Yes .............. . . . . . . . . . . . . . . . . . . . . . . . . . . .. .................. 7 .Sufficient acreage.ayailable lndrilJiog unit. . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.deviated, jsweJlboJe platJncluded . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Operator onl}' affected party. . . . . . . . . . . . . . . . . . Yes . . 3/5/04: Receiyed.d.esigna.tion ofoperator.forrn.sJrom.Kerr~McGee.. Sf 0 . . . . . . . . . . . . . . . . . . 10 Operator has.approprlate.b.o[ld in force. . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . 11 Pe(mitca[l Þe issu.ed without cons~r\{ation order. . . . . . . . . . . Yes. . . . . . . . . . .. ........................................ 12 Permitca[l Þe iJ>sued without adminis.tr.atille.approvaJ . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . 13 Can permit be approved before 15-day wait Yes 14 WeJIJocatedwi.thinareaan.d.strataauthorizedbY.llJjectioIJOrder#(puUO#lncommeots).(For. NA............... ................................... ............... 15 All wells.witþin .1l4.llJile.are.a.of review ideotlfied (fo(s.ervicewelJ onl}'). . . . . . . . . . . . . . . .NA . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre.-produced.i[ljector; duration.ofpre-productionless.tÞan.3.months.(For.seryicewelIon!y). . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ........ 17 ACMP.Fjndingot ConJ>iste[lcy.has beenis.sl,Jedfor.this prpiect . . . . . . . Yes. . . . . . . KayeLaughJilJ,JPO. Nlkaitchuq explpration.project was. de.termined to.be consistent withACMP~ . . . . . . . . . o o Program EXP On/Off Shore Off - - - - - - - - - - - - - - -- - - - - - - -- - - - - - - - - - - .. 18 .Gpoductpr s.t(in~provided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .Sur:faq:¡cas.ing.pJotec.ts.all.k[lownUSOWs.. ...... ............ NA.... .Allaquifers.exempted.AO.CFR147.102{b)(3)......... ............ 20CMTvola.dequate.to Circulate on cOnductor. & S.UJf.csg. ............ . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21 .CMTvoladequate.to ti~-inJong J>tri[lg to.SI,Jr:f CS-9. . . . . . . . . . . . . . . . . . . . . . . . . . . . N.o. . . . . . . . No production.casilJg is plalJn.ed.. P(oposaUs to.drilJ, .core.a[ld aba[ldon. . 22 .CMT.wil[ coyer.all klJown P[o~l,JctiYe horilonJ> . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . Surf.ac~ ceme[lt will coverpote[ltiaJ West.S.aklS6 J>ands. PM plugs. will cover any hydro.carÞons.in 6-'112" hoJe. . 23 .Gasiog de.sig[ls. adequa.t~ fo( C,.T, 6.&.perllJafrost. . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . .. ...... . . . . . . . . . . . . . . . . . 24 Adequatetan.kage.oJre.servepit..................................... Yes. . .Rigis.e~uippe.d.withsteelpits...No.reseJV.e.pjtp[a[lI1ed. WaJ>te.toan.approYed.dis.posaJwelt.... 25 Jf.a.re-d(iII, has a tOc4.03 fOJ aba.ndonme[lt beelJ approved. . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Adequate w.eUbore. s.eparation propos.ed. . . . _ . _ . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . _ . . . _ . . . . . . . . . . . . . . . _ _ . . . . . 27 Jf.diver:t~r r~quired, does it meetreguJa.tions . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 28 DrilJiog fluid.pJogram sc.hematlc.&. ~quip Jist.adequate . . . . . . . . . . . . . . . . . .. .... Yes. ..... Max. ~xpectedBHP9.8 EMW.i1J multiple fO(llJatioos~ PJa.n[led. MW 10.'4-11.0 ppg from 95.00'Jo TO. 29 .BOPEs,do .they meet reg uJa.tio n . . . . . . . . . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 30 ßOPEpre.ss ratiog approp(iate; .t~st to.(pu.t ps.ig in.comments.). . . . . . . Yes. . . . . . . M,ð,SP calcu[atedat 33.67 psi.. Pla[l isJo tesUo 500.0 psi, . . . . . . . .. ........... 31 .Ghokemanifold compJies. w/,ð,E'LRF'-53. (May 84). . . . . . . . . . . . . . . . . . . . .... . . Yes ....... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WOJk will OCcU( without.operatlonsbutdown . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 Js.prese[lceoJH2Sgas.prob.aÞle ...................... No. . Mud s.hould preclude.H2.S.on.the.rig, Rjgisequjppedwithse[ls.ors.and.alarms..... ............ 34 Meçhanical.colJdjtio[l of weJls within ,ð,QR verified. (for.service well onJy) . . . . . NA . . . . . . . . .. ................ . . . . . . . . . . . . . . . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - . 35 Pe(mit Ca[l Þe iJ>$ued wlo. hydrogen.s.uIJide measuœs. . . . . . . . 36 .Datapr~selJted on. potential O\lerr:~ressure .zon.es. . . . 37 Seismlc.a[lalysisoJ shaJlow gas.zolJ~s . . . . . . . . . 38 .Seabed conditiolJ survey (it off-s.hoœ) . . . . . . . . . . . . . . . . . . . 39 . Co.ntaçt name/p!1Qn.eJorwee~ly progres.sreports [e1<ploratol"Y .0 [l Iy] . . . . . . . . . .......... ...... N.o. . . . . . . . . . Yes . Yes. . NA Yes . . . . Cur(e[ltly, the neares.t Sag-Ivisba.kpeo~tratio.n.is. 7. miles.away.. . . . . . . . . . . AbnorrnaJ pres.su(e.is. 00.1 expected. . Well. wilJ be. mudJogged from base ofpermafrpsUo TO. . . . . . Gas. hydrates expected fJom 600' -.2700' JVDss; [lO evide[lce. of aIJY. otheJ shaJlow hazards.. . . . . . . . . . . N/A; well is Þeiog driJled from lJaturally.occurring offshore isJand.. . . . . . . . . . . . . . . . . . . . . . . . . Skip COY[ler, 907~3;39-626.9, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - - - - - - - - - - - - Engineering Commissioner: Date Ó/¢:ðf Date e e 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 information, 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. A I:ore lab RESERVOIR OPTIMIZATION Core Analysis Data FINAL REPORT ~6 ""~' '" ') t for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska FILE NO.: HOU-040292 July 30,2004 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 refiect the examina- tion. study and testing of these items, and represent the best judgement 01 Core Laboratories, LP. AJlY 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. Core Petrophysics 6316 Windfern Houston, TX 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 A [ore Lab RESERVOIR OfTll1lZATlON Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Table of Contents July 30, 2004 Discussion ... .................................... ......... ............... ........................... ......... .Page(s) i - iv Data Tables Routine Core Analvsis Prooram CMS-300 Core Analysis Data (1.0" Diameter Samples) .................. ...... ..Page(s) 1-9 CMS-300 Core Analysis Saturations (1.0" Diameter Samples) .................Page(s) 10-18 CMS-300 Core Analysis Data (1.5" Diameter Samples) ..........................Page(s) 19-21 Analysis Protocol ........................................................................... .Page( s) 22 Description & Lamination Key............ ........................... ......... ..........Page(s) 23 Explanation of CMS-300 Terms ..........................................;.............. page( s) 24 Figures Appendix I Appendix II Appendix III Appendix IV CD-ROM Routine Core Analvsis Prooram Permeability vs Porosity @ 2500 psig NCS (Composite) ...................... ..Figure 1 Permeability vs Porosity @ 2500 psig NCS (1.0" Diameter Samples) .......Figure 2 Permeability vs Porosity @ 2500 psig NCS (1.5" Diameter Samples) ....... Figure 3 Permeability vs Porosity @ Various NCS (1.0" Diameter Samples) .......... Figure 4 Permeability vs Porosity @ Various NCS (1.5" Diameter Samples) ..........Figure 5 Permeability vs Stw (2500 psig NCS) ...................................................Figure 6 Permeability vs Grain Density (2500 psig NCS) ....................................Figure 7 Spectral Gamma Plot (10350 ft -10500 ft) ...........................................Figure 8 Depth Plot (10350 ft - 10500 ft) ..........................................................Figure 9 Profile Permeability - 5" Scale (10350 ft - 10500 ft) ............................... .Figure 10 Statistical Histograms (2500 psig NCS) .............................................. .Figure 11 Core Sample Log ........................................................................... Page( s) 1 - 9 Qualitative Spontaneous I mibibition Study ........................................... Page( s) 1 - 9 Statistical Averages............................................. ......... ......... ... ...... Page(s) 1 Final Report Distribution '.' ......... ... ...... .._ ...... ... ... ... ... ... ... ... ... ... ... ... ... Page(s) 1 Contains all core analysis data (graphical & tabular) TI1is report is based entirely upon core samplGs, soils. solids, liquids, or gases, together with related obseNational data,provided solGly by the client. The conclusions. inferences. deduciions and opinions rendered herein reneet the examina- tion, study and testing of these items, and represent the best judgement of Core Laboratones, 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 tile client. and Core Laboratories, LP, neither extends nor makes any warranty or representation whatseever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Core Petrophysics · 6316 Windfern · Houston, TX 77040 USA · Tel: 713-328-2565 · Fax: 713-328-2567 A [ore Lab RESERVOIR OPTIMIZATION CONVENTIONALCOREANALYSŒ for Kerr-McGee Oil & Gas Corporation Nikaitchuq 02 Well NW Milne Point Alaska Report No. HOU-040292 August 18, 2004 I I I I I I I I Portions of the laboratory core processing and measurements discussed herein were performed by Core Laboratories, Houston, Texas under the direction of Robert Skopec of Petrophysical Applications, Inc., The Woodlands, Texas. Well site Coring operations recovered 90.9 feet of four-inch diameter conventional core from the subject well ranging from 10390.00 to 10480.90 feet. Upon surfacing and inspection, the recovered core was immediately inventoried, marked and stabilized. The 30-ft inner barrels were cut into 3-foot sections, sealed with rubber caps and duct tape and placed into insulated wooden crates for transport back to Houston. All of the core material was then shipped to Core Laboratories in Houston, Texas for analysis. Core Analvsis Upon arrival (March 28, 2004), the core material was inventoried and a total gamma radiation log was produced. A spectral core gamma was also run over the same interval. Both sets of gamma data are included on the CD-ROM located at the back of this report. The core was then removed from the inner barrels, cleaned of drilling mud, measured and marked. Upon completion of labeling, the core was then slabbed into % - % sections using a . low vibration radial saw. Visible and UV light source photographs were taken in Y2 scale format of each % section (the final core photography report was issued under separate cover - FHe No.: HOU-040292A). A total of 91, 1.0" diameter routine samples were acquired using a 6% simulated KCI brine as the bit lubricant. The plugs were taken statistically every foot and placed into Dean Stark equipment immediately to facilitate measurement of water & oil saturations. This report is based entirely upon core samples, soils, solids. liquids, or gasos. 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 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 whatsoevor with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. Core Petrophysics · 6316 Windfern · Houston, TX 77040 USA · Tel: 713-328-2565 · Fax: 713-328-2567 I I I I I I I I I I I I I I I I I A subset of nine (9) samples was selected for a Pilot Study to determine the impact of routine core analysis methods on data quality. These samples were CT scanned prior to initiation of analytical processing. To date, the Pilot Study is still ongoing and will be reported under separate cover. Twenty-six (26) pairs of vertical samples were acquired to provide vertical permeability data. 1.0" diameter samples, designated as "BV", were selected to be included as part of the routine data set and 1.5" diameter samples designated as "CV" were stored in a "chiller" to be used for possible future tests. A subset of 1.5" diameter horizontal samples, designated as "CH" & "DH", were acquired adjacent to the 1.0" diameter routine samples in reservoir quality intervals. A total of seventy- eight (78) "CH" & sixty-eight (68) "DH" samples were recovered and stored in a "chiller" for future use. Appendix I contains the list of all samples including the plug type, quality, and status. The samples selected for routine analysis were placed in thimbles for Dean Stark distillation extraction using toluene to recover the total pore water and to initiate hydrocarbon extraction. Upon stabilization of water collection via Dean Stark, the plugs were then transferred to Soxhlet extractors cycling between chloroform/methanol azeotrope and methanol to facilitate oil extraction and remove salts. Hydrocarbon extraction is considered complete upon cessation of discoloration and fluorescence of effluent being used for extraction. Silver nitrate is used as an indicator to test for the presence of salt during methanol batch extraction. A negative test indicates the absence of salt. Seven (7) weeks were required to thoroughly extract samples of hydrocarbons and salt. Upon completion of salt extraction, the samples were then vacuum dried at 1050 C until weight equilibrium was achieved. This drying technique allows for the measurement of total porosity. Permeability and porosity values were measured at reservoir net effective stress (2500 psig) as instructed by representatives of Kerr-McGee Oil & Gas Corporation. Per,meability and porosity measurements at four (4) additional confining pressures (1000, 1750, 3250, & 4000 psig) were made on a subset of samples. Grain volumes were determined at ambient conditions using the Boyle's Law double-cell technique with helium as the expansion gas (API RP-40, See 5.3.2.1). Pore volumes were determined at indicated net confining stress (NCS) using the CMS-300 core measurement system utilizing the Boyle's Law double-cell technique (API RP-40, See 5.3.2.2). Porosity at each confining stress is calculated by the following equation: 11 I I I I I I I I I I _J I I I I I I I I Porosity = Pore Volume I {Pore Volume + Grain Volume} X 100 Klinkenberg permeability was measured at each indicated net confining stress (NCS) using the unsteady-state method in the CMS-300 measurement system. The results of the plug analyses are presented in tabular format on pages 1 - 24 of this report. Graphical presentations of Permeability vs. Porosity, histograms of permeability and porosity, and depth plots of gamma ray, permeability, porosity and grain density are included in the Figures section. Saturations were determined using a brine saturation of 50000 ppm TDS and an oil density of 0.816 glee. Profile Permeabilitv Unsteady-state profile permeability measurements were made on the entire cored interval at a frequency of ten (10) measurements per foot. Nine hundred one (901) total measurements were performed to characterize core heterogeneity. The results of these measurements are represented in Figure 10. Spontaneous Imbibition Study Immediately following photography of selected % slabs, a qualitative spontaneous imbibition study was performed, employing synthetic formation brine (35000 ppm TDS) and lab oil (420 API) as test fluids, in order to determine the relative wettability of the core material. The results of these analyses should be considered qualitative at best (illustrated ,in Appendix II of this report). Geology A number of geological tests, including XRD, SEM & thin sections description, were performed on selected samples over the cored interval. These data have been reported under separate cover (File No.: BR-040412-2). Special Core Analysis A number of special core analysis tests are currently underway. The special core analysis will be reported under separate cover (File No.: HOU-040292). Rock Mechanics A number of rock mechanics tests are currently being performed and will be issued under separate cover (File No.: HOU-040292). Thirteen (13) copies of this report have been prepared for Kerr-McGee Oil & Gas Corporation et al. The final report distribution can be found in Appendix IV of this report·. The contents of this ll1 I I I I I I I I I I I I I I I I I I I report, the CT scans, and the core photography is presented on the CD ROM located at the back of this report. We sincerely appreciate the opportunity to provide these data to Kerr-McGee Oil & Gas Corporation. £Q~J ---. Russ Peacher Core Laboratories Houston A TC Laboratory Supervisor July 30, 2004 References 1. "Recommended Practices for Core Analysis", RP 40, Second Edition, American Petroleum Institute, February 1998. IV A I:ore LaIÎ RESERVOIR OPTIHIZATIOK CMS-300 CORE ANALYSIS DATA 1.0" Diameter Samples for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: May 21, 2004 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 Petrophysics, Inc. 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 Petrophysics, Inc., 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. CORE PETROPHYSICS 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 - ---. ~ .- - ~ -...., - ----. ~ ~ ~ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21,2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Core Lab ntJDUlIII StllVIUS CMS-300 CORE ANAL YSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number De pth Stress Density Footnote ft psig microns glcm3 1 10390.30 1000 7.40 0.005 0.011 106.33 6.84E+15 1.13E+05 2.791 1 10390.30 1750 6.93 0.003 0.006 126.03 9.42E+15 7.79E+04 2.791 1 10390.30 2500 6.65 0.001 0.004 142.89 1.28E+16 6.33E+04 2.791 1 10390.30 3250 6.48 0.001 0.003 157.12 1.92E+16 6.48E+04 2.791 1 10390.30 4000 6.38 0.001 0.002 169.93 3.43E+16 8.39E+04 2.791 2 10391.20 2500 11.77 0.007 0.014 104.09 8.40E+15 1.81E+05 2.700 3 10392.20 2500 13.88 0.014 0.035 130.40 4.90E+14 2.19E+04 2.674 4 10393.20 2500 15.38 0.034 0.068 78.83 2.09E+14 2.32E+04 2.705 5 10394.20 1000 14.07 0.029 0.062 92.44 . 1.71E+14 1.56E+04 2.692 5 10394.20 1750 13.81 0.018 0.044 118.50 1.78E+13 9.84E+02 2.692 5 10394.20 2500 13.63 0.013 0.033 124.50 4.61E+13 1.98E+03 2.692 5 10394.20 3250 13.50 0.011 0.029 132.43 5.67E+13 1.99E+03 2.692 5 10394.20 4000 13.41 0.009 0.026 134.06 1.03E+14 3.13E+03 2.692 6 10395.20 2500 10.66 0.005 0.009 87.67 1.12E+15 1.71E+04 2.765 7 10396.20 2500 15.30 0.060 0.120 74.52 1.26E+12 2.49E+02 2.794 8 10397.10 2500 16.48 8.23 9.15 6.15 3.94E+09 1.05E+02 2.868 (1 ) 101BV 10397.70 2500 17.21 0.215 0.369 49.50 3.85E+11 2.70E+02 2.701 9 10398.20 2500 16.59 0.673 0.885 20.16 1.01E+12 2.20E+03 2.686 10 10399.20 1000 16.77 0.950 1.32 24.36 8.95E+10 2.75E+02 2.677 10 10399.20 1750 16.52 0.911 1.26 24.19 8.12E+10 2.39E+02 2.677 10 10399.20 2500 16.37 0.882 1.22 24.20 8.61E+10 2.46E+02 2.677 10 10399.20 3250 16.27 0.861 1.19 24.07 9.51 E+1 0 2.66E+02 2.677 10 10399.20 4000 16.21 0.844 1.17 24.49 8.70E+10 2.37E+02 2.677 11 10400.10 2500 17.84 4.28 5.40 14.99 7.58E+09 1.05E+02 2.714 (1) Page 1 FINAL REPORT July 30,2004 - ~ - - -... - ~ --- - - ~ - CORE LABORA TORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU~040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst( s): RP, LA, JH Alaska £:ore Lab m.QI.E!IJ( SEUIUS CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity Beta Alpha Grain Number Depth Stress Density Footnote ft psig % microns g/cm3 103BV 10400.40 2500 17.34 1.45 1.95 21.07 3.59E+ 10 1.68E+02 2.668 12 10401.20 2500 16.66 1.00 1.36 22.71 8.28E+10 2.69E+02 2.669 13 10402.15 2500 18.43 3.59 4.43 13.52 5.20E+09 6.04E+01 2.668 14 10403.20 2500 17.17 1.87 2.42 17.79 2.23E+10 1.35E+02 2,744 105BV 10403.70 2500 18.52 2.62 3.42 18.01 8.63E+09 7.25E+01 2.681 15 10404.20 1000 18.90 5.14 6.23 11.91 3.42E+09 5.69E+01 2.674 15 10404.20 1750 18.67 5.02 6.06 11.71 2.98E+09 4.85E+01 2.674 15 10404.20 2500 18.52 4.93 5.95 11.69 3.15E+09 5.02E+01 2.674 15 10404.20 3250 18.42 4.86 5.87 11.75 3.12E+09 4.90E+01 2.674 15 10404.20 4000 18.35 4.80 5.79 11.71 3.28E+09 5.10E+01 2.674 16 10405.20 2500 17.82 3.14 3.92 14.33 6.60E+09 6.72E+01 2.677 17 10406.20 2500 18.05 5.01 5.98 10.96 2.77E+09 4.49E+01 2.677 107BV 10406.50 2500 19.85 5.33 6.60 13.39 2.62E+09 4.51E+01 2.692 18 10407.40 2500 18.76 6.76 7.98 10.02 1.75E+09 3.83E+01 2.677 19 10408.20 2500 18.61 4.86 5.88 11.85 3.26E+09 5.13E+01 2.671 20 10409.20 1000 19.14 6.47 7.72 10.74 1.83E+09 3.83E+01 2.682 20 10409.20 1750 18.90 6.27 7.46 10.62 1.73E+09 3.51 E+01 2.682 20 10409.20 2500 18.74 6.13 7.30 10.61 1.81E+09 3.60E+01 2.682 20 10409.20 3250 18.64 6.03 7.18 10.62 1.83E+09 3.58E+01 2.682 20 10409.20 4000 18.58 5.96 7.09 10.60 1.93E+09 3.71 E+01 2.682 109BV 10409.70 2500 18.20 2.80 3.59 16.54 1.01E+10 9.15E+01 2.681 21 10410.20 2500 18.66 4.21 5.11 12.34 4.29E+09 5.85E+01 2.679 22 10411.20 2500 16.36 1.21 1.58 18.79 5.26E+10 2.06E+02 2.685 23 10412.20 2500 14.25 0.304 0.450 32.46 2.47E+11 2.43E+02 2.677 Page 2 FINAL REPORT July 30,2004 - - - ~ --. - -... - - - ~ - - CORE LABORA TORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Core Lab m.olZll( SUYIUS CMS-300 CORE ANAL YSIS DATA Sample Net Confining Porosity Beta Alpha Grain Number Depth Stress Density Footnote ft psig % microns g/cm3 111 BV 10412.70 2500 17.22 1.10 1.49 22.14 8.11E+10 2.89E+02 2.686 24 10413.20 2500 16.84 1.61 2.07 17.04 2.73E+10 1.43E+02 2.693 25 10414.20 1000 18.73 5.55 6.60 10.72 2.39E+09 4.28E+01 2.675 25 10414.20 1750 18.50 5.42 6.45 10.63 2.24E+09 3.93E+01 2.675 25 10414.20 2500 18.35 5.33 6.33 10.60 2.32E+09 4.01E+01 2.675 25 10414.20 3250 18.26 5.26 6.25 10.61 2.36E+09 4.02E+01 2.675 25 10414.20 4000 18.20 5.20 6.18 10.62 2.40E+09 4.04E+01 2.675 26 10415.20 2500 18.36 4.14 4.98 '11.75 4.03E+09 5,39E+01 2.693 113BV 10415.70 2500 13.29 0.055 0.106 70.09 5.82E+13 1.04E+04 2.676 27 10416.20 2500 15.35 0.947 1.24 19.75 8.69E+10 2.67E+02 2.666 28 10417.20 2500 16.42 0.892 1.19 21.12 1.05E+11 3.04E+02 2.679 29 10418.20 2500 16.55 1.27 1.66 18.91 4.73E+10 1.94E+02 2.671 115BV 10418.70 2500 15.64 0.392 0.560 28.34 2.50E+11 3.18E+02 2.676 30 10419.20 1000 17.61 2.16 2.74 15.97 1.32E+10 9.21 E+01 2.673 30 10419.20 1750 17.37 2.11 2.66 15.62 1.44E+10 9.83E+01 2.673 30 10419.20 2500 17.22 2.06 2.60 15.60 1.48E+10 9.89E+01 2.673 30 10419.20 3250 17.12 2.03 2.56 15.63 1.47E+10 9.63E+01 2.673 30 10419.20 4000 17.05 2.00 2.53 15.62 1.53E+10 9.89E+01 2.673 31 10420.90 2500 17.42 1.12 1.52 22.35 8.57E+10 3.10E+02 2.685 32 10421.20 2500 17.22 1.53 1.99 18.41 3.02E+10 1.49E+02 2.673 117BV 10421.70 2500 15.19 0.154 0.258 47.02 1.53E+12 7.70E+02 2.669 33 10422,20 2500 13.67 0.097 0.173 56.77 3.88E+12 1.23E+03 2.670 34 10423.20 2500 15.76 0.448 0.625 26.08 1.70E+11 2.47E+02 2.660 Page 3 FINAL REPORT July 30, 2004 - - - - - ~ -- - - - - ~ - - -.¡ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21 2004 NW Milne Point Analyst( s): RP, LA, JH Alaska Core Lab ,nloLt\IK UaYlCU CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity Alpha Grain Number Depth Stress Density Footnote ft psig % microns g/cm3 35 10424.20 1000 15.48 0.493 0.686 25.77 1.03E+11 1.64E+02 2.667 35 10424.20 1750 15.22 0.467 0.651 25.96 1.37E+11 2.07E+02 2.667 35 10424.20 2500 15.06 0.449 0.629 26.23 1.02E+11 1.48E+02 2.667 35 10424.20 3250 14.96 0.437 0.610 25.88 1.41E+11 2.00E+02 2.667 35 10424.20 4000 14.89 0.429 0.600 26.06 1.13E+11 1.57E+02 2.667 119BV 10424.70 2500 15.52 0.158 0.273 51.25 1.05E+12 5.40E+02 2.668 36 10425.20 2500 13.34 0.080 0.147 60.95 2.48E+12 6.47E+02 2.666 37 10426.20 2500 12.33 0.050 0.085 52.68 3.04E+14 5.00E+04 2.669 38 10427.20 2500 13.98 0.076 0.146 68.36 7.98E+11 1.97E+02 2.673 121BV 10427.70 2500 15.14 0.113 0.199 55.50 2.42E+12 8.87E+02 2.663 39 10428.20 2500 15.39 0.184 0.291 40.26 8.02E+11 4.80E+02 2.673 40 10429.30 1000 13.60 0.043 0.079 63.52 2.92E+14 4.49E+04 2.671 40 10429.30 1750 13.32 0.032 0.072 97.77 1.29E+13 1.20E+03 2.671 40 10429.30 2500 13.13 0.026 0.060 99.35 3.03E+12 2.54E+02 2.671 40 10429.30 3250 13.00 0.023 0.053 96.31 2.13E+13 1.72E+03 2.671 40 10429.30 4000 12.91 0.022 0.049 97.67 1.25E+13 9.45E+02 2.671 41 10430.50 2500 12.01 0.027 0.044 48.29 2.99E+15 2.70E+05 2.680 123BV 10430.70 2500 11.67 0.006 0.014 102.51 1.06E+15 2.26E+04 2.682 42 10431.45 2500 13.93 0.052 0.093 60.07 2.26E+14 3.65E+04 2.678 43 10432.20 2500 13.96 0.064 0.115 59.91 9.23E+13 1.82E+04 2.676 44 10433.20 2500 16.41 0.129 0.218 49.35 3.18E+11 1.33E+02 2.674 125BV 10433.70 2500 17.59 0.246 0.394 41.11 1.86E+12 1.48E+03 2.675 (1 ) Page 4 FINAL REPORT July 30, 2004 - - - - -- -- - -- -.... --- - - ----. -- - CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska I:Dre Lab m.OLEIIK U1YltIS CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig microns g/cm3 45 10434.30 1000 15.38 0.095 0.181 65.13 2.22E+12 6.79E+02 2.684 45 10434.30 1750 15.10 0.092 0.171 61.47 2.35E+12 7.13E+02 2.684 45 10434.30 2500 14.92 0.090 0.167 61.91 1.97E+12 5.71 E+02 2.684 45 10434.30 3250 14.81 0.088 0.161 60.97 3.19E+12 9.08E+02 2.684 45 10434.30 4000 14.73 0.086 0.158 61.26 2.97E+12 8.24E+02 2.684 46 10435.20 2500 14.64 0.066 0.135 78.33 1.86E+12 3.98E+02 2.682 47 10436.20 2500 13.15 0.031 0.058 70.13 7.54E+14 7.54E+04 2.680 127BV 10436.75 2500 12.28 0.010 0.021 89.43 6.96E+15 2.30E+05 2.684 48 10437.20 2500 13.58 0.030 0.061 82.80 3.14E+14 2.90E+04 2.682 49 10438.20 2500 13.20 0.033 0.058 59.09 1.10E+15 1.12E+05 2.677 50 10439.20 1000 13.88 0.044 0.081 66.88 2.55E+14 4.01E+04 2.669 50 10439.20 1750 13.63 0.032 0.076 107.22 1.19E+13 1.10E+03 2.669 50 10439.20 2500 13.47 0.026 0.063 107.36 7.42E+12 6.25E+02 2.669 50 10439.20 3250 13.36 0.023 0.055 105.09 1.80E+13 1.45E+03 2.669 50 10439.20 4000 13.28 0.022 0.052 105.41 1.77E+13 1.35E+03 2.669 129BV 10439.70 2500 10.92 0.005 0.008 58.86 1.40E+15 2.36E+04 2.682 51 10440.20 2500 15.30 0.095 0.179 64.99 5.53E+11 1.70E+02 2.669 52 10441.20 2500 15.80 0.157 0.271 50.90 4.96E+11 2.53E+02 2.673 53 10442.20 2500 16.06 0.207 0.340 44.07 6.32E+11 4.25E+02 2.679 131BV 10442.75 2500 18.94 0.294 0.465 38.97 5.19E+10 4.82E+01 2.677 54 10443.20 2500 15.28 0.099 0.191 66.89 2.02E+11 6.51 E+01 2.678 Page 5 FINAL REPORT July 30, 2004 - - - ~ -- ~ ~ -- ~ ~ - - -- =-- CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Core Lab mlDLEUK SUVIt.£S CMS-300 CORE ANAL YSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig microns g/cm3 55 10444.20 1000 14.85 0.079 0.159 74.79 8.65E+12 2.26E+03 2.678 55 10444.20 1750 14.61 0.069 0.146 82.48 9.85E+11 2.19E+02 2.678 55 10444.20 2500 14.45 0.063 0.136 84.05 4.28E+11 8.77E+01 2.678 55 10444.20 3250 14.33 0.060 0.127 82.32 3.83E+12 7.63E+02 2.678 55 10444.20 4000 14.25 0.058 0.123 81.70 5.75E+12 1.11 E+03 2,678 56 10445.20 2500 17.83 0.320 0.503 38.34 1.02E+11 1.03E+02 2.666 133BV 10445.70 2500 13.82 0.028 0.052 67.65 1.19E+15 1.11E+05 2,677 57 10446.20 2500 15.47 0.119 0.217 59.60 5.99E+11 2.31 E+02 2.674 58 10447.20 2500 15.49 0.123 0.219 55.93 1.83E+12 7.32E+02 2.681 59 1 0448. 1 0 2500 15.47 0.137 0.239 52.21 7.25E+11 3.23E+02 2.675 135BV 10448.70 2500 15.36 0.073 0.152 81.03 9.40E+12 2.24E+03 2.678 60 10449.35 1000 14.24 0.050 0.097 69.60 1.02E+14 1.75E+04 2.680 60 10449.35 1750 13.98 0.040 0.086 88.47 5.27E+12 6.48E+02 2.680 60 10449.35 2500 13.81 0.034 0.075 90.62 1.06E+11 1.16E+01 2,680 60 10449.35 3250 13.70 0.031 0.068 87.84 1.35E+13 1.43E+03 2.680 60 10449.35 4000 13.61 0.030 0.064 86.95 1.93E+13 1.95E+03 2.680 61 10450.20 2500 14.16 0.095 0.169 56.43 2.57E+12 7.93E+02 2.688 62 10451.20 2500 14.85 0.112 0.193 51.46 1.73E+12 6.32E+02 2.710 137BV 10451.60 2500 14.93 0.082 0.157 66.42 1.36E+13 3.65E+03 2,697 63 10452.20 2500 14.42 0.104 0.188 57.90 1.95E+12 6.50E+02 2.709 64 10453,20 2500 14.86 0.143 0.240 47.84 2.99E+11 1.37E+02 2.700 Page 6 FINAL REPORT July 30,2004 - - --'""\ ---- ~ - ~ - - - - CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst( s): RP, LA, JH Alaska I:Dre Lab nTJDLEI/JI SEaVltIS CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig psi ft -1 microns g/cm3 65 1 0454.20 1000 13.16 0.052 0.094 60.36 1.25E+14 2.30E+04 2.691 65 10454.20 1750 12.93 0.040 0.090 94.28 9.65E+11 1.14E+02 2.691 65 10454.20 2500 12.79 0.034 0.075 90.69 1.13E+13 1.27E+03 2.691 65 10454.20 3250 12.69 0.031 0.068 90.92 8.18E+12 8.64E+02 2.691 65 10454.20 4000 12.61 0.029 0.065 92.57 3.39E+12 3.37E+02 2.691 139BV 10454.70 2500 12.46 0.014 0.028 83.92 1.08E+15 4.99E+04 2.698 66 10455.20 2500 10.66 0.016 0.033 82.33 2.37E+15 1.19E+05 2.727 67 10456.20 2500 14.07 0.110 0.186 49.65 1.76E+12 6.08E+02 2.703 68 10457.20 2500 10.92 0.048 0.081 50.87 9.31E+13 1.41 E+04 2.756 141BV 10457.50 2500 14.00 0.074 0.139 63.64 2.84E+13 6.89E+03 2.732 69 10458.20 2500 11.99 0.059 0.103 54.84 2.26E+13 4.17E+03 2.722 70 10459.20 1000 13.45 0.059 0.111 66.64 2.29E+13 4.43E+03 2.692 70 10459.20 1750 13.26 0.053 0.103 71.19 1.03E+12 1.75E+02 2.692 70 10459.20 2500 13.13 0.050 0.095 68.67 7.00E+12 1.15E+03 2.692 70 10459.20 3250 13.04 0.048 0.091 67.82 9.02E+12 1.43E+03 2.692 70 10459.20 4000 12.97 0.047 0.090 68.63 6.74E+12 1.02E+03 2.692 71 10460.50 2500 13.09 0.098 0.193 70.32 2.19E+13 6.84E+03 2.730 (1 ) 143BV 10460.70 2500 12.84 0.028 0.060 90.56 . 3.19E+14 2.94E+04 2.710 72 10461.20 2500 12.96 0.064 0.097 39.43 5.47E+14 1.11E+05 2.719 73 10462.50 2500 6.70 0.017 0.024 28.93 2.10E+16 1.18E+06 2.737 (1 ) 74 10463.20 2500 7.24 0.064 0.104 47.83 4.69E+12 9.28E+02 2.814 (1 ) Page 7 FINAL REPORT July 30,2004 - - - - ~ - - --- ...-... -....... -----. ---- - ~ - CORE LABORA TORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation .& CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21,2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Core LaI:Ì mlDLtIIK SEaYltU CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig microns g/cm3 75 10464.20 1000 6.17 0.003 0.006 107.12 9.42E+15 8.58E+04 2.879 75 10464.20 1750 5.80 0.002 0.004 140.89 1.41E+15 7.39E+03 2.879 75 10464.20 2500 5.56 0.001 0.003 152.46 5.83E+15 2.23E+04 2.879 75 10464.20 3250 5.40 0.001 0.002 162.70 9.63E+15 2.82E+04 2.879 75 10464.20 4000 N/A <0.001 <0.001 N/A N/A N/A 2.879 (2) 76 10465.20 2500 4.85 0.008 0.016 95.69 1.23E+15 3,13E+04 2.705 77 10466.20 2500 2.75 0.003 0.008 117.61 5.27E+16 5.78E+05 2.686 78 10467.20 2500 2.81 0.005 0.012 105.25 1.05E+16 1.81E+05 2.692 145BV 10467.70 2500 2.66 0.0005 0,001 187.36 2.73E+16 4.48E+04 2.720 79 10468.20 2500 1,97 0.001 0.002 168.51 1.27E+16 3.22E+04 2.698 80 10469.20 1000 2.92 0.002 0.004 140.91 3.18E+15 1.67E+04 2.698 80 10469.20 1750 2.63 0.002 0.004 142.32 1.19E+17 6.03E+05 2.698 80 10469.20 2500 N/A <0.001 <0.001 N/A N/A N/A 2.698 (2) 80 10469.20 3250 N/A <0.001 <0.001 NIA N/A N/A 2.698 (2) 80 10469.20 4000 N/A <0.001 <0.001 N/A N/A N/A 2.698 (2) 81 10470.20 2500 3,04 0.001 0.003 150.75 5.35E+15 2.14E+04 2.713 147BV 10470.70 2500 2.11 0.0003 0.001 208.21 6.47E+16 6,94E+04 2.700 82 10471.20 2500 1.99 0.001 0.002 166.89 1.18E+16 3.10E+04 2.702 83 10472.20 2500 1.66 0.001 0.002 180.98 2.20E+16 4.18E+04 2.699 84 10473.20 2500 2,92 0.001 0.002 163.54 1.00E+16 2,88E+04 2.676 (1 ) 149BV 10473.70 2500 1,97 0.0003 0.001 218.52 9.38E+16 8.26E+04 2.678 Page 8 FINAL REPORT July 30, 2004 - - - ~ -- -. - - - - ---.¡ ~ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation .. CL File No.: HOU-040292 Nikaitchuq 2 Well Date: May 21, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska £:orE! Lab nTlQLEIIJ( SEaVICU CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig psi ft -1 microns g/cm3 85 10474.20 1000 3.40 0.002 0.005 137.10 2.57E+15 1.51 E+04 2.685 85 10474.20 1750 3.13 0.002 0.004 139.12 1.03E+17 5.72E+05 2.685 85 10474.20 2500 N/A <0.001 <0.001 N/A N/A N/A 2.685 (2) 85 10474.20 3250 N/A <0.001 <0.001 N/A N/A N/A 2.685 (2) 85 10474.20 4000 N/A <0.001 <0.001 N/A N/A N/A 2.685 (2) 86 10475.20 2500 2.83 0.001 0.003 158.83 8.01E+15 2.59E+04 2.684 (1 ) 87 10476.20 2500 2.59 0.001 0.002 179.94 2.10E+16 4.08E+04 2.681 151BV 10476.70 2500 1.85 <0.001 <0.001 N/A N/A N/A 2.700 (3) 88 10477.20 2500 2.52 0.001 0.002 172.61 1.53E+16 3.51 E+04 2.685 89 10478.20 2500 2.08 0.001 0.002 185.12 2.65E+16 4.57E+04 2.690 90 10479.20 1000 3.06 0.002 0.004 141.38 2.39E+17 1.24E+06 2.689 90 10479.20 1750 N/A <0.001 <0.001 N/A N/A N/A 2.689 (2) 90 10479.20 2500 N/A <0.001 <0.001 N/A N/A N/A 2.689 (2) 90 10479.20 3250 N/A <0.001 <0.001 N/A N/A N/A 2.689 (2) 90 10479.20 4000 N/A <0.001 <0.001 N/A N/A N/A 2.689 (2) 91 10480.05 2500 3.57 0.001 0.003 158.92 3.22E+16 1.04E+05 2.687 Footnotes : (1) : Denotes fractured or chipped sample. Permeability and/or porosity may be optimistic. (2) : Sample permeability less than 0.001 mD at indicated stress. Porosity unavailable at indicated NCS. (3) : Sample permeability less than 0.001 mD at indicated stress. Porosity determined using Boyle's law grain volume & dimension calculated bulk volumes at ambient conditions. Page 9 FINAL REPORT July 30, 2004 -----~~--....._-----.--- CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . ÜJrE! Lab lnlBUUK 51.VlCES CL File No.: HOU-040292 Date: May 21,2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number (ft) psig % mD I mD % Pore Volume g/cm3 Description Flu 1 10390.30 1000 7.40 0.005 0.011' 2.791 1 10390.30 1750 6.93 0.003 0.006 2.791 1 10390.30 2500 6.65 0.001 0.004 7.1 78.9 2.791 Sst gry vfg shy lam(1 ,2) vslty na 1 10390.30 3250 6.48 0.001 0.003 2.791 1 10390.30 4000 6.38 0.001 0.002 2.791 2 10391.20 2500 11.77 0.007 0.014 6.4 90.2 2.700 Sst gry vfg shy lam(2) vslty vft 3 10392.20 2500 13.88 0.014 0.035 7.7 85.7 2.674 Sst gry vfg shy lam(2) vslty biot vft 4 10393.20 2500 15.38 0.034 0.068 25.3 67.3 2.705 Sst gry vfg sshy-shy lam(2) slty fty 5 10394.20 1000 14.07 0.029 0.062 2.692 5 10394.20 1750 13.81 0.018 0.044 2.692 5 10394.20 2500 13.63 0.013 0.033 10.3 88.7 2.692 Sst gry vfg sshy-shy lam(1,2) vslty biot matt vft 5 10394.20 3250 13.50 0.011 0.029 2.692 5 10394.20 4000 13.41 0.009 0.026 2.692 6 10395.20 2500 10.66 0.005 0.009 4.2 82.6 2.765 Sst dk gry vfg shy-vshy lam( 1,2) slty no 7 10396.20 2500 15.30 0.060 0.120 13.0 73.2 2.794 Sst dk gry vfg sshy-shy slty fty 8 10397.10 2500 16.48 8.23 9.15 20.6 59.6 2.868 Dol It gry svuggy bt gld 101BV 10397.70 2500 17.21 0.215 0.369 22.5 56.4 2.701 Sst gry vfg sshy lam(1 ,2) slty stks gld 9 10398.20 2500 16.59 0.673 0.885 20.9 55.1 2.686 Sst gry vfg sshy slty biot gld 10 10399.20 1000 16.77 0.950 1.32 2.677 10 10399.20 1750 16.52 0.911 1.26 2.677 10 10399.20 2500 16.37 0.882 1.22 19.6 54.7 2.677 Sst gry vfg sshy slty gld 10 10399.20 3250 16.27 0.861 1.19 2.677 10 10399.20 4000 16.21 0.844 1.17 2.677 11 10400.10 2500 17.84 4.28 5.40 26.1 52.9 2.714 5st gry vf-fg sshy slty svuggy gld Page 10 FINAL REPORT July 30, 2004 ~ - ----........--.-..~-- --. CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska 4\ Core Lab lETlDUDI! SUYlCES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number (ft) psig % mD I mD % Pore Volume g/cm3 Description Flu 103BV 10400.40 2500 17.34 1.45 1.95· 22.2 45.9 2.668 Sst gry vf-fg sshy slty gld 12 10401.20 2500 16.66 1.00 1.36 23.0 55.0 2.669 Sst gry vf-fg sshy slty gld 13 10402.15 2500 18.43 3.59 4.43 20.8 52.9 2.668 Sst gry vf-fg sshy slty gld 14 10403.20 2500 17.17 1.87 2.42 20.4 58.6 2.744 Sst gry vf-fg sshy slty gld 105BV 10403.70 2500 18.52 2.62 3.42 19.1 46.7 2.681 Sst gry vf-fg sshy slty gld 15 10404.20 1000 18.90 5.14 6.23 2.674 15 10404.20 1750 18.67 5.02 6.06 2.674 15 10404.20 2500 18.52 4.93 5.95 18.7 53.9 2.674 Sst gry vf-fg sshy slty gld 15 10404.20 3250 18.42 4.86 5.87 2.674 15 10404.20 4000 18.35 4.80 5.79 2.674 16 10405.20 2500 17.82 3.14 3.92 17.5 57.7 2.677 Sst gry vf-fg sshy slty gld 17 10406.20 2500 18.05 5.01 5.98 14.9 59.6 2.677 Sst gry vf-fg sshy slty gld 107BV 10406.50 2500 19.85 5.33 6.60 14.5 49.8 2.692 Sst gry vf-fg sshy slty gld 18 10407.40 2500 18.76 6.76 7.98 14.1 57.6 2.677 Sst gry vf-fg sshy slty gld 19 10408.20 2500 18.61 4.86 5.88 18.0 54.3 2.671 Sst gry vf-fg sshy slty gld 20 10409.20 1000 19.14 6.47 7.72 2.682 20 10409.20 1750 18.90 6.27 7.46 2.682 20 10409.20 2500 18.74 6.13 7.30 15.4 56.4 2.682 Sst gry vf-fg sshy slty gld 20 10409.20 3250 18.64 6.03 7.18 2.682 20 10409.20 4000 18.58 5.96 7.09 2.682 109BV 10409.70 2500 18.20 2.80 3.59 16.5 51.4 2.681 Sst gry vf-fg sshy slty gld 21 10410.20 2500 18.66 4.21 5.11 14.7 60.4 2.679 Sst gry vf-fg sshy slty gld 22 1 0411.20 2500 16.36 1.21 1.58 23.1 52.9 2.685 Sst gry vf-fg sshy slty gld 23 10412.20 2500 14.25 0.304 0.450 15.5 59.5 2.677 Sst gry vfg sshy lam(1) vslty stks gld Page 11 FINAL REPORT July 30, 2004 -----._-~-..--~-~-~-. CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . ÜJr'E! Lab rETIIIJ.EUII SlIYICES CL File No.: HOU-040292 Date: May 21 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number eft) psig % mD I mD % Pore Volume glcm3 Description Flu 111 BV 10412.70 2500 17.22 1.10 1.49· 19.8 51.5 2.686 5st gry vf-fg sshy slty gld 24 10413.20 2500 16.84 1.61 2.07 19.4 52.0 2.693 5st gry vf-fg sshy slty gld 25 10414.20 1000 18.73 5.55 6.60 2.675 25 10414.20 1750 18.50 5.42 6.45 2.675 25 10414.20 2500 18.35 5.33 6.33 16.7 52.3 2.675 5st gry vf-fg sshy slty gld 25 10414.20 3250 18.26 5.26 6.25 2.675 25 10414.20 4000 18.20 5.20 6.18 2.675 26 10415.20 2500 18.36 4.14 4.98 14.6 58.0 2.693 5st gry vf-fg sshy slty gld 113BV 10415.70 2500 13.29 0.055 0.106 22.3 52.4 2.676 5st gry vf-fg sshy lam( 1,2) slty stks gld 27 10416.20 2500 15.35 0.947 1.24 25.4 48.3 2.666 5st gry vf-fg sshy vslty gld 28 10417.20 2500 16.42 0.892 1.19 20.8 51.6 2.679 5st gry vf-fg sshy vslty gld 29 10418.20 2500 16.55 1.27 1.66 17.9 54.3 2.671 115BV 10418.70 2500 15.64 0.392 0.560 27.2 50.4 2.676 5st gry vf-fg sshy slty gld 30 10419.20 1000 17.61 2.16 2.74 2.673 30 10419.20 1750 17.37 2.11 2.66 2.673 30 10419.20 2500 17.22 2.06 2.60 25.8 44.9 2.673 5st gry vf-fg sshy slty gld 30 10419.20 3250 17.12 2.03 2.56' 2.673 30 10419.20 4000 17.05 2.00 2.53 2.673 31 10420.90 2500 17.42 1.12 1.52 16.2 56.1 2.685 5st gry vf-fg sshy lam (1) vslty stks gld 32 10421.20 2500 17.22 1.53 1.99 20.8 48.6 2.673 5st gry vf-fg sshy vslty gld 117BV 10421.70 2500 15.19 0.154 0.258 20.5 49.3 2.669 5st gry vfg sshy-shy lam( 1,2) vslty stks y 33 10422.20 2500 13.67 0.097 0.173 11.4 70.2 2.670 5st gry vfg sshy-shy lam(1,2) vslty stks y 34 10423.20 2500 15.76 0.448 0.625 16.5 55.8 2.660 5st gry vfg sshy-shy lam(1) vslty stks y Page 12 FINAL REPORT July 30, 2004 - - - - -- ---. - -- - ~ CORE LAB ORA TORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . I:orE! Lab lETAIJUUJI SEaVICES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number (ft) psig % mD I mD % Pore Volume gIcm3 Description Flu 35 10424.20 1000 15.48 0.493 0.686' 2.667 35 10424.20 1750 15.22 0.467 0.651 2.667 35 10424.20 2500 15.06 0.449 0.629 18.7 53.8 2.667 Sst gry vfg sshy-shy lam(1) vslty stks y 35 10424.20 3250 14.96 0.437 0.610 2.667 35 10424.20 4000 14.89 0.429 0.600 2.667 119BV 10424.70 2500 15.52 0.158 0.273 19.7 52.2 2.668 Sst gry vfg shy lam(1 ,2) vslty stks ft Y 36 10425.20 2500 13.34 0.080 0.147 7.5 76.4 2.666 Sst gry vfg shy lam( 1,2) vslty stks ft Y 37 10426.20 2500 12.33 0.050 0.085 5.8 78.2 2.669 Sst gry vfg shy lam(1 ,2) vslty stks ft Y 38 10427.20 2500 13.98 0.076 0.146 9.7 71.6 2.673 . Sst gry vfg sshy lam(1,2) slty stks ft y 121BV 10427.70 2500 15.14 0.113 0.199 16.4 56.1 2.663 Sst gry vfg sshy lam(1 ,2) slty stks ft Y 39 10428.20 2500 15.39 0.184 0.291 16.2 58.1 2.673 Sst gry vfg sshy slty y 40 10429.30 1000 13.60 0.043 0.079 2.671 40 10429.30 1750 13.32 0.032 0.072 2.671 40 10429.30 2500 13.13 0.026 0.060 0.3 83.7 2.671 Sst gry vfg shy lam(1 ,2) vslty stks vft 40 10429.30 3250 13.00 0.023 0.053 2.671 40 10429.30 4000 12.91 0.022 0.049 2.671 41 10430.50 2500 12.01 . 0.027 0.044 0.6 89.4 2.680 Sst It gry vfg shy lam(1 ,2) vslty stks vft 123BV 10430.70 2500 11.67 0.006 0.014 0.5 80.6 2.682 Sst It gry vfg shy lam(1,2) vslty no 42 10431.45 2500 13.93 0.052 0.093 0.3 87.1 2.678 Sst It gry vfg shy lam(1,2) vslty no 43 10432.20 2500 13.96 0.064 0.115 0.5 80.0 2.676 Sst It gry vfg shy lam(1 ,2) vslty stks vft 44 10433.20 2500 16.41 0.129 0.218 2.9 78.9 2.674 Sst It gry vfg sshy lam(1 ,2) slty stks ft Y 125 BV 10433.70 2500 17.59 0.246 0.394 2.1 73.0 2.675 Sst It gry vfg sshy lam(1 ,2) slty stks ft y Page 13 FINAL REPORT July 30, 2004 -----~,........,---.--...~-- - -- CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab PUlØU1/]( SlUICES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg r Kair Oil r Water Density Number (ft) psig % mD r mD % Pore Volume g/cm3 Description Flu 45 10434.30 1000 15.38 0.095 0.181- 2.684 45 10434.30 1750 15.10 0.092 0.171 2.684 45 10434.30 2500 14.92 0.090 0.167 0.9 78.0 2.684 Sst It gry vfg sshy lam(1,2) slty stks vft 45 10434.30 3250 14.81 0.088 0.161 2.684 45 10434.30 4000 14.73 0.086 0.158 2.684 46 10435.20 2500 14.64 0.066 0.135 1.7 83.0 2.682 Sst It gry vfg sshy lam(1 ,2) slty stks vft 47 10436.20 2500 13.15 0.031 0.058 0.5 76.5 2.680 5st It gry vfg sshy-shy lam( 1,2) vslty no 127BV 10436.75 2500 12.28 0.010 0.021 0.2 74.2 2.684 5st It gry vfg sshy-shy lame 1,2) vslty no 48 10437.20 2500 13.58 0.030 0.061 0.7 85.4 2.682 5st It gry vfg sshy-shy lam(1 ,2) vslty no 49 10438.20 2500 13.20 0.033 0.058 0.7 81.3 2.677 5st It gry vfg sshy-shy lam(1 ,2) vslty no 50 10439.20 1000 13.88 0.044 0.081 2.669 50 10439.20 1750 13.63 0.032 0.076 2.669 50 10439.20 2500 13.47 0.026 0.063 0.7 83.2 2.669 5st It gry vfg sshy-shy lam(1,2) vslty no 50 10439.20 3250 13.36 0.023 0.055 2.669 50 10439.20 4000 13.28 0.022 0.05~ 2.669 129BV 10439.70 2500 10.92 0.005 0.008 1.0 83.1 2.682 5st It gry vfg sshy lam(1 ,2) vslty stks vft 51 10440.20 2500 15.30 0.095 0.179 0.9 . 83.2 2.669 Sst It gry vfg sshy lam(1 ,2) vslty stks vft 52 10441.20 2500 15.80 0.157 0.271 1.0 77.0 2.673 5st It gry vfg vsshy lam(1 ,2) vslty stks vft 53 10442.20 2500 16.06 0.207 0.340 5.9 72.6 2.679 5st It gry vfg vsshy lam(1,2) slty stks ft y 131BV 10442.75 2500 18.94 0.294 0.465 0.9 76.7 2.677 5st It gry vfg vsshy lam(1,2) slty stks vft 54 10443.20 2500 15.28 0.099 0.191 1.5 83.6 2.678 5st It gry vfg vsshy lam(1 ,2) slty stks vft Page 14 FINAL REPORT July 30,2004 - - ----~-------.--- --. - ~ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab PETlSUUH SUVItES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number (ft) psig % mD I mD % Pore Volume g/cm3 Description Flu 55 10444.20 1000 14.85 0.079 0.159' 2.678 55 10444.20 1750 14.61 0.069 0.146 2.678 55 10444.20 2500 14.45 0.063 0.136 0.3 84.0 2.678 5st It gry vfg vsshy lam(1 ,2) slty stks vft 55 10444.20 3250 14.33 0.060 0.127 2.678 55 10444.20 4000 14.25 0.058 0.123 2.678 56 10445.20 2500 17.83 0.320 0.503 1.0 81.6 2.666 5st It gry vfg vsshy lam(1,2) vslty no 133BV 10445.70 2500 13.82 0.028 0.052 0.9 80.2 2.677 5st It gry vfg vsshy lam(1 ,2) vslty no 57 10446.20 2500 15.47 0.119 0.217 0.2 84.7 2.674 5st It gry vfg sshy lam(1 ,2) slty no 58 10447.20 2500 15.49 0.123 0.219 0.5 82.1 2.681 5st It gry vfg sshy lam(1,2) slty no 59 10448.10 2500 15.47 0.137 0.239 0.1 83.5 2.675 5st It gry vfg sshy lam(1,2) slty no 135BV 10448.70 2500 15.36 0.073 0.152 1.5 79.0 2.678 5st It gry vfg sshy lam(1,2) slty no 60 10449.35 1000 14.24 0.050 0.097 2.680 60 10449.35 1750 13.98 0.040 0.086 2.680 60 10449.35 2500 13.81 0.034 0.075 4.7 78.3 2.680 5st gry vfg sshy-shy lam(1,2) slty stks y 60 10449.35 3250 13.70 0.031 0.068 2.680 60 10449.35 4000 13.61 0.030 0.064 2.680 61 10450.20 2500 14.16 0.095 0.169 5.3 80.9 2.688 5st It gry vfg sshy lam(1,2) vslty stks ft y 62 10451.20 2500 14.85 0.112 0.193 1.1 76.1 2.710 5st It gry vfg sshy lam(1,2) vslty stks ft y 137BV 10451.60 2500 14.93 0.082 0.157 2.0 69.9 2.697 5st It gry vfg sshy lam(1,2) vslty stks ft y 63 10452.20 2500 14.42 0.104 0.188 1.7 81.6 2.709 5st It gry vfg sshy lam(1,2) vslty stks vft 64 10453.20 . 2500 14.86 0.143 0.240 1.7 78.8 2.700 5st gry vfg sshy lam(1,2) slty stks y Page 15 FINAL REPORT July 30,2004 - - -- - ..-...-, ~ ~ -.... -- - ~ ~ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab nnlJ1.EUK SUYItES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Pe rmea bility Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number eft) psig % mD I mD % Pore Volume g/cm3 Description Flu I 65 10454.20 1000 13.16 0.052 0.094' 2.691 65 10454.20 1750 12.93 0.040 0.090 2.691 65 10454.20 2500 12.79 0.034 0.075 0.9 85.2 2.691 Sst gry vfg sshy lam(1 ,2) vslty stks vft 65 10454.20 3250 12.69 0.031 0.068 2.691 65 10454.20 4000 12.61 0.029 0.065 2.691 139BV 10454.70 2500 12.46 0.014 0.028 0.9 82.5 2.698 Sst gry vfg sshy lam( 1,2) vslty stks vft 66 10455.20 2500 10.66 0.016 0.033 1.6 80.1 2.727 Sst gry vfg sshy lam( 1,2) vslty stks vft 67 10456.20 2500 14.07 0.110 0.186 3.3 75.2 2.703 Sst gry vfg sshy lam( 1,2) slty stks ft y 68 10457.20 2500 10.92 0.048 0.081 6.7 62.2 2.756 Sst gry vfg sshy lam(1 ,2) vslty stks ft Y 141BV 10457.50 2500 14.00 0.074 0.139 15.3 68.6 2.732 Sst gry vfg sshy lam( 1,2) slty stks ft Y 69 10458.20 2500 11.99 0.059 0.103 13.7 60.8 2.722 Sst gry vfg sshy lam(1 ,2) slty stks Y 70 10459.20 1000 13.45 0.059 0.111 2.692 70 10459.20 1750 13.26 0.053 0.103 2.692 70 10459.20 2500 13.13 0.050 0.095 11.3 64.9 2.692 Sst gry vfg sshy lam( 1,2) slty stks ft y 70 10459.20 3250 13.04 0.048 0.091 2.692 70 10459.20 4000 12.97 0.047 0.090 2.692 71 10460.50 2500 13.09 0.098 0.193 1.4 77.4 . 2.730 Sst gry vfg sshy lam( 1,2) slty svuggy stks vft 143BV 10460.70 2500 12.84 0.028 0.060 0.2 81.0 2.710 Sst gry vfg sshy lam( 1,2) slty stks vft 72 10461.20 2500 12.96 0.064 0.097 0.6 81.1 2.719 Sst gry vfg sshy lam(1 ,2) slty stks vft 73 10462.50 2500 6.70 0.017 0.024 0.5 95.8 2.737 Sst gry vfg shy lam(1 ,2) vslty no 74 10463.20 2500 7.24 0.064 0.104 0.6 87.8 2.814 Sst gry vfg shy lam(2) vslty pyr no Page 16 FINAL REPORT July 30, 2004 - ------- ~ -..... -- -- - - - - CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab UTllDUlX SUYICES CL File No.: HOU-040292 Date: May 21,2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample Depth Stress Klinkenberg I Kair Oil I Water Density Number (ft) psig % mD I mD % Pore Volume g/cm3 Description Flu 75 10464.20 1000 6.17 0.003 0.006' 2.879 75 10464.20 1750 5.80 0.002 0.004 2.879 75 10464.20 2500 5.56 0.001 0.003 0.7 92.6 2.879 Sst gry vfg shy lam(1 ,2) slty Imy wcons vfoss min 75 10464.20 3250 5.40 0.001 0.002 2.879 75 10464.20 4000 N/A <0.001 <0.001 2.879 76 10465.20 2500 4.85 0.008 0.016 0.0 91.8 2.705 Ls dk gry vf xln shy-vshy lam(1 ,2) slty wcons no 77 10466.20 2500 2.75 0.003 0.008 21.1 73.6 2.686 Ls gry vf xln shy lam(1 ,2) slty wcons stks dull brz 78 10467.20 2500 2.81 0.005 0.012 19.2 72.3 2.692 Ls gry vf xln shy lam(1 ,2) slty wcons stks dull brz 145BV 10467.70 2500 2.66 0.0005 0.001 16.0 74.0 2.720 Ls gry vf xln shy lam(1,2) slty wcons stks dull brz 79 10468.20 2500 1.97 0.001 0.002 15.9 75.5 2.698 Ls gry vf xln shy slty weons dull brz 80 10469.20 1000 2.92 0.002 0.004 2.698 80 10469.20 1750 2.63 0.002 0.004 14.8 76.2 2.698 Ls gry vf xln shy lam(1 ,2) slty wcons stks dull brz 80 10469.20 2500 N/A <0.001 <0.001 2.698 80 10469.20 3250 N/A <0.001 <0.001 2.698 80 10469.20 4000 N/A <0.001 <0.001 2.698 81 10470.20 2500 3.04 0.001 0.003 14.4 79.0 2.713 Ls gry vf xln shy lam(1,2) slty weons stks dull brz 147BV 10470.70 2500 2.11 0.0003 0.001 11.2 79.2 2.700 Ls gry vf xln shy lam(1,2) slty wcons stks dull brz 82 10471.20 2500 1.99 0.001 0.002 11.7 80.4 2.702 Ls gry vf xIn shy lam(1 ,2) slty wcons stks dull brz 83 10472.20 2500 1.66 0.001 0.002 14.8 75.7 2.699 Ls gry vf xln shy slty weons dull brz 84 10473.20 2500 2.92 0.001 0.002 8.1 84.2 2.676 Ls gry vf xln shy slty wcons stks min 149BV 10473.70 2500 1.97 0.0003 0.001 5.6 84.6 .2.678 Ls gry vf xln shy lam(1,2) slty weons stks min Page 17 FINAL REPORT July 30, 2004 - --- ~ - ~ - ..-.-. - - -.... -- -- - CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab PETlIIUIIX SJIYICES CL File No.: HOU-040292 Date: May 21, 2004 Analyst(s): RP, LA, JH CMS-300 CORE ANALYSIS DATA Net Confining Porosity Permeability Saturation Grain Sample De pth Stress Klinkenberg .1 Kair Oil I Water Density Number eft) psig % mD I mD % Pore Volume glcm3 Description Flu 85 10474.20 1000 3.40 0.002 0.005 2.685 85 10474.20 1750 3.13 0.002 0.004 2.3 84.3 2.685 Ls gry vf xln shy slty wcons stks min 85 10474.20 2500 N/A <0.001 <0.001 2.685 85 10474.20 3250 N/A <0.001 <0.001 2.685 85 10474.20 4000 N/A <0.001 <0.001 2.685 86 10475.20 2500 2.83 0.001 0.003 5.1 88.3 2.684 Ls gry vf xln shy lam(1 ,2) slty weons stks min 87 10476.20 2500 2.59 0.001 0.002 12.6 70.7 2.681 Ls gry vf xln shy lam(1 ,2) slty wcons stks min 151BV 10476.70 2500 1.85 <0.001 <0.001 8.9 70.0 2.700 Ls gry vf xln shy slty weons stks min 88 10477.20 2500 2.52 0.001 0.002 16.5 71.6 2.685 Sst gry vfg shy lam(1 ,2) slty vlmy wcons stks min 89 10478.20 2500 2.08 0.001 0.002 2.8 81.7 2.690 Sst gry vfg shy lam(1 ,2) slty vlmy wcons stks min 90 10479.20 1000 3.06 0.002 0.004 11.9 75.2 2.689 Sst gry vfg shy lam(1,2) slty vlmy wcons stks min 90 10479.20 1750 N/A <0.001 <0.001 2.689 90 10479.20 2500 N/A <0.001 <0.001 2.689 90 10479.20 3250 N/A <0.001 <0.001 2.689 90 10479.20 4000 N/A <0.001 <0.001 2.689 91 10480.05 2500 3.57 0.001 0.003 9.4 84.0 2.687 Sst gry vfg shy lam(1 ,2) slty foss wcons stks min Page 18 FINAL REPORT July 30, 2004 - - --. ~ ~ - - . I:oœ LaIÏ RES[JIVOIR OPTDlIZATIO!l CMS-300 CORE ANALYSIS DATA 1.5"0 Diameter Samples for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: July 2, 2004 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 Petrophysics, Inc. 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 Petrophysics, Inc., 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. CORE PETROPHYSICS 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 - - - - ~ --. - -.... - - - - CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: July 2, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Cere Lab PlnøtI1l1t UIIVlcn CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig psi ft -1 microns g/cm3 153CH 10397.40 1000 16.97 0.216 0.342 40.22 8.43E+11 5.84E+02 2.731 153CH 10397.40 1750 16.85 0.195 0.309 40.10 9.51 E+11 6.02E+02 2.731 153CH 10397.40 2500 16.74 0.180 0.288 41.42 1.13E+12 6.59E+02 2.731 153CH 10397.40 3250 16.66 0.169 0.276 43.95 5.10E+10 2.75E+01 2.731 153CH 10397.40 4000 16.59 0.160 0.262 44.22 3.69E+11 1.92E+02 2.731 154CH 10398.35 2500 16.71 0.643 0.918 27.38 2.73E+11 5.65E+02 2.693 155CH 10399.35 2500 16.15 1.01 1.38 22.52 2.47E+11 8.15E+02 2.672 156CH 10400.90 2500 17.33 4.15 4.82 9.17 4.64E+10 6.26E+02 2.664 (1 ) 157CH 10401.35 2500 16.19 0.780 1.09 25.25 4.14E+11 1.05E+03 2.669 158CH 10402.55 1000 18.30 12.4 15.0 11.03 1.08E+10 4.19E+02 2.677 (1 ) 158CH 10402.55 1750 18.09 8.73 10.5 10.90 1.66E+10 4.71E+02 2.677 (1 ) 158CH 10402.55 2500 17.95 6.86 8.26 10.94 2.23E+10 4.97E+02 2.677 (1 ) 158CH 10402.55 3250 17.85 5.82 7.04 11.17 2. 75E+1 0 5.03E+02 2.677 (1 ) 158CH 10402.55 4000 17.78 5.21 6.03 8.44 5.15E+10 8.86E+02 2.677 (1 ) 159CH 10403.30 2500 18.84 3.33 4.18 14.84 . 2.51E+10 2.72E+02 2.682 160CH 10404.05 2500 18.69 3.28 4.10 14.52 2.99E+10 3.19E+02 2.675 161CH 10405.35 2500 17.63 2.37 3.03 16.50 5.73E+10 4.39E+02 2.680 162CH 10406.35 2500 18.44 2.86 3.62 15.51 3.95E+10 3.65E+02 2.679 163CH 10407.10 1000 19.02 5.35 6.46 11.78 1.01E+10 1.75E+02 2.699 163CH 10407.10 1750 18.84 5.20 6.28 11.77 1.07E+10 1.80E+02 2.699 163CH 10407.10 2500 18.73 5.08 6.15 11.79 1.11E+10 1.83E+02 2.699 163CH 10407.10 3250 18.65 5.00 6.05 11.79 1.14E+10 1.85E+02 2.699 163CH 10407.10 4000 18.59 4.94 5.97 11.82 1.17E+10 1.88E+02 2.699 164CH 10408.45 2500 18.36 2.54 3.25 16.55 4.76E+10 3.91 E+02 2.674 Page 19 FINAL REPORT July 30, 2004 - - ~ ~ -. - -- - ~ - - -. CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation . CL File No.: HOU-040292 Nikaitchuq 2 Well Date: July 2, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska CarE! Lab PETlDU1IIt stIlYlC£S CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He} Beta Alpha Grain Number Depth Stress Density Footnote ft psig psi ft -1 microns g/cm3 165CH 10409.10 2500 18.98 10.0 11.8 9.38 1.31E+10 4.26E+02 2.687 (1 ) 166CH 10410.35 2500 18.09 1.84 2.41 18.55 8.57E+10 5.09E+02 2.683 (1 ) 167CH 1 0411 .35 2500 16.07 0.800 1.01 16.57 2.20E+12 5.68E+03 2.683 168CH 10412.05 1000 14.27 0.207 0.335 42.68 9.51 E+11 6.33E+02 2.687 168CH 10412.05 1750 14.05 0.185 0.300 42.97 1.14E+12 6.82E+02 2.687 168CH 10412.05 2500 13.91 0.171 0.278 43.50 1.37E+12 7.58E+02 2.687 168CH 10412.05 3250 13.81 0.161 0.263 43.88 1.61E+12 8.42E+02 2.687 168CH 10412.05 4000 13.73 0.154 0.253 44.16 1.98E+12 9.91 E+02 2.687 169CH 1 0413.35 2500 20.42 0.890 1.07 12.98 5.41 E+12 1.56E+04 2.717 170CH 10414.35 2500 18.11 4.48 5.48 12.65 1.76E+10 2.56E+02 2.697 (1 ) 171CH 10415.35 2500 17.94 1.99 2.58 17.97 6.59E+10 4.23E+02 2.693 (1 ) 172CH 10416.35 2500 14.85 0.413 0.551 22.07 1.10E+11 1.47E+02 2.678 173CH 10417.35 1000 16.03 0.463 0.681 34.69 1.57E+10 2.23E+01 2.690 173CH 10417.35 1750 15.86 0.458 0.642 34.64 8.11E+10 1.10E+02 2.690 173CH 10417.35 2500 15.74 0.447 0.632 24.12 2.17E+10 3.24E+01 2.690 173CH 10417.35 3250 15.66 0.446 0.618 23.06 2.14E+11 3.18E+02 2.690 173CH 10417.35 4000 15.61 0.420 0.604 23.18 1.93E+11 2.79E+02 2.690 174CH 10418.35 2500 16.51 0.936 1.28 22.91 4.18E+11 1.26E+03 2.674 175CH 10419.35 2500 16.98 1.32 1.76 20.37 2.22E+11 9.49E+02 2.696 177CH 10421.35 2500 16.71 0.677 0.883 19.43 3.16E+12 6.93E+03 2.673 178CH 10422.35 2500 14.54 0.145 0.245 49.21 1.93E+10 9.04E+00 2.673 Page 20 FINAL REPORT July 30, 2004 ~ - - - -....¡ ~ ~ ~ - - - - - ~ CORE LABORATORIES, INC. HOUSTON ADVANCED TECHNOLOGY CENTER Kerr-McGee Oil & Gas Corporation .. CL File No.: HOU-040292 Nikaitchuq 2 Well Date: July 2, 2004 NW Milne Point Analyst(s): RP, LA, JH Alaska Core LaI:Î PE TlØ tE1I!t SEll" en CMS-300 CORE ANALYSIS DATA Sample Net Confining Porosity b(He) Beta Alpha Grain Number Depth Stress Density Footnote ft psig microns g/cm3 179CH 10423.35 1000 15.88 0.273 0.424 37.42 5.35E+10 4.71E+01 2.669 179CH 10423.35 1750 15.70 0.261 0.398 35.78 6.21 E+11 5.27E+02 2.669 179CH 10423.35 2500 15.58 0.250 0.383 36.09 6.79E+11 5.48E+02 2.669 179CH 10423.35 3250 15.51 0.241 0.370 36.32 7.15E+11 5.57E+02 2.669 179CH 10423.35 4000 15.45 0.233 0.358 36.50 7.59E+11 5.74E+02 2.669 180CH 10424.35 2500 15.87 0.356 0.515 29.70 1.16E+10 1.34E+01 2.696 181CH 10425.05 2500 13.34 0.062 0.131 84.47 7.59E+12 1.52E+03 2.673 182CH 10426.35 2500 13.41 0.047 0.098 83.80 1.13E+14 1.71E+04 2.677 183CH 10427.35 1000 13.92 0.058 0.129 96.08 1.46E+13 2.63E+03 2.665 183CH 10427.35 1750 13.80 0.057 0.118 77.54 8.91 E+12 1.68E+03 2.665 183CH 10427.35 2500 13.70 0.053 0.109 78.56 6.91 E+12 1.20E+03 2.665 183CH 10427.35 3250 13.61 0.051 0.104 78.27 1.09E+13 1.79E+03 2.665 183CH 10427.35 4000 13.53 0.048 0.099 78.91 9.86E+12 1.54E+03 2.665 Footnotes : (1) : Denotes fractured or chipped sample. Permeability and/or porosity may be optimistic. (2) : Sample permeability less than 0.001 mD at indicated stress. Porosity unavailable at indicated NCS. (3) : Sample permeability less than 0.001 mD at indicated stress. Porosity determined using Boy/e's law grain volume & dimension calculated bulk volumes at ambient conditions. Page 21 FINAL REPORT July 30,2004 ,-- - - - - ~ ---. - .-..-oI! - - ~ - - Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . ÜJre Lab PETaDUIIJ( SUYltES CL File No.: HOU-040292 Date: July 2,2004 Analyst(s): RP, LA, JH ANAL YSIS PROTOCOL Sample Preparation 1.0" & 1.5" diameter plugs were drilled with a 6% simulated KCI brine solution and trimmed into right cylinders with a diamond-bladed trim saw. The samples selected for analysis were placed into extraction·prior to analysis. All other samples were labeled, wrapped in plastic wrap, placed into hermetically sealed opaque sample jars and stored in Core Laboratories "chiller" along with the 3/4 core sections. A sample inventory outlining the location of each sample has been included in the back of this report (Appendix I). Core Extraction 1.0" diameter samples were placed in Dean Stark equipment using toluene until water collection reached equilibrium (minimum 48 hours), followed by soxhlet extraction cycling between chloroform/methanol azeotrope and methanol. The samples were extracted in a chloroform methanol azeotrope until cessation of discoloration and fluorescence of effluent. Silver nitrate was used as the indicator to test for the presence of salt during methanol extraction. 1.5" diameter samples were placed directly into batch extraction since no saturation data was requested. Sample Drvina Samples were vacuum dried at 105° F to weight equilibrium. Porosity Porosity was determined using Boyle's Law technique by measuring grain volume at ambient conditions and pore volume at 2500 psig NCS Additional pore volumes were measured at 1000, 1750, 3250 and 4000 psig NCS on selected samples. Grain Densitv Grain density values were calculated by direct measurement of ~rain volume and weight on dried plug samples. Grain volume was measured by Boyle's Law technique. Permeabilitv Klinkenberg permeabilities were measured using unsteady-state method at 2500 psig NCS. Additional permeabilities were measured at 1000, 1750, 3250, and 4000 psig NCS on selected samples. fluid Saturations Fluid saturations were determined by the Dean Stark technique using the following fluid properties: Brine 50000 ppm TDS Oil 0.816 g/cc Page 22 FINAL REPORT July 30, 2004 - - ,-....¡ - ~ - ---. - - - - CL File No.: HOU-040292 Date: July 2, 2004 Analyst(s): RP, LA, JH A CorE! Lab lnJIDUVI( 5EBYItES Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska IINTERLAMsm THIN BED SAMPLE DESCRIPTION I DESCRIPTION CODE KEY AND ABBREVIATIONS LITHOLOGY 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 b-w blue-white vs very slightly Sst Sand bz bronze s slightly Sh Shale gld gold m moderately Sltstn Silt gry gray mw moderately well Sf Shell Fragments y yellow v very w well GRAIN SIZE OTHER vfg very fine grain calc calcareous biot bioturbated fg fine grain cln clean hd hard mg medium grain carb carbonaceous lam laminated(ion) cg coarse grain cern cementation mic micaceous con consolidated ms mudshot dns dense shy shaley flu fluorescence slty silty foss fossiliferous tr trace frc fractured(s) vug vuggy It light vt vertical TYPE 2 TYPE 1 . . .' ... .' . ... . . .. .. ." .. . . ··0.. .. . 0..".· .. .. SHALE LAMINATIONS 1-5 mm SHALE LAMINATIONS < 1 mm TYPE 4 TYPE 3 :.' -t . . ' ,¿. . ' .- ~ !. ',f 's.. O)i;'."- . -.' .'"-, ~-= . ':~'_1 . ~._~ 0"'-:- )'. ." - . ". : .'-~~ ~~};:. "." --"'~ ~: : . . .:~ '!. -':." ~ ,.., j. -., " SHALE LAMINATIONS> 10 mm SHALE LAMINATIONS 5-10 mm :.-::;}- -" ". .....~. ". ~ . July 30,2004 FINAL REPORT Page 23 - - - ~ - - - - - Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska . Core Lab rnuuvII: SJJlYIŒS APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" K., = Kair b ß (Beta) = a (Alpha) = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD Permeability to Air, calculated using K", and b, mD Klinkenberg slip factor, psi Forcheimer inertial resistance factor, ft-1 A factor equal to the product of Beta and K",. This factor is employed in determining the pore level heterogeneity index, Hi' Hi a, microns = 3.238E -9 ßK., log10 (aø/RQI) ø = Porosity, fraction RQI = Reservoir Quality Index, microns RQI 0.0314(K/ø)O.5 = For further information please refer to: Jones, S. C.: "Two-Point Determination of Permeability and PV vs. Net Confining Stress" SPE Formation Evaluation (March 1988) 235-241. Jones S.C.: "A Rapid Accurate Unsteady-State Klinkenberg Permeameter," Soc. Pet. Ena. J. (Oct. 1972) 383-397. Jones, S.C.: "Using the Inertial Coefficient, ß, To Characterize Heterogeneity in Reservoir Rock: SPE 16949 (September 1987). Amaefule, J.D.; Kersey, D.G.; Marschall, D.M.; Powell, J.D.; Valencia, L.E.; Keelan, D.K.: "Reservoir Description: A Practical Synergistic Engineering and Geological Approach Based on Analysis of Core Data,: SPE Technical Conference (Oct. 1988) SPE 18167. Page 24 FINAL REPORT -- ~ - CL File No.: HOU-040292 Date: May 21,2004 Analyst( s): RP, LA, JH July 30, 2004 - .-- - - -- - --==--=~.. ~ . ÚJœ LaI:Î RESERVOIR oPT!HIZAnoll Figures for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well ,·NW Milne Point Alaska CL File No.: HOU-040292 Date: July 30, 2004 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 Petrophysics, Inc. 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 Petrophysics, Inc., 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. CORE PETROPHYSICS 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 .. .. .. .. Kerr-McGee Oil &. Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska ..- c 52 0.0001 100 Samples 10 .---¡-----¡-- I I 0.1 0.01 I 4> 0.001 o Figure 1 .. .. .. .. - - - - - .. - Permeability vs Porosity @ 2500 psig NCS (Composite) H1!W!TIII! H~Yln5 5 10 4> 15 Porosity (%) - - - - CL File No.: HOU-040292 Date: July 30,2004 20 25 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil 8. Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: July 30, 2004 HfkIlJ.ŒI\S!'.ßVltrs Permeability vs Porosity @ 2500 psig NCS (1.0" Diameter Samples) 100 , ----L -j- 10 I ., .. ê .s - c:: S2 0.1 . 0.01 I I I I . 0.001 . 0.0001 o 5 10 15 20 25 Figure 2 Porosity (%) .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil &. Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska ê E ......, - c 2 0.0001 CL File No.: HOU-040292 Date: July 30, 2004 Permeability vs Porosity @ 2500 psig NCS (1.511 Diameter Samples) 100 I I I I I I I I I I I , I I I I ~ I I , I I I I I I I I I I I ì I I I I I I I I I I I I I I I I I I , ! I I I I I I I I I I I I I I I ; I I I I I I I I I I I I I I I I I I I I I I , I I I ì I. I I I I I M I I I I I .'1' I : I , , I I I I I I I I I I I I I I I :'" I I I I I I k I .. . I .: I I I I I I I I I I I I : " I I I I I I I I I ~ " " I I , I A I I I I I I I . I I : I I , , I I I I I I , I , I I I I I I I I I I I , I I , , I I , , I , I I I I I ! , I I I I I I , I , , I I , I , , , , , , I I I I I I I I I I I I I , .- , I I I , I I , I I I I I I , I I , I I I I I I I I I I I I I I I I I I I I , , I I I I I , I I I I I I I I I I I I I I I I I I I I I 10 0.1 0.01 0.001 o 10 25 5 15 20 Figure 3 Porosity (%) .. .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska 100 10 ê §. .... c 52 0.1 0.01 0.001 0.0001 Figure 4 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. CL File No.: HOU-040292 Date: July 30, 2004 Permeability vs Porosity @ Various NCS (1.011 Diameter Samples) 1.0" Diameter " 1.0" Diameter Samples 1.0" 1.0" 1 ""----'-- 1 1 1 o . 1 1 1 1 1 1 .' 1 1 5 10 15 20 25 Porosity (%) .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska ..- c 52 0.0001 0.001 CL File No.: HOU-040292 Date: July 30, 2004 Permeability vs Porosity @ Various NCS (1.511 Diameter Samples) 100 I , ~ 1i111.5" Diameter Samples (1000 psigNCS) I I I I I I I I I , I I I I ! I I I i I I , I I I I I I I , I 1.5" Diameter Samples r ~~, I , I 1.5" Diameter , i i I i , I '.", i · I , i , i i ,. I I i , X1.5" i I , , i I , I 1.5" I , " ,''' -- i I , ü' I , i I ! I : I I A I I I I I I i · i i , i . "'a Q I i I I I I I I I I I I I i I , , , , , i , , i , I I I I I , I , I I I I A ~ I , I I 'A' I I I I I ,: ~ , , '" , I I I I · , , , , ~ ~: , , I i I I I I I , I I I I , , , , i , i , ---+- I ~ ! I I I ~ ! I I I I , , , , , , , I I I i , i I , I . I I I I I , , , i . , , , , , , , i I I I I I I I , I , i , , , , i , "- I I I I I ! I I I I I I , , , -' , I ! I I I I , , , , , , I I I I I , , , I I , , I I I I I , , , , , , , , , I , I I I I I I I I I I I I I , , , , , ~ I , I , I I I I I I I , I I ! , I I I I I I I I I I , , , i ,!! I , I I I I I , , , , , ! I I I I I I I I I I , I I ! I ! I I I I I I I I I I I I , I ! I I I I I I I , I I I I I I , 10 0.1 0.01 o 5 10 15 20 25 Figure 5 Porosity (%) ------------------- Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: July 30, 2004 Permeability vs Water Saturation @ 2500 psig NCS (1.011 Diameter Samples) 100 10 , --+ , , , I I , I , I I , , I , I I I I , I I I I I , , , , , I , , , , , , , , , , [ , ",-, A .. , . , .. , .;. . "" , i . , Iii' , , , , , , , , ..., . , , , !IIi 11II A , , , , '.,. , "",. , , , . "" , , . , I ... .. , . .. ~. , , , , . - .-- - A , , I , . A . . t I : I , , I I r'f''''' . " Ii' , , , I» . I - c---- , I I , ... 1 , [ , i , . , I , ; , , , I : : ! , , I I I 1/1I . - . , ~ 1 . 1 I , i I I , , I ... ! , , I , 1/1I' , , , I , I , I I I I , I I : , , I I , ; , I , , , , i ; i I , I Ô E - - c: ::;2 0.1 0.01 0.001 0.0001 o 10 20 30 40 50 60 Water Saturation (%) 70 80 90 100 Figure 6 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: July 30, 2004 PfrRfiH:ü¥. srG~![rs Permeability vs Grain Density @ 2500 psig NCS (Composite) 100 10 ~ 1.0" ~: I I I I 1 I , I I I I I I I I 1 1 , I I I I ~ 1 , . '.;;1 I I , I I I I I , I , I ~ ~; I I , 1 , I I i I , I , I I I I I I I I , i I , I I 1 , , 1 I , I , , I I I I , , 1 I I , , , , I , 1 1 i -' , , I , , I , I 1 I , I I , ~ i , , 1 i , i , , i , I I 1IIIr, '" I I I I I , I I I I 1 I i I I , I , I ,f 1_ , i , , , , , , , 1 , , I , ~.. I"" , i I 1 , , I ; : 1 , , I I I I I I I I , I I , , , , 1 I , 1 1 I 1 1 , , . . ._, III , , I I I I I ... _" I I . , - 1 , 1 I .. .-.. I 1 , I I I I I I , , , , , , 1 I 1 I .:~ ,". I , ~ I I I I I I I I I I 1 I 1 I ; 1 1 1 I ~ . IIÞ i 1 i i I I I 1 1 1 I 1 I I ... I 1 , , .-. ~ . . , , I I I I .. !IO"- "I' I 1 1 I I I I I I I I , I I I I 1 I I i i 1 I I .: .: I i i , I i I , I I i I i . I· . , ; ; I I I I i , , , , i , 1 1 , I ,- I I I I - 'm I 1 I I I I I 11III , i I , I I . 1 , , i , , , , I I I I I 1 , 1 1 I , I 1 I I I I I 1 , , , I 1 , 1 I I I I , , 1 1 1 I 1 1 1 1 I , , , I I 1 I 1 1 1 1 , . , I 1 1 , , - ,. , 1 I , I . , ~ , , , , 1 , III ""I , I I , I I , I ... , 1 I , I I I I I I I 1 J. , , : I I i , I I I I I 1 I 1 iIiI 1 I : 1 , I , , , I I , I I I I , I i , I , , I , , , I I I , I I I I I , , I I I I , , I : I I I I i I I I I I I i I I I i I I I I I , I I I I I , I I I I I I I I I I I I 1 I - c 52 0.1 0.01 0.001 0.0001 2.6 2.65 2.7 2.75 Grain Density (glee) 2.8 2.85 2.9 Figure 7 I I I I I I I I I I I I I I I I I I I -Total Gamma o Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 File No.: HOU-040292 Spectral Core Gamma Scale 5" = 100' - Potassium (%) Uranium (ppm) - Thorium (ppm) 100 200 300 400 500 0 10350 5 0 3 30 ~~------- Figure 8 I~n~__ 10360 10370 10380 ---- 10390 10400 10410 10420 10430 10440 10450 10460 10470 10480 10490 10500 5 0 ---------- p '----- I ----- ~ ....... i - __ ___n__________________ 10470 10480 10490 10500 0 50 0 100 2.0 2.5 3,0 I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska I I -Kin! (mD) I -Total Gamma I I I I I I I I I I I I I I I Figure 9 CORE ANAL YSIS DA TA Scale 5" :::: 100' -Sco (%) -Stw (%) 10350 10360 10370 10380 __ ___ _.______mm_ 10390 10400 10410 10420 10430 10440 10450 File No.: HOU·040292 Date: July 30, 2004 Analyst(s): RP, LA, JH -Porosity(%) - Grain Density (glee) I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska I I Profile Permeability (Klinkenberg Corrected) Measurements 5" = 100' 100 10 0.1 0.01 0.001 10350 10360 10370 10380 10390 10400 10410 10420 10430 10440 10450 10460 10470 10480 10490 10500 I I I I I I I I I I I I I I I Figure 10 File No : HOU 040292 Date: April 8, 2004 I I I I I I I I I I I I I I ~ 60 Z I W 50 -::¡¡¡ I 5 40 ~ I I I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: May 21 , 2004 Analyst(s): RP, LA, JH PERMEABILITY HISTOGRAM 100 90 80 70 (') 60 c: i!1: c: ¡- 50 ::¡ <: IT! 40 -;J¿ 0 30 20 10 0 100-1000 100 - - - CUMULATIVE CAPACITY 90 80 70 -;J¿ 0 -I 60 <t I- Z W 50 :::¡¡¡ W ex: u 40 ~ 30 20 10 0 0.0001-0.001 0.001-0.01 0.01-0.1 .1-1.00 1.00-10.0 PERMEABILlTY-Kinf 10.0-100 POROSITY HISTOGRAM 100 - - - CUMULATIVE CAPACITY 90 80 70 30 - 20 10 o 7-10 10-13 13-16 16-19 POROSITY 19-22 22-25 1-4 4-7 Figure 11 100 90 80 70 (') 60 c: i!1: c: 50; -I <: 40 IT! -;J¿ o 30 20 10 o - - - - - - - - - - - - - - - - - - - .. Core LaI:Î RESERVOIR OPTIMIZATION Appendix I Sample Inventory for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska CL File No.: HOU-040292 Date: July 30, 2004 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 Petrophysics, Inc. 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 Petrophysics, Inc., 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. CORE PETROPHYSICS 6316 WINDFERN HOUSTON, TEXAS 77040 (713) 328-2565 FAX (713) 328-2567 .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Core Sample Log (Updated 07-27-04) Smpl Depth Smpl Smpl End Routine Dean Thin No. ff Vert Len Dia Trims Analysis Stark SCAl Section XRD SEM Remarks location Date Sent Additional Comments x .00 1.50 3 x Chilled Storage 4/2212004 x 1.50 1.00 2 " j( Short Ambient Storage 5/24/2004 x 3.00 1.50 3 x Chilled Storage 4/22/2004 3 10392.20 x 2.00 1.00 2 x '- Ambient Storage 5/24/2004 Trims to B. Wawak (04-08·04) 238DH 10392.35 x 3.00 1.50 8 " Chilled Storage 4/2212004 4 10393.20 x 1.75 1.00 2 " " Ambient Storage 5/24/2004 239DH 10393.35 x 2.75 1.50 3 Chilled Storage 4/2212004 5 10394.20 g 1.75 1.00 2 x ¡ Ambient Storage 5/24/2004 240DH 10394.35 2.75 1.50 3 " Chilled Storage 4/2212004 6 10395.20 1.00 2 " x Ambient Storage 5/24/2004 Trims to 8. Wawak (04-08·04) 241DH 10395.35 3.00 1.50 3 " Chilled Storage 4/2212004 7 10396.20 1.75 1.00 2 . '- Ambient Storage 24/2004 242DH 10396.35 3.00 1.50 3 . Chilled 92PS 10396.90 x =t= 2.00 1.50 2 Chilled Storage 4/8/2004 8 10397.10 x 2.00 1.00 2 " " 5/24/2004 153CH 10397.40 x 3.00 1.50 2 x x Ambient Storage 5/24/2004 243DH 10397.45 x 3.00 1.50 3 x Chilled Storage 4/2212004 101BV 10397.70 x x 2.50 .00 2 x \( Ambient Storage 5/24/2004 102CV 10397.70 x x 2.75 1.50 2 x Chilled Storage 4/9/2004 9 10398.20 jj 2.00 1.00 2 x x Ambient Storage 5/24/2004 154CH 10398.35 2.00 1.50 2 x x Ambient Storage 5/24/2004 244DH ~ x 3.00 1.50 3 x Chilled Storage 4/22/2004 245DH 10399.10 x 3.00 1.50 3 Chilled Storage 4/2212004 1 2.00 1.00 2 t 103BV 10400.40 x x 1.00 5/24/2004 104CV 10400.40 I x I x 3.00 Chilled Storage 4/9/2004 156CH 10400.90 x 3.00 1. 5/24/2004 157CH 10401.35 x 3.00 1.50 2 x x Ambient Storage 5/24/2004 x 158CH 10402.55 x 1.50 2 x Frac Ambient Storage 5/2412004 14 I 10403.20 I x 1.00 2 j( I Ambient Storage I 5/24/2004 Trims to B. Wawak (04-08-04) Page 1 .. .. .. .. .. .. .. .. Nikaitchuq 02 Sample Inventory .. .. .. .. .. Start Date' 03--28-04 File No : HOU 040292 .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 WeB NW Miine Point Alaska Start Date: 03-28-04 File No : HOU 040292 Core Sample Log (Updated 07-27-04) Smpl Depth No. (ft) 159CH 10403.30 1058V 10403.70 105CV 10403.70 End Trims Routine Dean Stark SCAl Thin Section XRD SEM Remarks location Date Sent Additional Comments x Page 2 Nikaitchuq 02 Sample Inventory - .. - Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Core Sample Log (Updated 07-27-04) Smpl Deplh Smpl Smpl End Routine Dean Thin No. tt Vert Len Día Trims Anal is Stark SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 257DH 10412.40 Chilled Storage 4/2212004 111BV 10412.70 x Ambient Storage 5/2412004 112CV 10412.70 x Short Chilled S10rage 4/9/2004 258DH 10413. Chilled Sto 4/2212004 169CH 10413.35 x 3.00 1.50 3 x x 259DH 10414.05 x 2.75 1.50 3 J( 25 10414.20 x 2.00 1.00 2 J( x 170CH 10414.35 x 3.00 1.50 2 x x Frac 260DH 10415.05 x 2.50 1.50 3 Short 3.00 x Ambient Storage 5/24/2004 113BV 10415.70 x x 3.00 , Ambient S10rage 5/24/2004 114CV 10415.70 x x 3.00 1.50 2 x Chilled Storage 4/9/2004 x 2.00 1.00 2 := x Ambient Storage 5/24/2004 3.00 1.50 3 x Ambient Storage 5/24/2004 3.00 1.50 3 174CH 10416.35 x 3.00 1.50 3 x Ambient Storage 5/24/2 263DH 10418.45 x I 2.75 J( Chilled Storage 4/22/2004 115BV 10418.70 x I I )( 3.00 x Ambient Storage 5/24/2004 116CV 10418.70 x )( 3.00 1.50 2 x Chilled Storage 4/912004 2ô4DH 10419.10 )( 2.75 1.50 3 x Chilled S10rage 4/22/2004 30 10419.20 x 2.00 1.00 2 J( x Ambient S10rage 5/2412004 175CH 10419.35 3.00 10421.10 3 Chilled Storaae 4/2212004 Rubble @ 10420-10420.8 10421.20 x 2 J( Ambient S1Qrage 5/2412004 Trims to B. Wawak (04·08-04) 177CH -~ x 3 J( x Ambient S10rage 5/24/2004 Rubble @ 10420-10420.6 117BV 10421 x )( 3.00 00 2 )( I )( Ambient S10rage 5/24/2004 116CV 10421.70 x .50 I 2 I x Chilled Storage 4/912004 Page 3 .. - .. - - .. .. - Nikaitchuq 02 Sample Inventory - - .. - .. .. Start Date: 03·28-04 File No : HOU 040292 - - - - - - - - .. - - .. - - - - - - - - - Kerr-McGee Oil & Gas Corporation Nikaftchuq 2 Weli NW Milne Point Alaska Start Date: 03-28-04 File No : HOU 040292 Core Sample log (Updated 07-27-04) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Good Fair Vert Len Dia Trims Analysis Stark SCAl Section XRD SEM Remarks location Date Sent Addftional Comments 33 10422.20 x 2.00 1.00 2 x x Ambient Storage 5/24/2004 178CH 10422.35 x 3.00 1.50 3 x x Ambient Storage 5/2412004 266DH 10422.45 x 3.00 1.50 3 x Chilled Storage 4/2212004 10423.05 3 Chilled Sto 4/2212004 179CH 10423.35 x 1.50 3 x x Ambient Storage 5/24/2004 268DH 10424.10 x 3.00 1.50 3 x Chilled S10rage 4/2212004 35 10424.20 x 2.00 1.00 2 k x Ambient Storaoe 5/24/2004 180CH 10424.35 x 3.00 1.50 3 x x Ambient Storage 5/24/2004 269DH 10424.45 x 3.00 1.50 3 J( Chilled Storage 4/2212004 119BV 10424.70 x x 3.00 1.00 2 Ambient Storage 5/24/2004 120CV 10424.70 x x 3.00 Chilled Storage 4/9/2004 181CH 10425.05 x A 5/24/2004 37 10426.20 x 2 J( x Ambient Storage 5124/2004 182CH 10426.35 x I I 3 j¡ I J( I Ambient Storage 5/24/2004 270DH 10426.45 x 3 4/2212004 38 10427.20 x 2 J( x Ambient Storaoe 5124/2004 183CH 10427.35 x 1.50 3 j¡ j¡ Ambient Storage 5124/2004 271DH 10427.66 x 1.50 3 j¡ Chilled Storaoe 412212004 10427.70 1.00 2 j¡ x 10427.70 1.50 2 3.00 1.50 3 j¡ Chilled Storage 4/1012004 10428.45 3.00 1.50 3 . Chilled Storage 412212004 40 10429.30 2.00 1.00 2 J( x Ambient Storage 5/24/2004 Trims to B. 185CH 10429.45 x 3.00 1.50 3 J( Chilled Storage 4/1012004 273DH 10429.60 x t±= 3.00 1.50 3 x Chilled Storage 4/2212004 f=i= 10430.50 x 2.00 1.00 2 J( x Ambient Storage 512412004 10430.85 x 3.00 3 x Chilled Storaoe 411012004 10430.70 x x 3.00 . x Ambient Storage 5124/2004 10430.70 x x 3.00 " 10430.85 x 3.00 167CH 10431.60 x 3.00 J( Chilled Storage 4/1012004 Page 4 Nikaitchuq 02 Sample Inventory .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Weil NW Milne Point Alaska Start Date: 03-28-04 File No : HOU 040292 Core Sample Log (Updated 07-27-04) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Vert Len Dia Trims Analysis Stark SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 10431.70 3.00 1.50 Chilled 4/2212004 188CH 10432.35 3.00 1.50 3 ]( 4/10/2004 276DH 10432.50 3.00 1.50 3 ]( hìlled Storage 4/2212004 277DH 10433.10 3.00 1.50 3 ]( hilled Storage 4/2212004 44 10433.20 2.00 1.00 2 ]( ;< Ambient Storage I 5/24/2004 189CH 10433 3.00 1.50 3 ]( 4/10/2004 .70 J( 3.00 1.00 = )( Ambient Storage 5/24/2004 .70 J( 3.00 1.50 2 ]( Chìlled Storage 419/2004 45 2.00 1.00 2 ]( x Ambient Storage 5/24/2004 190CH 10434 .45 x 1.50 1.50 3 ]( Short Chiiled Storage 4/10/2004 278DH 10434.55 x 2.25 1.50 3 x Short Chiiled Storage 4/2212004 45 10435.20 2.00 1.00 2 x x Ambient Storage 5/24/2004 191CH 10435.45 3.00 1.50 3 x Chilled Storage 4/10/2004 279DH 10435.60 1.50 3 x 3 x Chilled Storage x Chìlled Storage 4/2212004 Ambient Storage 5/24/2004 Chilled 4/9/2004 3.00 Chilled Storage 4/22/2004 2.00 ' I x Ambient Storage 5/24/2004 194CH 10438.35 x 3.00 x Chìlled Storage 4/10/2004 282DH 10438.50 x 3.00 1.50 x Chilled Storage 4/2212004 50 10439 .20 x 2.00 1.00 x x Ambient Storage 5/2412004 Trims to 6. Wawak 195CH 10439.35 x 3.00 1.50 3 =: Chilled Storage 4/10/2004 283DH 10439.50 x 3.00 1.50 3 Chilled Storage 4/2212004 129BV 10439.70 x 1.00 2 x x Ambient Storage 5/24/2004 130CV 10439.70 x 1.50 2 x Chilled Storage 4/9/2004 196CH 10440.05 x 1.50 3 )( Chilled Storage 4/10/2004 51 10440.20 x 1.00 2 x x Ambient Storage 5/2412004 2ß4DH 10440.50 x 1.50 3 x Chilled storage 4I22!2OO4 265DH 10441.10 x 3.00 1.50 3 x I Chilled storage 4/2212004 52 ''''~ 2.00 1.00 2 J( x I Ambient Storaae 5/24/2004 197CH 10441.35 3.00 1."" .. x Chilled StoraQe 4/10/2004 286DH 10442 3.00 1.50 3 J( Chilled Storage 412212004 Page 5 Nikaitchuq 02 Sample Inventory .. .. .. Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Core Sample Log (Updated 07-27-04) No. Trims Anal is Stark SCAl Section XRD Remarks location Date Sent Additional Comments 3.00 1.50 3 x Chilled Storage 4/1 1318 x 2.25 1.00 2 . x Ambient Storage 5/24/2004 132CV 10442.75 x 1 .50 2 x Chilled Storage 419/2004 287DH 10443.05 x 1.50 3 x Chilled Storage 4/2212004 54 10443.20 x 1.00 2 . x Ambient Storage 5/24/2004 199CH 10443.35 x 1.50 3 x Chilled Storage 4/10/2004 55 10444.20 x 1.00 2 x x Ambient Storage 5/24/2004 200CH 10444.35 x 1.50 3 x Chilled Storage 4/10/2004 288DH 10444.45 x 1.50 3 x Chilled Storage 4/2212004 56 10445.20 x 1.00 2 x x Ambient Storage 5/24/2004 201CH 10445.35 x 3.00 1.50 3 x Chilled Storage 289DH 10445.45 x 3.00 1.50 3 x Chilled Storage 133BV 10445.70 x x 3.00 1.00 2 x 1. Ambient 134CV 10445.70 x x 3.00 1.50 2 'ffi3 Chilled Storage 4/9/2004 57 10446.20 x 2.00 2 Ambient Storage 5/24/2004 202CH 10446.35 x 3 Chilled Storage 4/1012004 290DH 10446.45 x 3 x Chilled Storage 4/2212004 97PS 10447.05 x 2 Chilled Storage 4/8/2004 58 10447.20 x I x Ambient Storage 5/24/2004 T.'~. .D 291DH 10447.65 x 1.50 3 Chilled Storage 4/2212004 59 10448.10 x 1.00 2 . x Ambient Storage 5/24/2004 204CH 10448.35 1.50 3 j( Chilled Storage 4/10/2004 3. 1.50 3 j( Chilled Storage 4/2212004 x 3. 1.00 2 J( x Ambient Storage 5/24/2004 )( 3. 1.50 2 60 10449.35 2.00 1.00 2 j( Ambient Stora!:!e 5/24/2004 205CH 10449.35 x 3.00 1.50 I 3 j( Chilled Storage 4/10/2004 293DH 10449.60 3.00 4/2212004 206CH 10450.35 x 3.00 1.50 Chilled Storaoe 4/1012004 294DH 10450.75 )( 3.00 1.50 I I j( Chilled Storage 4/2212004 295DH 10451.05 x 1.50 4!22!2OO4 10451.35 )( 1.50 j( ChUIed Storage 4/1012004 137BV 10451.60 x 3.00 1,00 2 x I I Ambient Storage 5/24/2004 Page 6 .. .. .. .. .. .. .. .. Nikaitchuq 02 Sample Inventory .. .. .. .. .. .. Start Date: 03-28-04 File No : HOU 040292 .. .. - - - - - - - - - - - - - - - - - - - Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Start Date: 03-28-04 File No . HOU 040292 Core Sample Log (Updated 07-27-(4) Smpl Depth ~':" :± 'm,' End Routine Dean Thin No. (ft) Len Dia Trims Analysis Stark SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 138CV 10451.60 3 1.50 2 J< Chilled Storage 4/9/2004 296DH 10452.05 3.00 1.50 3 J< Chilled Storage 412212004 2û8CH 10452.35 x 3.00 1. 4/10/2004 209CH 10453.35 3.00 1.50 3 J< Chilled Storage 4/10/2004 297DH 10453.50 x 3.00 1.50 3 J< Chilled Storage 412212004 298DH 10454.10 x 3.00 1.50 ±" Chilled Storage 412212004 65 10454.20 x 2.00 1.00 ,,< Ambient Storage 5/24/2004 210CH 10454.35 x 3.00 1.50 3 J< Chilled Storage 4/10/2004 1398V 10454.70 x x 3.00 1.00 2 J< < Ambient Storage 5/24/2004 140CV 10454.70 x x 3.00 1.50 2 x Chilled Storage 4/9/2004 299DH 10455.10 x 3.00 1.50 3 " Chilled Storage 412212004 66 10455.20 x H={ 2.00 1.00 2 J< x Ambient Storage 5/24/2004 211CH 10465.35 3.00 1.50 3 " Chilled Storage 4/10/2004 300DH 10456.10 3.00 1.50 2 x Chilled Storage 4/2212 67 10456.20 I ¡ 2.00 1.00 2 k Ambient Storage 5 212CH 10456.35 1.50 Chilled 4 1.00 2 x x Ambient Storage 5/24/2004 Trím5 10 B. M ... 213CH 1.50 3 x Chilled Storage 4/10/2004 141BV 7.50 1.00 2 J< r Ambient Storage 5/24/2004 142CV 7.50 1.50 2 J< Chilled Storage 4/9/2004 69 10458.20 1.00 2 J< x Ambient Storage 5124/2004 214CH 10458.35 x 1.50 3 J< Short Chilled Storage 4/10/2004 301DH 10458.60 J< 1.50 3 '" Short Chilled Storage 412212004 302DH 10459.10 x 1.50 3 J< Chilled Storage 412212004 70 10459.20 x 1.00 2 x x Ambient Storage 512412004 215CH 10459.35 x 1.50 3 )( Short Chilled Storage 4110/2004 216CH 10460.05 1.50 3 Short 4/10/2004 10450.50 x )( x Ambient Storage 5124/2004 10450.70 x 2 j( )( 512412004 144CV 10460.70 x x 3.00 1.1;0 2 '" Chilled Storaae 419/2004 303DH 10461.05 x 3.00 1.50 3 '" Chilled Storaae 412212004 72 10461.20 x 2.00 1.00 2 )( x Ambient Storage 512412004 217CH 10461.40 x 2.75 1.50 3 a x ChiDed Storaae 4/10/2004 73 10462.50 x 1.75 1.00 2 )( Ambient Storage 512412004 21SCH 10462.65 x 3,00 1.50 3 '" Frac Chilled Storage 4110/2004 Page 7 Nikaitchuq 02 Sample Inventory - - - - - - - - - - - - - - - - - - Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Start Date: 03-28-04 File No . HOU 040292 Core Sample Log (Updated 07-27-04) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Vert Len Dia Trims Analysis Stark SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 74 10463.20 2 Ambient Stor 5/24/2004 to Wawak ,~, M ." 10465.20 1.00 2 ~ x Ambient Storage 5124/2004 Trims to 8. Wawak (04-08-04) 77 10466.20 1.00 2 x x Ambient Storage 512412004 99PS 10467.05 2.00 1.50 2 Chilled Storage 41812004 78 10467.20 x 2.00 2 Ambient Storage 5/24/2004 219CH 10467.35 x 3.00 3 x Chilled Storage 4/10/2004 145BV 10467.70 x x .00 2 )( Ambient Storage 5/24/2004 146CV 10467.70 ill 1.50 2 )( Chilled Storage 4/9/2004 79 10468.20 1.00 2 )( Ä Ambient Storage 5/24/2004 220CH 10468.35 x 1.50 3 )( Chilled Storage 4/1012004 80 10469.20 x 2.00 1.00 2 x x Ambient Storage 5/24/2004 221CH 10469.35 x 3.00 1.50 3 x Chilled Storage 4/1012004 81 10470.20 x 2.00 1.00 2 x x Ambient Storage 5/24/2004 222CH 10470.35 x 3.00 1.50 3 x Chilled Storage 4/1012004 147BV 10470.70 x x 2.50 1.00 2 x x Ambient Storage 5/24/2004 148CV 10470.70 x x ~: x Chilled Storage 4/9/2004 82 10471.20 x x x ~ Ambient Storage 5/24/2004 Trims to 8. 223CH 10471.35 x I 2.50 1.50 3 x Chilled Storage 4/10/2004 83 10472.20 x 2.00 1.00 2 x x Ambient Storage 5/24/2004 224CH 10472.35 x 3.00 1.50 3 x Chilled Storage 4/1012004 84 x 2.00 1.00 2 x x Ambient Storage 5/24/2004 225CH 10473.35 x 3.00 1.50 3 x Chilled Storage 4/1012004 149BV 10473.70 x m 1.00 :2 x Ambient Storage 5/24/2004 150CV 10473.70 x 1.50 2 x Chilled Storage 41912004 65 10474.20 x 1.00 2 x x Ambient Storage 5/2412004 Trims to 8. mcH ß§~ x 1.50 3 x Chilled Storage 4/1012004 86 20 x 2.00 1.00 2 x x Ambient Storage 5/2412004 227CH 10475.35 x 3.00 1.50 3 )( Frac Chilled Storage 4/1012004 87 10476.20 t 1.00 :2 x )( Ambient Storage 5124/2004 Trims to 8. " ..^ MM. 228CH 10476.35 1.50 3 x Chilled Storage 411012004 1518V 10476.70 x 2.00 1.00 2 x )( Ambient Storage 5/24/2004 152CV 10476.70 x x 3.00 1.50 :2 )( Chilled Storane 41912004 100PS 10477.05 x 2.00 1.50 2 Chilled Storage 4/812004 88 10477.20 x 2.00 1.00 2 J( )( _._"~ 229CH 10477.55 x 2.00 1.50 3 x Short 234PS 10477.70 x 1.75 ~ 2 Short,frac Chilled Storage ment "PS" sample 235PS 10477.65 x 2.75 2 Chilled~ Replacement "PS" sample 230CH 10478.10 x 3.00 1.50 3 x Chilled Page 8 Nikaitchuq 02 Sample Inventory - - - - - - - - - - - - - - - - - - - Kerr-McGee Oil & Gas Corporation Start Date: 03-28-04 Nikaitchuq 2 Well File No : HOU 040292 NW Milne Point Alaska Core Sample Log (Updated 07-27-04) Smpl Depth Smpl Smpl End Routine Dean Thin No. (ft) Good Fair Poor Failed Vert Len Dia Trims Analysis Stark SCAL Section XRD SEM Remarks Location Date Sent Additional Comments 89 x 1.50 1.00 2 x x Short Ambient Stora e 5/24/2004 Trims to B. Wawak (04-08-04) 231CH x 3.00 1.50 3 x Frac 4/1012004 90 x 1.88 1.00 2 x x Trims to B. Wawak (04-08-04) Page 9 Nikaitchuq 02 Sample Inventory I I I I I I I I I I I I I I I I I I I A CorE! LaI:Î RESERVOIR OPTIMIZATION Appendix II Qualitative Spontaneous Imbibition Study for Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well 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 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 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. Core Petrophysics . 6316 Windfern . Houston, TX 77040 USA . Tel: 713-328-2565 . Fax: 713-328-2567 I Â\ [orE! Lab RESERVOIR OPTOOZATIOH IKerr-MCGee Oil & Gas Corporation Nikaitchuq 2 Well INW Milne Point Alaska File No : HOU-040292 Date: April 30, 2004 I Qualitative Spontaneous Imbibition Photoaraphv Analytical Protocol I,-hree (3) sections of core (10409.30 - 10410.00, 10432.10 - 10432.70 & 10468.00 - 10468.63) were selected from sand intervals for qualitative spontaneous imbibition photography. Two (2) fluids were used for this test: a brine solution (35000 ppm) Ihi9h gravity mineral oil (420 API). The results of this photographic analysis can be found in this report. I I I I I I I I I I I I I Table of Contents Depth Range (ft) 10409.30 - 10410.00 10409.30 - 10410.00 10409.30 - 10410.00 10409.30 - 10410.00 10409.30 - 10410.00 10409.30 - 10410.00 10432.10 - 10432.70 10432.10- 10432.70 10432.10 - 10432.70 10432.10 - 10432.70 10432.10 - 10432.70 10432.10 - 10432.70 10468.00 - 10468.63 10468.00 - 10468.63 10468.00 - 10468.63 10468.00 - 10468.63 10468.00 - 10468.63 10468.00 - 10468.63 Time Interval (minutes) 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 Appendix II CORE PETROPHYSICS . 6316 WINDFERN . HOUSTON, TEXAS 77040 . (713) 328-2565 . FAX (713) 328-2567 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photoqraphv 10409.30 - 10410.00 o minutes 10409.30 - 10410.00 5 minutes Page 1 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oii & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photography 10409.30 - 10410.00 10 minutes 10409.30 - 10410.00 20 minutes Page 2 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photography 10409.30 - 10410.00 30 minutes 10409.30 - 10410.00 60 minutes Page 3 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photoaraphv 10432.10 - 10432.70 o minutes 10432.10 - 10432.70 5 minutes Page 4 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photography 1 0432.1 0 - 1 0432.70 10 minutes 10432.10 - 10432.70 20 minutes Page 5 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photography 10432.10 - 10432.70 30 minutes 10432.10 - 10432.70 60 minutes Page 6 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photography 10468.00 - 10468.63 o minutes 10468.00 - 10468.63 5 minutes Page 7 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photoaraphv 10468.00 - 10468.63 10 minutes 10468.00 - 10468.63 20 minutes Page 8 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I Qualitative Spontaneous Imbibition Photo~raphv 10468.00 - 10468.63 30 minutes 10468.00 - 10468.63 60 minutes Page 9 Qualitative Spontaneous Imbibition File No : HOU-040292 Date: April 30, 2004 I . Core Lab RESERVOIR OPTIMIZATION I I I I Appendix III Statistical Averages I for I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point I I Alaska I I I I I I I I I 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 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. Core Petrophysics 6316 Windfern Houston, TX 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 I I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well I NW Milne Point Alaska I I I I I I I I I I I I I I I I .ê Core Lab P£TRDLEIJX SEIIVICES CL FileNo.: HOU-040292 Date: May21, 2004 Analyst(s): RP, LA, JH STATISTICAL AVERAGES Net Confining Stress Total Core Footage Footage Included in Statistics PERMEABILITY (Klinkenberg) Arithmetic Mean Geometric Mean Harmonic Mean Flow Capacity POROSITY Arithmetic Mean Storage Capacity 10390.00 - 10480.90 2500 NCS 90.90 Feet 90.90 Feet 0.847 0.082 0.004 77.0 mD mD mD mD - feet Core Interval for Statistical Averages 13.14 % 1,194.4 Por.-feet Grain Density 2.694 glee Oil Saturation 10.2 Water Saturation 70.6 Page 1 I Â\ [ore LaIÎ RESERVOIR OPTIHI7.ATIDN I I I I Appendix IV Report Distribution I for I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point I I Alaska I I I I I I I I I This rep:xt is based entirely upon core samples, soils, solids, liquids, or gases, together with related observationaj 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 profitability or productivity on any well, sand, or drilling actNity 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. Core Petrophysics 6316 Windfern Houston, TX 77040 USA Tel: 713-328-2565 Fax: 713-328-2567 I I I I I I I I I I I I I I I I I I I I Kerr-McGee Oil & Gas Corporation Nikaitchuq 2 Well NW Milne Point Alaska Distribution of Final Reports Kerr-McGee Oil & Gas 16666 Northchase Houston, TX 77060 Attn: Rebecca Isbell Armstrong Alaska, Inc. 700 1 ih Street, Suite 1400 Denver, CO 80202 Attn: Jesse Sommer BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Blvd. Anchorage, AK 99419-6612 Attn: Brett Chambers Herbaly Exploration LLC 1420 W. Canal Ct. Ste. 150 Littleton, Colorado 80120 Alaska Oil & Gas Conservation Commission 333 West 7 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 Petrophysical Applications Inti, Inc. PO Box 130304 The Woodlands, TX 77393-0304 Attn: Dr. Robert Skopec Page 1 Report Distribution CL File No.: HOU-040292 Date: July 30, 2004 Analyst(s): RP, LA, JH 4 copies / 1 CD-ROM 4 copies / 1 CD-ROM 1 copy / 1 CD-ROM 1 copy 11 CD-ROM 1 copy / 1 CD-ROM '*'" 1 copy / 1 CD-ROM 1 copy / 1 CD-ROM Appendix IV I I I I I I I I I I I I I I I I I I I sper--r--v-sun C R I L...L.I N G 5 E R V I c: E S Kerr McGee Corporation END OF WELL REPORT Nikaitchuq 2 :J- Ò f-( - 0 J 8 I I I I TABLE OF CONTENTS I 1. Digital Compilation I 2. General Information I 3. Daily Summary 4. Morning Reports /2 PM Reports I 5. Bit Record I 6. Mud Reports 7. Show Reports I 8. Survey Report I 9. Days vs Depth 10. Gas & Lithology ASCII data I 11. Formation Evaluation Logs I 12. Engineering Log I I I I I spe...,I""Y- sun I I:IRIL.L.INt:i 5E~\JIt:E:!:ii I I I I I I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date (TD): North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: SDL Engineers: Company Geologist: SSDS Unit Number: Kerr Mcgee Corporation Nabors N27E Nikaitchuq 2 N. Milne Pt. North Slope Alaska United States 50-629-23199-00 AKAM0002893109 13th March 2004 25th March 2004 True 24.95 deg 80.906 deg 57581 NT August 21 , 2003 North 70 deg 33 min 13.99 sec East 149 deg 46 min 29.28 sec Doug Wilson Howard McClellan David Hutchins R. Geesman 101/117 sperr"v-sun ¡:¡ RI L.L.I N ~ SE FnJ I t;; E 5 I I I I I I I I I I I I I I I I I I I Nikaitchuq 2 - Diary of Events 13th March 2004 Spudded well and Drilled to 371 ft and POOH to pick up MWD tools, mud motor and 12 1,4" Bit #1 (MXC1, TFA= 0.5900). 14th March 2004 Completed picking up tools, RIH and continued drilling to 2500 ft. Mud weight was 9.4 ppg. Average ROP was 220 ft/hr, and average gas 100 unit. Maximum gas was 349 units at 2538' MD. 15th March 2004 Drillo 1214" hole to 2595' MD. Carried out wiper trip from 2500 ft to 992 ft. Serviced top drive, then RIH and continued drilling. A bottoms up gas peak of 500 units was recorded. Restricted ROP of 200 ft/hr after 4450' MD. Continued drilling and recorded gas peak of 365 units. Gas peak of 1370 units was noted at 4574' MD. Drilling continued to 4944 ft. ROP decreased in intervals 4807-4814' and 4840-4857' with no change in lithology. Average gas in this interval was 150 units. Mud weight was 9.4 ppg. 16th March 2004 Drilled to 5430 ft., circulated bottoms up and POOH to surface. Rigged up casing handling equipment, and, after a pre-job safety meeting started running 9 5/8" casing (by 23:45). 12 14" MXC1 Bit #1 statistics ( 5430 feet, 30.5 hours and 258K revolutions. 17th March 2004 Completed running casing and carried out cement job as per programme. Started working on BOPE. 18th March 2004 Testing BOPE. Started Picking up and racking 5" drill pipe. Picked up new 8 W' BHA and RIH with same. Bit #2 8 W' HCM605 PDC with TFA=0.5430. Mud weight conditioned to 9.15 ppg. 19th March 2004 Continued RIH and carried out casing test to 3500 psi. Drilled shoe track ( cement top tagged at 5333' ), float and casing shoe and 20 ft of new hole. After circulating and conditioning mud a LOT was performed to 1352 psi. Drilling resumed and a 20 stand wiper trip was made at 7910 ft without problems. 126 units trip gas was noted after short trip. Drilling continued (after washing down the last stand after the wiper trip) to 8000 ft by midnight. Start increasing mud weight to 10.4 ppg, reaching 9.7 ppg by 8000 ft. Average gas in this interval was 50-100 units. Formation consisted if Claystone and Siltstone, with traces of sand. 20th March 2004 I I I I I I I I I I I I I I I I I I I Drilled to 8363 ft. MWD tool "dies" After several attempts to revive the tool the drilling assembly is pulled to surface. The pulsar and "nuke" is replaced and the assembly is run back into the hole. Drilling resumes with mud weight being reduced to 10.3 ppg. Drilled to 8640 ft by midnight. Bit #2 was rerun. Lost returns were encountered at 8450' MD. This was treated with Barafiber while drilling, monitoring losses and reducing mud weight to 10.3 ppg. Maximum gas was 721 units at 8557' MD. Average gas was 50- 100 units in this interval. Fonnation consisted of predominately Claystone with scattered Siltstones and occasional sand stringers. 21st Match 2004 Drilling continued from 8640 ft with background level of gas increasing to 1977 units (maximum). At 9217 ft the drilling assembly was pulled due to a suspected washout after a pressure loss of some 500psi. No washout was found (checked pressure integrity twice) and after running back to bottom drilling resumed to 9575 ft. without further problems with reduced pump pressure at same GPM that caused trip for washout. Fonnation consisted of Claystone with interbedded Siltstones. Mud weight was 10.3 ppg with background gas ranging from 500 to 1500 units. At 8890' MD produced water was introduced from the Nikaitchuq #1 well ( from well testing), that gave a large heavy gas background (high C5's (pentanes) and suspected heavier hydrocarbons (C6's, C7's, etc.). The chromatograms show this clearly -(nonnal 3 minute run shows Cl through C5's). On the total gas readings from 8900 to 9575' approximately 1000-1200 units of the total gas is a result of the addition of produced water. Due to the mud system ( shakers, pumping, etc. and the" friction effect" heat of the mud pumps this was slowly being "distilled" out of the system). Polymer mud seems to hold the long chain hydrocarbons longer. 22nd March 2004 Drilling continued to 10370 ft, the potential coring point and bottoms up for samples was circulated. Drilling continued to 10390 ft, core point. In the interval 9575 to 10390' background gas average was 655 units, of which 300-400 units was due to produced water addition at 8890' MD. Produced water heavy hydrocarbon contamination continued dissipating slowly. Wiper trip perfonned. After circulating bottoms up ( maximum wiper trip gas 2014 units), the bit was pulled to surface for Core #1. Maximum drilled gas from this interval was 713 units at 9621' MD. Mud weight was 10.3 ppg. Statistics for 8 W' Bit #2 was 4960 feet, 41 hours and 677 K revolutions. 23rd March 2004 A coring assembly was made up (CB #1 8 Yz" ARC 425 C3 ) . The first and only core for this well was cut from 10390 ft to 10480 ft. Average gas while coring was 150 to 200 units, with a mud weight of 10.3 ppg. Approximately 100 units of total average gas due to lingering effects of produced water from Nikaitchuq #1 well. This additional background has stabilized. Trip gas prior to coring was 719 units. 24th March 2004 I I I I I I I I I I I I I I I I I I I The core barrel was pulled to surface and 100% core recovered. The BOPE was tested as per programme and the previous drilling assembly ( BN3 was a 8 Y2" HCM605 that had a TFA of .5520 )(as for before the core) was run. 25th March 2004 There were no problems during the trip in hole. The last stand was washed to bottom and drilling continued to 11,001 ft MD / 9507 ft TVD - the TD of the well. Noted large quantities of gas after 10613' MD, peaking at 5043 units at 10630' MD, with liquid hydrocarbons present at the shakers. The mud weight was increased to 10.6+ ppg. After reaching TD a 10 stand wiper trip was performed. Wiper Trip gas was 1299 units (background of 400 units). The hole was circulated and conditioned, with noted reduction in gas levels to 400 units. The trip out of the hole was begun. Bit #3 statistics= 521 feet, 4.7 hours and 101 K revolutions. 26th March 2004 After pulling to around 2600ft it was noted that the well was not taking the correct fluid. The bit was run back to bottom and bottoms up circulated (maximum gas = 732 units). The drilling assembly was pulled to surface without further problems. The Schlumberger wireline unit was rigged up and the logging programme begun. 27th March 2004 Continued with wireline logging programme. I I I I I I I I I I I I I I I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: 1 3/13/2004 371 371 P/U MWD tools White/ Lewis spe....,...,v-sun DRILLING SERVICES Current R.O.P. 150 Gas* Temp Out ftIh r units Deg F 14 hr Avg ftIh r ( unit~ ( ( 14 hr Max Pump and Flow Data spm Flow rate Pump 1 Pump 2 Pump SPP Liner 6.5 x Stk 700 12 Mud Wt In Mud Wt Out 9.05 ppg 9.05 ppg Visc 72 secs PV 18 cp 6.2 ml HTHP m Mud Wt at Max Gas YP 34 Ibs/100ft2 Gels 13 \ 21 \ 24 pH ppg 9.6 Sd -- Bit No.: Type: MXC1 Bit Size: 12.25" Jets: 1 x 10 \ 3x 15 \ \ TFA: 0.5900 - Wt On Bit: RPM: Hrs. On Bit: c1.5 Total Revs on Bit: 403 Footage for Bit Run 371 Trip Depth: 371 ft Trip Gas: N/A Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 90 % Sand 10 % Clay % % % Connection Gas and Mud Cut NA ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 14 hr Recap: Picked u DP and BHA. S udded Nikaitchu 2 and drilled to 371 ft. POOH to ick u MWD tools. Logging Engineer: Howard McClellan I Dave Hutchins spe..........v-sun [J RILL IN G 5 e R V I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: 1 3/14/2004 2500 2129 Drilling White/ Lewis Mudlogger's Morning Report Current 112 100 66 14 hr Avg fVhr ( unit! ( ( 14 hr Max Pump and Flow Data Pump 1 60 spm Flow rate Pump 2 60 Pump Liner 6.5 x Stk SPP 1450 fVhr units Deg F 349 2538 Mud Wt In Mud Wt Out 6.2 ml HTHP m Mud Wt at Max Gas YP 31 Ibs/100ft2 Gels 11 \ 26 \ 30 pH 9.6 Sd Visc 58 sees PV 19 eP 9.40 ppg 9.05 ppg -- 1 Type: 0-30 RPM: Bit Size: Hrs. On Bit: \ \ TFA: 0.5900 -- Footage for Bit Run 2500 Jets: 1 x 10 \ 3 x --- Total Revs on Bit: 85k MXC1 112 15 12.25" 11.4 Trip Depth: 371 ft Trip Gas: N/A Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 70 % Sand 25 % Clay 5 % Gravel % % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to 600 12 ppg 1 % Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: 1 3/15/2004 4944 2444 Drilling White/ Lewis sperrv-sun CRI LLI N G 5ERVI C:E 5 Current 14 hr Avg 14 hr Max Pump and Flow Data 200 ftIhr ftIh r ( Pump 1 67 spm Flow rate 665 150 units unit! ( 1370 4574 Pump 2 67 66 Deg F ( Pump Liner 6.5 x Stk 12 SPP 2100 Mud Wt In Mud Wt Out 9.40 ppg 9.40 ppg Visc 56 sees PV 23 eP 5.6 ml HTHP m Mud Wt at Max Gas YP 24 Ibs/100ft2 Gels 10 \ 25 \ 32 pH 9.2 Sd ppg 0.75 % -- 1 0-30 Type: RPM: MXC1 130 Bit Size: Hrs. On Bit: 12.25" 25.3 Jets: 1 x 10 \ 3 x --- Total Revs on Bit: 201 K 15 \ \ TFA: 0.5900 -- Footage for Bit Run 4944 Trip Depth: ft Trip Gas: N/A Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 50 % Sand 50 % Clay % Gravel % % Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to sper'r'v-sun C R I L..L..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 #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 4 3/16/2004 5030 486 Running CSG White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data 122 ftIhr 413 ftIh r ( 4960 Pump 1 67 spm Flow rate 665 47 units unit~ ( 74 4983 Pump 2 67 88 Deg F ( Pump Liner 6.5 x Stk 12 SPP 2100 Mud Wt In Mud Wt Out 9.45 ppg 9.45 ppg Visc 53 sees PV 20 eP Fit 6.0 ml HTHP m Mud Wt at Max Gas YP 25 Ibs/100ft2 Gels 9 \ 24 \ 31 pH -- 1 Type: 0-30 RPM: MXC1 130 Bit Size: Hrs. On Bit: 8.6 Sd ppg 0.5 % 12.25" 30.5 Jets: 1 x 10 \ 3 x --- Total Revs on Bit: 258 \ \ TFA: 0.5900 -- Footage for Bit Run 5430 15 Trip Depth: ft Trip Gas: N/A Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 10 % Sand 90 % Clay % Gravel % % Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to spe...,...,v-sun [J R I '-'- I N G 5 E R V I c: E 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Current 14 hr Avg ft/h r ( unit! ( ( R.O.P. Gas* Temp Out ft/hr units Deg F Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: 5 3/17/2004 5430 o Test BOP's White/ Lewis 14 hr Max Pump and Flow Data Pump 1 67 spm Flow rate Pump 2 67 Pump Liner 6.5 x Stk SPP 2100 12 gpm gps in. Mud Wt In Mud Wt Out 9.40 ppg 9.40 ppg Vise 48 secs PV 19 cP Fit 6.6 ml HTHP m Mud Wt at Max Gas YP 21 Ibs/100ft2 Gels 6 \ 24 \ 31 pH -- Type: RPM: MXC1 130 Bit Size: Hrs. On Bit: Bit No.: Wt On Bit: 1 0-30 Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 8.7 Sd ppg 0.25 % 12.25" 30.5 Jets: 1 x 10 \ 3 x Total Revs on Bit: 258 \ \ TFA: 0.5900 -- Footage for Bit Run 5430 15 N/A ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Mud Cut: Mud Cut: to ppm ppm ft % Gravel % 10 % Sand 90 % Clay % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to spe.....,.....,v- sun [J RILL IN G 5 = R V I c: = 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Current 14 hr Avg ftIh r ( unit~ ( ( ftIhr units Deg F Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 6 3/18/2004 5430 o Prep for CGS test White/ Lewis 14 hr Max Pump and Flow Data spm Flow rate gpm gps in. Pump 1 Pump 2 Pump SPP Liner 6.5 x Stk 12 Mud Wt In Mud Wt Out 9.15 ppg 9.15 ppg Vise 50 sees Fit 5.8 ml HTHP m Mud Wt at Max Gas PV 13 cP YP 18 Ibs/100ft2 Gels 5 \ 11 \ 14 pH 10.2 Sd -- 2 0-30 Type: RPM: Bit Size: Hrs. On Bit: PDC o ppg 0.1 % 81/2 0.0 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 0 \ \ TF A: 0.5430 -- Footage for Bit Run 0 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 10 % Sand 90 % Clay % Gravel % % Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 7 3/19/2004 8000 2570 Drilling Wh itel Lewis spel'""'l'""'\I-sun [JRILLING seRVIc:es Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. 208 fVhr fVhr ( Pump 1 60 spm Flow rate 580 Gas* 50/100 units unitf ( Pump 2 60 Temp Out Deg F ( Pump Liner 6.5 x Stk 12 SPP 3100 Mud Wt In Mud Wt Out 9.70 ppg 9.70 ppg Visc 47 secs Fit 5.8 ml HTHP m Mud Wt at Max Gas PV 17 cP YP 19 Ibs/100ft2 Gels 5 \ 23 \ 27 pH 9.6 Sd ppg 0.1 % -- 2 Type: PDC Bit Size: 81/2 Jets: 5 x 12 \ 3 x \ \ TFA: 0.5430 - - - - 0-30 RPM: 140 Hrs. On Bit: 12.4 Total Revs on Bit: 231 k Footage for Bit Run 2570 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 7910 ft Short Trip Gas: 126 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft tr % Sand 70 % Clst 30 % Sltst % % Connection Gas and Mud Cut ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 8 3/20/2004 8640 277 Drilling White/ Lewis spe..........v-sun [J RILL IN G 5; e R v I c: e 5; Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. 99 ft/hr N/A ft/h r ( Pump 1 54 spm Flow rate 527 gpm Gas* 50-1 00 units unit~ ( 721 8557 Pump 2 54 gps Temp Out Deg F ( Pump Liner 6.5 x Stk 12 in. SPP 2900 Mud Wt In Mud Wt Out 10040 ppg 10040 ppg Visc 47 secs PV 20 cP Fit 4.2 ml HTHP 904 m Mud Wt at Max Gas YP 20 Ibs/100ft2 Gels 5 \ 20 \ 24 pH 9.6 Sd ppg 0.1 % -- 2rr Type: HCM 605 Bit Size: 81/2 Jets: 5 x 12 \ 3x \ \ TFA: 0.5430 - - 0-30 RPM: 140 Hrs. On Bit: 2.8 Total Revs on Bit: 38 Footage for Bit Run 277 Trip Depth: 8363 ft Trip Gas: 279 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 90 % CLST 10 % SLTS Tr % SD % % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: 9 3/21/2004 9575 935 Drilling White/ Lewis spe............v-sun [J A I LL IN G seA v I c: e s Current 99 500-1500 102 14 hr Avg ft/hr NI A ft/hr ( units unit~ ( Deg F ( 14 hr Max Pump 1 Pump 2 Pump SPP Pump and Flow Data 51 spm Flow rate 50 Liner 6.5 x Stk 2734 505 12 Mud Wt In Mud Wt Out 10.30 ppg 10.30 ppg Vise 55 secs PV 23 cP Fit 3.8 ml HTHP 9.0 m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 24 pH 8.8 Sd ppg 0.1 % -- 2rr Type: HCM 605 Bit Size: 81/2 Jets: 5 x 12 \ 3x \ \ TFA: 0.5430 - - 0-30 RPM: 140 Hrs. On Bit: 16.2 Total Revs on Bit: 245 Footage for Bit Run 1212 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 9217 ft Short Trip Gas: 2443 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 30 % CLST 70 % SLTS % % % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to I I I I I I I I I I I I I I I I I I I Customer: spe....,....,v- sun Well: -c Fffï::"I::..ï...··i\ï·..·G-·····-s E Ffv ICE 5i Area: Lease: Rig: Job No.: ....................................--.........................---.----........................--......--........ Mud logger's Morning Report Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: 10 3/22/2004 10390 815 POOH White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data 79.8 fVhr N/A fVhr ( Pump 1 51 spm Flow rate 505 200 units unitf ( 713 9621 Pump 2 50 102 Deg F ( Pump Liner 6.5 x Stk 12 SPP 2734 Mud Wt In Mud Wt Out 10.30 ppg 10.30 ppg Visc 45 secs PV 18 cP Fit 3.0 ml HTHP 8.0 m Mud Wt at Max Gas YP 19 Ibs/100ft2 Gels 8 \ 22 \ 28 pH 9.2 Sd 2rr Type: 0-30 RPM: HCM 605 140 Bit Size: Hrs. On Bit: -- ppg 0.05 % 81/2 25.4 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 408 \ \ TFA: 0.5430 -- Footage for Bit Run 2027 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 10390 ft Short Trip Gas: 2014 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft nt Lithology: 90 0/0 SH 10 % 5L T/CLSl % % % ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ppg c units ppg ft units ppg ft ft ft units units units Depth Drill Rate during before to to Logging Engineer: Howard McClellan / Doug Wilson Drilling Breaks after Gas during after before units units units % Lithology Cgl Sst Ls Sh ppg ppg ppg I I I I I I I I I I I I I I I I I I I Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. 13.2 ftfhr ftfhr ( Pump 1 spm Flow rate 290 Gas* 150-200 units unit! ( Pump 2 58 Temp Out Deg F ( Pump Liner 6.5 x Stk 12 SPP 810 Customer: sper'r'v-sun Well: -c-Ffï···Ci:·i'···i\ï···G¡_········s e Fi\::-iï"'E-e"'s Area: Lease: Rig: Job No.: m..............................._.__._.....___....................._____.. Mud logger's Morning Report Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 11 3/23/2004 10480 90 POOH /CB White/ Lewis Mud Wt In Mud Wt Out 10.30 ppg 10.30 ppg Visc 45 secs PV 18 cp Fit 3.0 ml HTHP 8.0 m Mud Wt at Max Gas YP 19 Ibs/100ft2 Gels 6 \ 22 \ 28 pH 9.2 Sd 4 Type: 20.00 RPM: ARC 425 C3 Bit Size: 118 Hrs. On Bit: ft ft ft units _ ppg units ppg units ppg Depth Drill Rate during before to to Logging Engineer: Howard McClellan I Doug Wilson -- ppg 0.05 % 81/2 6.8 Jets: x \ 3 x --- Total Revs on Bit: 49 \ \ TFA: 0.7500 -- Footage for Bit Run 90 Connection Gas and Mud Cut ft units ppg c units ppg ft units ppg ft ft ft Trip Depth: 10390 ft Trip Gas: 719 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: 90 % SH 10 % 5LT/CLSl % % % Drilling Breaks after Gas during after before units units units % Lithology Cgl Sst Ls Sh ppg ppg ppg I I I I I I I I I I I I I I I I I I I Customer: spe.....,.....,v-sun Well: -ï:J'FiTCL.1 N-G-5ifEfA\iïEes Area: -..---. ........................................ . Lease: Rig: Job No.: Mud logger's Morning Report Current 14 hr Avg fVhr ( unit~ ( ( ftlhr units Deg F Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: 12 3/24/2004 10480 90 RIH White/ Lewis 14 hr Max Pump and Flow Data spm Flow rate Pump 1 Pump 2 Pump Liner 6.5 SPP x Stk Mud Wt In Mud Wt Out 10.30 ppg 10.30 ppg Vise 55 sees Fit 3.4 ml HTHP 8.4 m Mud Wt at Max Gas PV 19 eP YP 19 Ibs/100ft2 Gels 5 \ 21 \ 26 pH 9.0 Sd -- HCM 605 118 Bit Size: Hrs. On Bit: Type: 20.00 RPM: 12 ppg 0.1 % 81/2 6.8 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 49 \ \ TFA: 0.5430 -- Footage for Bit Run 90 Trip Depth: 10390 ft Trip Gas: 719 Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft Current Lithology: % SH % 5L T/CLSl % % % Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg ft units ppg c units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to I I I Customer: spe............v- sun Well: _c··ï=ffi:::::i:·'ï'···i\ï····[j··..···ms;e..fif v I c::"s 5 Area: Lease: Rig: Job No.: ..........-...............................-........................................-.-.............-..... Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 24h's Rig Activity: Report For: 13 3/25/2004 11001 521 POOH Whitel Lewis Mud logger's Morning Report I I Current 14 hr Avg 14 hr Max Pump and Flow Data 110.8 ftIh r fVhr ( Pump 1 60 spm Flow rate 440 130-400 units unit~ { 5043 10630 Pump 2 60 Deg F ( Pump Liner 6.5 x Stk 12 SPP 1625 I Mud Wt In Mud Wt Out 10.65 ppg 10.65 ppg Visc 55 secs PV 27 cp Fit 3.8 ml HTHP 8.4 m Mud Wt at Max Gas YP 20 Ibs/100ft2 Gels 7 \ 30 \ 32 pH 8.9 Sd ppg 0.1 % -- I I I Type: 20.00 RPM: HCM 605 118 Bit Size: Hrs. On Bit: 81/2 4.7 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 129 \ \ TF A: 0.5430 -- Footage for Bit Run 521 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth 11001 ft Short Trip Gas: 1299 /732 Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft nt Lithology: 100 % SH % % % % I I I I ft ft ft units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg c units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh Depth I to to I I I I 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 14 hr Recap: Restarted drillin from 10480 ft and drilled to TD of 11001 ft MD 1 9507 ft TVD. Noted lar e uantities of as after 10613 ft, peaking at 5043 units at 10630 ft. The mud weight was increased to 10.6+ ppg. After reaching TD a ten-stand wiper trip was made, after which 1299 units of trip gas was noted. After circulating and cleaning hole, and with reduced gas levels, the trip out to surface was begun. However, it was noted that the hole was not taking the correct amount of fluid, so the bit was run to bottom and bottoms up circulated ( max gas = 732 units). Started POOH again. Logging Engineer: Howard McClellan I Doug Wilson * 10000 units = 100% Gas In Air I Customer: spe............v- sun Well: -ï:fAI-Ci::-i···i\ï···ï::;············S··E··ï=i'v I I:: læ s Area: .................-..--.-................... ...................... .........................--..- Lease: Rig: Job No.: Mud logger's Morning Report Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 24h·s Rig Activity: Report For: 14 3/26/2004 11001 E-Iogging White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. ftIh r ftIh r ( Pump 1 60 spm Flow rate 440 gpm Gas* units unit! ( Pump 2 60 gps Temp Out Deg F ( Pump Liner 6.5 x Stk 12 in. SPP 1625 9.2 Sd ppg 0.1 % Mud Wt In Mud Wt Out 10.60 ppg 10.60 ppg Visc 52 secs PV 24 cp Fit 3.8 ml HTHP 8.8 m Mud Wt at Max Gas YP 20 Ibs/100ft2 Gels 6 \ 29 \ 32 pH -- Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 100 % SH % % % % Bit No.: 2 RR Type: Wt On Bit: 20.00 RPM: HCM 605 118 Bit Size: Hrs. On Bit: 81/2 4.7 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 129 \ \ TFA: 0.5430 -- Footage for Bit Run 521 Connection Gas and Mud Cut ft units ppg ft units -ppg ft units ppg ft units ppg c units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 14 hr Recap: Runnin Logging Engineer: Howard McClellan I Doug Wilson oz. spe....,....,v-sun [J R I L..L..I N G 5 Ei R V I c:: Ei 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 14h's Rig Activity: Report For: 1 (2PM) 3/22/2004 10370 794 CBU White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data 190 ft/hr 82 ft/hr ( 193 10365 Pump 1 54 spm Flow rate 544 gpm 535" units 655" unit~ 740' 9595 Pump 2 54 gps Deg F Pump Liner 6.5 x Stk 12 in. " see note below SPP 2750 Mud Wt In Mud Wt Out Visc PV 10.30 ppg 10.30 ppg secs cp YP 2RR Type: 35-45 RPM: HCM 605 140 Bit Size: Hrs. On Bit: Ibs/100ft2 ml HTHP Gels \ m Mud Wt at Max Gas \ pH % ppg Sd -- 81/2 25.4 Jets: 5 x 12 \ 3 x --- Total Revs on Bit: 399K \ \ TFA: 0.5430 -- Footage for Bit Run 2007 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 5 % SHALE 5 % SST 10 % SILT % % Connection Gas and Mud Cut NA ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to spe............v-sun [J R I L..L..I N G 5 = R V I c: = 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Current 1 (2PM) 3/24/2004 10480 90 TOH White/ Gorelich Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: fVhr units Deg F 14 hr Avg 14 hr Max 13 fVhr ( 24 285* unit¡ 344* 10472 10408 Pump 1 Pump 2 Pump SPP Pump and Flow Data 68 spm Flow rate * see note below Liner 6.5 x Stk 655 Mud Wt In Mud Wt Out Vise PV 10.30 ppg 10.30 ppg sees cP YP CB1 Type: 15.00 RPM: ARC 425 C3 Bit Size: 118 Hrs. On Bit: Ibs/1 00ft2 ml HTHP Gels \ m Mud Wt at Max Gas \ pH Sd 250 12 ppg % 90 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft % SHALE % SST % SILT % % -- 81/2 7.0 Jets: x \ 3 x --- Total Revs on Bit: 81 K \ \ TFA: -- Footage for Bit Run Connection Gas and Mud Cut NA ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to * see note below spe....,....,v-sun [J A I LL IN G 5 = A V I c: = 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Current 58 1521 * 14 hr Avg 112 fVhr ( 800* unit~ ft/hr units Deg F 24 5043* Mud Wt In Mud Wt Out Visc PV 10.60 ppg 10.60 ppg secs cP YP BN3 Type: 30.00 RPM: Bit Size: Hrs. On Bit: HCM605 134 Kerr McGee Nikaitchuq #2 North Slope NW Miline Point Nabors 27E AK-AM- 2893109 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: 1 (2PM) 3/25/2004 10982 502 DRILLING Whitel Gorelich 14 hr Max Pump and Flow Data 52 spm Flow rate 50 Liner 6.5 x Stk 2660 12 504 10472 10630 Pump 1 Pump 2 Pump SPP gpm gps in. Ibs/100ft2 ml HTHP Gels \ m Mud Wt at Max Gas \ pH % ppg Sd -- 81/2 4.5 Jets: x \ 3 x --- Total Revs on Bit: 82 \ \ TFA: 0.5520 -- Footage for Bit Run 502 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm Tight Spots: to to to Feet of Fill on Bottom: ft 100 % SST/CONG % SST % SILT % % Connection Gas and Mud Cut NA ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh 10613 to 10630 150 113 122 280 5043 5043 50 50 10630 to 10680 122 158 91 5043 3800 4600 70 30 10680 10750 91 238 230 4600 4522 4300 30 70 10750 10800 230 240 165 4300 3450 1550 100 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 14 hr Recap: TIH W/8 1/2" dc BIT, Drill from 10480 to 10982. NOTE: * 100 units of total due to lingering effects of produced water from Nikaitchuq #1 well. GAS DID NOT DISIPATE DUE TO OIL LIQUID BEING RECIRCULATED Logging Engineer: Howard McClellan / Doug Wilson 5pe....,~V-5un CFfI LLI N G SEFfVI C:E 5 Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Current 14 hr Avg fVhr ( unit! ( ( R.O.P. Gas' Temp Out fVhr units Deg F Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: White/ Lewis 14 hr Max Pump and Flow Data spm Flow rate Pump 1 Pump 2 Pump SPP Liner 6 x Stk 12 Mud Wt In Mud Wt Out 10.70 ppg 10.70 ppg Vise 46 sees PV 17 cp 6.0 ml HTHP m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 27 pH -- 2 Type: HCM 605 (PDC) Bit Size: 15-20 RPM: 110 Hrs. On Bit: Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 70 % Sand Current Lithology: ppg 9.0 Sd % 81/2 46.6 Jets: x \ 3 x --- Total Revs on Bit: 403 \ \ TFA: 0.6480 -- Footage for Bit Run 5290 Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft % 30 % SLTST % % Connection Gas and Mud Cut NA ft units ppg ft units -ppg ft units ppg ft units ppg ft units -ppg ft units ppg ft units ppg ft units ppg ft units ppg Drilling Breaks Depth Drill Rate Gas % Lithology before during after before during after Cgl Sst Ls Sh to to 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Logging Engineer: Howard McClellan I Dave Hutchins - - - - - - - - - - - - - - - - - - - WELL NAME: Nikaitchnq 2 LOCATION: Spy Island OPERATOR: Kerr McGee Corp AREA: North Slope CONTRACTOR: Nabors N27E STATE: Alaska BIT Bit Bit Bit Footage TFA # Type Size Hrs 1 MXC1 12.25 30.50 5430 0.590 2 HCM605 8,5" 41.00 4960 0.543 CORE1 ARC425C3 8.5" 7.00 90 na 3 HCM605 8,5" 4.70 521 0.552 - - - - - - -- - - - -- - - - - - - .§perrv-Sun Casing Record Company: Kerr McGee Corporation Lease Drilling SeNices Well Nikaitchuq 2 Area North Slope - Alaska 133/8" CSG 118 ft MD Rig Nabors N27E Job No: AK-AM-0002893109 95/8" 5416 ft MD Water-based Mud Record Mud Co Baroid Spud Date 13 March 2004 7" Liner N/A TD Date: 25 March 2004 Date Depth Wt Vis PV YP Gels FiIt R600/R300 Cake Solids Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft-MD ppg see Ib/1 00 Ib/100tt< m/30m 32nds % 0/0 % ppm(k) Ca++ 13-Mar 371 9.05 61 18 34 13/21/24 6.2 70/52 2 1 94.5 .25 9.6 5.0 0.15/0.55 54 320 Spud well 14-Mar 2400 9.4 58 19 31 11/26/30 6.2 69/50 2 2.2 93.5 1 9.3 5.5 0.05/0.6 52 320 Drilling 15-Mar 4885 9.4 58 23 24 1 0/25/32 5.6 70147 2 3.2 100 0.75 9.2 10.0 0.1/0.58 53 320 16-Mar 5430 9.45 53 20 26 9/24/31 6.0 66/46 1 4.0 91.5 0.5 0.2 8.6 11.0 0.05/0.7 55 320 Drilled to CSG pt. 17 -Mar 5430 9.5 48 19 21 6/21/31 6.6 59/40 1 3.8 100 0.25 0.2 8.7 12.0 0.05/0.72 51 360 18-Mar 5430 9.15 50 13 18 5/11/14 5.8 44/31 1 1.0 93.8 0.1 1.3 10.2 0 0.45/1.1 62 240 DrlQ 8.5" Hole 19-Mar 7860 9.7 48 17 19 5/23/27 5.8 53/36 1 4.7 90 0.1 0.9 9.6 11 0.3/1.0 65 480 Incr mud to 10.4 20-Mar 8559 10.4 47 20 20 5/20/24 4.2 60/40 1 6.9 88 0.1 0.7 9.6 9 0.3/0.8 64 560 Deer MW to 10.3 21-Mar 9432 10.3 55 23 18 6/22/24 3.8 64/41 1 5.9 89 0.1 0.4 8.8 8.8 0.2/0.8 64 600 22-Mar 10390 10.3 45 18 19 6/22/28 3.0 55/37 1 6.5 88.5 0.05 0.5 9.2 9.0 0.2/0.8 63 540 Coring point 23-Mar 1 0480 10.3 45 18 19 6/22/28 3.0 55/37 1 6.5 88.5 0.05 0.5 9.2 9.0 0.2/0.8 63 540 Cut core 24-Mar 10480 10.3 55 19 19 5/21/26 3.4 57/38 1 6.5 88.4 0.1 0.3 9 8.8 0.2/0.7 64 560 Drill to TD 25-Mar 11001 10.65 53 27 20 7/30/32 3.8 74147 1 9.2 86.5 0.1 0.4 8.9 10 0.2/0.8 56 400 Well at TD 26-Mar 11001 10.6 52 24 20 6/29/32 3.8 68 44 9.3 86.5 0.1 0.4 9.2 9.0 0.25/0.7 55 400 E-LoQQinQ I I sperry-sun DRILLING SERVICES Show Report Well Name: Location: Operator: Report Report Delivered To: Depth (MD) (TVD) to to Show Report DatelTime: # I I I C1 C5 Mud Chlorides C1 C2 C1 C3 I ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 :; C1/C3 C1/C4 C1/C5 1000.0 I ____n ____._~___ ___ NPH -.---'..~----~... -- - 100.0 I Non-Producible Hydrocarbons Mud Chlorides (ppm):; Gas I ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 C1/C3 :; C1/C4 C1/C5 :; 10.0 I Oil -----,---~-- ----~--- NPH 1.0 I I Non-Producible Hydrocarbons Hydrocarbon Ratios C1 C1 C2 Depth --Flõ"Wi¡ñë--- ppm ppm ppm (Steam Still PPM's in 1000's) Mud Chlorides (ppm):; C1 C5 I Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 1000.0 I NPH I -- -- u __:_:-.~_~_'""~ 100.0 Non-Producible Hydrocarbons Gas Depth ft Gas -~õ"Wnñ-ë-------šüè1rõñ--- ppm ppm ppm (Steam Still PPM's in 1000's) Mud Chlorides (ppm):; I ...-...-......--..........""................--..........---...---...----- ------ Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 :; C1/C5 10.0 I Oil NPH 1.0 I I I I I sperry..sun DRILLING SERVICES Show Report Well Name: Location: Operator: Report Report Delivered To: Depth (MD) (TVD) I I I Mud Chlorides C2 I ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 1000.0 I --~- -~-- NPH --- 100.0 I Non-Producible Hydrocarbons Mud Chlorides (ppm) ::: Gas I ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 10.0 I Oil NPH 1.0 I Non-Producible Hydrocarbons Hydrocarbon Ratios C1 C1 C4 Mud Chlorides (ppm) ::: C1 C1 C5 I ~M______________________________ ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1IC5 1000.0 I NPH I -- -- ~-- -~- ~~'.........~:'^'.. 100.0 Non-Producible Hydrocarbons Gas Mud Chlorides (ppm)::: I ....---- ppm ppm ppm (Steam Still PPM's in 1000's) Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1IC5 10.0 I Oil -~-"'-,-._,.,..-- NPH 1.0 I I I I I sperry-sun DRILLING SERVICES Show Report Well Name: Location: Operator: Report Report Delivered To: I Depth (MD) (TVD) to to Show Report No. DatelTime: # I Interpretation: Chromatograph analysis from gas in air samples from gas trap at possum belly. Formation consisted of: Conglomerate sandstone, medium to very coarse grain with chert fragments, 20% bright yellow sample fluorescence, trace to poor White streaming cut fluorescence, no white light cut. Conglomerate sandstone from 10750' md, Carbonaceous limestone from 10700. I I Depth # ft Gas ~~~ëivvnñ~ë--~-~~-SüctTõñ----- ppm ppm ppm (Steam Still PPM's in 1000's) -~----------------------- Mud Chlorides I I Hydrocarbon Ratios C1/C2 7.1 C1/C3 C1/C4 C1/C5 cible H drocarbons Mud Chlorides (ppm) '" I I I Hydrocarbon Ratios C1/C2 '" C1/C3 C1/C4 C1/C5 Non-Producible Hydrocarbons I Mud Chlorides (ppm) '" ppm ppm ppm (Steam Still PPM's in 1000's) I I Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 Non-Producible Hydrocarbons Mud Chlorides (ppm) '" I Depth ft Gas --Fiëivvnñ~----~-~Süctíõñ~~--- ppm ppm ppm (Steam Still PPM's in 1000's) I I I I Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 '" C1/C5 1000.0 1000.0 C2 NPH 100.0 Gas 10.0 Oil NPH 1.0 Hydrocarbon Ratios C1 C4 NPH -..--.....-... -.--..- -- 100.0 -- -~._- ----"-......-~-- ---- ,~.~_....,. '.......-III!i!!!!. - Gas 10.0 on -~.".. ~~~---~ NPH 1.0 C1 C5 C1 C5 Halliburton Sperry-Sun Western North Slope, Kerr McGee Spy Island Nikaitchuq #2 Job No. AKMW2893109, Surveyed: 25 March, 2004 Survey Report 2 April, 2004 Your Ref: API 500292319900 Surface Coordinates: 6052263.00 N, 527462.33 E (70033'13.9873" N, 149046'29.2758" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Global Coordinates: 3534.49 S, 7793.30 E (Grid) Surface Coordinates relative to SHL of Nikaitchuq #1: 3563.35 S, 7780.15 E (True) Kelly Bushing Elevation: 39.95ft above Mean Sea Level sper"r":Y-SUi! DAILL.IN.G SeA.VICeS A Halliburton Company DEFINITIVE Survey Ref: svy2073 ------------------- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee 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) 0.00 0.000 0.000 -39.95 0.00 0.00 N 0.00 E 6052263.00 N 527462.33 E 0.00 MWD Magnetic - IIFR+MS 343.46 0.230 172.510 303.51 343.46 0.68 S 0.09 E 6052262.32 N 527462.42 E 0.067 -0.68 618.38 0.450 28.810 578.43 618.38 0.28 S 0.68 E 6052262.72 N 527463.01 E 0.236 -0.26 704.42 2.300 344.230 664.44 704.39 1.67 N 0.38 E 6052264.67 N 527462.70 E 2.330 1.69 798.60 3.810 350.990 758.48 798.43 6.58 N 0.63W 6052269.58 N 527461.68 E 1.646 6.55 893.63 6.410 353.450 853.13 893.08 14.97 N 1.73W 6052277.97 N 527460.55 E 2.745 14.90 985.99 9.770 354.450 944.56 984.51 27.90 N 3.07W 6052290.89 N 527459.15 E 3.641 27.77 1081.11 11.540 359.970 1038.03 1077.98 45.45 N 3.86W 6052308.43 N 527458.30 E 2.146 45.27 1174.86 12.320 3.290 1129.76 1169.71 64.81 N 3.29W 6052327.80 N 527458.80 E 1.108 64.65 1270.15 13.630 3.870 1222.61 1262.56 86.16 N 1.95W 6052349.15 N 527460.06 E 1.382 86.03 1363.45 15.420 1.230 1312.93 1352.88 109.53 N 0.94W 6052372.53 N 527460.98 E 2.045 109.42 1456.89 17.970 1.360 1402.42 1442.37 136.37 N 0.33W 6052399.37 N 527461.49 E 2.729 136.26 1555.39 18.460 2.050 1495.99 1535.94 167.14 N 0.59 E 6052430.14 N 527462.30 E 0.544 167.05 1649.12 18.790 3.220 1584.81 1624.76 197.04 N 1.96 E 6052460.05 N 527463.56 E 0.532 196.98 1743.64 19.840 3.490 1674.01 1713.96 228.25 N 3.80 E 6052491.27 N 527465.28 E 1.115 228.24 1837.10 19.970 3.350 1761.88 1801.83 260.02 N 5.69 E 6052523.04 N 527467.06 E 0.148 260.05 1928.95 19.620 3.440 1848.31 1888.26 291.07 N 7.54 E 6052554.09 N 527468.79 E 0.382 291.15 2021.79 22.220 7.170 1935.02 1974.97 324.05 N 10.66 E 6052587.09 N 527471.79 E 3.145 324~22 2115.03 24.410 9.280 2020.65 2060.60 360.56 N 15.97 E 6052623.62 N 527476.96 E 2.513 360.91 2206.52 27.470 9.050 2102.91 2142.86 400.07 N 22.34 E 6052663.15 N 527483.19 E 3.346 400.62 2301.31 30.420 5.800 2185.85 2225.80 445.55 N 28.21 E 6052708.65 N 527488.88 E 3.526 446.28 2395.41 33.780 2.940 2265.56 2305.51 495.39 N 31.96 E 6052758.50 N 527492.45 E 3.918 496.23 2489.54 36.060 3.840 2342.74 2382.69 549.17 N 35.15 E 6052812.30 N 527495.45 E 2.483 550.09 2585.72 36.200 2.520 2420.42 2460.37 605.79 N 38.30 E 6052868.93 N 527498.38 E 0.822 606.79 2677.89 36.500 2.300 2494.66 2534.61 660.37 N 40.60 E 6052923.52 N 527500.48 E 0.355 661.42 2772.37 37.700 1.840 2570.01 2609.96 717.33 N 42.65 E 6052980.48 N 527502.32 E 1.304 718.41 2865.83 37.600 1.600 2644.01 2683.96 774.39 N 44.37 E 6053037.55 N 527503.82 E 0.190 775.50 2961.33 37.980 2.210 2719.48 2759.43 832.88 N 46.31 E 6053096.04 N 527505.55 E 0.558 834.02 3055.53 38.730 2.700 2793.35 2833.30 891.28 N 48.82 E 6053154.45 N 527507.84 E 0.859 892.47 3149.45 39.010 2.660 2866.47 2906.42 950.15 N 51.57 E 6053213.34 N 527510.38 E 0.299 951.41 3243.81 39.120 2.670 2939.74 2979.69 1009.55 N 54.34 E 6053272.75 N 527512.93 E 0.117 1010.87 3335.64 39.310 2.670 3010.88 3050.83 1067.55 N 57.04 E 6053330.75 N 527515.42 E 0.207 1068.92 3428.42 39.370 2.500 3082.64 3122.59 1126.30 N 59.70 E 6053389.52 N 527517.85 E 0.133 1127.74 3521.47 39.220 1.690 3154.65 3194.60 1185.19 N 61.85 E 6053448.41 N 527519.79 E 0.574 1186.67 3615.69 39.100 1.090 3227.71 3267.66 1244.67 N 63.29 E 6053507.90 N 527521.01 E 0.422 1246.16 2 April, 2004 - 14:21 - - -- - - - -- Page 2 of 6 _.- - -- DrillQuest 3.03.06.002 ----- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee 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) (o/100ft) 3708.94 38.900 0.670 3300.18 3340.13 1303.35 N 64.20 E 6053566.58 N 527521.70 E 0.355 1304.83 3806.01 38.490 359.860 3375.94 3415.89 1364.03 N 64.48 E 6053627.26 N 527521.75 E 0.671 1365.48 3900.72 38.670 359.710 3449.98 3489.93 1423.09 N 64.26 E 6053686.32 N 527521.31 E 0.214 1424.50 3991.91 38.790 359.250 3521.12 3561.07 1480.15 N 63.74 E 6053743.37 N 527520.58 E 0.342 1481.49 4087.21 38.900 358.830 3595.34 3635.29 1539.91 N 62.74 E 6053803.13 N 527519.36 E 0.300 1541.18 4180.67 39.000 358.620 3668.02 3707.97 1598.65 N 61.43 E 6053861.87 N 527517.83 E 0.177 1599.83 4273.91 38.970 358.470 3740.50 3780.45 1657.29 N 59.94 E 6053920.50 N 527516.13 E 0.106 1658.37 4368.68 39.190 357.750 3814.07 3854.02 1717.00 N 57.97 E 6053980.20 N 527513.93 E 0.532 1717.97 4463.58 38.700 357.440 3887.88 3927.83 1776.60 N 55.47 E 6054039.79 N 527511.21 E 0.556 1777.43 4556.85 38.140 357.600 3960.95 4000.90 1834.50 N 52.96 E 6054097.69 N 527508.49 E 0.610 1835.21 4651.17 38.310 358.000 4035.05 4075.00 1892.82 N 50.72 E 6054156.00 N 527506.03 E 0.318 1893.40 4746.58 37.830 357.420 4110.16 4150.11 1951.60 N 48.37 E 6054214.77 N 527503.47 E 0.627 1952.06 4840.43 37.720 357.080 4184.34 4224.29 2009.03 N 45.61 E 6054272.18 N 527500.49 E 0.251 2009.34 4935.70 37.930 0.120 4259.60 4299.55 2067.42 N 44.19 E 6054330.57 N 527498.86 E 1.969 2067.64 5026.03 37.680 0.630 4330.97 4370.92 2122.79 N 44.55 E 6054385.94 N 527499.01 E 0.443 2122.99 5121.54 36.810 0.280 4407.00 4446.95 2180.59 N 45.01 E 6054443.74 N 527499.26 E 0.938 2180.77 5215.11 36.970 359.590 4481.84 4521.79 2236.76 N 44.95 E 6054499.91 N 527498.99 E 0.475 2236.90 5308.33 36.580 359.310 4556.51 4596.46 2292.56 N 44.41 E 6054555.71 N 527498.24 E 0.455 2292.64 5466.07 34.870 359.280 4684.56 4724.51 2384.66 N 43.28 E 6054647.80 N 527496.77 E 1.084 2384.63 5558.53 34.270 359.100 4760.69 4800.64 2437.11 N 42.54 E 6054700.25 N 527495.83 E 0.658 2437.03 5653.10 33.570 358.940 4839.17 4879.12 2489.88 N 41.64E 6054753.02 N 527494.74 E 0.746 2489.72 5746.40 33.200 359.930 4917.07 4957.02 2541.21 N 41.13 E 6054804.35 N 527494.04 E 0.706 2541.01 5842.20 33.780 3.270 4996.98 5036.93 2594.04 N 42.61 E 6054857.18 N 527495.33 E 2.017 2593.85 5937.09 34.950 5.430 5075.30 5115.25 2647.43 N 46.69 E 6054910.59 N 527499.21 E 1.781 2647.36 6030.00 37.020 6.480 5150.48 5190.43 2701.73 N 52.37 E 6054964.90 N 527504.68 E 2.325 2701.82 6124.27 38.140 7.390 5225.19 5265.14 2758.79 N 59.31 E 6055022.00 N 527511.42 E 1.326 2759.11 6219.20 37.160 7.280 5300.35 5340.30 2816.31 N 66.72 E 6055079.53 N 527518.61 E 1.035 2816.85 6313.35 36.370 7.310 5375.77 5415.72 2872.20 N 73.87 E 6055135.46 N 527525.56 E 0.839 2872.97 6407.88 36.270 7.080 5451.94 5491.89 2927.75 N 80.89 E 6055191.03 N 527532.36 E 0.179 2928.74 6501 .45 37.800 6.550 5526.63 5566.58 2983.71 N 87.57 E 6055247.01 N 527538.84 E 1.670 2984.91 6597.05 36.800 6.700 5602.68 5642.63 3041.25 N 94.25 E 6055304.58 N 527545.31 E 1.050 3042.66 6691.78 35.590 6.290 5679.12 5719.07 3096.83 N 100.58 E 6055360.18 N 527551.43 E 1.303 3098.44 6786.45 34.350 5.630 5756.70 5796.65 3150.80N 106.22 E 6055414.17 N 527556.87 E 1.369 3152.57 6877.99 36.290 3.870 5831.39 5871.34 3203.53 N 110.58 E 6055466.92 N 527561.04 E 2.393 3205.43 6970.34 37.460 2.200 5905.26 5945.21 3258.87 N 113.51 E 6055522.27 N 527563.76 E 1.668 3260.84 2 April, 2004 - 14:21 ----- Page 3 of6 DrillQuest 3.03.06.002 - - ------------ Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee 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) (n) (0/100ft) 7063.81 36.670 1.880 5979.85 6019.80 3315.17 N 115.51 E 6055578.57 N 527565.55 E 0.870 3317.17 7157.61 36.730 2.110 6055.06 6095.01 3371.19 N 117.46 E 6055634.60 N 527567.30 E 0.160 3373.23 7248.01 35.890 1.570 6127.90 6167.85 3424.69 N 119.19 E 6055688.11 N 527568.82 E 0.994 3426.76 7344.05 36.320 1.750 6205.50 6245.45 3481.26 N 120.83 E 6055744.69 N 527570.25 E 0.461 3483.35 7438.85 35.300 1.160 6282.37 6322.32 3536.71 N 122.24 E 6055800.14 N 527571.46 E 1.136 3538.81 7531.73 35.040 0.910 6358.30 6398.25 3590.20 N 123.20 E 6055853.63 N 527572.23 E 0.320 3592.30 7626.20 33.730 0.950 6436.26 6476.21 3643.54 N 124.07 E 6055906.98 N 527572.89 E 1.387 3645.64 7719.85 32.620 0.130 6514.64 6554.59 3694.78 N 124.56 E 6055958.22 N 527573.19 E 1.278 3696.87 7814.64 33.070 0.770 6594.28 6634.23 3746.19 N 124.96 E 6056009.63 N 527573.41 E 0.600 3748.25 7909.05 31.680 0.500 6674.01 6713.96 3796.74 N 125.53 E 6056060.18 N 527573.78 E 1 .480 3798.79 8004.11 31.220 0.840 6755.11 6795.06 3846.34 N 126.10 E 6056109.78 N 527574.18 E 0.519 3848.37 8098.23 32.960 2.630 6834.85 6874.80 3896.31 N 127.64 E 6056159.75 N 527575.53 E 2.107 3898.36 8192.41 31.560 1.600 6914.49 6954.44 3946.54 N 129.50 E 6056209.99 N 527577.20 E 1.597 3948.63 8278.08 30.440 1 .420 6987.92 7027.87 3990.65 N 130.67 E 6056254.10 N 527578.20 E 1.312 3992.75 8371.34 29.770 1.550 7068.60 7108.55 4037.41 N 131.88 E 6056300.87 N 527579.24 E 0.722 4039.53 8447.63 29.510 1.390 7134.91 7174.86 4075.12N 132.84 E 6056338.59 N 527580.07 E 0.356 4077.25 8558.62 26.370 2.790 7232.95 7272.90 4127.09 N 134.71 E 6056390.56 N 527581.74 E 2.890 4129.25 8652.83 25.760 0.690 7317.58 7357.53 4168.46 N 135.97 E 6056431.93 N 527582.85 E 1.174 4170.64 8745.97 26.970 1.220 7401.03 7440.98 4209.81 N 136.67 E 6056473.29 N 527583.39 E 1.323 4211 .99 8840.53 26.190 1.280 7485.59 7525.54 4252.11 N 137.59 E 6056515.59 N 527584.16 E 0.825 4254.29 8934.61 25.970 2.280 7570.10 7610.05 4293.45 N 138.87 E 6056556.93 N 527585.29 E 0.523 4295.65 9028.30 24.630 2.450 7654.80 7694.75 4333.45 N 140.52 E 6056596.94 N 527586.79 E 1 .432 4335.69 9122.75 26.380 4.320 7740.04 7779.99 4374.04 N 142.95 E 6056637.54 N 527589.06 E 2.039 4376.34 9217.96 26.570 4.650 7825.27 7865.22 4416.36 N 146.27 E 6056679.87 N 527592.23 E 0.252 4418.75 9310.53 26.930 6.860 7907.93 7947.88 4457.81 N 150.45 E 6056721.33 N 527596.25 E 1.143 4460.32 9405.24 27.050 5.340 7992.33 8032.28 4500.54 N 155.01 E 6056764.09 N 527600.66 E 0.739 4503.20 9498.92 26.580 3.340 8075.93 8115.88 4542.68 N 158.22 E 6056806.23 N 527603.71 E 1.086 4545.42 9592.65 27.370 3.580 8159.47 8199.42 4585.11 N 160.78E 6056848.68 N 527606.12 E 0.851 4587.93 9686.40 28.290 2.450 8242.37 8282.32 4628.82 N 163.08 E 6056892.39 N 527608.25 E 1.131 4631.69 9780.78 26.690 0.340 8326.10 8366.05 4672.36 N 164.16 E 6056935.94 N 527609.17 E 1.984 4675.24 9874.38 27.050 1.060 8409.59 8449.54 4714.66 N 164.68 E 6056978.24 N 527609.53 E 0.518 4717.53 9970.38 24.030 0.190 8496.20 8536.15 4756.04 N 165.15 E 6057019.62 N 527609.85 E 3.170 4758.90 10063.60 23.490 2.150 8581.52 8621.47 4793.59 N 165.91 E 6057057.17 N 527610.47 E 1.026 4796.45 10157.60 23.390 359.820 8667.76 8707.71 4830.97 N 166.55 E 6057094.55 N 527610.98 E 0.992 4833.83 10252.04 23.150 1.140 8754.52 8794.47 4868.28 N 166.86 E 6057131.86N 527611.15 E 0.608 4871.12 2 April, 2004 - 14:21 - - -- - - - -- Page 4 of6 ------- DrillQuest 3.03.06.002 - -- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Western North Slope, Kerr McGee 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) 10346.05 20.790 358.400 8841.70 8881.65 4903.44 N 166.76 E 6057167.02 N 527610.92 E 2.736 4906.25 10440.15 19.920 359.340 8929.93 8969.88 4936.16 N 166.11 E 6057199.74 N 527610.15 E 0.988 4938.93 10532.36 18.830 357.300 9016.91 9056.86 4966.73 N 165.23 E 6057230.31 N 527609.15 E 1.391 4969.45 10627.04 16.980 359.200 9107.00 9146.95 4995.82 N 164.32 E 6057259.40 N 527608.13 E 2.049 4998.48 10720.03 15.300 358.000 9196.33 9236.28 5021.66 N 163.70 E 6057285.23 N 527607.42 E 1.842 5024.28 10815.53 15.160 359.270 9288.47 9328.42 5046.74 N 163.10 E 6057310.31 N 527606.73 E 0.379 5049.32 10906.35 14.910 358.550 9376.18 9416.13 5070.30 N 162.66 E 6057333.86 N 527606.19 E 0.344 5072.85 11001.00 14.910 358.550 9467.65 9507.60 5094.64 N 162.04 E 6057358.21 N 527605.49 E 0.000 5097.15 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB Est @ 35' MSL. Northings and Eastings are relative to 2440 FNL, 1293 FEL. 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 2440 FNL, 1293 FEL and calculated along an Azimuth of 2.1100 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11 001.00ft., The Bottom Hole Displacement is 5097.22ft., in the Direction of 1.822° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11001.00 9507.60 5094.64 N 162.04 E Projected Survey - 2 April, 2004 - 14:21 - -- - - - - - Page 50f6 - - - - - - - DrillQuest 3.03.06.002 - -- Western North Slope, Halliburton Sperry-Sun Survey Report for Spy Island - Níkaitchuq #2 Your Ref: API 500292319900 Job No. AKMW2893109, Surveyed: 25 March, 2004 Survey tool program for NikaitchuQ #2 From Measured Vertical Depth Depth (ft) (ft) 0.00 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 11001.00 9507.60 MWD Magnetic - IIFR+MS Kerr McGee 2 April, 2004 - 14:21 ----- Page 60f6 ----------- DríllQuest 3.03.06.002 - -- Date Day Prog Actual 12-Mar 13·Mar 1 0 371 14-Mar 2 0 2500 15-Mar 3 1900 4944 16-Mar 4 3800 5430 17 -Mar 5 5700 5430 18·Mar 6 5700 5430 19-Mar 7 5700 8000 20-Mar 8 5700 8640 21·Mar 9 5700 9575 22-Mar 10 6710 10390 23·Mar 11 7720 10480 24-Mar 12 8730 10480 25·Mar 13 9740 10480 26-Mar 14 10750 10480 27-Mar 15 10800 10480 28-Mar 16 10900 10480 29-Mar 17 11200 10480 30-Mar 18 11200 10480 10000 12000 -~.. Kerr McGee Corp o o 5 10 2000 ~ ~ \ \ \ \ \ ~ . ~4H It -rtf' ft r-, \ ." \ \ '\ \ Ac rual f\ K 1\ r-. \ \ , ! ] --! r-.. ~ ¡........ 4000 8000 I I NIKAITCHUQ #2 LITHOLOGY ASCII DATA I Depth % Lithology Description 100 100 0 270 100 0 I 300 90 SAND clr-why-gy, sb ang-s rnd-rnd, spher i/p, p srtd, grdg to grav, dk gy-dk brn-blk, qtz, chrt peb, rnd-s rnd -s ang 300 10 CLAY Lt -med gy, amorph, stky, v sft. I 330 90 SAND 330 10 CLAY 360 90 SAND 360 10 CLAY I 390 95 SAND 0 390 5 CLAY 410 100 SAND 450 100 SAND I 480 100 SAND Clr-off wh-It gy, mainly vf-fn grns, rnd s- s rnd,- sang mod srtd, tr glauc 520 90 SAND Clr-off wh-It gy, mainly vf-fn grns, rnd s- s rnd,- sang mod srtd, tr glauc, tr pyr I 520 5 CLAY 520 5 GRAVEL 540 80 SAND 540 5 CLAY I 540 15 GRAVEL 570 70 SAND Clr-off wh-It gy, varicolor, vf- fn grns, rnd s- s rnd,- sang mod srtd, tr glauc, tr pyr I 570 10 CLAY 570 20 GRAVEL 600 70 SAND 600 10 CLAY I 600 20 G RAVEL 630 80 SAND Clr-off wh-It gy, varicolor, vf- fn grns, rnd s- s rnd,- sang mod srtd, tr glauc I 630 5 CLAY 630 15 GRAVEL 660 85 SAND 660 5 CLAY I 660 10 G RAVEL 690 70 SAND Clr-off wh-It gy, varicolor, vf- fn grns, rnd s- s rnd,- sang mod srtd, tr glauc I' 690 25 CLAY 690 5 GRAVEL 720 60 SAND 720 35 CLAY I 720 5 GRAVEL 750 45 SAND 750 50 CLAY It gry- gry, gmmy, intbd w sd + gvl I 750 5 GRAVEL 780 30 SAND 780 65 CLAY It gry- gry, gmmy, intbd w sd + gvl, sft 780 5 GRAVEL I 810 30 SAND 810 60 CLAY 810 10 GRAVEL I 840 50 SAND Clr- wh, It brn, vf- fn grns, rnd- s rnd,- sang mod srtd, tr glauc 840 45 CLAY I I I I I I I I I I, I I I I I I I I I I 840 5 870 25 870 60 870 15 900 20 900 60 900 20 930 35 930 45 930 20 960 15 960 75 960 10 990 10 990 85 990 5 1020 20 1020 75 1020 5 1 050 1 0 1050 85 1050 5 1080 25 1080 65 1080 10 1110 15 1110 75 1110 10 1140 10 1140 80 1140 1 0 1170 10 1170 80 1170 1 0 1200 5 1200 85 1200 1 0 1230 1 0 1230 80 1230 1 0 1260 15 1260 80 1260 5 1290 1 0 1290 80 1290 1 0 1320 5 1320 90 1320 5 1350 5 1350 90 1350 5 1380 15 1380 80 1380 5 1410 15 G RAVEL SAND CLAY GRAVEL SAND CLAY It gry- gry, gmmy, intbd w sd + gvl, sft- frm GRAVEL SAND Clr- wh, It brn, vf- fn grns, rnd- s rnd,- sang mod srtd, tr glauc CLAY It gry- gry, gmmy, intbd w gvl, sft- frm GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY It gry- gry, gmmy, intbd w sd + gvl, sft GRAVEL SAND CLAY GRAVEL SAND CLAY It gry- gry, gmmy, intbd w sd + gvl, sft GRAVEL SAND CLAY GRAVEL SAND CLAY It gry- gry, gmmy, intbd w sd + gvl, sft G RAVEL SAND CLAY GRAVEL SAND CLAY It gry- gry, gmmy, stky, intbd w sd + gvl, sft GRAVEL SAND CLAY GRAVEL SAND Clr, It brn ip, vf- fn grns, rnd- s rnd,- sang, mod srtd CLAY It gry- gry, gmmy, stky, sft G RAVEL SAND CLAY GRAVEL SAND CLAY It- drk gry, amorph, gmmy, stky, sft GRAVEL SAND CLAY GRAVEL SAND Clr- off wh, It brn ip, vf- fn grns, rnd- s rnd,- sang, mod srtd CLAY It- drk gry, amorph, gmmy, stky, imbd gvl, sft G RAVEL SAND I I I I I I I I I I I I I I I I I I I 1410 80 1410 5 1450 15 1450 80 1450 5 1470 5 1470 95 1 500 1 0 1500 90 1 530 1 0 1530 90 1560 20 1560 80 1590 5 1590 80 1590 15 1 620 15 1620 70 1620 1 5 1650 15 1650 70 1650 15 1680 15 1680 70 1680 15 1700 15 1700 70 1700 15 1710 15 1710 70 1710 15 1740 5 1740 90 1740 5 1770 15 1770 70 1770 15 1800 20 1800 70 1800 10 1830 10 1830 80 1 830 1 0 1860 25 1860 65 1 860 1 0 1890 25 1890 65 1890 1 0 1920 25 1920 65 1920 10 1950 25 1950 65 1950 10 1980 5 CLAY GRAVEL SAND CLAY It- drk gry, amorph, gmmy, stky, sft GRAVEL SAND CLAY It- drk gry, amorph, gmmy, stky, sft SAND CLAY SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft SAND CLAY SAND CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL m- drk gry, blk ip, varic, m- pea sz, tr pyr SAND CLAY GRAVEL SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft GRAVEL SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft GRAVEL SAND CLAY GRAVEL SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft GRAVEL SAND Clr- off wh, It brn ip, vf- fn grns, rnd- s rnd,- sang, mod srtd grds to vf sit CLAY GRAVEL SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft tr cht GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND Clr- off wh, vf- fn grns, rnd- s rnd,- sang, mod - w srtd, tr carb matt CLAY GRAVEL SAND CLAY G RAVEL SAND 1980 90 1980 5 2010 5 2010 90 2010 5 2040 5 2040 90 2040 5 2070 5 2070 90 2070 5 2100 30 matt rr tr glaue 2100 65 2100 5 2130 30 2130 65 i/p 2130 5 GRAVEL 2160 10 SAND 2160 85 CLAY 2160 5 GRAVEL 2190 20 SAND Clr- off wh, vf- fn grns, rnd- s rnd,- s ang-elong, mod - w srtd, tr earb matt rr tr glaue Oee gravel pebbles (rnd -s ang) 2190 75 CLAY 2190 5 GRAVEL 2220 15 SAND 2220 80 CLAY 2220 5 GRAVEL 2250 50 SAND 2250 45 CLAY 2250 5 G RAVEL 2280 70 SAN D 2280 25 CLAY 2280 5 GRAVEL 2310 70 SAND Clr- off wh- gy, vf- fn grns, rnd- s rnd,- s ang-elong, mod - w srtd, tr earb mat 2310 2310 2340 2340 2340 2370 spher 2370 2370 2400 2400 i/p 2400 2430 2430 2430 2460 2460 i/p I I I I I I I I I I I I I I I I I I I 25 5 10 85 5 70 25 5 25 70 5 25 70 5 70 25 CLAY It- drk gry, amorph, gummy, v stky, imbd gvl, sft tr eht sl slty i/p GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND Clr- off wh, vf- fn grns, rnd- s rnd,- s ang-elong, mod - w srtd, tr earb CLAY GRAVEL SAND CLAY It- drk gry, amorph, gummy, v stky, imbd gvl (frq pebbles), sft tr eht sl slty CLAY G RAVEL SAND CLAY GRAVEL SAND Clr-wh-It gy, vf-fn grn grdg to sit, mad-wel srtd, rnd - s rnd - sang - ace CLAY G RAVEL SAND CLAY It- drk gry, amarph, gummy, v stky, imbd gvl (frq pebbles), sft tr eht sl slty GRAVEL SAND CLAY G RAVEL SAND CLAY It- drk gry, amarph, gummy, v stky, imbd gvl (frq pebbles), sft tr eht sl slty I I I I I I I I I I I I I I I I I I I 2460 5 GRAVEL 2490 60 SAN D 2490 35 CLAY 2490 5 GRAVEL 2520 60 SAN D 2520 35 CLAY 2520 5 G RAVEL 2550 70 SAND Clr-wh-It gy, vf-fn grn occ med grn, grdg to sit, mod-wel srtd, rnd - s rnd - sang - occ spher 2550 25 CLAY 2550 5 G RAVEL 2580 70 SAN D 2580 25 CLAY 2580 5 G RAVEL 2610 80 SAND 2610 15 CLAY 2610 5 GRAVEL 2640 80 SAND Clr-wh-It gy, vf-fn grn occ med grn, grdg to sit, mod-wel srtd, rnd - s rnd - sang - occ spher 2640 15 CLAY 2640 5 GRAVEL 2670 70 SAN D 2670 25 CLAY 2670 5 GRAVEL 2700 45 SAND 2700 50 CLAY It- drk gry- occ dk brn, amorph, gummy, v stky, imbd gvl, sft tr cht sl slty i/p 2700 5 GRAVEL 2730 45 SAN D 2730 50 CLAY 2730 5 GRAVEL 2760 50 SAND Clr-wh-It gy, vf-fn grn occ med grn, mod-wel srtd, rnd - s rnd - sang - occ spher, tr glauc 2760 45 CLAY 2760 5 0 2790 50 SAN D 2790 45 CLAY 2790 5 0 2820 75 SAND Clr-wh- It gy, It brn ip, vf- fn grn occ med grn, mod-wel srtd, rnd- s rnd- s ang- occ spher, tr glauc 2820 20 CLAY 2820 5 0 2850 70 SAN D 2850 25 CLAY 2850 5 0 2880 60 SAND Clr-wh- It gy, It brn ip, vf- fn grn occ med grn, mod srtd, rnd- s rnd- s ang- occ spher, tr glauc, cht 2880 35 CLAY 2880 5 0 2910 45 SAND 2910 45 CLAY 2910 10 0 2940 35 SAN D 2940 60 CLAY It- drk gry, dk brn, amorph, gummy, sft, cht, lig, slty 2940 5 0 2970 45 SAN D 2970 55 CLAY 3000 45 SAND Clr, It gy, It brn ip, vf- tn grn occ med grn, mod srtd, rnd- s rnd- s ang- occ spher, tr glauc, cht, lig, pyr 3000 55 CLAY 3030 45 SAND Clr, It gy, It brn ip, vf- tn grn occ med grn, mod srtd, rnd- s rnd- s ang- occ spher, tr glauc, cht, lig, pyr 3030 55 CLAY 3060 50 SAN D 3060 30 CLAY 3060 20 0 3090 55 SAND 3090 30 CLAY 3090 15 0 3120 50 SAND Clr, It gy, It- drk brn, tn- m grn, sme cr grn, p srtd, rnd- s rnd- s ang- occ spher, cht 3120 30 CLAY 3120 20 0 3150 50 SAND 3150 45 CLAY 3150 5 0 3180 40 SAND 3180 55 CLAY It- drk gry, dk brn, amorph, gummy, sft, cht, slty 3180 5 0 3210 50 SAND 3210 45 CLAY 3210 5 0 3240 70 SAND Clr, It gy, It- drk brn, tn- m grn, sme cr grn, p srtd, rnd- s rnd- s ang- occ spher, cht, tr pyr, glauc 3240 25 CLAY 3240 5 0 3270 80 SAN D 3270 20 CLAY 3300 60 SAND Clr, It- drk brn, tn- cr grn, p srtd, rnd- s rnd- s ang- occ spher, tr pyr, glauc 3300 40 3330 60 3330 40 3360 35 3360 45 3360 20 3390 45 spher, tr glauc 3390 40 3390 15 3420 45 3420 50 3420 5 3450 70 3450 30 3480 50 3480 45 3480 5 3510 80 pyr, nsatc 3510 5 3510 15 I I I I I I I I I I I I I I I I I I I CLAY SAND CLAY SAND CLAY o SAND CLAY o SAND CLAY o SAND CLAY SAND CLAY o SAND CLAY o brn- blk, sb blky- blky, intmx w sd + cly, trm- hd It- drk gry, dk brn ip, amorph, gummy, sft, cht, slty Clr- trnsl, It- drk brn, tn- vf grn, ace cr grn, m srtd, rnd- s rnd- s ang- occ Clr- trnsl, It- drk brn, cr- vcr grn, m srtd, ang- sang, tr glauc Clr- trnsl, It- drk brn, wh, p grn, cr- vcr grn, m srtd, ang- sang, glauc, tr blk, brn ip, blky, trm- hd 3540 70 3540 20 3540 10 3570 70 glauc, tr pyr 3570 25 3570 5 3600 30 3600 70 3630 20 3630 80 3660 30 3660 70 3690 35 3690 65 3720 30 3720 70 3750 25 3750 75 3780 85 glauc, tr pyr 3780 15 3810 80 3810 20 3840 80 3840 20 3870 85 pyr 3870 15 3900 80 3900 20 3930 70 tr glauc 3930 30 3960 60 3960 40 3990 60 glauc 3990 40 CLAY 4020 70 SAN D 4020 30 CLAY 4050 70 SAND Clr- trnsl, It- drk brn, wh, blk, vf- f grn, m- w srtd, ang- s rnd, cht, glauc 4050 30 CLAY 4080 85 SAN D 4080 15 CLAY 411 0 85 SAN D 4110 15 CLAY 4140 85 SAND Clr- trnsl, It- drk brn, wh, gry, blk, vf- f grn, sme cr, m srtd, ang- s rnd, cht, glauc, tr pyr 4140 15 CLAY 4170 70 SAND 4170 30 CLAY 4200 70 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc, tr pyr Strg pa yel/wh flour (poss from mud?) 4200 30 CLAY 4230 70 SAN D I I I I I I I I I I I I I I I I I I I SAND CLAY o SAND Clr- trnsl, It- drk brn, wh, p grn, f grn, cr- vcr grn, p srtd, ang- sang, CLAY o SAND CLAY SAND CLAY SAND CLAY SAND CLAY SAND CLAY SAND CLAY SAND It- drk brn, It- drk gry ip, amorph, grdg sltst ip, sft- frm, c frags It- drk brn, It- drk gry ip, amorph, grdg sltst ip, sft- frm, c frags It- drk gry, It- drk brn ip, amorph, blky ip, sft- frm Clr- trnsl, It- drk brn, wh, vf- f grn, cr ip, m srtd, ang- sang, rd ip, tr CLAY SAND CLAY SAND CLAY SAND Clr- trnsl, It- drk brn, wh, blk, vf- f grn, cr ip, m srtd, ang- s rnd, glauc, tr CLAY SAND CLAY SAND Clr- trnsl, It- drk brn, wh, blk, vf- f grn, cr- vcr ip, m srtd, ang- s rnd, cht, CLAY SAND CLAY SAND Clr- trnsl, It- drk brn, wh, blk, vf- f grn, m- w srtd, ang- s rnd, cht, tr I I I I I I I I I I I I I I I I I I I 4230 30 CLAY 4260 60 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc Wk pa yel/why flour 4260 30 CLAY 4260 10 0 4290 60 SAN D 4290 25 CLAY 4290 15 0 4320 60 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc 4320 35 CLAY 4320 5 0 4350 60 SAN D 4350 35 CLAY 4350 5 0 4380 60 SAN D 4380 35 CLAY 4380 5 0 4410 60 SAND 4410 35 CLAY 4410 5 0 4440 35 SAN D 4440 60 CLAY Lt-med gy, v sft, non-calc, sl sit no shows 4440 5 0 4470 35 SAND 4470 60 CLAY 4470 5 0 4500 60 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc, pyr Strgwh/yelflour with fast stmg cut.Oil sheen on samples 4500 35 CLAY 4500 5 0 4530 70 SAN D 4530 25 CLAY 4530 5 0 4560 35 SAND 4560 60 CLAY 4560 5 0 4590 35 SAN D 4590 60 CLAY Lt-med gy, v sft, non-calc, sl sit 4590 5 0 4620 35 SAN D 4620 60 CLAY 4620 5 0 4650 35 SAN D 4650 60 CLAY 4650 5 0 4680 35 SAN D 4680 60 CLAY Lt-med gy, v sft, non-calc, sl sit no 4680 5 0 4700 55 SAND 4700 40 CLAY 4700 5 0 4710 55 SAND 4710 40 CLAY 4710 5 0 4770 40 SAND 4770 55 CLAY 4770 5 0 4800 60 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc, pyr, wk-mod yel/wh flour 4800 35 CLAY 4800 5 0 4830 25 SAND Clr- trnsl, It- drk brn, wh, gry, p bl, blk, vf- cr grn, p srtd, ang- s rnd, cht, glauc, pyr 4830 70 4830 5 4860 60 4860 35 4860 5 4890 20 4890 80 4920 40 4920 60 4950 1 0 4950 90 4980 1 00 5010 100 5040 100 5070 100 5100 100 5130 100 5160 100 5190 100 5220 95 5220 5 5250 95 5250 5 5280 90 5280 10 5310 80 5310 20 5340 60 5340 40 5370 55 5370 45 5400 35 5400 65 5430 20 5430 80 5460 60 5460 40 5490 40 5490 40 5490 20 5520 90 5520 10 5550 90 5550 10 5580 90 5580 1 0 5610 90 5610 10 I I I I I I I I I I I I I I I I I I I CLAY o SAND CLAY o SAND CLAY SAND CLAY Lt-med gy, v sft, nan-calc, sl sit SAND CLAY CLAY Lt-med gy, v sft, non calc, stky, occ sl slty CLAY CLAY CLAY CLAY CLAY CLAY CLAY Lt-med gy, acc dk gy, sft-frm, occ sl slty, non calc CLAY SILTSTONE CLAY SILTSTONE CLAY Lt-med gy, occ dk gy, sft-frm, sl slty, nan calc, carb mat SILTSTONE CLAY SILTSTONE CLAY SILTSTONE CLAY SILTSTONE CLAY SILTSTONE Lt- med gy, acc dk gy, sft, amorph, tr carb mat CLAY SILTSTONE CLAY Lt-med gy, sft, aff mod hd, non calc, stky occ sl sit SILTSTONE CLAY SILTSTONE SAND Clr-It gr, vf-fn - acc med grn, mod srtd, s rnd-s ang. Ise CLAY SILTSTONE CLAY SILTSTONE CLAY SILTSTONE CLAY Lt-med gy, sft, off mod hd, non calc, stky acc sl sit SILTSTONE Lt-med gy, acc dk gy, sft-frm, acc sl slty, non calc, tr carb mat Lt-med gy-occ dk gy,sft-mod hd,frm.Non calc,trcarb mat Lt- med gy, occ dk gy, sft- mod hd, frm, Non calc,tr carb mat 5640 90 CLAY 5640 1 0 SILTSTONE 5670 90 CLAY Lt-med gy, sft, off mod hd, non calc, stky occ sl sit 5670 1 0 SILTSTONE 5700 90 CLAY 5700 1 0 SILTSTONE 5730 80 CLAY 5730 20 SILTSTONE 5760 50 CLAY 5760 50 SILTSTONE 5790 20 CLAY 5790 80 SILTSTONE 5820 20 CLAY 5820 80 SILTSTONE sd lams, crumbly 5850 10 CLAY 5850 90 SILTSTONE 5880 30 CLAY 5880 70 SILTSTONE 5910 40 CLAY 5910 60 SILTSTONE 5940 40 CLAY 5940 60 SILTSTONE crumbly 5970 50 5970 50 6000 50 6000 50 6030 50 6030 50 6060 60 6060 40 crumbly 6090 40 6090 60 6120 30 6120 70 crumbly 6150 20 6150 50 6150 30 6180 5 6180 20 6180 75 lith, NSOFC 6210 1 0 CLAYSTONE 6210 20 SILTSTONE 6210 70 SAND 6240 40 CLAYSTONE 6240 10 SILTSTONE 6240 50 SAND clr,transl, gry, blk, tr wh,tr or, vf-tgr, sbang-sbrnd, wsrt, uncons, cly mtx, neale, lith, NSOFC 6270 40 CLAYSTONE 6270 40 SILTSTONE 6270 20 SAN D 6300 60 CLAYSTONE It-mgry ip, sft-trm, incr slty, neale, sdy lams ip. I I I I I I I I I I I I I I I I I I I CLAY SILTSTONE CLAYSTONE SILTSTONE CLA YSTON E SILTSTONE CLA YSTON E SILTSTONE CLAYSTONE SILTSTONE CLAYSTONE SILTSTONE Med gy, mod hd, non calc, tr carb matter, grdg to clyst ip Med gy, mod hd, non calc, tr carb matter, mic mica, sme xf-vfgr Med gy, mod hd, non calc, tr carb matter, mic mica, tr toss trag, It-mgry, trm-vfrm, neale, tr slty, tr mic carb Med gy, mod hd, non calc, tr carb matter, mic mica, tr toss trag, Med gy, mod hd, non calc, tr mic carb, mic mica, tr sd+xsm gvl, CLA YSTON E SILTSTONE SAND CLA YSTON E SILTSTONE SAND clr,transl, gry, blk, tr wh,tr or, vf-tgr, sbang, wsrt, uncons, cly mtx, neale, 6300 30 SILTSTONE 6300 10 SAND 6330 50 CLAYSTONE 6330 30 SILTSTONE 6330 20 SAN D 6360 50 CLAYSTONE 6360 30 SILTSTONE 6360 20 SAND 6390 30 CLAYSTONE 6390 20 SILTSTONE 6390 50 SAND clr,transl, gry, blk,wh vf-fgr, tr mgr, sbang, wsrt, uncons, cly mtx, neale, lithic,drty, NSOFC 6420 20 CLAYSTONE 6420 1 0 SILTSTONE 6420 70 SAND 6450 70 CLAYSTONE It-mgry ip, sft-vfrm, sli slty, neale, 6450 1 0 SILTSTONE 6450 20 SAND 6480 15 CLAYSTONE 6480 80 SILTSTONE 6480 5 SAN D 6510 15 CLAYSTONE 6510 80 SILTSTONE ip 6510 5 SAND 6540 15 CLAYSTONE 6540 80 SILTSTONE 6540 5 SAN D 6570 1 0 CLAYSTONE 6570 80 SILTSTONE incr carb/coal frags, incr sdy 6570 10 SAND 6600 10 CLAYSTONE 6600 80 SILTSTONE 6600 10 SAND 6630 10 CLA YSTON E 6630 70 SILTSTONE 6630 20 SAND pale gry, clr, xf-vfgr, sbang, wsrt, uncons,tuff, ncalc,as lams in sltst ,grdg to sst, NSOFC 6660 1 0 6660 60 6660 30 6690 5 6690 85 6690 10 6720 5 6720 80 6720 15 6750 5 6750 80 6750 15 6780 20 6780 70 6780 10 6810 10 6810 80 I I I I I I I I I I I I I I I I I I I CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE It gy, sft-mod hd ip, sli calc, tr carb, mic mica, sme tuff, sh ip, sdy It gy, sft-mod hd ip,sli calc, tr carb, mic mica, sme tuff, wh cly ip, It gy, sft,sli calc, tr carb, mic mica, sme tuff, sme wh cly ip It gy, sft-mfrm"sli calc, tr carb, mic mica, miclam ip, sme wh cly I I I I I I I I I I I I I I I I I I I ip 6810 10 6840 10 6840 85 6840 5 6870 10 6870 85 6870 5 6900 40 6900 55 ip, incr hyd 6900 5 6930 70 6930 25 6930 5 6960 70 6960 28 6960 2 6990 70 6990 28 6990 2 7020 70 7020 28 7020 2 7050 80 7050 18 7050 2 7080 60 7080 30 7080 10 7110 50 7110 40 7110 10 7140 50 7140 40 7140 10 7170 40 7170 50 lams ip 7170 10 7200 40 7200 50 7200 1 0 7230 40 7230 50 7230 10 7260 40 7260 40 7260 20 7290 40 7290 40 7290 20 7320 40 7320 50 7320 10 to sst, NSOFC SAND CLA YSTON E SILTSTONE SAND CLA YSTON E SILTSTONE SAND CLAYSTONE SILTSTONE It gy, sft-mfrm,sli calc, tr carb, mic mica, miclam ip, sme wh cly SAND CLA YSTON E SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE It-gry ip, sft-vsft, sli slty, neale, vhyd in smpl SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE It gy, sft-mfrm,sli calc, tr carb, mic mica, miclam ip, incr hyd SAND CLAYSTONE SILTSTONE SAND CLA YSTON E SILTSTONE SAND CLAYSTONE SILTSTONE It gy, sft-mfrm,sli calc, tr carb, mic mica, miclam ip, incr hyd, sdy SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE It-gry ip, sft-vfrm, sli slty, neale, vhyd in smpl SILTSTONE SAND CLAYSTONE SILTSTONE SAND CLAYSTONE SILTSTONE SAND pale gry, clr, xf-vfgr, sbang, wsrt, uncons,tuff, ncalc,as lams in sltst ,grdg I I 7350 30 CLAYSTONE I 7350 60 SILTSTONE 7350 10 SAND 7380 70 CLA YSTON E 7380 20 SILTSTONE It gy, sft-mfrm,sli calc, tr earb, mie mica, mielam ip, iner hyd I 7380 10 SAND 7410 70 CLA YSTON E 7410 20 SILTSTONE I 7410 10 SAND 7440 90 CLAYSTONE 7440 10 SILTSTONE 7470 90 CLAYSTONE It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl I 7470 10 SILTSTONE 7500 90 CLAYSTONE 7500 10 SILTSTONE 7530 80 CLAYSTONE I 7530 20 SILTSTONE It gy-dk gy, sft-mfrm,non-sli calc, tr earb, mie mica, mielam ip, iner hyd 7560 70 CLAYSTONE I 7560 30 SILTSTONE 7590 70 CLAYSTONE 7590 30 SILTSTONE 7620 60 CLAYSTONE I 7620 40 SILTSTONE It gy-dk gy, sft-mfrm,non-sli calc, tr earb, mie mica, mielam ip 7650 60 CLAYSTONE 7650 40 SILTSTONE I 7680 60 CLAYSTONE 7680 40 SILTSTONE 7710 50 CLA YSTON E It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl 7710 50 SILTSTONE I 7740 40 CLA YSTON E 7740 60 SILTSTONE It gy-dk gy, sft-mfrm,non-sli calc, tr earb, mie mica, mielam ip 7770 70 CLAYSTONE I 7770 30 SILTSTONE 7800 90 CLAYSTONE It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl 7800 10 SILTSTONE 7840 90 CLA YSTON E I 7840 10 SILTSTONE 7870 90 CLAYSTONE 7870 10 SILTSTONE I 7900 80 CLA YSTON E 7900 20 SILTSTONE It gy-dk gy, sft-mfrm,non-sli calc, tr earb, mie mica, mielam ip 7930 80 CLAYSTONE 7930 20 SILTSTONE I 7960 80 CLAYSTONE 7960 20 SILTSTONE 7980 80 CLAYSTONE It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl I 7980 20 SILTSTONE 8010 90 CLAYSTONE 8010 10 SILTSTONE 8040 90 CLAYSTONE It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl I 8040 10 SILTSTONE 8070 90 CLAYSTONE It-gry ip, sft-vtrm, sli slty, neale, vhyd in smpl 8070 10 SILTSTONE I 8100 90 CLAYSTONE 8100 10 SILTSTONE I I I 8130 95 CLA YSTON E I 8130 5 SILTSTONE 8160 95 CLA YSTON E 8160 5 SILTSTONE 8190 95 CLA YSTON E I 8190 5 SILTSTONE 8220 95 CLAYSTONE It-gry occ brn/gry, sft-vfrm, v sli slty, nan-sli calc 8220 5 SILTSTONE I 8250 95 CLAYSTONE 8250 5 SILTSTONE 8280 95 CLAYSTONE 8280 5 SILTSTONE I 8310 95 CLAYSTONE 8310 5 SILTSTONE 8340 95 CLAYSTONE 8340 5 SILTSTONE I 8370 100 CLAYSTONE 8400 100 CLAYSTONE Med-dk brn - acc med gry, sft-frm, non- v sl calc, tr carb matt 8430 100 CLAYSTONE I 8460 100 CLAYSTONE Dk gry-med/drk red brn, v sft, non- non calc, tr carb matt 8490 100 CLAYSTONE 8520 100 CLAYSTONE 8550 85 CLAYSTONE I 8550 10 SILTSTONE Lt-dk gy, mad hd, nan-sli calc, blk carb specs 8550 5 SAND 8580 85 CLA YSTON E I 8580 10 SILTSTONE 8580 5 SAND Clr-wh-gy, vf - fn grns, ang-s ang acc s rnd. 8610 85 CLAYSTONE 8610 10 SILTSTONE I 8610 5 SAND 8640 85 CLAYSTONE 8640 10 SILTSTONE I 8640 5 SAND 8670 75 CLAYSTONE 8670 20 SILTSTONE 8670 5 SAND I 8700 80 CLAYSTONE Med-dk brn - occ med gry, sft-frm, nan- v sl calc, tr carb matt 8700 15 SILTSTONE Lt-dk gy, mod hd, non-sli calc, blk carb specs 8700 5 SAND I 8730 65 CLAYSTONE Med-dk brn - acc med gry, sft-frm, non- v sl calc, tr carb matt 8730 30 SILTSTONE Med-dk brn-rd/brn,acc dk gy, mod hd, non-sli calc, blk carb specs 8730 5 SAND I 8760 15 CLAYSTONE 8760 80 SILTSTONE 8760 5 SAND I 8790 15 CLAYSTONE 8790 80 SILTSTONE 8790 5 SAND 8820 15 CLAYSTONE I 8820 80 SILTSTONE Lt-dk gy, mad hd, non-sli calc, blk carb specs 8820 5 SAND 8850 15 CLAYSTONE Med-dk brn - acc med gry, sft-frm, non- v sl calc, tr carb matt I 8850 80 SILTSTONE 8850 5 SAND I 8880 20 CLAYSTONE 8880 80 SILTSTONE 8910 20 SHALE 8910 75 SILTSTONE 8910 5 SANDSTONE 8940 10 SHALE 8940 40 SILTSTONE 8940 50 SANDSTONE clr, brn,gry,blk vf-fgr, sbang, msrt,uncons, tr cons clust, abnt carb frags, tr pyr, tr yel fluor, NSOC 8970 20 SHALE 8970 60 SILTSTONE 8970 20 SAN DSTON E 9000 30 SHALE 9000 60 SILTSTONE 9000 10 SANDSTONE 9030 60 SHALE dk gry, blk, fiss, pity, tr pyr, splntry,carb, mhd-brit 9030 35 SILTSTONE 9030 5 SAN DSTON E 9060 40 SHALE 9060 30 SILTSTONE 9060 30 SANDSTONE 9090 20 SHALE 9090 70 SILTSTONE 9090 10 SANDSTONE 9120 10 SHALE 9120 80 SILTSTONE 9120 10 SANDSTONE 9150 10 SHALE 9150 80 SILTSTONE 9150 10 SANDSTONE 9180 5 SHALE 9180 90 SILTSTONE 9180 5 SANDSTONE 9210 5 SHALE 9210 90 SILTSTONE 9210 5 SANDSTONE 9240 5 SHALE 9240 90 SILTSTONE 9240 5 SAN DSTON E 9270 5 SHALE 9270 90 SILTSTONE sdy 9270 9300 9330 9360 9390 9390 9420 9420 specs 9450 9450 9480 9510 9510 I I I I I I I I I I I I I I I I I I I 5 100 100 100 10 90 5 95 5 95 100 70 30 Lt gy,tn, sft-vfrm, clyy-grdg to clyst, non-sli calc, blk carb specs Tn, sft-vfrm, clyy-grdg to clyst, non-sli calc, blk carb specs, tr SANDSTONE SILTSTONE SILTSTONE SILTSTONE SHALE Dk gy-blk, fiss, pity, splntry, tr pyr carb mhd-hd, brit SILTSTONE SHALE SILTSTONE SHALE SILTSTONE SILTSTONE SILTSTONE CLAYSTONE Lt-med gry, sft-frm, clyy- grds to clst, non- v sli calc, brlk carb Lt-med gry, v sft-sft, non calc, stky, v sl slty I I 9540 60 SILTSTONE I 9540 40 CLAYSTONE 9570 50 SILTSTONE Lt-med gry, sft-frm, non-sli calc, grds to clyst, tr blk carb specs 9570 50 CLAYSTONE 9600 80 SILTSTONE I 9600 20 CLA YSTON E 9630 50 SILTSTONE 9630 50 CLA YSTON E Lt-med gry, occ dk gry, v sft-sft, stky, non calc v sl slty I 9660 50 SILTSTONE 9660 50 CLAYSTONE 9690 60 SILTSTONE 9690 40 CLA YSTON E I 9720 30 SILTSTONE 9720 70 CLAYSTONE Lt-med gry, occ dk gry, v sft-sft, stky, non calc v sl slty 9750 20 SILTSTONE I 9750 80 CLAYSTONE 9780 30 SILTSTONE 9780 70 CLAYSTONE 9810 70 SILTSTONE Lt-med gry, sft-frm, non-sli calc, grds to clyst, tr blk carb specs I 9810 30 CLAYSTONE 9840 30 SILTSTONE 9840 70 CLAYSTONE Lt-med gry, occ dk gry, v sft-sft, stky, non calc v sl slty I 9870 50 SILTSTONE 9870 50 CLAYSTONE 9900 20 SILTSTONE 9900 60 CLA YSTON E Lt gry, occ m gry, v sft-sft, stky, non calc ,v sl slty, tr shly I 9900 20 SHALE 9930 20 SILTSTONE 9930 70 CLA YSTON E I 9930 10 SHALE 9960 20 SILTSTONE 9960 60 CLAYSTONE 9960 10 SHALE I 9960 10 SANDSTONE It gry, tr clr,m gry, xf-vtgr-grdg to sltst, as intbds in clyst, ncalc 9990 20 SILTSTONE 9990 65 CLAYSTONE 9990 10 SHALE I 9990 5 SANDSTONE 10020 9 SILTSTONE 10020 60 CLAYSTONE I 10020 30 SHALE It gry-m gry ip, plty-fiss, grdg to fiss clyst. n-vsli calc, frm-mhd ip 10020 1 SANDSTONE 10050 4 SILTSTONE 10050 65 CLAYSTONE I 10050 30 SHALE 10050 1 SANDSTONE 10080 4 SILTSTONE I 10080 65 CLAYSTONE 10080 30 SHALE 10080 1 SANDSTONE 10110 4 SILTSTONE I 10110 55 CLAYSTONE 10110 40 SHALE It gry, incr m gry, plty-fiss, grdg to fiss clyst. n-vsli calc, incr miccarb miclams, frm-mhd ip I 10110 1 SANDSTONE 10140 4 SILTSTONE I 10140 55 10140 40 10140 1 10170 4 10170 55 lams 10170 40 10170 1 1 0200 1 10200 49 10200 49 1 0200 1 1 0230 1 10230 69 10230 29 1 0230 1 1 0260 25 1 0260 30 1 0260 40 1 0260 5 1 0290 1 5 1 0290 10 1 0290 70 frm-mhd ip 10290 5 SAN DSTON E 10320 20 SILTSTONE 10320 35 CLA YSTON E 1 0320 40 SHALE 10320 5 SANDSTONE 10350 10 SILTSTONE 10350 35 CLAYSTONE 10350 50 SHALE 10350 5 SANDSTONE 10360 10 SILTSTONE 10360 15 CLAYSTONE 10360 70 SHALE m gry, dk gry, plty-fiss, n calc, incr miccarb miclams, carb,vslty +mica ip, tr sdy, pyr frags, frm-mhd ip 10360 5 SANDSTONE dk gry,brn,vfgr,mhd-hd, ncalc, vcarb, pyr ip, slty, lam ip, intbd wIsh, NSOFC 10370 1 0 SILTSTONE 10370 5 CLAYSTONE 10370 80 SHALE 10370 5 SANDSTONE 10380 5 SILTSTONE 10380 5 CLAYSTONE 10380 85 SHALE 10380 5 SANDSTONE 10390 5 SILTSTONE 10390 5 CLAYSTONE 10390 85 SHALE 10390 5 SANDSTONE 10480 0 100 10500 50 SHALE 10500 50 LIMESTONE ip, tr or min fluor 10530 30 SHALE I I I I I I I I I I I I I I I I I I I CLAYSTONE SHALE SANDSTONE SILTSTONE CLA YSTON E Lt gry, incr m gry, v sft-vfrm, stky, non calc ,v sl slty, mic carb SHALE SANDSTONE SILTSTONE CLAYSTONE SHALE SANDSTONE SILTSTONE CLAYSTONE Lt gry, v sft-vfrm, stky, non calc ,v sl slty SHALE SANDSTONE SILTSTONE CLA YSTON E SHALE SANDSTONE SILTSTONE CLA YSTON E SHALE m gry,tr dk gry, plty-fiss, n calc, incr miccarb miclams,pyr frags, carb, wh-dk gry-blk mott,micxln, chlky, carb lams, slty ip, vshly, mhd I I I I I I I I I I I I I I I I I I I 10530 70 LIMESTONE 10560 30 SHALE dk gry-blk, fiss-plty, mhd-hd vcalc-grdg to arg Is 10560 70 LIMESTONE 10590 40 SHALE 10590 60 LIMESTONE 1 0620 20 SHALE 10620 80 LIMESTONE wh-dk gry-blk mott,micxln, chlky ip,v carb lams, slty ip, vShly, mhd ip,no vis por, prob frac por,40% dl yel fluor,o in smpl, strng 0 od, fr-gd wh strmg ct fluor, no wh It cut 10650 20 SHALE 10650 80 LIMESTONE 1 0680 30 SHALE 10680 70 LIMESTONE 10710 40 SHALE 10710 60 LIMESTONE wh-dk gry-blk mott,micxln, chlky ip,v carb lams, slty ip, vShly, mhd ip,no vis por, prob frac por,20% dl yel fluor,tr 0 in smpl, tr 0 od, -prfr wh strmg ct fluor, no wh It cut 10740 70 SHALE 10740 30 LIMESTONE 10780 10 SHALE 10780 10 LIMESTONE 10780 80 SAN DSTON E 10800 10 SHALE 10800 10 LIMESTONE 10800 80 SANDSTONE clr, wh, gry, m-vcgr,ang, cht frags, grdg to congl, neale, 20% bri dull yel fluor, tr -pr wh strmg cut fluor 10830 19 SHALE 10830 1 LIMESTONE 10830 80 SANDSTONE 10860 19 SHALE 10860 1 LIMESTONE 10860 80 SANDSTONE clr, wh, gry, m-vcgr,ang, cht frags, grdg to congl, neale, abnt blk dead 0 in smpl, 30% bri dull yel fluor, fr-pr wh strmg cut fluor 1 0890 5 SHALE 10890 1 LIMESTONE 10890 94 SANDSTONE 10920 5 SHALE 10920 1 LIMESTONE 10920 94 SANDSTONE clr, incr wh, gry, m-vcgr,ang, tr cht frags, grdg to congl, neale, abnt wh cly mtx, sme blk dead 0 in smpl, 20% bri dull yel fluor, fr-pr wh strmg cut fluor 10950 5 SHALE 10950 1 LIMESTONE 10950 94 SANDSTONE 1 0980 5 SHALE 10980 1 LIMESTONE 10980 94 SANDSTONE 11000 5 SHALE 11000 1 LIMESTONE 11000 94 SANDSTONE clr, incr wh, gry, m-vcgr,ang, tr cht frags, grdg to congl, neale, abnt wh cly mtx, 2% bri dull yel fluor, tr wh strmg cut fluor