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Home My WebLink About204-018THE STATE °fALASKA July 24, 2019 GOVERNOR MIKE DUNLEAVY Ms. Lindsay Wright SEQ Specialist and Land Technician ENI US Operating Co Inc 3800 Centerpoint Drive, Suite 300 Anchorage, AK 99503-5818 Re: Location Clearance Rock Flour #2 (PTD 2061660) Rock Flour #3 (PTD 2070050) Maggiore #1 (PTD 2070060) Nikaitchuq #1 (PTD 2040180) Nikaitchuq #2 (PTD 2040380) Nikaitchuq #3 (PTD 2042600) Nikaitchuq #4 (PTD 2050010) Dear Ms. Wright: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 v .00gcc.aloska.gov Eni US Operating Company Inc. (Eni) has requested guidance regarding the final site clearances for seven exploration wells located on its leases. The seven referenced wells are listed above. All seven wells have been plugged and abandoned in accordance with Alaska Oil and Gas Conservation Commission (AOGCC) regulations and the approved sundry applications. The AOGCC approves the location clearances for these seven wells. The Maggiore #1, Rock Flour 42 and Rock Flour #3 well sites were initially inspected by the AOGCC on July 12, 2007. Due to debris left at the sites, final location clearances were not issued at that time. The sites were subsequently cleaned by Eni between August 1, 2010 and August 3, 2010. Photographs of these three well locations taken during the inspections and a closeout report were provided to AOGCC on October 1, 2010 and October 11, 2010, respectively. After a thorough review, these onshore well sites were found to be in compliance with location clearance requirements as stated in 20 AAC 25.170. By email dated July 2, 2008, the AOGCC responded to requests from the prior operator (Kerr- McGee) and the State of Alaska Department of Environmental Conservation concerning the status of the four offshore Nikaitchuq wells. The AOGCC responded that the wells were plugged and abandoned as required by AOGCC regulation 20 AAC 25.112 and offshore location clearance requirements as stated in 20 AAC 25.172. The AOGCC requires no further work on the subject wells or locations at this time. However, Eni remains liable if any problems occur with these wells in the future. Sincerely, '?"AtZ"'dL� Jessie L. Chmielowski Commissioner • • Page 1 of 2 Maunder, Thomas E (DOA) From: Silfven, Laurie A (DEC) Sent: Wednesday, July 02, 2008 9:55 AM To: Maunder, Thomas E (DOA) Subject: RE: Kerr-McGee -Anadarko Two Bits and NW Milne wells Thank you, Tom! Laurie Silfven Ph: (907) 269-7540 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 ~ ao~. o ~~ Laurie, et al, As requested, I have competed a file review of 8 Kerr-McGee operated exploration penetrations that were drilled and plugged and abandoned nominally in 2Q 2004 and 2Q 2005. Total work accomplished was 6 grass-roots wells and 2 redrills as listed below. ermit # ~20 - 204- 38 204-249 205-025 204-260 205-001 205-039 205-056 Well Name 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) ~~~9t~~® J~'L ~ 20D8 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 2/2A), 20 AAC 25.170 (onshore location clearance, Ataruq 2/2A) and 20 AAC 25.172 (offshore location clearance, remaining wells). Please contact me if further information is needed. Tom Maunder, PE Sr. Petroleum Engineer AOGCC From: Silfven, Laurie A (DEC) Sent: Thursday, June 26, 2008 11:38 AM To: Maunder, Thomas E (DOA) Cc: Gould, Greg M (DEC); Bob Britch Subject: Kerr-McGee -Anadarko Two Bits and NW Milne wells Hi Tom, We received a request from Anadarko to rescind two Anadarko (formerly Kerr-McGee) exploration oil discharge prevention and contingency plans. The contingency plans are for Two Bits (Ataruq) and Northwest Milne Point (Nikaitchuq). In order to do this, we need AOGCC verification that the wells were properly abandoned. Bob Britch, consultant for Anadarko, let me know that an a-mail request to you would be sufficient. According to 7/2/2008 • Page 2 of 2 Bob, the drilling performed for the two plans essentially covered two exploration wells from the Two Bits (Ataruq) Prospect and six exploration wells from the NW Milne Point (Nikaitchuq) Prospect. At your convenience, please provide confirmation that all wells were properly plugged and abandoned. Thanks! Laurie Laurie Si/fven 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 ~ • .~--~ _. MICROFILMED 03/0112008 DO NOT PLACE a~ ~- ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CbrPgs_InsertslMicrofilm_Marker.doc / M~ Ä-O-O (0 DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 $¡t- C(J¿ I' ~~ y API No. 50-629-23193-00-00 Permit to Drill 2040180 MD 1101~ TVD Well Name/No. NIKAITCHUQ 1 Operator KERR-MCGEE OIL & GAS CORP 9307"""'- Completion Date 4/1/2004"-- Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: AI, Den, CNL, GR, SP, Caliper, LWD, ResMDT, SWC, CMR, (data taken from Logs Portion of Master Well Data Maint Well Log Information: Logl Electr Data Digital Dataset Log Log Run Interval OHI Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ~ Sonic 25 Blu 1 149 4750 Open 2/27/2004 Dipole Shear Sonic Log Caliper log ¿~t_ 25 Blu 1 149 4750 Open 2/27/2004 Array I nduction/Density/CNLlGam ma Ray/SP/Caliper - Platform Express \ tog SP " 25 Blu 1 - 149 4750 Open 2/27/2004 Array I nduction/Density/CN LIGam ma Ray/SP/Caliper - Platform Express fog Neutron 25 Blu 1 \ìVD 149 4750 Open 2/27/2004 Array J I nd uctionlDensity/CNLlGam ma Ray/SP/Caliper- Platform Express Log Density 25 Blu 149 4750 Open 2/27/2004 Array I nd uction/Density/CNLlGam ,J ma Ray/SP/Caliper - Platform Express I i Log Induction/Resistivity 25 Blu 149 4750 Open 2/27/2004 Array I nduction/Density/CNLlGam ma Ray/SP/Caliper - V Platform Express (0 C Exc 12519 Sample 5/3/2004 SWC ANALYSIS REPORT(Hardcopy ,/ ~521 included) ED C Induction/Resistivity 150 4750 Open 6/25/2004 3 CD's PEX AIT-Density- CNL-GR-SP-CAL Includes PDS & LAS. files Run 3 is Cased Hole ~ Report: Final Well R 0 0 Mud Log 1" MD and TVD, Engineering Log 1" . 9 Mud Log 5 Col 0 0 Open . . DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040180 Well Name/No. NIKAITCHUQ 1 Operator KERR-MCGEE OIL & GAS CORP API No. 50-629-23193-00-00 MD 11010 TVD 9307 Completion Date 4/1/2004 Completion Status P&A Current Status P&A UIC N ~. Mud Log 5 Col 0 0 Open ~ Rate of Penetration 12 Col foI/1J 245 11010 Open ROP,DGR,EWR,CTN,SLD Rate of Penetration 12 Col ,V-Þ 245 11010 Open ROP,DGR,EWR,CTN,SLD ;(;; Perforation 5 Blu 1 9414 10770 Case PERFORATION RECORD / Cement Evaluation 5 Blu 9350 10770 Case SLIM CEMENT BOND Cog LOG, SCMT-GR-PRESS- ~ TEMP . Induction/Resistivity 5 Blu 1MJ> 149 4750 ARRAY INDUCTION/DENSITY/CNL IGAMMA RA Y/SP/CALlPER ~ Induction/Resistivity 5 Blu þ'lj 5703 10988 ARRAY INDUCTION/DENSITY/NE ~ UTRON/GRlSP/CALlPER Induction/Resistivity 5 Blu 'VI/V 5703 10988 ARRAY INDUCTION/DENSITY/NE ~ UTRON/GRlSP/CALlPER I nd uctionlResistivity 5 Blu 1 rvl) 149 4750 ARRAY INDUCTION/DENSITY/CNL /GAMMA RAY/SP/CALlPER -EfJ C Las ¡j.5313 I nd uction/Resistivity 195 11012 Open GR Res CTN SLD Graphics files in .cgm, .emf, .pdf formats .- )žó C Wrd 13314 Report: Final Well R 0 0 Open EOW Report (.doc), Gas & . Lith ASCII files, Mud Logs (.cgm, .tiff) Dir Surveys ßØ"' C Dls Jf3315 Sonic 149 10995 Open AIT Dens CNL GR Cali PEX .dlis plus .pds Files span two CD's Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ---- Cuttings 150 11010 1146 --Cores andlor Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 2/2/2004. DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040180 Well Name/No. NIKAITCHUQ 1 Operator KERR-MCGEE OIL & GAS CORP API No. 50-629-23193-00-00 MD 11010 TVD 9307 Completion Date 4/1/2004 Completion Status P&A Current Status P&A UIC N ADDITIONAL INFORMATION Well Cored? (¡)t N (l~~"t\) IN C ,-~ Daily History Received? ~N ~/N Chips Received? ""¥+N-t Analysis ~ N Received? Formation Tops comments/A / 3, g?-..-. Cf W~Jl 'D-st \)~( IS f+fO /)~1-Ct\ -------1 ( Compliance Reviewed By: r' Date: ')V7 ßt ~ % G . . · e ~!)if§ð;¡m!t II;,. ¡šFjí:!f"1.ì-jJ:gSm _ 'nj':ßj.nlnÎ 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. ~ ;;).0'-\- J-CøO Kerr-McGee operates the Nikaitchuq prospect and holds a 70% interest. Armstrong Alaska Inc. holds a 30% stake. ~ dO ~ - 'd--'-\ " 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 ~ òlO 5 -Od.-S- earn additional acreage. After completion, Kerr-McGee will operate the well with a 55% working interest. dO~-Cf~<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. ~ dQ\.\-(:)\ <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. 10f2 3/17/2005 10:41 AM Kerr McGee / Nikaitchuq # I Salinity Analysis . e Subject: Kerr McGee / Nikaitchuq #1 Salinity Analysis From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Wed, 16 Feb 2005 11:14:40 -0900 To: "tom _ maunder@admin.state.ak.us" <tom _ maunder@admin.state.ak.us> ~4-o Lcr Attached are the independent analysis done by Schlumberger and by Sperry Sun on their respective logs run in Nikaitchuq #1 last year. We asked them to analyze the salinity of the sands exposed below the planned surface casing shoe. The exposed sands all have > 10,000 ppm. See attachment. Our proposal is to pump an additional 50 to 100 bbl of diesel down the 9-5/8" x 7" annulus at 3 - 4 bpm with the goal of breaking through the wall cake and formation damage. We could pump water instead but would then need to freeze protect afterward. SÆip Coyner 907-339-62690fc 907-748-3689 cell Content-Description: Sakinity Analysis.pdf Analysis.pdf Content-Type: application/acrobat Content-Encoding: base64 I of I 2/16/2005 II :34 AM e e SchluRlberger To: From: Skip Coyner ASRC Aron Kramer Formation Evaluation Team leader Schlumberger Nikaitchuq 11 Rw Evaluation 18-Nov-2004 ~L\-t)~8: Subiect: Date: Dear Mr. Coyner: Schlumberger (myself and Mr. Doug Hupp) has reviewed the Nikaitchuq #1 wireline logs acquired on 21-Feb- 2004 and 02-Mar-2004 respectively to determine the formation water resistivity (Rw) as per your request. A basic Archie relationship approach was used incorporating the deep induction (AHF90), the Gamma Ray, the formation density (RHOZ) and the neutron porosity (NPOR) measurements. The shallowest zone that was reviewed was·found at 2,200 feet measured depth on the wireline log acquired on 21-Feb-2004. The Rw value for this zone was determined to be 0.9 ohm-m, which can be converted to a NaCI parts-per-million concentration (ppm) of approximately 9,000 pprn at 50 deg F (50 deg F is the lowest temperature on the charts and theformation temperature at this depth should be close to this). Several more zones were analyzed from the first. logging pass (21-Feb-2004) and determined to have Rw values much less than the 2,200 foot zone with the typical values aróund to 0.1 ohm-rn: The second set of logs using the same type of tools (Platform Express- PEX) was acquired on 02-Mar-2004 to a depth of 10,996 feet measured depth. All Of the zones analyzed in this logging pass had a cornputed Rw value of O.l.ohm-m +/- 0.05 ohm-m. The deepest zone analyzed was at 1O,800feet measured depth with an Rw value of 0.1 ohm-m. The NaCI part-per-million concentration at 10,800 feet, assuming a formation temperature of 214 deg F is about 21.000 ppm as read from chart Gen-9. Please advise if you any further need of Schlumberger's assistance in this or any other matter. Regards, Aron Kramer Formation Evaluation Team leader Schlumberger Data and Consulting Services All interpretations are opinions based on inferences from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of any interpretations and we shall not. except in the case of gross or willful negligence on our part. be liable or responsible for any loss. cost. damages or expenses incurred or sustained by anyone rewlting from any interpretation made by any of our officers. agents or employees. These interpretations are also subject to clause 4 of our general terms and conditions as set out in our current price schedule. e ,. ~e-r"y - Su,.., ) Water Salinity Analvsis for NikaltchuQ #1- Rwa method (~Y-O\<6 The purpose of this short study is to attempt to define potable aquifer zones below the permafrost in the vicinity of the Nikaitchuq prospect. The apparent water resistivity (Rwa) method is better suited for this particular case than SSP, given the drilling fluid and formation characteristic parameters. The following criteria and assumptions act as guidelines for the log analysis: 1) Potable water is defined as that containing 3000 ppm total dissolved solids (IDS), or less. 2) TDS is herein defined as NaCl equivalent. 3) Base permafrost exists in the study well at 1840'TVD. 4) Base permafrost is taken as 32 deg. F boundary as well, although this gives an anomalously high geothermal gradient of over 3 deg/l00 ft to be able to attain the 114 deg F bottom-hole temperature evident on the wireline logs. 5) Shale volume is calculated by both GR and Neutron-density methods, and the lesser of the two results finds use in the subsequent equations. 6) Porosity is calculated by both the N-D shale corrected average and sonic transit . time using a Hunt-Raymer based algorithm (cI>s = 0.6*(ôt-56/ L\t). The lesser of . the two porosities is used to calculate formation factor F. This will tend to err on the side of apparently fresher formation water. 7) The formation factor, F, is calculated using the Humble formula for unconsolidated sands (F = 0.62/(þ2.1S).. ..' 8) The AHF90 resistivity curve ftom the wire line log is taken as Rt. 9) High resistivity is due either to a) decreased porosity, orb) decreased formation water salinity, not by the presence of hydrocarbons. My gas or oil present would cause apparently high Rwa (low salinity), causing eriórs.on the side of ftesher formation water. 10) Sand intervals, for analysis) are defined as having GR < 75 api (60 api after correcting for KCl mud), and thicker than 5 feet vertically. Given the above parameters and assumptions, Rwa analysis yields the following calculated salinities for the following sand intervals: Depth (TVD) Rwa ~ of Chart-derived TDS Feet Q-m ppm NaCl 2038-2090 0.887 @ 50 10,000 2262-2271 1.29 @ 50 6,000 2310-2319 0.76 @ 55 11 ,000 3105-3114 0.42 @ 80 13,000 3540-3570 0.12 @ 100 41,000 3658-3673 0.126 @ 100 41,000 3726-3780 0.09@ 105 55,000 PJ I ,f :;... e C) e c ) The above calculations show no aquifers bearing concentrations less than 3000 PPM TDS. Two possible scources of error in the calculations may be tem.perature gradient, as it is uncertain if the 32 deg F isotherm actually exists at 1840 ft TVD, and the possible presence of small amounts of hydrocarbons in any of the sand sections. Hydrocarbons being present would produce an underestimation of the TDS content, whereas too high a temperature gradient would tend to produce Rwa that was lower than actual (underestimation ofTDS). ~D4-0~ ~ R. Kalish 11/13/04 Sperry-Sun Drilling Services ~ .:¿ ðF ;¿. . . To Alaska Oil & Gas Conservation Comission Sclt.'IIIIS:llllIIP From Aron Kramer - Schlumberger cc file Subject Nikaitchuq #1 - Final CD Date June 2~, 2004 To Whom It May Concern: Enclosed in this mailing are three CDs containing field data files, field graphics files and processed graphics/data files for the following well: Kerr McGee Corporation Nikaitchuq #1 NW Milne Point North Slope, Alaska API: 500292319300 AFE: ZDRM7HA14011501 :# / ~ 5-J-I This data was acquired on three different Schlumberger Wireline logging runs from February to March 2004. The files are organized as per the picture below: "'t,;~C) -- ,,,,CC)_ ÈJCC) --., r5··-CJt:::A .......... saca -., [ ,·oca ~no. ¡. ¡·.oca _...n.. ; ,·oca__..- ÈJ oca -'2 , 'oca~- ; ¡oc¡ ~n.. !··oc¡~ aCD ~~_~_ . oca 0....._ ··cca_._..... .then Kramm Schlumberger .,. ~ ;;<GLf-OI8 ..' , .. _ STATE OF ALASKA a ALAS~L AND GAS CONSERVATION COMMI~N WELL COMPLETION OR RECOMPLETION REPORT AND LOG OilU GasU Plugged GJ AbandonedGJ SuspendedU WAGU 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GlNJD WINJD WDSPLD No. of Completions Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: Kerr McGee Oil & Gas Corporation Aband.: April 1, 2004 204-018 3. Address: 6. Date Spudded: 13. API Number: .I 3900 C Street, Suite 744, Anchorage, Alaska 99503 February 16, 2004 50-629-23193-00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 1336' FWL & 404 FSL Section 16 T14N R9E UM ' March 1, 2004 ./ Nikaitchuq #1 Top of Productive Horizon: 10406' MD (8713' TVD) 8. KB Elevation (ft): 15. Field/Pool(s): 1201' FWL & 397' FSL Section 9 T14N R9E UM 36 ft (Mud Line = 42 ft) Exploration 11010' MD (9307' TVD) 9. Plug Back Depth(MD+TVD): 1190' FWL & 507' FSL Section 9 T14N R9E UM ,¡ 8 ft below the mud line 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): Surface: x- 519,518.28' I y- 6,054,881.08'/ Zone- 4 .¡ 11010' MD (9307' TVD)oI TPI: x-519,354.12' y-6,060,153.71' Zone-4 11. DepthWhereSSSVSe!: Total Depth: x- 519,343.98' y- 6,060,263.18' Zone- 4 n/a: (retrieved from well) 18. Directional Survey: Yes 0 No TI 19. Water Depth, if Offshore: 20. Thickness of Permafrost: MWD surveys with IRF Cazandra verification 3.5 feet MSL 525' Run #1: Array Induction, Density, CNL, GR, SP, Caliper. LWO run #1: GR, Resistivity. Run #2: Array Induction, Density, CNL, GR, SP, Caliper, MDT, SWC, CMR, Dipole Sonic. LWD run #2: GR, Resistivity. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE 36' 151' 36' 151' 35' 5708' j 35' 4688' 1a. Well Status: Total Depth: 16. Property Designation: ADL 388580 I 388582 17. Land Use Permit: 21. Logs Run: 22. CASING WT. PER FT. 68# 40# L-80 L-80 Drive Pipe 12-1/4" NIA 592 sx of Perafrost "L" followed by 560 sx of Premium CMT + 1% CaCI2 GRADE CEMENTING RECORD AMOUNT PULLED 14' 27' 13-3/8" 9-518" Tapered Liner wI PBR between the 5-112" and the 3-1/2" sections: 9450'-74'. 5-1/2" I 17# I L-80 I 5556'.J I 9450' ..) I 4571' 3-1/2" 9.2# L-80 9474'.J 11000' J 7827' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7809' " 9297' ; 8-1/2" 8-1(2" 635 sx (265 bbl) of Microlite + 455 sx (94 bbl) of Premium TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 9450' PBR: 9450' - 74'" nla nla 24. (-:oçSlZF > 3-1/2" Sag River: 10408' - 10472' MD (6 spf) 8715' - 8777' TVD ~~ ~~~~~ 10380' MD 5870' to 68' MD PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.): Flowing Water-Bbl: 70.3 Water-Bbl: 135 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Frac'd with 1530 bbl of 35# gel carrying 96,440# of 20/40 Carbolite. EZSV + 26' of "G" CMT. TOC = 10354' MD. 2150 sx (440 bbl) PrEtmium CMT. 10408' - 10472' MD 26. Date First Production: March 17,2004 Date ofTes!: Hours Tested: Production for Oil-Bbl: 3/22/2004 12.5 Test Period -+ 459 Flow Tubing Casing Press: Calculated Oil-Bbl: Press. 291 psi 840 psi 24-Hour Rate ... 881 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips an~~sence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". . pe) /' ~-~ ~ I~ {'ë7:i~:¡p"'>:~~:) Cut and recovered 3~obt;Y ~e wall cores in zones of interest from 8405' MD t.QC,ð. E I VE D . lAf \ 3:il~ \ \'of ~~~ Core Lab's Preliminary Report is attached. "n~ ~ t \"~;l'."r;n \ <Jr!.J;";.>-~-:r;J\. No chips were taken. APR 202004 \~__\ ,~ ~"1\)\ø\ >~'~;::'~-~-~'-'-"Sl:f 0 R , GIN A I Gas-MCF: 289.4 Gas-MCF: 556 Choke Size: IGaS-Oil Ratio: 32/64 631 Oil Gravity - API (carr): 37.9° Form 10-407 Revised 12/2003 CONTINUED ON REVERSE Alaska Oil & Gas Cons. L;ommission __~"'" 2 3 200\ ..... IY \1) NAME GEOLOGIC MARKERS ~ TVD 29. FORMATION TESTS to. '. Include and briefly su&ze test results. List intervals tested, and attach detailed supporting dJlls necessary. If no tests were conducted, state "None". 28. Top Permafrost Base Permafrost Ugnu West Sak Colvillè· HRZ Kalubik Kuparuk D Kuparuk C LCU Kuparuk A Kingak Sag River sand Shublik Ivishak 1160' 1740' ?459' _c 4902' 5165' 8594' 8652' 8761' 8888' 8892' 8905' 8959' 10406' 10478' 10739' 1148' 1673' 2231' 4063' 4262' 7063' 7112' 7205' 7313' 7316' 7327' 7374' 8713' 8783' 9039' The Sag River sand was perforated, frac'd and tested with results as listed on page #1 of this report: 881 BOPD, 556 MCFPD, 135 BWPD, FTP = 291 psi. GOR = 631, Oil Gravity = 37.9° API 30. List of Attachments: Final well bore diagram, final survey data, side wall core data, E-Line logs (Platform Express, SCTM, Perforating Record), LWD Logs, final location plat. 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 Durkee ~ L Signature: / 1JQ ~ ;> 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-Altemating-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 8: The Kelly Bushing elevation in feet above mean low low water. this form and in any attachments. ¡c. '~:.' ,.. . "tVli '~'J': ~.ý Use same as refere~S&1I:./fP~ ~asurements given in other spaces on ~~··;:(cI:.j Item 4b: TPI (Top of Producing Interval). 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". F~rm 10-407 ~ev~ed 12/2003 ~ 'W\ . . Core iaI::i RESERVOIR OPTllllZATIDJI Kerr-McGee Oil & Gas Corporation Nikaitchuq No.1 Spy Island Field Alaska . )J.-çt q CL File Number: HOU-040220 Date: March 25, 2004 . This report is based entirely upon core samples, soils, solids, liquids, or gases, togcther with related observational data, provided solely by the client. The conclusions, inferences, deductions and opinions rendered herein reflect the examination. study and testing of these items, and represent the best judgement of Core Laboratories. Any reliance on the information containcd hercin concerning the profitability or productivity on any well, sand, or drilling activity is at the sole risk of the client, and Core Laboratories, neither cxtends nor makes any warranty or representation whatsoever with respect to same. This report has been prepared for the exclusive and confidential use of the client and no other party. PETROLEUM SERVICES . 6316 WIND FERN . HOUSTON, TEXAS 77040 . (713) 328-2565 . FAX (713) 328-2567 ~ ðt.{ -01 ~ .. ÜJre Lati Kerr-McGee Oil & Gas Corporation RESERVOIR OPTIMIZATION CL File No.: HOU-040220 Nikaitchuq No. 1 Date: March 25, 2004 Spy Island Field Analyst(s): MS,JH,LA Alaska CMS-300 ROTARY CORE ANALYSIS Sample Depth Net Confining Porosity Permeability b(He) Beta Alpha Grain Number Stress Klinkenberg I Kair Density Footnote fi psig % mD mD psi fi( -1) microns g/cm3 . 32 8405.00 1200 13.57 .011 .024 102.05 4.42E+14 1.51 E+04 2.650 31 8432.00 1200 14.99 .042 .064 40.15 7.60E+14 9.99E+04 2.653 30 8490.00 1200 15.39 .041 .071 57.09 2.58E+14 3.29E+04 2.666 29 10355.00 1200 7.59 .022 .032 34.54 1.74E+13 1.22E+03 2.715 (1 ) 28 10365.00 1200 6.79 .006 .013 95.59 1.48E+16 2.91 E+05 2.675 27 10369.00 1200 6.42 .004 .009 115.93 5.33E+16 6.22E+05 2.695 10 10405.00 1200 13.65 .044 .071 47.28 6.87E+14 9.35E+04 2.723 9 10411.00 1200 17.92 3.25 4.05 14.48 7.84E+09 8.17E+01 2.667 8 10414.00 1200 16.85 2.54 3.17 14.86 1.00E+10 8.15E+01 2.672 7 10417.00 1200 19.35 9.26 10.7 8.57 6.37E+08 1.90E+01 2.692 6 10420.00 1200 18.25 1.52 2.16 25.48 2.74E+10 1.33E+02 2.652 5 10423.00 1200 16.73 2.38 2.96 14.58 8.83E+09 6.73E+01 2.666 4 10426.00 1200 15.95 .509 .775 34.29 2.52E+11 4.08E+02 2.689 3 10429.00 1200 17.30 .885 1.27 27.73 1.19E+11 3.37E+02 2.660 2 10432.00 1200 15.64 .243 .421 50.21 4.24E+11 3.26E+02 2.659 . 1 10435.00 1200 13.77 .127 .223 54.32 3.08E+12 1.23E+03 2.665 17 10438.00 1200 17.12 .331 .496 33.55 1.69E+12 1.78E+03 2.663 16 10441.00 1200 12.35 .055 .075 27.42 1.15E+15 1.99E+05 2.675 15 10442.00 1200 14.69 .057 .099 56.95 1.46E+14 2.54E+04 2.674 14 10444.00 1200 15.52 .075 .132 56.76 8.39E+13 1.96E+04 2.674 13 10447.00 1200 10.75 .036 .048 25.28 5.05E+15 5.69E+05 2.680 12 10449.00 1200 15.40 .079 .150 67.65 1.39E+13 3.41 E+03 2.668 11 10450.00 1200 15.22 .070 .135 68.41 2.10E+13 4.52E+03 2.667 26 10453.00 1200 15.93 .149 .261 53.22 1.96E+12 9.09E+02 2.684 25 10456.00 1200 16.32 .144 .264 59.74 7.78E+11 3.48E+02 2.668 24 10459.00 1200 16.86 .238 .386 42.78 6.08E+11 4.59E+02 2.677 Page 1 Kerr-McGee Oil & Gas Corporation Nikaitchuq No.1 Spy Island Field Alaska . r::ore Lab RESEJlYBUI. BPTlftlZATIUIf CL File No.: HOU-040220 Date: March 25, 2004 Analyst(s): MS,JH,LA CMS-300 ROTARY CORE ANAL YSIS Sample Depth Net Confining Porosity Permeability b(He) Beta Alpha Grain Number Stress Klinkenberg I Kair Density Footnote ft psig % mD mD psi ft( -1) microns g/cm3 . 23 10462.00 1200 15.92 .162 .279 50.54 1.05E+12 5.31 E+02 2.693 22 10465.00 1200 13.14 .062 .105 52.03 8.93E+13 1.75E+04 2.672 21 10468.00 1200 12.70 .092 .150 45.67 1.14E+13 3.31E+03 2.737 20 10471.00 1200 13.57 .063 .113 60.07 8.46E+13 1.63E+04 2.672 19 10474.00 1200 15.10 11.3 13.4 9.80 4.15E+09 1.52E+02 2.771 18 10478.00 1200 4.16 .004 .009 113.68 6.02E+14 7.63E+03 2.687 Footnotes : (1) : Denotes chipped sample. Permeability and/or porosity may be optimistic. . Page 2 A Core .ì:åI:i Kerr-McGee Oil & Gas Corporation IlESlRYUIR GPTIKIZAnlH CL File No.: HOU-040220 Nikaitchuq No.1 Date: March 25, 2004 Spy Island Field Analyst(s): MS,JH,LA Alaska CMS-300 ROTARY CORE ANAL YSIS - DEAN STARK FLUID SA TURA TIONS Sample Depth Net Confining Porosity Permeability Saturation Grain Number Stress Klinkenberg I Kair Oil I Water Density Footnote ft pslg % mD mD % Pore Volume g/cm3 Description Flu .- 32 8405.00 1200 13.57 .011 .024 0.0 91.6 2.650 Siltst gry shy-vshy no 31 8432.00 1200 14.99 .042 .064 0.9 85.4 2.653 Siltst It gry sshy w/carb lams no 30 8490.00 1200 15.39 .041 .071 1.2 69.3 2.666 Siltst gry shy w/carb lams no 29 10355.00 1200 7.59 .022 .032 0.0 94.1 2.715 Shale dk gry no (1 ) 28 10365.00 1200 6.79 .006 .013 0.0 92.7 2.675 Siltst vshy dk gry no 27 10369.00 1200 6.42 .004 .009 1.0 93.2 2.695 Siltst vshy dk gry no 10 10405.00 1200 13.65 .044 .071 3.7 93.4 2.723 Sst vfg gry shy slty glauc no 9 10411.00 1200 17.92 3.25 4.05 14.5 70.6 2.667 Sst It gry sshy slty btyel 8 10414.00 1200 16.85 2.54 3.17 16.5 64.2 2.672 Sst It gry sshy slty btyel 7 10417.00 1200 19.35 9.26 10.7 16.8 64.9 2.692 Sst It gry sshy-shy slty btyel 6 10420.00 1200 18.25 1.52 2.16 21.0 41.7 2.652 Sst It gry sshy slty bt yel 5 10423.00 1200 16.73 2.38 2.96 14.9 66.5 2.666 Sst It gry sshy slty btyel 4 10426.00 1200 15.95 .509 .775 25.6 37.6 2.689 Sst It gry sshy-shy slty btyel 3 10429.00 1200 17.30 .885 1.27 15.8 53.9 2.660 Sst It gry sshy slty btyel 2 10432.00 1200 15.64 .243 .421 18.4 56.6 2.659 Sst It gry sshy slty btyel . 1 10435.00 1200 13.77 .127 .223 19.2 60.6 2.665 Sst It gry sshy lam(1) slty stk bt yel 17 10438.00 1200 17.12 .331 .496 18.2 51.2 2.663 Sst gry sshy slty btyel 16 10441.00 1200 12.35 .055 .075 9.0 80.3 2.675 Sst It gry sshy-shy slty stk ft yel 15 10442.00 1200 14.69 .057 .099 11.4 77.2 2.674 Sst It gry sshy-shy slty stk yel 14 10444.00 1200 15.52 .075 .132 12.8 70.9 2.674 Sst It gry sshy-shy slty stk yel 13 10447.00 1200 10.75 .036 .048 7.2 86.7 2.680 Sst It gry shy lam(2) slty ft yel 12 10449.00 1200 15.40 .079 .150 13.2 81.6 2.668 Sst It gry sshy-shy slty ft yel 11 10450.00 1200 15.22 .070 .135 10.2 86.1 2.667 Sst It gry sshy slty ft yel 26 10453.00 1200 15.93 .149 .261 18.3 71.7 2.684 Sst It gry sshy slty spt yel 25 10456.00 1200 16.32 .144 .264 13.8 76.6 2.668 Sst It gry sshy slty ftyel 24 10459.00 1200 16.86 .238 .386 28.0 55.4 2.677 Sst It gry sshy slty stk yel Page 3 Kerr-McGee Oil & Gas Corporation Nikaitchuq No.1 Spy Island Field Alaska . Core catï RESIRVDIR BPTIJ1UATWH CL File No.: HOU-040220 Date: March 25, 2004 Analyst{s): MS,JH,LA CMS-300 ROTARY CORE ANALYSIS - DEAN STARK FLUID SATURATIONS Sample Depth Net Confining Porosity Permeability Saturation Grain Number Stress Klinkenberg I Kair Oil I Water Density Footnote ft psig % mD mD % Pore Volume g/cm3 Description Flu . 23 10462.00 1200 15.92 .162 .279 28.7 52.2 2.693 Sst It gry sshy-shy slty stk yel 22 10465.00 1200 13.14 .062 .105 14.0 77.4 2.672 Sst It gry sshy lam(1) slty ftyel 21 10468.00 1200 12.70 .092 .150 14.1 52.2 2.737 Sst It gry sshy slty spt yel 20 10471.00 1200 13.57 .063 .113 10.9 70.1 2.672 Sst It gry sshy slty stk yel 19 10474.00 1200 15.10 11.3 13.4 15.7 58.6 2.771 Sst gry shy-sshy slty spt yel 18 10478.00 1200 4.16 .004 .009 2.9 86.7 2.687 Siltst gry vshy vft Footnotes: (1) : Denotes chipped sample. Permeability and/or porosity may be optimistic. . Page 4 Kerr-McGee Oil & Gas Corporation Nikaitchuq No.1 Spy Island Field Alaska .. Core tab ßESEJIYØrft DPTUUlAnOK CL File No.: HOU-040220 Date: March 25, 2004 Analyst(s): MS,JH,LA APPENDIX A: EXPLANATION OF CMS-300 TERMS "b", "Beta, and "Alpha" K., = Equivalent non-reactive liquid permeability, corrected for gas slippage, mD . Kair = Permeability to Air, calculated using K"" and b, mD b = Klinkenberg slip factor, psi ß (Beta) = Forcheimer inertial resistance factor, ft-1 a (Alpha) = A factor equal to the product of Beta and K"". This factor is employed in determining the pore level heterogeneity index, Ii. Hi = log10 (aø/RQI) a, microns = 3.238F9 ßK., ø = Porosity, fraction RQI = Reservoir Quality Index, microns RQI = O.0314(K/ø)0.5 . 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. EnQ. 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.O.; 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. REV I DATE I BY I CK I APP I e DESCRIPTION NOTES: 1. COORDS SHOWN ARE AK. STATE PLANE ZONE 4, NAD27. 2. DATE OF SURVEY: 2/4/04-2/5/04, F.B. L04-03, pp 1-8. 3. BASIS OF LOCATION: 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. NIKAITCHUQ _#J CONDo AS-BUILT LOCA TED WITHIN PROTRACTED SEC. 16, T 14 N, & R 9 E, UMIAT MERIDIAN. 404' F.S.L, 1336' F. W.L. / LAT = 70' 33' 39.985" LONG = 149' 50' 23.590" Y = 6,054,881.08 "' X = 519,518.28 .¿ TOP OF CELLAR ELEV. = 2.34' 1336' .. NIKAITCHUQ ~~6 20121 ~~~"--'" ,...·~c OF 11 / ". .+ 1'>.\ \..- ........... t..... /I. (\ .. .. "\ \" .... -..; ì\JL . ; 0 ...... *.....: L,,-, +.. . .- ..' ...~ ¡J;!./ 49th .\*~ .. I....:..........I.........................~....., ~ ~ ~....I...................II...I.I................" '" '" . . ,. ~ r;;, \. BRIAN G. MANGOLD ¡ þ_ ~/. '0- .... ú'--, .... LS-8626 .... ¡¡;;. . ..... ~ I. .- :-0' . ... -Pr- .... .... CJ . . ~'/\ -" ..- <"'\ . . v j::J ........... ~v. -" Yi'OF"tSSIONþ..1.- \-~..+ ""--"'~~~ . IREV DATE I BY I CK IAPP DESCRIPTION ::0::0 13 ffl ~ 18 17 16 15 14 24 19 201 21 23 THS SURVEY 25 30 29 28 27 26 36 31 34 35 32 33 OllKTOK Oliktok Point 6DOCK ~ 4 ß;~ OS 3R T14N T13N 2 A VICINITY MAP Scale: 1" = ? Miles N )1 #1 0 .. ..q- o ..q- ,.. 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 8, 2004. CADD FILE NO. LK601D542 r DRAWING NO: 02/05/04 ~ LOUNSBURY & ASSOCIATES, INC. S~VEYORS ENGINEERS PLANNERS AREA: MODULE: NIKAITCHUQ #1 CONDUCTOR ASBUIL T UNIT: NSK 6.01-d542 I PART: 1 I REV: OF 1 0 NikaitchuQ No.1 Surface Location: 70033' 39.9854" N & 149050' 23.5896" W 1336' FWL & 404 FSL Section 16 T14N R9E 6054881.08' N & 519518.28' E NAD 27, Zone 4 Bottom Hole Location: 1190' FWL & 501' FSL Sec 9 T14N R9E 6060263.18' N & 519343.98' E NAD 27, Zone 4 8 ADL 388581 Armstrong 0 & G Kerr McGee 0 & G ADL 388583 Armstrong 0 & G Kerr McGee 0 & G 11 ADL 388580 (2560 acres) Armstrong 0 & G Kerr McGee 0 & G 9 Nikaitchuq No.1 (Bottom Hole Location) 4------1190' FVVL ~ 501' FSL Y ADL 388582 (1280 acres) Armstrong 0 & G Kerr McGee 0 & G ::!Ill ~~ 'fr_",::, , , , , , , , , , , 16 Nikaitchuq No.1 -....a (As Built Location) ~1336' FVVL _ ~ 404' FSL V April 9, 2004 ~ ~NW Milne Point #1 To BHL 16,260' (3.08 miles) 'â. , , " MPF-33 To BHL 21,386' (5.19 mile,S!, , , , , , , , 4. NIKAITCHUQ #1 NIKAITCHUQ #1 (ALASKA) DRILLING TMD 150.0 (ft) 150.0 (ft) 394.8 (ft) 1,535.0 (ft) 3,292.0 (ft) 5,322.0 (ft) 5,720.0 (ft) Legal Well Name: Common Well Name: Event Name: DATE 2/1412004 2/1512004 2/1612004 2/1712004 2/18/2004 2/1912004 2/20/2004 2/21/2004 5,720.0 (ft) 2/22/2004 5,720.0 (ft) 2/2312004 5,720.0 (ft) 2/2412004 5,720.0 (ft) 2/2512004 5,720.0 (ft) 2/26/2004 8,003.0 (ft) 2/2712004 8,852.4 (ft) 2/28/2004 9,852.0 (ft) 2/2912004 10,731.0 (ft) 3/112004 11,010.0 (ft) 3/2/2004 11,010.0 (ft) 3/312004 11,010.0 (ft) 3/412004 11,010.0 (ft) 3/512004 11,010.0 (ft) 3/612004 11,010.0 (ft) 3f7/2004 11,010.0 (ft) 3/812004 11,010.0 (ft) e -e KERR-MCGEE CORPORATION Final Well J Event Summary Page 1 of 1 End Date: 3/8/2004 Start Date: 2/1/2004 24 HOUR SUMMARY RIGGING UP NABORS 27E WITH BALL MILL, AUXILARY EQUIPMENT & CAMPS. Nm & TEST DtVERTER SYSTE;M. REPAIR CROWN-Q-MATIC, OFF-LOAD MUD, PIU DP. RIG REPAIR, PIU MORE DRILL PIPE, SPUD AT NOON ON 2/16/04. DRILLED TO 278. PIU BHA .. REPLACED MUD MOTOR, REPAIRED BALL MILL PUMP, DRILLED AHEAD. DRILLED AHEAD, REPAIRED BALL MILL. CIRC & WIPER TRIP AT 3233'. DRILLED AHEAD. CONTROL DRILLED WHILE WORKING ON BALL MILL. DRILLED AHEAD. DRILLED AHEAD TO CASING POINT AT 5720'. MADE A WIPER TRIP. CIRC & CONDITION HOLE, DROPPED A MAGNETIC MULTI-SHOT SURVEY. POOH FOR LOGS. R/U E-LlNE. RIH: TOOLS HIT OBSTRUCTION AT 1900'. POOH. RID E-LlNE. RIH. CIRC & CONDITION. POOH FOR LOGS: SECOND ATTEMPT. POOH. RlU E-LlNE. ATTEMPTED TO LOG: TOOLS STOPPED (TWICE) AT 474750' MD. RID E-LlNE. RIH. CIRC & CONDITION. POOH TO RUN CASING. RlU CASING TOOLS. RAN 9-518" CASING TO 5708' MD (4688' TVD). CIRC. CEMENTED CASING WITH KI:: I~"";S'TO 5tJI,"'",\;.1: f:ft::r-ORE LOSING CIRCULATION. RID CSG TOOLS. NID DIVERTER LINE, ETC. NIPPLE UP B.O.P. AND TEST FINISH TESTING BOPE. RUN BHA & PIU MORE DRILL PIPE. TEST CASING TO 3500#. PIU DRilL PIPE. DRILL OUT. DRILLED 20'. p..rrIl"UDT (t3.»BlW). WORK ON CHOKE LINE & VALVES. RE-TEST SAME. DRILL AHEAD DRILLED AHEAD TO 8097'. CIRC. DRILLED AHEAD. DRILLED AHEAD TO 9096'. CIRC. DRILLED AHEAD. DRILLED TO 10540'. POOH FOR WASHOUT #1. DRILLED TO 10731'. POOH FOR WASHOUT #2. FINISHED TRIPPING FOR WASHOUT #2, REPLACED SHOCK HOSE. CIRC & CONDITIONED. DRILLED TO TO AT 11010' MD (9306' TVD). CIRC. POOH FOR LOGS. ~ POOH. RlU E-LlNE. RAN: QUAD COMBO, DI-POLE SONIC CONTINUED LOGGING. MDT, CMR & ROTARY SIDEWALL CORES FINISHED E-LlNE LOGS. TESTED BOPE. RIH. FINISHED RIH. CIRC & CONDITION HOLE FOR LINER. POOH. R/U TUBING TOOLS. PIU TBG INNER STRING. START RUNNING LINER. FINISHED RUNNING TAPERED LINER. -'3'-1IZ'"INNERSTRINGt ~H WITH LINER ON 5" DP CIRC & COND, R/U TO CEMENT LINER. SET THE LINER HANGER. CEMENTED THE LINER. SET THE LINER-TOP PKR & TESTED SAME. DISPLACED W/ SEAWATER. LDDP. RIH WITH COMPLETION ASSEMBLY & PIU MORE TUBING. SPACED OUT & TESTED THE ANNULUS: TESTFAIlEO U. PORTCOLLAR lEAK. Printed: 4/612004 6:46:37 PM e e KERR-MCGEE CORPORATION Final Weill Event Summary Page 1 of 1 Legal Well Name: NIKAITCHUQ #1 Common Well Name: NIKAITCHUQ #1 (ALASKA) Event Name: COMPLETION DATE TMD 319/2004 11,010.0 (ft) 3/1012004 11,010.0 (ft) 3/11/2004 11,010.0 (ft) 3/1212004 11,010.0 (ft) 3/13/2004 11,010.0 (ft) 3/1412004 11,010.0 (ft) 3/15/2004 11,010.0 (ft) 3/16/2004 11,010.0 (ft) 3/17/2004 11,010.0 (ft) 3/18/2004 11,010.0 (ft) 3/19/2004 11,010.0 (ft) 3/20/2004 11,010.0 (ft) 3/21/2004 11,010.0 (ft) 3/2212004 11,010.0 (ft) 3/2312004 11,010.0 (ft) 3/24/2004 11,010.0 (ft) 3/2512004 11,010.0 (ft) 3/26/2004 11,010.0 (ft) 3/27/2004 11,010.0 (ft) 3/28/2004 11,010.0 (ft) 3/29/2004 11,010.0 (ft) 3130/2004 11,010.0 (ft) 3/31/2004 11,010.0 (ft) 4/1/2004 11,010.0 (ft) 41212004 11,010.0 (ft) End Date: 3/10/2004 Start Date: 3/9/2004 24 HOUR SUMMARY CIRCULATED OUT FREEZE PROTECT FLUID. POOH. PIU PORT COLLAR TOOL. RIH AND CLOSED PORT COLLAR. POOH. UD PORT COLLAR TOOL. ~TUBING~ TESŒØANNUlUST035OOIt:OK. RIU SLU. MADE GAUGE RING RUN, NID BOPE. NIU & TEST TREE. RELEASED RIG AT 21:30 ON 3/10/04. MOVED OUT DRILLING RIG. RIGGED UP TEST EQUIPMENT, ETC. CONTINUED R/U WELL TEST EQUIPMENT. MIl & R/U CTU FOR Cl..E!!lW'OUTfWN. RIH WI COIL TBG. WASHED DOWN WISEAWATER DISPLACED WI DIESEL. CBU. DISPLACE WITH DIESEL. POOH. RID CTU. RlU E-LlNE. RJ\I: 8~MT-GBæRESS-TEMJ? LOG. PERFORATED SAG RIVER 10408-72' MOWI 2-1/2" HSC. 6 SPF. RID E-LlNE. RAN STATIC BHP. FINISHED R/U WELL TESTERS. PREP FOR FRAC JOB. ~ FRAC'D THE SAG RIVER PERFS. SION. OPENED WELL AND BEGAN FLOW TEST & "POST FRAC" CLEAN-UP OPERATIONS. FLOW TEST. RlU SLU. ATTEMPTED DOWNHOlE SAMlES: FAILED. FLOW TEST WELL. FLOW TESTED WELL. R/U SLU. RAN FBHP BOMBS. POOH. RID SLU. FLOW TESTED WELL. R/U E-LlNE. RAN PROD LOG. RID E-LlNE. FLOW TESTED WELL. FLOW TESTED WELL. RlU SLU. HUNG OFF BHP GAUGES. FLOW TESTED WELL AT STABLE RATE. SI FOR BHP BUILDUP. WELL SHUT IN FOR BHP BUILDUP. WELL SHUT-IN FOR BHP BUtLDUP. SLU PULLED BHP GAUGES. CAUGHT DOWN HOLE FLUID SAMPLES. RID SLU. KILLED THE WELL WI MUD & BRINE. R/U E-LINE. SET EZSV AT 1Ð38Ø'. BAa..ED26' OF CMT.10354' - 80'. RID E-LlNE. R/U SLU. QPENEDSUDlNGSlEEVE. SET "PUMP THROUGH VALVE" IN SLIDING SLEEVE. SET "RP" SHEAR VALVE IN GlM. RID SLU. COULD NOT PUMP THROUGH SLIDING SLEEVE. R/U E-LlNE. PERORATED TBG 5860' - 70'. RID E-LlNE. CEMENTED WITH 440 BBlS OF "G" WITH CEMENT TO SURFACE. E-LINE CUT TBG AT 68' MD. RID E-LlNE. NID TREE. UD TBG HANGER & TBG STUB v RlU POWER SWIVEL. RAN CASING CUTTER & ATTMPTED TO CUT 9-518" CASING: FAILED. CHANGED OUT CASING CUTTERS. CUTBaRi STRINGS WITH "MUL TI-STRfNG" CUlTER. RID POWER SWIVEL, ETC. RECOVERED 9-5/8" & 13-3/8" CASING +1- 30' BELOW THE MUD LINE. RE-CUT & RECOVERED 13-3/8" CASING +1- 8' BELOW THE MUD LINE. DUG OUT THE CELLAR BOX & DIRTY ICE. SPOTTED 3-1/2 CU-YDS OF READY-MIX IN THE CONDUCTOR HOLE. BACK-FILLED THE CELLAR AREA WITH ICE. oJ DE-MOBILlZED EQUIP & PERSONNEL.. SCRAPED & CLEANED LOCATION. FINAL REPORT. Printed: 41612004 7:04:42 PM e -·l-.à-·-·-·t·-·-·- Mud Line: 42' MD 8ft I - - -+ - 26 ft . - ~t ~ 1 .:.....~:.*-::...;.: .-::*-~.-3..",,~ '~;".:^,;:) I ~/ :~mr G~; ;:.~ /%~ I·) ./1 J :. ., . .J :':1 ~~~~~I:" II) '.~~' ; _ N:,,~ 0 ."::" t: 0 '_.:, It) .~~, . .~ ns .::.~ N :.¡:.~ t: 0 ':::.~'.":~~'Iò, ~i: :~~~m~~~ .... " E ~~.......~~....... [~ :J:-'. . .:~;~;~:~.. . .j.. TOL at 5556' MD fe' :;¿m~""~ .,.fH~!~!~ (4571' TVD) t~ e: :~~~~~þ~ ~S:;:;:~:S~~~~~i . . D.. ·.-..·..~....."'v·.. ......., (Tested to 3500 pSI) ~~j. , ~~m~~ff~~~~9-5/8" at 5708' MD I ::::: ~I~m~~ :~~S:'~j (4688' TVD) 1<: ~, "~"...... ,', 'I Ii,: ~}:~$ ~:'::I Tubing Punch Holes: 5860'-70' MD 1.$:' 00 '..:::j Sliding Sleeve at 5878' MD ~: ~ m:;~ (could not pump through it) I: .~ :U:1 I: :æ 'i i,::~j I' ><, ::::J li~:::.,:. .:~ ~ ' L),>~,~';ì f +:iml I, ~ ..;)::j í. ~, iii::~ í' O' -gii:;·'¡t f. ~, E ::':(, r~' ! ::~;:~ ìi:9;; ~ :::':1 1::;<; .::::g. 1..·:.).'.··.·.·.·..·.·.·.1. &'¡:' I:: .;'3:::J l.f::::: :.::'::~ 1.;< .\. ::::Î ·~}t~~~~~ :~~~~~~~ f"E~"~"~'~ .!ot"-,,,,~ - .þJ ~~ :!:..!:.-::.~ ~ _ c '. "'b"'~ ..~ ~!~~.:~é~_m~EZSV at 10380' wi 26' of"G" cement. TOC = 10354' MD .à: ~~~.......~~~ (Tagged & tested to 1500 psi.) ............ ."to....... '-"'-,/'-,/'- Ir/'_.I'_r/'_. ~,»t1.~ '\1.1..11 .,tU" ,t1.¡'¡' t~~\-~ f:~\-~ 1~·rI'·"·"·. "'...... .J>.. t~!~!~!~~ :!~~~~~~ [~~~S~'!-t~ ·~~~~S~~ ...... .......'\,... .-t'! ,S~~~S~5I ~~~~~~a r/'""'."'.r/'" ..~~~"'- e @ KERR-MCBEE CORPDRATlOII Nikaitchuq #1 Plug & Abandon Report (Sundry No.: 304-088) 1. Displaced the tubing and lower liner from 5800' to the perforations with 10.6 ppg mud. Set an EZSVat 10,380' MD. Tagged & tested the EZSV to 1500 psi. Dumped 26' of "G" cement on top. TOC = 10,354' MD. Circulated 2150 sx of Premium cement via tubing, through the perforations 5860'-70', and had cement returns to surface. Displaced with 10 bbl water and allowed the well to U-tube: leaving the TOC at 75' MD. 2. 3. 3-1/2" Tubing cut & retrieved at 68' MD 9-5/8" Casing cut & retrieved at 63' MD 13-3/8" Casing cut & retrieved at 50' MD Covered the casing stubs and back filled conductor hole with 3.5 yd3 Ready Mix 3-1/2",9.2#, L-80, 1ST-Mod Tubing 5-1/2", 17#, L-80 Upper Liner PBR: 9450'-74' MD Perforations: 10408' to 10472' MD 8716' to 8778' TVD PBTD = 10,750' MD (CTU Tag) 11,010' TMO (9307' TVD) .. . Kerr-McGee Corporation Western North Slope, Alaska NW Milne Point (Spy Island) Nikaitchuq #1 Job No. AKZZ2893103, Surveyed: 1 March, 2004 Survey Report 9 April, 2004 Your Ref: API 500292319300 Surface Coordinates: 6054881.08 N, 519518.28 E (70033' 39.9854" N, 149050' 23.5896" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 35.94ft above Mean Sea Level Survey Ref: svy2069 e e Kerr-McGee Corporation Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 0.00 0.000 0.000 -35.94 0.00 0.00 N 0.00 E 6054881.08 N 519518.28 E 0.00 SHL (404' FSL & 1336' FWL, Se 16 - T14N - R9E) 100.00 0.538 180.940 64.06 100.00 0.47S 0.01 W 6054880.61 N 519518.27 E 0.538 -0.47 200.00 1.077 180.940 164.05 199.99 1.885 0.03W 6054879.20 N 519518.25 E 0.538 -1.88 300.00 1.615 180.940 264.02 299.96 4.235 0.07W 6054876.85 N 519518.22 E 0.538 -4.22 e 400.00 0.767 184.565 363.99 399.93 6.58S 0.14W 6054874.50 N 519518.16 E 0.851 -6.58 500.00 1.791 6.107 463.98 499.92 5.88S 0.07W 6054875.20 N 519518.23 E 2.557 -5.88 600.00 4.732 1.363 563.81 599.75 0.22 S 0.19 E 6054880.86 N 519518.47 E 2.951 -0.22 700.00 7.586 1.287 663.21 699.15 10.60 N 0.42 E 6054891.68 N 519518.67 E 2.854 10.58 800.00 9.661 1.322 762.06 798.00 25.69 N 0.86 E 6054906.77 N 519519.07 E 2.075 25.66 900.00 11.344 358.536 860.38 896.32 43.89 N 0.88 E 6054924.97 N 519519.04 E 1.758 43.84 1000.00 13.488 355.881 958.08 994.02 65.17 N 0.26W 6054946.25 N 519517.85 E 2.218 65.15 1100.00 16.197 355.546 1054.73 1090.67 90.71 N 2.30W 6054971.78 N 519515.74 E 2.710 90.74 1200.00 18.629 356.357 1150.11 1186.05 120.66 N 4.41 W 6055001.73 N 519513.55 E 2.445 120.74 1300.00 21.286 356.882 1244.16 1280.10 154.55 N 6.39W 6055035.62 N 519511.49 E 2.663 154.67 1400.00 24.405 356.778 1336.31 1372.25 193.30 N 8.48W 6055074.36 N 519509.30 E 3.119 193.46 1500.00 26.310 356.211 1426.50 1462.44 236.41 N 11.09 W 6055117.46 N 519506.57 E 1.920 236.63 1600.00 28.039 355.837 1515.53 1551.47 281.83 N 14.28 W 6055162.87 N 519503.25 E 1.737 282.12 1700.00 30.392 356.606 1602.84 1638.78 330.45 N 17.59 W 6055211.48 N 519499.81 E 2.383 330.81 1800.00 32.853 355.535 1687.99 1723.93 382.77 N 21.01 W 6055263.79 N 519496.26 E 2.524 383.20 1900.00 37.509 355.256 1769.83 1805.77 439.98 N 25.70 W 6055320.99 N 519491.42 E 4.659 440.53 2000.00 39.421 354.623 1848.02 1883.96 502.07 N 31.19 W 6055383.07 N 519485.77 E 1.953 502.75 e 2100.00 41.038 354.218 1924.31 1960.25 566.41 N 37.44 W 6055447.39 N 519479.35 E 1.638 567.24 2200.00 40.932 352.851 1999.76 2035.70 631.61 N 44.95 W 6055512.57 N 519471.66 E 0.902 632.63 2300.00 40.565 352.926 2075.65 2111.59 696.24 N 52.91 W 6055577.18 N 519463.54 E 0.371 697.45 2400.00 41.607 352.067 2151.03 2186.97 761.38 N 61.58 W 6055642.29 N 519454.69 E 1.186 762.81 2500.00 42.865 352.191 2225.14 2261.08 827.87 N 70.87 W 6055708.76 N 519445.23 E 1.261 829.53 2600.00 43.759 352.256 2297.58 2333.52 896.20 N 79.96 W 6055777.06 N 519435.96 E 0.895 898.09 2700.00 42.999 351.500 2370.22 2406.16 964.22 N 89.78 W 6055845.06 N 519425.96 E 0.920 966.36 2800.00 41.661 352.789 2444.03 2479.97 1030.99 N 99.48 W 6055911.80 N 519416.08 E 1.595 1033.38 2900.00 40.456 354.227 2519.57 2555.51 1096.14 N 106.48 W 6055976.93 N 519408.91 E 1.532 1098.69 9 April, 2004 - 10:34 Page 2 of7 DrillQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 3000.00 40.404 355.948 2595.85 2631.79 1160.52 N 112.39 W 6056041.30 N 519402.84 E 1.117 1163.22 3100.00 40.996 358.004 2671.69 2707.63 1225.61 N 115.66 W 6056106.38 N 519399.39 E 1 .466 1228.38 3200.00 41.981 359.653 2746.65 2782.59 1291.78 N 117.02W 6056172.55 N 519397.86 E 1 .471 1294.56 3300.00 42.170 359.901 2820.76 2856.70 1358.92 N 117.11 W 6056239.69 N 519397.59 E 0.252 1361.67 3400.00 41.983 359.836 2894.98 2930.92 1425.94 N 117.27W 6056306.71 N 519397.25 E 0.192 1428.68 e 3500.00 41.506 359.546 2969.57 3005.51 1492.54 N 117.61 W 6056373.31 N 519396.73 E 0.515 1495.26 3600.00 41.605 0.618 3044.42 3080.36 1558.86 N 117.56 W 6056439.62 N 519396.61 E 0.717 1561.55 3700.00 40.935 1.669 3119.60 3155.54 1624.78 N 116.19W 6056505.55 N 519397.81 E 0.964 1627.41 3800.00 40.684 1.355 3195.26 3231.20 1690.14 N 114.46W 6056570.91 N 519399.36 E 0.325 1692.69 3900.00 40.464 1.194 3271.35 3307.29 1755.01 N 113.12W 6056635.79 N 519400.54 E 0.244 1757.50 4000.00 41.257 1.847 3346.87 3382.81 1820.54 N 111.33 W 6056701.32 N 519402.16 E 0.901 1822.95 4100.00 41.066 1.912 3422.08 3458.02 1886.40 N 109.07 W 6056767.19 N 519404.24 E 0.196 1888.72 4200.00 40.567 1 .432 3497.80 3533.74 1951.69 N 107.17 W 6056832.48 N 519405.97 E 0.590 1953.93 4300.00 40.935 0.928 3573.78 3609.72 2016.69 N 105.81 W 6056897.49 N 519407.16 E 0.493 2018.87 4400.00 41.645 0.705 3648.72 3684.66 2082.91 N 104.98 W 6056963.70 N 519407.82 E 0.726 2085.03 4500.00 41.295 0.900 3723.57 3759.51 2149.21 N 104.05 W 6057030.00 N 519408.57 E 0.373 2151.28 4600.00 40.521 0.691 3799.11 3835.05 2214.73 N 103.05 W 6057095.53 N 519409.40 E 0.786 2216.75 4686.00 40.825 0.973 3864.52 3900.46 2270.55 N 102.36 W 6057151.36 N 519409.94 E 0.413 2272.53 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 4686.00ft MD. 3900.46ft TVD 4700.00 40.976 1.082 3875.11 3911.05 2279.72 N 102.19W 6057160.52 N 519410.08 E 1.190 2281.69 4800.00 41 .400 1.011 3950.27 3986.21 2345.67 N 100.87 W 6057226.47 N 519411.23 E 0.427 2347.57 4900.00 40.851 0.525 4025.51 4061 .45 2411 .53 N 99.97 W 6057292.34 N 519411.96 E 0.636 2413.38 e 5000.00 40.155 0.023 4101.55 4137.49 2476.47 N 99.66 W 6057357.28 N 519412.10 E 0.768 2478.29 5100.00 41.789 0.381 4177.13 4213.07 2541.94 N 99.45 W 6057422.75 N 519412.13 E 1.651 2543.73 5200.00 41.530 0.520 4251.82 4287.76 2608.44 N 98.89 W 6057489.25 N 519412.51 E 0.275 2610.18 5300.00 40.540 359.397 4327.26 4363.20 2674.07 N 99.00 W 6057554.88 N 519412.24 E 1.235 2675.80 5400.00 39.848 359.184 4403.73 4439.67 2738.51 N 99.79 W 6057619.31 N 519411.28 E 0.705 2740.23 5500.00 40.216 358.954 4480.21 4516.15 2802.93 N 100.87 W 6057683.73 N 519410.03 E 0.396 2804.65 5600.00 39.608 358.559 4556.87 4592.81 2867.12N 102.06 W 6057747.92 N 519408.66 E 0.658 2868.85 5700.00 39.010 357.118 4634.31 4670.25 2930.33 N 104.53 W 6057811.13 N 519406.02 E 1.092 2932.11 5800.00 38.502 356.793 4712.26 4748.20 2992.88 N 108.06 W 6057873.67 N 519402.33 E 0.547 2994.74 9 April, 2004 - 10:34 Page 3 of7 DrillQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 5900.00 38.095 356.326 4790.79 4826.73 3054.69 N 111.60 W 6057935.47 N 519398.63 E 0.500 3056.62 6000.00 37.653 356.049 4869.69 4905.63 3115.99N 115.83 W 6057996.75 N 519394.24 E 0.473 3118.01 6100.00 36.581 1.278 4949.36 4985.30 3176.35 N 118.06W 6058057.11 N 519391.85 E 3.332 3178.41 6200.00 35.611 2.758 5030.17 5066.11 3235.19 N 115.38 W 6058115.95 N 519394.38 E 1.304 3237.15 6300.00 34.820 1.903 5111.88 5147.82 3292.78 N 112.95 W 6058173.55 N 519396.65 E 0.933 3294.65 e 6400.00 34.301 1.028 5194.25 5230.19 3349.47 N 111.51 W 6058230.24 N 519397.94 E 0.718 3351.28 6500.00 33.810 1.078 5277.10 5313.04 3405.46 N 110.50 W 6058286.24 N 519398.81 E 0.492 3407.22 6600.00 33.511 0.883 5360.42 5396.36 3460.75 N 109.52 W 6058341.53 N 519399.64 E 0.318 3462.46 6700.00 34.959 0.291 5442.98 5478.92 3517.17 N 109.05 W 6058397.95 N 519399.96 E 1 .486 3518.84 6800.00 34.497 1.027 5525.10 5561.04 3574.22 N 108.28 W 6058455.00 N 519400.58 E 0.624 3575.85 6900.00 33.455 0.109 5608.07 5644.01 3630.04 N 107.63 W 6058510.83 N 519401.09 E 1.162 3631.63 7000.00 32.750 358.634 5691.85 5727.79 3684.63 N 108.30 W 6058565.41 N 519400.27 E 1.070 3686.21 7100.00 31.846 357.622 5776.28 5812.22 3738.18 N 110.02 W 6058618.95 N 519398.41 E 1.053 3739.79 7200.00 30.732 356.585 5861.83 5897.77 3789.89 N 112.68 W 6058670.66 N 519395.61 E 1.238 3791.56 7300.00 30.956 357.296 5947.88 5983.82 3840.74 N 115.73 W 6058721.50 N 519392.43 E 0.428 3842.47 7400.00 30.860 358.667 6033.43 6069.37 3892.50 N 117.39W 6058773.26 N 519390.63 E 0.711 3894.26 7500.00 31.757 359.161 6119.23 6155.17 3943.85 N 118.32W 6058824.61 N 519389.56 E 0.933 3945.62 7600.00 34.905 356.893 6202.91 6238.85 3998.54 N 119.83 W 6058879.29 N 519387.91 E 3.385 4000.33 7700.00 37.568 354.829 6283.43 6319.37 4057.66 N 124.29 W 6058938.40 N 519383.30 E 2.928 4059.55 7800.00 36.746 354.601 6362.77 6398.71 4118.25 N 130.05 W 6058998.97 N 519377.38 E 0.833 4120.28 7900.00 35.129 353.724 6443.74 6479.68 4176.64 N 135.93 W 6059057.34 N 519371.34 E 1.697 4178.81 8000.00 33.778 355.392 6526.21 6562.15 4232.92 N 141.43 W 6059113.61 N 519365.70 E 1.648 4235.22 e 8100.00 32.266 359.891 6610.06 6646.00 4287.34 N 143.75 W 6059168.02 N 519363.23 E 2.880 4289.68 8200.00 31.758 358.125 6694.98 6730.92 4340.14 N 144.73 W 6059220.82 N 519362.12 E 1.065 4342.49 8300.00 33.789 358.130 6778.88 6814.82 4394.50 N 146.53 W 6059275.18 N 519360.17 E 2.031 4396.88 8400.00 33.108 358.288 6862.28 6898.22 4449.65 N 148.17W 6059330.33 N 519358.38 E 0.687 4452.06 8500.00 32.019 357.741 6946.55 6982.49 4503.46 N 150.07 W 6059384.13 N 519356.35 E 1.128 4505.90 8600.00 31.223 357.510 7031.83 7067.77 4555.64 N 152.25 W 6059436.30 N 519354.02 E 0.806 4558.12 8700.00 31.699 358.377 7117.23 7153.17 4607.61 N 154.38 W 6059488.27 N 519351.75 E 0.657 4610.13 8800.00 31.964 359.355 7201.97 7237.91 4660.71 N 155.06 W 6059541.37 N 519350.94 E 0.580 4663.23 8900.00 30.993 359.125 7287.22 7323.16 4712.96 N 155.91 W 6059593.62 N 519349.95 E 0.979 4715.48 9000.00 29.922 0.133 7373.43 7409.37 4763.64 N 156.34 W 6059644.29 N 519349.39 E 1.187 4766.15 9100.00 28.713 359.978 7460.59 7496.53 4812.65 N 156.04 W 6059693.30 N 519349.56 E 1.211 4815.13 9200.00 27.599 359.360 7548.78 7584.72 4859.79 N 156.37 W 6059740.44 N 519349.10 E 1.152 4862.27 9300.00 26.785 359.097 7637.75 7673.69 4905.44 N 157.00 W 6059786.09 N 519348.35 E 0.822 4907.92 9 April, 2004 . 10:34 Page4of7 DrillQuest 3.03.06.002 Kerr-McGee Corporation Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 March, 2004 Western North Slope, Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9400.00 25.720 1.336 7727.42 7763.36 4949.71 N 157.01 W 6059830.36 N 519348.23 E 9500.00 24.879 4.235 7817.84 7853.78 4992.36 N 154.95 W 6059873.02 N 519350.18 E 9600.00 23.600 4.250 7909.00 7944.94 5033.33 N 151.81 W 6059913.99 N 519353.20 E 9700.00 21.820 0.868 8001.26 8037.20 5071 .86 N 150.14 W 6059952.53 N 519354.77 E 9800.00 20.416 2.005 8094.52 8130.46 5107.94 N 149.23 W 6059988.61 N 519355.59 E 9900.00 18.313 2.513 8188.87 8224.81 5141.02 N 147.87 W 6060021.69 N 519356.87 E 10000.00 16.782 1.369 8284.23 8320.17 5171.11 N 146.89 W 6060051.79 N 519357.76 E 10100.00 15.429 0.470 8380.30 8416.24 5198.86 N 146.33 W 6060079.54 N 519358.25 E 10200.00 14.291 358.065 8476.99 8512.93 5224.35 N 146.72 W 6060105.03 N 519357.79 E 10300.00 13.555 357.633 8574.03 8609.97 5248.47 N 147.73 W 6060129.14 N 519356.72 E 10400.00 13.005 356.337 8671.38 8707.32 5271 .34 N 148.84 W 6060152.01 N 519355.55 E 10406.00 12.979 356.219 8677.22 8713.16 5272.68 N 148.93 W 6060153.35 N 519355.46 E 10500.00 12.291 355.972 8768.92 8804.86 5293.29 N 150.46 W 6060173.95 N 519353.87 E 10600.00 11.163 355.827 8866.82 8902.76 5313.63 N 151.81 W 6060194.29 N 519352.47 E 10700.00 10.048 354.516 8965.12 9001.06 5331.92 N 153.36 W 6060212.58 N 519350.87 E 10800.00 9.457 352.824 9063.69 9099.63 5348.65 N 155.19W 6060229.30 N 519348.99 E 10900.00 9.384 351.545 9162.36 9198.30 5364.79 N 157.43 W 6060245.44 N 519346.71 E 11000.00 9.390 351.370 9261.02 9296.96 5380.92 N 159.88 W 6060261.56 N 519344.22 E _11010.00 9.390 351.370 9270.88 9306.82 ... 5382.54 N 160.12 W 6060263.18 N 519343.98 E 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@35.94' MSL. Northings and Eastings are relative to 404' FSL, 1336' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 404' FSL, 1336' FWL and calculated along an Azimuth of 358.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1101 0.00f!., The Bottom Hole Displacement is 5384.92f!., in the Direction of 358.296° (True). The Along Hole Displacement is 5405.72f!. The Total Accumulated Dogleg is 147.809° The Measured Tortuosity is 1.429°/100f!. The Directional Difficulty Index is 5.5. 9 April, 2004 - 10:34 Page 50f7 Kerr McGee Dogleg Vertical Rate Section Comment (°/1000) 1 .454 4952.17 1.497 4994.74 1.279 5035.61 2.207 5074.08 e 1 .463 5110.12 2.109 5143.14 1.569 5173.20 1.377 5200.92 1.294 5226.41 0.743 5250.55 0.625 5273.44 0.616 5274.78 Target (Top / Sag River) @ 1040 MD, 8713.16' TVD (39T FSL & 1201' FWL, Sec. 9 - T14N -R9E) 0.735 5295.43 1.128 5315.80 1.141 5334.13 0.657 5350.90 0.222 5367.10 0.029 5383.29 0.000 5384.91 Projected BHL : 1101 0.0f! MD, 9306.82 TVD (50T FSL & 1190' ... FWL, Sec. 9 - T14N - R9E) e DrillQuest 3.03.06.002 Western North Slope, Comments Measured Depth (ft) 0.00 4686.00 10406.00 11010.00 9 April, 2004 - 10:34 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 3900.46 8713.16 9306.82 0.00 N 2270.55 N 5272.68 N 5382.54 N 0.00 E 102.36 W 148.93 W 160.12 W Kerr-McGee Corporation Survey Report for Spy Island· Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 March, 2004 Comment SHL (404' FSL & 1336' FWL, Sec. 16 - T14N - R9E) 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 4686.00ft MD, 3900.46ft TVD Target (Top / Sag River) @ 10406' MD, 8713.16' TVD (397' FSL & 1201' FWL, Sec. 9 - T14N -R9E) Projected BHL : 1101 O.Oft MD, 9306.82 TVD (507' FSL & 1190' FWL, Sec. 9 - T14N - R9E) Kerr McGee Page 60f7 DrillQuest 3.03.06.002 e e Kerr-McGee Corporation North Reference Sheet for Spy Island· Nikaitchuq #1 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: 6054881.08 N, 519518.28 E Geographical Coordinates of Well: 70° 33' 39.9854" N, 149° 50' 23.5896" W Surface Elevation of Well: 35.94ft Grid Convergence at Surface is +0.151 ° Magnetic Declination at Surface is +24.895° (15 February, 2004) 9 April, 2004 - 10:34 Kerr McGee e e Page 70f7 DrillQuest 3.03.06.002 e Weekly Operations Report Nikaitchuq #1 Permit No.: 204-018 Weeks of February 7th _19t\ 2004 2/7/04 Commenced moving in Nabors 27E from staging area to the drill site. Temp = _450 F. 2/8/04 Continued moving in Nabors 27E from staging area to the drill site. Temp = _450 F. 2/9/04 Continued moving in and rigging up Nabors 27E on the drill site. Temp = _300 F. 2/10/04 Continued moving in and rigging up Nabors 27E on the drill site. Temp = _250 F. Phase 1. 2/11/04 Stopped moving in and rigging up Nabors 27E on the drill site. Temp = -300 F. Phase III. 2/12/04 Continued rigging up Nabors 27E on the drill site. Phase II: roads badly drifted, low visibility. 2/13/04 Continued rigging up Nabors 27E on the drill site. Phase I: roads drifted, low visibility. 2/14/04 Continued rigging up Nabors 27E on the drill site. 2/16/04 Continued R!U Nabors 27E on the drill site. Diverter function test witnessed by field inspector PID 180 jts of 5" DP. Spud Nikaitchuq #1 at noon on 2/16/2004. Cleaned out 13-3/8" drive pipe and drilled to 245'. POOH. PID BHA. DRLD to KOP of394' MD. 2/17/04 DRLD and built angle to 1534' MD. 11.5 HRS of rig repairs and PDM problems. 2/18/04 DRLD from 1534' to 3233' MD. 9.5 HRS of rig repairs (ball mill). Made wiper trip while working on the ball mill etc. Base of Permafrost = 1770' MD, 1695' TVD. ~ <;0 '''\v\':> 'S."-tJ- \ \av..:)ex 2/19/04 :,>~a-)\0 ~~ S't ()CJ \--\ \')~\r-..~~ a.~~'\(::~\\><::J..:~~ DRLD from 3233' to 4720' MD (4686' TVD). MW = 9.6 ppg. Conditioning the hole to run open-hole logs followed by 9-5/8" casing per program. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 e e ~I ¡!f tø~t , Weekly Operations Report Nikaitchuq #1 Permit No.: 204-018 Week of February 20th - 27t\ 2004 2/20/04 Drilled to casing point at 5720' MD (4686' TVD). Conditioned the hole for logs. POOH. MW = 9.6 (poor solids control). BlWest Sak ± 5350' MD (4400' TVD). 2/21/04 ,--- bú.. ~f..£. o~ ~ (:.."::~ .~C\. \. ,,\""C><...~~~ Q ~~C>, ~\...;)"\.~ .,] R/U E-Line. Ran Quad-Combo. Tools stopped at 1690' MD. RID'h-Line. Rill, washed to "-\ \0 \~\~~ bottom, conditioned the hole, POOH to re-try the logging run. 2/22/04 R/U E-Line. Ran Quad-Combo. Tools stopped at 4750' MD, Logged while POOH. Took off "stand off' centralizers and re-ran Quad-Combo: same result. POOH, RID E-Line. Rill with bit and BHA. E-line caliper log to 4750' MD showed 12-3/4" average hole size. 2/23/04 Conditioned the hole to run surface casing. POOH. R/U casing tools. 2/24/04 ,.-.. \ <:.a.0 ~c \ V\V\.1ë:. <. ~ \C)..~ ~ \"\0 ~ Ran 9-5/8" surface casing, set and cemented at 5708' MD. 500 sx lead & 520 sx tail. 80 bbl cement to surface, lost circulation the last 70 bbls of displacement. 2/25/04 NIU and tested BOPE as per the permit: Repaired manifold, valves, etc. 2/26/04 Finished testing BOPE. PIU additional 5" DP. Tested casing to 3500 psi. Drilled out shoe track plus 20 ft of new hole. Performed LOT: 13.2 ppg EMW. I 2/27/04 Drilled ahead to 8003' MD (6565' TVD). Made a wiper trip (precautionary). Drilling ahead. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 e Weekly Operations Report Nikaitchuq # 1 Permit No.: 204-018 Week of February 28th - March st\ 2004 2/28/04 Drilled 8-112" hole to 9850' MD. MW = 10.6 ppg. 2/29/04 Drilled 8-1/2" hole to 10450' MD. Tripped for wash out #1. Drilled 8-112" hole to 10731' MD. Tripped for wash out #2. MW = 10.7 ppg. ' 3/01104 Finished POOH for wash out #2. Slip & cut drilling line. Rig repairs. RIH. Drilled 8-112" hole to 11010' MD. Circulated & conditioned mud. POOH for logs. MW = 10.8 ppg. 3/02/04 S\\~ "-\ \'{ d~~~~'-\~" ~ \C3.,", ~.~ ~ \o<;aai Finished POOH. R/U Schlumberger. Ran Quad-Combo. Ran Di-Pole Sonic. MW = 10.8 ppg. 3/03/04 Schlumberger ran MDT (pressures only) CMR+ & SWC's. MW = 10.8 ppg 3/04/04 Finished SWC's. RID Schlumberger. Tested BOPE. RIH with bit & BHA. MW = 10.8 ppg. 3/05/04 Circulated & conditioned the hole to run the liner. POOH. MW = 10.8 ppg 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 · Weekly Operations Report Nikaitchuq #1 Pennit No.: 204-018 Week of March 6th - March 12t\ 2004 3/06/04 POOH. Ran tapered liner with inner string per program. Circulated. MW = 10.8 ppg 3/07/04 Set the liner hanger. RIU Halliburton & cemented the liner per program with cement volumes adjusted per the caliper log. Set liner top packer & tested to 1000 psi. Displaced with seawater. Recovered cement contaminated mud. LDDP. MW = 10.8 ppg 3/08/04 RIU & run 3-1/2" completion per program. Spaced out, stabbed in to PBR & attempted IA test negative. Port collar had opened. POOH 6 stds of tubing. 3/09/04 Displaced freeze protect fluid with seawater. PIU port collar shifting tool & RIH on DP. Shifted & tested the port collar. POOH with DP. 3/10/04 Re-ran the top 6 stands of tubing. Circulated in freeze protection fluid. Stabbed in to the PBR & landed the tubing hanger. Tested IA to 3500 psi: ok. Ran slick liner GIR & tagged 500 ft high on debris. N/D BOPE. NIU tree. Released the rig at 23:30 hours. 3/11/04 RID & MORT to Nikaitchuq #2. Organized CTU to clean out debris in the lower liner prior to starting the completion & testing phase. 3/12/04 Continued moving the rig to Nikaitchuq #2. Plan to clean out Nikaitchuq #1 lower liner on Saturday 3/13/2002. Application for Sundry Approval (perforate, frac & test) was submitted on Thursday 3/11/2004. Anticipate spudding Nikaitchuq #2 early on 3/13/2004. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 20 'f -bIg' e Weekly Operations Report Nikaitchuq #1 Permit No.: 204-018 Week of March 13th through March 19t\ 2004 3/13/04 RIU coiled tubing unit, tanks, etc. to clean out debris in the lower (3-112") liner. SIaN. 3/14/04 Cleaned out soft sand and fill (ftom the port collar incident) with CTU. Displaced the well with diesel. Blew down the coil. RID CTU. SIaN. 3/15/04 RIU Schlumberger E-Line. Ran SCMT with no pressure: poor bonding. Ran repeat with 1800 psi: good bonding across the pay zone. Perforated the Sag River per program: 10408' -72' MD. RID E-Line. SIaN. Prepare for ftac job. 3/16/04 RIU Slick Line. Ran pre- ftac static BHP bomb with gradient stops. RIU ftac equipment, haul and heat frac fluids. 3/17/04 Continued RIU ftac equipment. PJSM. Frac'd perforations 10408'-72' with 96,000# Carbo lite. SID. RID ftac equipment. 3/18/04 Continued to RID ftac equipment. Commenced load recovery: 1295 bbl ofload to recover. 3/19/04 Continued load recovery and flow tested the well. RIU Slick line & caught BH fluid samples. Lack 412 BLWTR. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 · Weekly Operations Report Nikaitchuq #1 Pennit No.: 204-018 Week of March 20th through March 26th, 2004 3/20/04 Continued to flow test the well and monitor fluid properties. R/U Slick Line. Ran FBHP and gradient stops. RID Slick Line. 3/21/04 Continued to flow test the well and monitor fluid properties. Phase 1 - 2 throughout the day. 3/22/04 Continued to flow test the well and monitor fluid properties. R/U E-Line. Ran production log. RID E- Line. Continued flow test. 3/23/04 R/U Slick Line. Ran BHP bombs and down-hole shut it tool on slick line. Hung the tools in the "X" nipple at 10,290' MD. RID SLU. Flowed well at stable rate prior to down-hole shut in & BHP build up test. Shut in for BHP build up. 3/24/04 Shut in for BHP build up. 3/25/04 Shut in for BHP build up. 3/26/04 R/U SLU. Recovered BHP bombs and made gradient stops. Preparing to P & A. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 Ló4l~()/5 . Weekly Operations Report Nikaitchuq #1 Permit No.: 204-018 Week of March 27th through April2Dd, 2004 3/27/04 Collected "down hole" fluid samples with SLU and "Pencor". RID SLD. RIU Halliburton. Displaced the liner and tubing (below the sliding sleeve at 5872') with 10.6# mud followed by water and freeze protect fluid. RIU E-Line. Set EZSV at 10,380' (28' above the perfs). Re- tagged the EZSV: OK. Tested the EZSV to 1000 psi: OK. 3/28/04 Dump bailed 26 ft of cement on top ofthe EZSV (2 runs). RID E-Line. RIU SLU. Opened and pumped through the sliding sleeve at 5872' MD. Set HES check valve in the sliding sleeve. Pulled the dummy GL V and set an "RP" shear valve in the GLM. Prepare to pump cement plug. 3/29/04 RIU Halliburton. Could not circulate through sliding sleeve and check valve. RIU E- Line. Ran tubing punch & perforated holes in the tubing 2 ft above the sliding sleeve. Broke circulation. Mixed and circulated 2150 sx of Premium cement (440 bbl) as per program. Cement to surface: witnessed by AOGCC. RIU E-Line and cut the tubing at 68 ft RKB. Allowed tubing ans IA to equalize. Blew down tubing and IA with air. N/D tree. Pulled tubing stub with a crane. 3/30/04 PIU power swivel and casing cutter with a crane. Attempted to cut 9-5/8" casing twice without success. SDON. 3/31/04 PIU Multi-string cutter and cut both the 9-5/8" and 13-3/8" casing at ± 65' RKB. SDON 4/1/04 Cut the 13-3/8" below the wellhead. RIU casing jacks and retrieved the 9-5/8" casing. Cleaning up location and de-mobilizing equipment this am. 4/2/04 RIU SLU. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907) 339-6370 · 7-Di.{ -ö I ~ Weekly Operations Report Nikaitchuq #1 Permit No.: 204-018 Week of April 2nd through April 8th 2004 412/04 Re-cut and recovered the 13-3/8" casing 14' below pad level (8 ft below the mud line). Continued cleaning location and de-mobilizing equipment. 4/3/04 Dug out the cellar box. Dumped 3.5 cu-yds of ready mix in the conductor hole. Back filled the cellar with ice. Continued de-mobilizing personnel and equipment. 4/4/04 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. 41704 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 · -- Sp·B....':/..5un D RI LLI N CSSeAVIt:eS A Halliburton Company Well Data Transmittal To: Alaska Oil & Gas ConselVation Commission Attn: Librarian 333 West 7th Avenue, Suite 100 Anchorage AK 99501 RE: :i~~i~~~:~ E;~ of Well Summaries, and Digital Data for: ::¿ f)'1"'"'' ..{)jg' April 5, 2004 Nikaitchua 1 Final: 511 MD Mud Log: 1 Color Set Separate Envelope 5111VD Mud Log: 1 Color Set Separate Envelope 1" MD Mud Log 1 Color Set Bound 1" 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 LEITER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Steve Carroll 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: J-/ - -:::¡ - l)i Signe;-~0\\~~\. ~_"Â-.,i~/\t, Print: . . Kerr-McGee Oil & Gas Corp. Well Day Report March 2004 Production API# 1 ~, 50-~23193-00-X01 PeJl1~^ft{- ~ ð ~ ~ /B Well # # Hours Produced 136 Well Days 5.7 RECEIVED APR 2 02004 Alaska Oil & Gas Cons. COmmissio,rr é~ ~ Anchorage ? ~cl{L~~,- <i CslJS(ß-:O'PŒ<?ft~~ \ft1Ö I" 'J'~L1ILf ¡f A~ ,(t'it (~~~ ~ð . Qu~ plLf}('l{(dt~\ ~¿¡ Td pM r{,L,~ vt~c~ t;.FtIl. .{Jj) 1;).. +A.. ' ~...., J/ (4~,~') ð ý) Æ1Ú?:) J/YI LL~ --. FA clJ; ~.<Z.. ~ (\ r\f~. flA "'. .. .A. ~. U:j (C)l '~L /J r \Ll{/V1/) . ~() A/)'L 1Dð y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FACILITY REPORT OF PRODUCED GAS DISPOSITION Title Accountin¡¡ Supervisor 1. Facility Number 12. Facility Name Disposition 3. Field Exploration Volume MCF 6. Sold 7. Reinjected 8. Flared or vented 1 hour or less .. Flared or vented more than 1 hour (see instr.) 5836.88 10. Pilot and Purge 11. Used for lease operations (specify in Remarks) 12. Other (see instructions) 13. TOTAL VOLUME (ITEMS 6-12) 5836.88 14. NGL Gas Equivalent 15. Purchased gas 16. Transferred from: .7. Transferred to: (Express as a negative #) 18. Remarks: Note: Test Production, Exploratory Well I h"eby œrt'" th" the to~t,"e ",d 00_ to th boot of my 'oowl,dge. Signature ð Printed Name Larry A. Johnson Phone (281) 673 6542 /4. Operator 15. MonthlYear of Disposition Kerr-McGee Oil & Gas Corp. Mar-04 20. For production from multiple pools, list contribution of each pool as a percent of Tota/ Volume. o Pool Name Pool Code Percent o o o o o Authorization >1 hr: MCF Safety MCF Lease Use MCF Conservation Waste: MCF Commissioner Date Date Note: All volumes must be corrected to pressure of 14.65 psia and to a temperature of 600 F. Authority 20 AAC25.235. 4/16/2004 Form 10-422 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate Name of Operator: Kerr-McGee Oil & Gas Corp. 1. Well No. 2. API No. 50-XXX-XXXXX-XX-XX 3. Type (see instruct.) ~')S¡ 1 50~~-23193-00-X01 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MONTHLY PRODUCTION REPORT 20 AAC 25.230 Field and Pool: Exploration 4. Field & 5. Method Pool Code (see instruct.) 388580 Note: Test Production, Exporatory Well . I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name: Larry A. Johnson Sig,"",e, ~ . (\,~~ F"~ 10405 RC: ,:::::-?J 0 .. 6. Days in Oper. 7. Tubing PSIG 13 291 Title: Accounting Supervisor Date: 4/16/2004 INSTRUCTIONS ON REVERSE SIDE IMonth and Year: DAILY AVG. PRODUCTION 8. OIL 9. WATER 10. GAS (BBL) (BBL) (MCF) 360.80 141.96 448.99 14. TOTAL Mar-04 TOTAL MONTHLY PRODUCTION 11. OIL 12. WATER 13. GAS (BBL) (BBL) (MCF) 4690.46 5836.88 1845.43 4690.46 1845.43 5836.88 Submit in Duplicate . MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg () f4 {\ "I at P.I. Supervisor '" (\ DATE: March 28, 2004 FROM: Chuck Scheve Petroleum Inspector SUBJECT: Plug & Abandonement Nkaitchuq #1 Kerr McGee Exploration 2()4..018 NON- CONFIDENTIAL Section: Lease No.: Operator Rep.: Township: Drilling Rig: Range: Rig Elevation: Meridian: Total Depth: Casin~lTubinQ Data: Conductor: 0..0. Shoe@ Surface: 0..0. Shoe@ Intermediate: 0..0. Shoe@ Production: O.D. Shoe@ Liner. 0..0. Shoe@ Tubing: 0..0. Tail@ Casin~ Removal: ft. Casing Cut@ ft. Casing Cut@ ft. Casing Cut@ ft. Casing Cut@ ft. Casing Cut@ ft. Casing Cut@ Feet Feet Feet Feet Feet Feet Type Plu~ (bottom up) Annulus Founded on Bottom of Cement 5870 Plu~~in~ Data: Top of Cmnt Depth Verified? surface visual Mud Weight above plug N/A Pressure Test Applied no Balanced Type Plu~ Open Hole: Perforation: Annulus: Casing Stub: Surface: Founded on: Bottom Bridge plug Balanced Retainer Verified? Drillpipe tag Wireline tag C.T. Tag I arrived on location as cement operations were ready to begin. Problems were incountered circulating thru the check valve set in the sliding sleeve. Perferation were shot in the tubing immediately above the sliding sleeve at 5878 and cement was circulated from this point to surface. Clean 15.8 lib per gal.cement returns were observed in the slop tank. Distribution: orig - Well File c - Operator c - DNR/DOG c - Database c - Rpt File c - Inspector Rev.:5/28/00 by L.R.G. 2004-0328 _P&A_Nikaitchuq#1_ cS.xls 416/2004 .. e @ KERll-IfCBEE CORPOIIA1II1N e March 22, 2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq # 1 Kerr McGee Oil & Gas Corporation Permit to Drill 204-018 Application for Sundry Approval Plug and Abandon Attached for your review is our Application for Sundry Approval to plug and abandon the Nikaitchuq #1 exploration well located four (4) miles north ofOliktok Point. Please note, this is a rig-less operation with actual plugs being set through tubing or via tubing. The well has been successfully drilled and completed. The Sag River has been perforated and frac' d. Well testing is ongoing. It is our intent to file the required form 407 soon after the well test is finished. Your timely review of our Application for Sundry Approval and the accompanying data is greatly appreciated. Sincerely, ~~ ASRC Energy Services Project (Drilling) Mngr. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 ORfGINAL (907)-339-6370 Abandon ~ Alter casing D Change approved program D 2. Operator Name: Kerr McGee Oil & Gas Corporation 1. Type of Request: STATE OF ALASKA A. OIL AND GAS CONSERVATION COM. ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: VJ~ ~/l.-~I LOOt¡ OrJ3 3!¿J I.:f:- Suspend U Repair well D Pull Tubing D 22 Perforate U Waiver U Stimulate D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Annular Dispos. U Other D Development Stratigraphic D D 204-018 /' Exploratory 0 D 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 7. KB Elevation (ft): 8. Property Designation: 11. Total Depth MD (ft): 11,010ft Casing Structural Conductor Surface Intermediate Upper Liner Lower Liner Perforation Depth MD (ft): 10408 ft -10472 ft Packers and SSSV Type: / 50-629-23193-00 Service 6. API Number: 9. Well Name and Number: 33 ft Nikaitchuq #1 / 10. Field/Pools(s): ADL 388580 I 388582 Exploration ITotal Depth TVD (ft): 9307 ft Length PRESENT WELL CONDITION SUMMARY I Effective Depth MD (ft): Effective Depth TVD (ft): PBTMD: 10,870 ft PBTVD: 9168 ft Size MD TVD Burst Plugs (measured): JUnk (measured): Collapse 80 ft 5676 13-3/8" 9-518" 149 ft 5708 ft 149 ft 4688 ft 5020 psi 5750 psi 2260 psi 3090 psi 3894 ft 5-112" 9,450 ft 1526 ft 3-1/2" 11,000 ft IperfOration Depth TVD (ft): ITubing Size: 8716 ft - 8778 ft 3-1/2",9.2# a) TIW 4" x 20 ft PBR in the tapered liner Packers and SSSV MD (ft): b) Halliburton WellstarTRSSV 7809 ft 7740 psi 6290 psi 9297 ft 10160 psi 10540 psi Tubing Grade: Tubing MD (ft): L-80 9450 ft + 20 ft seal nipple a) PBR at 9450 ft to 9474 ft wI X-O's b) TRSSV below mud line at 53 ft 12. Attachments: Description Summary of Proposal U Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for 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. ct--.fr_ ~ h'7í?J3nt" 907-339-6370 /7 ... COMMISSION USE ONLY Commencing Operations: 16. Verbal Approval: Signature March 25, 2004 Date: 13. Well Class after proposed work: Exploratory 0 / Development D Service D 15. Well Status after proposed work: Oil D Gas D Plugged 0 Abandoned 0 WAG D GINJ D WINJ D WDSPL D Date March 22, 2004 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ..3o~ _ Pð"fr Plug Integrity ~ Other: BOP Test D ~ D Mechanical Integrity Test Location Clearance ORIGINAL fM~~ () 1t}1\ COMMISSIONER Date'ð/?f Submit in Duplicate iFöIIIS.L. . ~ J :n04 BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE e e l <-1 KEIIIHIt:BEE CllRPlJllATltIM Abandonment Program Well Name: AOGCC Permit: Anchorage Contact Nikaitchuq #1 204-018 907 -339-6269 Classification: API No.: Location Contact: Exploration 50-629-23193 907 -646-8021 Estimated P & A Date: March 25, 2004 Prepared By: S. Coyner HSE OBJECTIVES FOR WELL: 1. No Lost time Accidents. 2. No Spills. 3. No environmental damage Well Control: The abandonment plugs will be set / pumped through tubing with the tree in place. Only after / testing the upper-most cement plug will the tree be removed. tJ.&. H2S has not been detected from this well or from any of the offset "Sag River" wells at Milne Point. The Sag River is the only zone perforated or exposed. Notify the AOGCC Field Inspector prior to commencing operations. / Nikaitchuq #1 Abandonment 1 3/22/2004 e e ~ KEIIIJ.IICBEE 1DPŒA1Ø Pluaaina Operations: 1. After testing operations are finished, bullhead down the tubing.±. 75 bbl of ~ 10 ppg // mud from well #2 followed by 50 bbl of water. 2. R/U E-Line. Set a CIBP above the perforations at.±. 10,375' MD. Test the CIBP to . 1000 psi. Dump bail ~ 25' (.21 bbl) of cement on top of the CIBP. RID E-Line. ,/ 3. R/U SLU. RIH and open the sliding sleeve at 5878' MD. Set the "Pump Throuqh" valve in the "X" profile in the sliding sleeve. Replace the dummy gas lift valve with an "RP" shear valve set to rupture at 1500 psi. RID SLU. 4. R/U Halliburton with a squeeze manifold. Tie the casing valve in to a slop tank and be prepared to catch ceæe . amples. Test lines to 3000 psi. Mix and pump 2150 /' sx of Premium cement ~ bbl) down the tubing - through the sliding sleeve - taking returns from the . sing and into the slop tank. Catch cement samples for AOGCC. Displace the lines with.±. 2 bbl of heated water. 5. Using the squeeze manifold, pressure up on the casing to rupture the "RP" sheaf valve. Circulate the well clean with heated salt water through the GLM at 68' MD in preparation to cut and pull tubing. RID Halliburton. 6. R/U E-Line. RIH and tag TOC in the GLM at.±. 68' MD. Cut the 3-1/2" tubing in the ./ 6 ft pup joint above the GLM at.±. 60' MD. RID E-Line. 7. N/D the upper tree assembly. Using a lift nipple, pull the TBG HGR, pup joints and SSSV from the well (.±. 30' over all). 8. P/U a power swivel, 1 jt of drill pipe and a casing cutter with a crane. Cut the 9-5/8" casing above the tubing stub at .±. 55' MD. UD the power swivel, etc. Using a lift nipple and the crane. Pull the 9-5/8" stub from the well. If the stub is cemented and won't move, proceed with step #9 below. 9. P/U the power swivel, 1 jt of drill pipe and a casing cutter again. Cut the 13-3/8" drive pipe as deep as possible. UD the power swivel, etc. Using slings, the pad /' eyes and the crane. Pull the 13-3/8" stub from the well. If the stub won't move, dig it out with a back hoe along with the cellar. 10. Once the casing and cellar are removed, dump.±. 2 cu-yds of ready mix on top of the / casing stubs. Clean up all fouled or soiled ice. Back-fill the cellar for safety. 11. Conduct an inspection with AOGCC personnel. Cut the road to prevent access. Attachments: 1. Well bore diagrams 2. Cementing Program Nikaitchuq #1 Abandonment 2 3/22/2004 Mud Line: 38 ft SSV at 53' GLM at 70' e E 00 e @ KERll-IfCSEE CØIII'OIIATlIIM Nikaitchuq #1 (Current Condition) 9-5/8",40#, L-80, BTC Casing cemented with 592 sx of Permafrost ilL" (438 bbl) & 560 sx of "G" (115 bbl): ± 80 bbl of cement to surface, lost ± 68 bbls down hole. Note: Open hole caliper was 12-3/4" avg hole size. TOL at 5556' MD (4571' TVD) Tested TOL & casing to 3500 psi 9-5/8" at 5708' MD (4688' TVD) LOT = 13.2 ppg EMW 5-112" Upper Liner: 5556' to 9450' MD 4571' to 7809' TVD Tapered Liner cemented with 635 sx of Lead cement (265 bbl) & 455 sx of "G" (94 bbl). Circulated trace of cement from liner top. Note: tail slurry was cut 30 bbl short due to mixing equipment malfunction. PBR at 9450' MD (7809' TVD) Tested to 3500 psi 3-112" Lower Liner: 9474' to 11000' MD 7827' to 9168' TVD Proposed Perf's: 10408' to 10472' MD 8716' to 8778' TVD PBTD = 10,750' MD 11,010' TMD (9168' TVD) Mud Line: 38 ft SSV at 53' GLM at 70' e E 00 e ~ __MCBEE ctIIII'IJIIA.",. Nikaitchuq #1 Step #1 : · Set an EZSV at 10375' MD · Dump 25' of cement on top / · Test to 1000 psi TOL at 5556' MD (4571' TVD) (Tested TOL & csg to 3500 psi) 9-5/8" at 5708' MD Sliding Sleeve at 5878' MD 3-1/2",9.2#, L-80, IBT-Mod Tubing 5-1/2",17#, L-80, IBT-Mod Liner PBR at 9450' MD (7809' TVD) ~ EZSV at.:!: 10375' MD ~ 25' of cement I Perrs: 10408' to 10472' MD 8716' to 8778' TVD PBTD = 10,750' MD (CTU Tag) 11,010' TMD (9168' TVD) Mud Line: 38 ft SSV at 53' GLM at 70' e Ir:.:., Iii I;. I::: I:f: I:.:::.:, I·:? I I· I·; I I: I':"" ~¡:b: :~"i~· I:::;'~: I;'::::: If:::,;, '"',^^"', l;¡'?J~ t~~~~ ~~~g~~~~~~~~~~ ~ I¡~~~¡~~~~~~~~..,,;.:.....:-¡::::;;.;J'.of'.' f!~~~=:!~~~~~r~~!~~~~!~!~~!~!~;J ....../'"~./'"'.t'..f"'.t'x..f,,.":....!'...."...~...""..; [~~!~.····..···:~~!~!k~P1~·····~~!~~~J .~~-!~....~:,~ ..~;:!.:~~;:; ,:, ~~~,'!. ~-:7;:~:'",~,,';,~^\, .;..¡,~;:,!~,\':;, :.,!:,.'!:.....'1 ........~...:.. '. ........;.;:....... ·······1 .S;i;; f ~"i ;,,;;;~ .~ 11 ~~'ij "\ f:::::j:~ ..' }I ~::::?:~ ..::1 f;"'~:¡ ;.~'~~ 1/:/1 I::::' ::;.::, !-?;;; . ':$:::., r"'·: . ...... ~}::;.~ ~m%: ~'~:;,;l :;'::1 ~.~: %~}: f:~.;:1 f:. . . ..'1 :; %:1 I{:":.: r '.: .:.... I::::..:~: :::: ~~~~;.~¡~ ~~~~~~~) ~..-:¡::-:;: . of' .. " f"::r~":";;: ~~;~}~)~J ~"..."........IO ~".,,*""""... ~~~~::~5; :~~~~~~J 1.":.."'............4"1o......~s......'\."..··....~ ~:.~.::~~':7~.::.~~~:a~~;;.~:..;.::.t ¿~~~;~~~::!~~. ~...."'........... "'...............:1 í:i"",,,·,.l'; "'"'"'...of,;,.-....' ,,:..:..:.'~ ,.......:.l"} ~-¡:"¡("¡(.... ~-¡::\."¡("i\ ~ . . . ~·t\i'!(:t . ~{::~¡{;~J ''';'':''''~''i e @ KERfl.AfCBEE COIII'ORAß,. Nikaitchuq #1 Step #2: · Open the Sliding Sleeve at 5878' · Set a check valve in the sliding sleeve at 5878' · Set an RP shear valve in the GLM · Mix & pump 2150 sx (440 bbl) of .,- Premium cement: circulate cement. · Pressure the IA & shear the RP valve. Reverse circulate through the GLM with heated water. TOL at 5556' MD (4571' TVD) (Tested TOL & csg to 3500 psi) 9-5/8" at 5708' MD Sliding Sleeve at 5878' MD (with check valve) 3-1/2",9.2#, L-80, 1ST-Mod Tubing 5-1/2",17#, L-80, 1ST-Mod Liner PBR at 9450' MD (7809' TVD) EZSV at ± 10375' MD + 25' of cement I ../ PerPs: 10408' to 10472' MD 8716' to 8778' TVD PBTD = 10,750' MD (CTU Tag) 11,010' TMD (9168' TVD) e Mud Line: 38 ft SSV at 53' GLM at 70' e @~CØIIPMA"" Nikaitchuq #1 Step #3: · Pressure test to 1000 psi. · Tag TOC inside tubing with E-Line · Cut the tubing with E-Line in the pup above the GLM (+ 63' MD) · Retrieve the tubing down to the cut. TOL at 5556' MD (4571' TVD) (Tested TOL & csg to 3500 psi) 9-5/8" at 5708' MD {-.1- ~ \" Sliding Sleeve at 5878' MD (with check valve) 3-1/2",9.2#, L-80, 1ST-Mod Tubing 5-1/2",17#, L-80, 1ST-Mod Liner t.{..eqt.. PBR at 9450' MD (7809' TVD) Perrs: 10408' to 10472' MD 8716' to 8778' TVD PBTD = 10,750' MD (CTU Tag) 11,010' TMD (9168' TVD) e e (; Kerr-McGee Corporation NW Milne Point Exploration Project Nikaitchuq #1 Nabors 27E Alaska Cement Abandonment Plug (3 Y2" tubing x 5 %" x 3 %" liner) Prepared for: Skip Coyner March 21,2004 Revision: 6 Prepared by: Rafael Hemández Halliburton Energy Services 6900 Arctic Blvd. Anchorage, Alaska 99518 (907) 275-2634 HALLIBURTDN .. e HALLIBURTON e Cement Abandonment Plug Assumptions for Abandonment plug: . 3 Yz" EZSV set above perforations and P&A with Dump Bailer not provided by Halliburton. · 9 5/8"x 3 Yz"annulus, 5 W' x 3 W' annulus and 3 Yz" production string to be plugged with cement. · Squeeze manifold to circulate out cement (down casing-up production string) thru GLM @ 66 ft. Abandonment Cement Recommendation Production Strin2 Cement PIU2 Recommendation: Pre flush I Spacer: 10 bbl Water, Plug Slurry: 440 bbls - 2150 Sks. Premium Cement + 0.2% CFR-3 Displacement: 0.5 bblofwater 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.) 38 hr (est.) P1Uf! Slurrv 15.8 1.15 5.00 >250 o +1- 6:20 >500 @ 80 of >2,000 @ 80 of Volume based on: Plug Slurry: 5878 ft + 7% in the 9 5/8" x 5 Yz" x 3 Yz" 2 .:p¡ ~ Calculated Wellhead Pressure Calculated Wcllhc;;d PR'S5\IIC v$.l.iquid Volll!OO 600 500- ~ 400- 5 <1.> 3 '" '" 2300- ¡:¡.. "0 oj <1.> ;:5 ~ 200- 100- oW o I 200 Volume In (bb!) Kerr McGee COrporaJiiJ!1 5 112" x 3 112" Cement Production Uner I 300 OptìCem Circulating Pressure and Density Downhole ArmlJ1ar Pressure and BCD vs. Uquid V01Ul11e Hydrostatic Pressure· ~ I CircuJating Pressure 4200 3800-- ~ 'Vö 5 3400- <1.> 3 '" '" 2 ¡:¡.. 3000- 2800 - I 300 Volume In (bb!) -15 -14 -13 0 U W -12 -]} -10 500 Fluids Pumped CD Fresh Water ø NSCI Spacer ø Shutdown ø Excess PT A Slurry (}) PT A Slurry l\]mulus CD PTA Slurry 3 1/2"' tubing CD Water fluids Pumped CD FreshWater ø NSC! Sp"""r ø Shutdown ø ExcessPTA Slurry (}) PTA Slurry Annulus CD PTA Slurry 3 1/2" tubing CD Water Kerr McGee Corpo¡aJion 5 112" x3 112" Cement ProductionLíncr The above report is based on sound engineering practices, and other information which must be relied upon, Halliburton makes no warranty, express (lr implied, as to the accuracy of the data or of any calcuJ¡¡Jions opinions expressed herein. You agree that Halliburton shan not be !ìable for any loss or damage whether due to negligence or otherwise arising out of or in connection with such data calculations or opinions. 5 · March 11,2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq #1 Kerr McGee Oil & Gas Corporation Pennit to Drill 204-018 Application for Sundry Approval Perforate, Frac and Test Attached for your review is our Application for Sundry Approval to perforate, ftac and test the Nikaitchuq #1 exploration well located four (4) miles north ofOliktok Point. The well has been successfully drilled. The production liner has been run and cemented. The production tubing has been run and tested. The rig was released on March 10, 2004, and well test operations are to begin on March 15th, 2004. A current wellbore sketch is attached as is a plan of operations and a ftac design/procedure. Your timely review of our Application for Sundry Approval and the accompanying data is greatly appreciated. Sincerely, š~~ ASRC Energy Services Project (Drilling) Mngr. \4AR 11 200 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 (907)-339-6370 ORfGf~L~L · STATE OF ALASKA . ALA Oil AND GAS CONSERVATION COM . ION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Operational shutdown U Plug Perforations 0 Perforate New Pool [] 4. Current Well Class: Abandon U Alter casing 0 Change approved program 0 2. Operator Name: Kerr McGee Oil & Gas Corporation 1. Type of Request: Suspend U Repair well 0 Pull Tubing 0 3. Address: 3900 C Street, Suite 744, Anchorage, AK 99503 1. KB Elevation (ft): 33 ft ~}¡S- J/ (.5'/~ Annular Dispos. U Other 0 Perforate U Waiver U s~0 Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: Development Stratigraphic o o Exploratory [] o 6. API Number: 50-629-23193-00 204-018 Service 9. Well Name and Number: Nikaitchuq #1 8. Property Designation: 10. Field/Pools(s): ADL 388580 I 388582 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 9307 ft PBTMD: 10,870 ft PBTVD: 9168 ft Casing Length Size MD TVD Burst Collapse Structural Conductor 80 ft 13-3/8" 149 ft 149 ft 5020 psi 2260 psi Surface 5676 9-5/8" 5708 ft 4688 ft 5750 psi 3090 psi Intermediate Upper Liner Lower Liner Perforation Depth MD (ft): 10408 ft - 10412 ft Packers and SSSV Type: 3894 ft 5-112" 9,450 ft 1526ft 3-1/2" 11,000 ft perfOration Depth TVD (ft): Tubing Size: 8716 ft - 8778 ft 3-1/2",9.2# a) TIW 4" x 20 ft PBR in the tapered liner Packers and SSSV MD (ft): b) Halliburton Wellstar TRSSV 7809 ft 7740 psi 6290 psi 9297 ft 10160 psi 10540 psi Tubing Grade: Tubing MD (ft): L-80 9450 ft + 20 ft seal nipple a) PBR at 9450 ft to 9474 ft wI X-O's b) TRSSV below mud line at 53 ft 12. Attachments: Description Summary of Proposal U Detailed Operations Program [i] BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: . , March 15,2004 Date: 13. Well Class after proposed work: Exploratory G Development 0 15. Well Status after proposed work: Oil G Gas 0 Plugged WAG 0 GINJ 0 WINJ Service 0 0 Abandoned 0 0 WDSPL 0 Commission Representative: ~,£\.::>\tIClX -\ ~ Il~ -0,--\ 11. 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 ~_~l¿^,'j~{þone Date March 11,2004 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 t..( - CJ 7 ¿;;;- Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Other: ~s Bf~L Location Clearance 0 MAR 1 i 'lM'¡; ZDO ~ ~ -\- ~~ 0.\ ~<l \l Approved BY ORDER OF COMMISSIONER THE COMMISSION Date J~/Š-ð'l tj~'t~11tAtE Submit in Duplicate . Mud Line: 38 ft I·~·~·,¡o.. .''1,'1)0( I,~,·,)I. ~"'~~1.' : 'h¡.··j Il~,,$:.., ..~..:p~ I',f;';:;': ',¡.l~.; . h"~{'t)l. ..,,:..... I"J.?~$:;': .,¡:,j,\,; . I~·;,¡,·,J-. 't.,~.~~.", "~"'" .......... . I",,:, ',... 1~~4?: :.J.~'~~ . 1':,,:,",)1. '.j.':5.'.' Ihj,~ 't):'t¡.',.. I~:~~~~; I~~~~~ I~~{~~ "t.;:i~tJ . I;:t~{~!.: 1"5.$5.$.:-. ..,,'t.... 1"J."5.:·: . '..Jc'1..:.... I:"'t~·; . 1~1.~~~. I$~~~; 't~'tJ.~.; Il~~'t; ':J<tfI.~ ~l%ð.~ I~":;~:,j ..s~:~ r,§:¡j . . E - SSV at 53' GLM at 66' ~~~~~¡ .....,...~ .;¡<~. ::(::{~'.; ~·$~·5t\J !'f{~~ v,.J.iJ. .,¡.......'i \;t....,,'{J :':I:~{~'~ "t./l;':"). .,......~ "..»»J:? }~~:ï1) . Nikaitchuq #1 9-5/8",40#, L-80, BTC Casing cemented with 592 sx of Permafrost JlL" (438 bbl) & 560 sx of JIG" (115 bbl): ± 80 bbl of cement to surface, lost ± 68 bbls down hole. Note: Open hole caliper was 12-3/4" avg hole size. TOL at 5556' MD (4571' TVD) Tested TOL & csg to 3500 psi 9-5/8" at 5708' MD (4688' TVD) LOT = 13.2 ppg EMW 5-1/2" Upper Liner: 5556' to 9450' MD 4571' to 7809' TVD Tapered Liner cemented with 635 sx of Lead cement (265 bbl) & 455 sx of "G" (94 bbl). Circulated trace of cement from liner top. Note: tail slurry was cut 30 bbl short due to mixing equipment malfunction. PBR at 9450' MD (7809' TVD) Tested to 3500 psi 3-112" Lower Liner: 9474' to 11000' MD 7827' to 9168' TVD Proposed Perf's: 10408' to 10472' MD 8716' to 8778'11nD S G. ~ \<.., '-> ~ " PBTD = 10,870' MD 11,010' TMD (9168' TVD) · '.' ~ TESTING PROCEDURE DRAFT VERSION NIKAITCHUQ #1 (NW MILNE POINT) KERR-McGEE OIL & GAS CORPORATION February 10,2004 . . Table Of Contents 1.0 Executive Summary 2.0 General Information 2.1 Logistics 2.2 Well Information 2.3 Kerr-Mcgee Contacts 2.4 Vendor Contacts 2.5 Well Schematics a) Current As Drilled Sketch b) Proposed Completion Sketch c) Proposed P&A Sketch 3.0 Mob Tanks, Testing Equipment, Electric Wireline and Slickline 4.0 Run Bond Log, Peåorate Sag River 5.0 Open Well and Clean Up, Obtain DoW&hole Samples and SBHP, Test Well 6.0 ObtainBHP Buildup Contin2encv Plans 9.0 Frac Sag Rivet 10.0 Cõil Tubing Clean-Out Attachments · Time Line · Location Plat · Deviation Summary · Slickline Tool S1ring & Gauges · Fluid Sampler Nikaitchuq #1 Testing PROC draft.doc . . 1.0 Executive Summary "SAFETY AND ENVIRONMENTAL ARE TOP PRIORITY" The Nikaitchuq #1 is an exploration well that will be drilled to an approximate depth of 10,890' MD = 9,150' TVD with Nabor's Rig 27E. This depth will drill through the Ivishak Formation with the primmy objective of the well being the Sag River. After drilling, the well will be set up as a 3 W'Mono-Bore Completion with the drilling rig. At this time, the drilling rig will be removed and the well completed and tested utilizing a rigless format. A contingency frac job and coil tubing clean out will be designed in case the productivity of the well warrants it The main objectives of the well test are to: 1) Establish the productivity of the well, 2) Obtain reservoir information from buildup analyses, and 3) Obtain fluid samples Potential zones of interest in the well are as follows: Kuparuk - 8,840' MD Nuiqsit - 9,485' MD Sag River - 10,.'itJ1 MD Ivishak - 10,790' MD Note: Actual depths wül be determined by well site geologist and logs. Once testing is complete, the well will be Plugged and Abandoned by a combination of mechanical and cement plugs. Estimated time to begin this procedure is mid March. The completion and well testing are included in the drilling APE of the #1 well as shown below. Notes: 1. Sch1wnberger will be performing the electric line work (CBL, IT Perforating, Setting CffiP, Dump Bail Cement, Chemical cut tubing) 2. H~burton will provide th~ slicldine services (Running BHP gauges, Shifting Sleeve, Setting Plugs, Pulling G~ dummy, Setting Shear valve, Cutting paraffin, Fishing toolstrings) and Cementing during P&A Operations 3. ASRC Energy Services, Operations & Maintenance will perform well test operations (Tanks separators, heaters, flare, Fluid hauling / disposal, Upstream sand separator) , 4. Pencor / Core Labs will provide bottom hole sample container and collect surface fluid samples for analysis 5. Schlumberger will provide Frac and Coil tubing equipment Nikaitchuq #1 Testing PROC draft.doc . 2.0 General Information 2.1 Logistics _'IlfÂttIJr'lflj¡t¡ NA Ift..._IÎ~f~l[m~!IWii]!im~~~~1 . Y=6,054,881.08'N X=519,518.28'E NAD27,Zone4 Lat=70033'39.9854"N I Long= 149ó50'23.5896"W _ 1,336'FWL & 407'FSL Section 16, T14NR9E UM Y= 6,060,234.46'N X= 519,654.17' E NAD27,Zone4 Lat = 70° 34' 32.6355"N Long= 149° 50' 19.1566"W 1,500' FWL & 477' FSL Section 9, T14N R9E UM Nabors 27E to run Mono·Bore Completion String Rigless Kerr-McGee Oil & Gas Corporation c/o ASRC Energy Services 3900 "c" Street, RM 744 Anchorage, AK. 99503 Main: (907) 339-6370 Fax: (907) 339-6253 Sharon St. Charles Phone: (907) 339-6275 Sharon St. Charles Fax: (907) 339-6276 Co. Man: b" 6 - 'iOJl. 1 Fax: t~III.'1III8i1ãWìllf'}mWJ Toolpusher Office: Nikaitchuq #1 Testing PROC draft.doc Kerr McGee Oil and Gas .yo ~. . . 2.2 Well Information . Perform well test on selected interval(s) in order to determine productivity and reservoir characteristics in helping determine the feasibility for field development. t.~", ·m··· ^' ".'" ""'11IIII"'-' .. "'::""'1' ;,,,'" '.. '; ,., .; 'f'··. ,", '>þ' 22 DaysAFE 18 Days Target ~ <,. , ,ijj .,. % , Ground Level RKB RKB - GL GL- Top of Wellhead 3' 33' 30' 10' Name: Perfs: Mid Perf: BHP BHf Porosity Permeability GOR Fluid Properties Fracture Gradient Sag River J 9~~j,'...ttl1 "}:¿ ~" -·';1f''ft1f tJ' 4488 psi (mid perf) 160 degrees F 16% 15md 400 26 degree API .68 psi I ft Est. "i,ttt::..~..,,~' TV f) 1>1;/"''#1'''7'' TI! Ð Name: Perfs: Mid Perf: BHP BHf Porosity Permeability GOR Fluid Properties Fracture Gradient 1IØI~1I_III!IiI'a"._~j'JI_li.1IIIra_.. Completion Fluids Diesel, Seawater. ' Nikaitchuq #1 Testing PROC draft.doc . . Drive Pipe Surface Production Liner 13 3/8" 9 5/8" 5 W' x 3 W' 68 40 17 9.2 K-55 L-80 L-80 PE BTC BTC IBT-Mod ¡If'f' jl.~B 571/8' Cq6r¿g'TIIÞ) qlStJ' (?t¿i>éf '7'"VP) .. 1/ DO/) ì (:e'f ~i¡"~7V()) N/A 9 518" 40# L~80 Surface 8.835 8.679 5,750 3,090 916,000 N/A BODY 979,000 CONN 5 W' 17# L-80 Liner 4.892 4.767 7,740 6,280 397,000 3,480 3 W' 9.2# L-80 Liner 2.992 2.867 10,160 10,530 159,090 3,200 3 W' 9.2# L-80 IBT-Mod Tubing 2.992 2.867 10,160 10,530 159,090 3,200 9 5/8" 40# Casing 5 W' 17# Casing 3 W' 9.2# Tubing 9 5/8" 40# Casing x 3 W' 9.2# Tubing 5 W' 17# Casing x 3 W' 9.2# Tubing 0.0758 bbVft 0.0232 bbl/ft 0.00870 bbl/ft 0.0639 bbVft 0.0113 bbl/ft 9518" 40# Casing x 3 W' Tubing (0 - 5,550') 5 W' 17# Casing x 3 Y2" Tubing (5550' - 5800') 3 Y2" 9.2# Tubing (0 - 10,500') 3 Y2" 9.2# Tubing (160- 5800') 354 2.8 91.4 49 Nikaitchuq #1 Testing PROC draft. doc . . 3.0 Mob Tanks, Testing Equipment, Electric Wireline and Slickline Prior to Testing EquipmentMobilization: · Verify drilling rig has demobilized, and that the ice pad is intact and ready to receive equipment. · As a precautionary measure, the frac flowback equipment will be rigged up upstream of the ASRC test equipment · Verify the containment berm is in tact and adequate · Be ready to flow well prior to perforating · RU any frac equipment that can be mobilized and rigged up such as frac tanks, etc. in preparation for fracing the welL · Have PENCOR representative on location with down hole and surface fluid samplers · Verify that Schlumberger & Halliburton have correct connections to rig up on top of tree 3.1 MIRU and spot ASRC well testing equipment, tanks, flare system and personnel as follows: a. 1 - 45 mmscfd Separator (9500 bpd, 1389 MA WP) b. 1 - 2 mmbtu 5K Heaters with chokes c. 1 - Pipe package with heat trace d. 6 - 400 bbl Upright tanks with Walkways & Stairs e. 1 - 200 bbl Relief Tank: f. 1 - Generator Package g. 1 - 75' Flare Stack h. 1 - HilLo Oil and Gas Scrubber Module i. 1 - Lab I Data Acquisition Package j. 2 - Tio~a Air Heaters k. 4 - Light Plants 1. 1 - Sand Separator for Frac Cleanup m. 1 - Transfer Pump n. 4 - Pickups o. 1 - Ll20C Loader with bucket, forks, and stinger p. 7 - Scott Air Packs q. 11 - Personnel (1- Well Test Supt., 4- Well Test Spec., 4- Well Test Techs., 2- Data Acquistion Spec.) r. I - Crane to Upright 400 bbl tanks (3rdparty) s. 1 - Winch Truck (3rd Party) t. 1- VacTruck(3rdparty) u. Glycol, Water, Diesel, Methanol as Required 3.2 RU lines from surface tree through test equipment. Test lines from tree to choke manifold to 5,000 psi. Test remaining lines and equipment to rated working pressures. Nikaitchuq #1 Testing PROC draft. doc . . 4.0 Run Bond Log and Perforate Sag River Formation Notes: 1. Electric wireline work to be performed by Schlumberger. All work will be performed rigless through a 3 *" Mono-bore completion string. 2. The Auto Release Anchor (MAXR) is not a readily available tool on the Slope, hence it wi/I not be used and the perforating guns will be shot & retritwed in 40' sections using the Powerjet 2306 Charges in a HSD gun casing 3. Will be shooting approximately 1390 psi underbalanced on the first run, be sure to have enough sinker bars 4. At the present time, only one zone wi/I be shot and tested. SAG RIVER 8809 4488 .510 3102 1386 1494 3431 4.1 RU Sclumberger to top of 3 1/8" x 5M surface tree utilizing the Otis tree cap with 5 %" - 4 TPI connector. Make up 2 %" Gauge ring. Make up lubricator with packoff and test to 2,000 psi. TlH with gauge ring to approximately 10,799' PBD. POOH with gauge ring. 4.2 MU and TIH with 111/16" bond logging tool string consisting ofGRI SCMT 1 CCL to approximately 10,799' MD. Log from PBD to top of5 W' x 3 W' Liner crossover at approximately 9,400' inside 3 W'tubing. Verify that the Sag River and any other formations of interest have good bond 1 isolation. POOH with logging tool. 4.3 MU and TlH with the following through tubing perforating assembly: a. 60' x 2 1/8" HSD gun carriers loaded with PI 2306 charges, 6 ISPF, 60 degree phasing. (22.8" TIP, .27" EHD) Note: Gun lengths up to max 40' will be determined after log rtwiew. b. 3' GR/CCL Logging tool c. Sinker bars as required 4.4 TIH at moderate rate, slowing down through nipple profiles. Run depth correlation strip. Record PU and Slack-off weights. Position guns on depth to perforate the Sag River ~ , 1ølf(F~' ttJ JOq.?:J..· M f) (~ìI6 I fo <J71C' 7VP) . 4.5 With choke closed on surface, actuate the firing head to detonate the guns. PU above perfs to verify guns are free. Record SITP. Note: Maximum SITP is 1,390 psi assuming a BHP of 4488 psi and that the tubing is filled with diesel from surface to PBR seals at 9,400' MD/7,711' TVD andKClwater from PBR seals to perforations. 4.6 POOH & RD Schlumberger EWL. RU Halliburton Slíckline. Nikaitchuq #1 Testing PROC draft. doc . . 5.0 Open Well and Clean Up, Obtain Down-hole Samples I BHP, Test Well Notes: 1. Have Pen cor Representative on location with sample containers for both downhole and surface samples 2. Have Schlumberger Frac Equipment, Tree Saver, and Coil Tubing unit on Standby 3. Verify Pre..job tank straps prior to opening the well up 4. It is anticipated that the flow test will last approximately 72 hrs followed by a buildup of 48- 72 hrs The clean up and flow test objectives of the well are as follows: a. Remove wellbore completion fluids and any recoverable fluids lost to the formation during drilling activities b. Measure well productivity c. Gather down-hole fluid samples d. Gather produced fluid and gas samples e. Obtain BHP buildup information for reservoir characterization 5.1 Open the well through the ASRC well test equipment. Ifwell will flow, then flow until getting bottoms up (- 92 bbls). Check oil samples for contamination, BS&W, and solids. Once good oil sample is obtained, shut in the well and obtain SlTP. 5.2 RU the following bottom hole sampling tool string on slickline. If there is enough lubricator, then run the sampling tools in tandem along with the BHPlTemp gauge. If there is not enough lubricator, then make separate runs for the samples and BHP. a. 16 Y2' x 1 11/16" Single phase sampling tool (600 cc sample volume & 7/8" sucker rod connection) - Pencor provide b. 123/4' x 111/16" Positive Displacement sampling tool (600 cc sample volume & 7/8" sucker rod connection) - Pencor Set Mechanical Delay on Clock for well conditions c. 26" x 1 W' Sapphire SS2500 10K Spartek BHP I Temp gauge - Halliburton provide 5.3 Connect lubricator to surface tree and test to SlTP. With pressure trapped on lubricator, open swab valve on tree and TIH with samplers and gauge to . Maintain position until mechanical clock on sample tool aCtivates and takes QOwn note samplt:s. TOH making gradient stops every 1,500' (ie: 9,000', 7,500', 6,000', 4,500', 3,000',1,500', and surface). Close in surface tree, bleed off lubricator, and recover samples and BHP data. RD slickline. Note: Verify that samples have been recovered and prepare for shipment Pencor / CoreLab will be performing the analysis. Download the BHP & Temperature data and provide to Kerr McGee and Pencor. 5.4 If well will flow sufficiently to test, then open well up to test. Otherwise, prepare to frac the well as outlined in the following attachments. Nikaitchuq #1 Testing PROC draft. doc 5.5 Open well through ASRC wen test equipment on an adjustable choke. Flow test the well by stepping the rate up in 250 bpd increments if possible until reaching max rate. The following table is to be used as a guide ifthe reservoir parameters are similar. a) Tubing capacity (ie: bottoms up) is 92 bbls, of which the first 82 bbls should be diesel followed by 10 bbls of3% KCI water. b) The following table AFTER CLEANUP! UNLOADING phase may be adjusted based upon well results. 3-6 Unload Unload 4 250 500 3802 / 872/ .1 42 42 83 83 4 375 750 3468/657/.1 63 105 125 208 48 500 1,000 3131/500/.2 1000 1105 2000 2208 Note: [fwell is capable ofprodudng at higher rates, the ramp up schedule and time duration will be adjusted accordingly c) Ensure that ASRC records !documents the minimum data ftom TABLE 1 during the flowback (Additional Data Collection is a discretionary call by the Kerr-McGee Engineer onsite). d) No drawdown limit will be imposed on the test. e) Nodal rates for Sag River Sand are based upon the following reservoir parameters: .. Permeability = 25 md., GOR = 500 ft3/bbl, Reservoir pressure = 4488 psi @ mid Perfs, Skin = 0, Perforated interval = 60', FTP limit of 500 psi 5.6 Continue to step up the flow rate as outlined above or at the discretion ofthe Kerr-McGee representative on location. Monitor tubing and casing pressures. Have Pencor collect surface samples at initial and fmal rates. Haul off fluid ftom tanks as necessary in order to keep maximum storage capacity. ANTICIPATED RATES AFTER A 300' FRAC JOB ARE AS FOLLOWS: 5.7 After Frac, open well through ASRC well test equipment on an adjustable choke. Flow test the well by stepping the rate up in 500 bpd increments if possible untill'eaching max rate. The following table is to be used as a guide ifthe reservoir parameters are similar. a) Tubing capacity (ie: bottoms up) is 92 bbls, of which the first 15 bbls should be diesel followed by broken 20# slick water. b) The following table AFTER CLEANUP! UNLOADING phase may be adjusted based upon well results. Nikaitchuq #1 Testing PROC draft.doc .. 3-6 Unload Unload 4 250 500 4087/1085/2.8 42 42 83 83 4 500 1000 3442/ 784/4.3 84 126 167 250 48 790 1,580 3291/478/6.7 1580 1706 3160 3410 Note: lfwell is capable ofproducìng at higher rates, the ramp up schedule and time duration will be adjusted accordingly c) Ensure that ASRC records /documents the minimum data from TABLE 1 during the flowback (Additional Data Collection is a discretionary call by the Kerr-McGee Engineer onsite). d) No drawdown limit will be imposed on the test. e) Nodal rates for Sag River Sand are based upon the following reservoir parameters: .. Permeability = 25 md, GOR = 500 ft3/bbl, Reservoir pressure = 4488 psi @ mid Perfs, Skin = 0, Perforated interval = 60', FTP limit of 500 psi, 300' Frac length 5.8 Continue to step up the flow rate as outlined above or at the discretion ofthe Kerr-McGee representative on location. Monitor tubing and casing pressures. Have Pencor coHect surface samples at initial and final rates. Haul off fluid from tanks as necessary in order to keep maximum storage capacity. Nikaitchuq #1 Testing PROC draft.doc . . TABLE 1 SURFACE DATA COLLECTION DETAll.S AND TIME (TO mE NEAREST MINUTES) OF THE FOLLOWING ACTIVITIES SHOULD BE RECORDED: 1. PRESSURE / TEMPERATURE CLOCK START TIMES. 2. CHOKE SIZES AND CHOKE CHANGES (FOR ALL FLOW PERIODS). AT A MINIMUM OF 1S-MINUTE INTERVALS: A) FLOWING lUBING HEAD PRESSURE. B) FLOWING PRESSURE DOWNSTREAM OF CHOKE, BEFORE SEPARATOR MEASUREMENTS. C) FLOWING TUBING HEAD TEMPERATURE. D) FLOWING TEMPERATURE DOWNSTREAM OF CHOKE, BEFORE SEPARATOR MEASUREMENTS. E) CHOKE SIZE AND TYPE (ADJUSTABLE OR POSITIVE). F) GAS, OIL, AND WATER PRODUCTION RATES AND CUMULATIVES. G) BS&W CONTENT H) SEPARATOR PRESSURE AND TEMPERATURE OF OIL AND GAS METER RUNS. I) ORIFICE SIZES, METER SIZES. J) ANNULUS PRESSURE. K) BOTIOMHOLE PRESSURE AND TEMPERATURE, IF SURFACE READOur GAUGES ARE USED. L) CHEMICAL INJECI10N RATES, VOLUMES, CUMMUNATIVE VOLUME AND PRESSURES AT TIlE CHOKE MANIFOLD ETC. AT HOURLY INTERVALS A) H2S AND C02 LEVELS. B) OIL, CONDENSATE GRAVITY AND POUR POINT. C) GAS GRA VTIY. D) OIL, CONDENSATE SHRINKAGE. E) WATER PH & CHLORIDES. F) PRODUCED WATER RESISTIVITY. G) SAND CONTENT OF BS&W SAMPLES. H) A CHECK OF TIlE PRESSURE READINGS USING A DEADWEIGHT TESTER or CALffiRATED ELECfRONIC GAUGE. A DEADWEIGHT TESTER SHOULD BE USED TO PROVE ELECTRONIC PRESSURE READINGS DURING THE TEST IF THERE IS ANY QUESTION ABOUT THE ACCURACY OF THE ELECTRONIC READINGS. Nikaitchuq #1 Testing PROC draft.doc . . 6.0 Obtain SBHP Buildup 6.1 Prior to shutting the well in, RU Halliburton slickline. With well flowing, make 2.75" gauge ring run to top of perfs in order to verify no buildup or obstructions in the tubing. POOH with gauge ring. 6.2 PU and TIH with the following BHP gauge equipment on slickline and set in 2.813" "X" Landing Nipple at approximately 10,485' MD. a. Tandem 1 11/16" Sapphire gauges (26" x 1 W' each) b. 23 ~"x 1 11/16" Shock absorger c. 3 Yz" Downhole Shut-in Tool (2.37 in2 Flow area, equivalent to 1 %" diameter) (program tool to shut in 2 hours after bombs are on bottom) (May use Mulit Flow Shut- in Tool) d. 12 W' x 2.81" Lock Mandrel with Mechanical Equalizing Sub (2.40 in2 Flow area) e. Running Tool f. Slickline to surface 6.3 After landing out in 2.813" "X" landing nipple at 10,485' MD, shear offand POOH with slickline. Continue flowing well until the downhole shut-off device closes and flow stops. At this time, shut in well at choke on surface. 6.4 Leave well shut in for 48 hours. Once Down hole shut off tool opens, record SITP at surface. TIH and retrieve BHP bombs. 6.5 POOH. Download gauge data to verify that data has been collected. If data is sufficient, then RD Slickline and RU Schlumberger Electric wireline. If there is no data or it is insufficient, then discuss options and timing with repect to continuing operations, additional shut in time, or additional flow periods. Nikaitchuq #1 Testing PROC draft.doc . Nikaitchuq #1 Testing PROC drajt,doc Contingency Plans . . . 8.0 Frac Design for Sag River · Tubing Movementfor thisfracjob yields 8' of movement upwards with 8,500 psi screenout & tubing full of 8 ppg proppant laden fluid while holding 3,500 psi on annulus and BHT cooled down to 100 degrees. Equipment Mobilization & Prep 2 Days Prior to Frac Job: · Verify where equipment will be spotted on location with respect to well test equipment, etc. · MIRU 5 - 500 bbl frac tanks from Schlumberger and fill with 1000 FRESH water (Available from water plant at Prudhoe) · Ensure the header connection is heated for 6 hours prior to fiUing the tanks and that Dowell pumping supervisor has authorized filling of the tanks. Remind the truck drivers and Hot Oil operators to check for leaks while filling and heating · Verify that the tree valves are aU functioning and that the master valve holds pressure so that the tree saver can be stabbed in the tree · Tattle Tail (If well test equipment can't be used): Rig up 225 bbl tattle tail tank to the companion valve on the tree. Pressure test to 4,000 psi and set up a heater and heat sock on the tattle tail line to the tank in order to make sure that it will not freeze during the frac job and damage the well head Equipment Mobilization & Prep 1 Day Prior to Frac Job: · Have Hot Oil check the temperatures of the frac tank fluids and roll the tanks if necessary in order to get consistent temperatures within 100 for all tanks · Have VECO rig up pressure relief valve skid and iron from the 9 518"x 3 %" casing annulus to a Tiger Tank and set pop off at 3,800 psi. Also, have them pressure test the casing annulus to 4,000 psi. · Mobilize and load sand silos with 190,000 Ibs of 20140 Carbolite proppant · Perform QA/QC on fluids to determine x-link and breaker schedules. Cross link time should be designed for 213 pipe time. Breaker schedule should be designed for 1 hr at BHT and 4 hrs at surface fluid temperature Equipment Mobilization & Prep Day of Frac Job: · Have 4 additional Tioga heaters on location by 6 am (Do not include the ones on the frac tanks or tattle tail line) · Have Dowell Diesel Tanker on location. Have Hot Oil fill with 100 Mis of warm (- 100 degree) diesel · After filling Diesel Tanker, have Hot Oil stay on location in order to maintain 3,500 psi pressure on the annulus during the frac job with diesel · Mobûizel0K tree saver I isolation tool for 3 %" 9.2# tubing. Pump 15 Mis of warm diesel down tree and into tubing prior to stabbing I setting isolation tool · MIRU 4 pump trucks (3-primary & I-backup), blender, andfrac iron. Hook up to well and tanks. Pressure test lines to 9,000 psi. Set Pressure relief valve to 8,500 psi and pump trips to 8,000 psi. Expected treating pressure for the well is 6,500 psi. · Have two Dirty Vacuum trucks available with one on location by 7:30 am and the other for 12:00 noon in order to catch water products and hydrocarbons · Will need to callfor approximately 2,000 gals offuel around 2:00 pm Nikaitchuq #1 Testing PROC draft. doc . . · Have Pre-job meeting, review all QA/QC tests on fluid & proppant, confirm volumes, confirm pressure settings & reliefs, review safety issues & escape routes Fluid Volumes Required · 20# Linear Gel (Approx. 500 bblfor Flush Fluid, Step Rate Tests, Pre-Pad) containing: 4.6 gpt J877 Guar 2 gpt FI03 Non-ionic surfactant .5 gpt J318 Breaker aide .25 ppt M275 Bacteriacide · YF-130LG Guar gel with Borate X-link Base Fluid (Approx.1500 bblfor Data Frac, Pad, Proppant Laden Fluid) containing: 6.8 gpt J877 Guar 2 gpt FI03 Non-ionic Surfactant .25 ppt M275 Bacteriacide 11 gpt Activator pH Adjuster Breaker as determined from tests · Catch samples during pad, mid sand concentration, and final sand concentration 8.1 Displace hydrocarbons (92 bbls) back into the formation at 5 bpm by pumping the following 20# linear gel injectivity I step rate test followed by a 30# Crosslinked gel Mini-fÏ'ac. Displace the Mini-fÏ'ac with 20# linear gel. The injectivity test will utilize 240 bbl of20# slick water spacer and will be pumped at 2, 4,6,8, 10, 14, 18,22, and 25 bpm rates. Shut down for short period and determine ISIP and let the formation heal. 1 20# LINEAR 2 3 6 6 2 20# LINEAR 4 3 12 18 3 20# LINEAR 6 3 18 36 4 20# LINEAR 8 3 24 60 5 20# LINEAR 10 2 20 80 6 20# LINEAR 14 2 28 108 7 20# LINEAR 18 2 36 144 8 20# LINEAR 22 2 44 188 9 20# LINEAR 25 2 50 238 8.2 Follow up the slickwater displacement with the 10,500 gal (250 bbl) Mini-Frac. Pump the YF130LG frac fluid at 25 bpm and displace with WF120 (20# Linear Gel) as follows: MINI- FRAC FLUSH 25 30# x- LINKED 20# LINEAR 10,500 10,500 250 10.0 25 3,864 92 14,364 342 13.68 Nikaitchuq #1 Testing PROC draft.doc . . IB~RI 8.3 After pumping the Mini - Frac at 25 bpm, shut down immediately and record the decline data. a) Determine ISIP, closure, leakoff coefficient, and fluid efficiency. b) Continue to watch and observe decline data while redesigning the ftac 8.4 Based on the Mini-Frac analysis, optimize the ftacture design and treatment schedule for the existing well conditions. 8.5 Re-confirm all pressures and volumes for the job. 8.6 Bullhead the 20# linear gel into the formation ahead of the pad at 10 bpm. a) When the pad fluid is within 10 bbl of the perfs, increase the rate to 25 bpm or whatever the redesign rate is determined b) Pump the following ftac treatment, or re-designed one at 25 bpm c) Dirty Vol (Bbls) = Clean Vol + (.00092 * Lbs Proppant) for Intermediate Strength Prop Pad /30# 25 12,600 300 300 12,600 300 300 0 X-Link 1 ppaf 25 4,200 100 400 4,368 104 404 4,200 ~O# X-Hnlc 2 ppaf 25 6,300 150 550 6,804 162 566 12,600 ~(!# X_Hnlc 4ppaf 25 6,300 150 700 7,266 173 739 25,200 ~O#X_Hnlc 6ppaf 25 8,400 200 900 10,332 246 985 50,400 ~O# X_Hnlc 8 ppaf 25 8,400 200 1,100 11,004 262 1,247 67,200 ~O# X-Hnlc Flush / 25 3,108 74 1,174 3,108 74 1,321 0 20# Linear Flush f 25 630 15 1,189 630 15 1,336 0 d) Flush ftacture treatment w/linear gel (20# Slickwater) and Diesel for Freeze Protection. e) Flush will be 2 bbl short of the top perf. t) Expected treating pressure is 6,500 psi (3983 HHP) at 25 bpm Nikaitchuq #1 Testing PROC draft. doc . . g) Once tip screen out occurs, net pressure will begin to rise. As net pressure reaches maximum, be prepared to alter the pumping schedule if deemed necessary. If an early screen out occurs shut down and release tubing pressure. b) Density equivalent at 8 ppa = 12.31 ppg = 1.48 SG = .640 psi/ft 8.7 Calculate how much proppant is left in the well. Be prepared to RD tree saver immediately and begin flow back operations through ASRC test equipment while continuing to rig down frac iron. Bleed off annulus pressure. 8.8 If well will flow, then procede with clean up and testing of well as outline in Section 5, beginning with Step 5.5. Once well is sand free, then begin testing well. Ifwell will not flow, then rig up coil tubing as outlined in next section. Nikaitchuq #1 Testing PROC draft.doc . . 9.0 Coil Tubing Clean-Out 9.1 Ifnecessary, RU Schlumberger 1 W' Coil Tubing BOP's and injector head to wellhead. RU tank with either 2% KCl water or filtered seawater. Add 1 gal ftiction reducer per 1,000 gal water. RU flowback tank to catch returns. 9.2 Test BOP's. TIH with wash nozzle and dual checks. Get PU and slackoffmeasurements every 1,000'. Be careful when tripping through downhole restrictions. 9.3 Prior to tagging fill, pump a 5 - 10 bbl pill of Biozan to use as a sweep. General rule of thumb is a 10 bbl sweep ofBiozan should be pumped for every 50' offill. Wash down through the Sag River perfs at 10,519 - 10,579' MD. 9.4 After pumping fmal sweep around, PU wash nozzle above top of perfs and SD for 30 minutes. Lower back down through perfs and verify that there is no fill. 9.5 POOH with coil tubing. Once inside lubricator, Close off the swab valve. Open the well through the test equipment and see if it will flow. If it will, then RD coil tubing unit. If it will not flow, then RU nitrogen unit and TIH with coil tubing jetting well in. 9.6 Return to Section 5, Step 5.5 and flow test well. Nikaitchuq #1 Testing PROC draft.doc . Nikaitchuq #1 Testing PROC draft.doc Attachments . , tII!L!D" ...... UNm.. . ...... -- ~ J It.L _~ NE IfIPIIaI{. wa .-.......... þ-"-' ..... a. _ IIr- J . . ADD Vetco Tree .... M.tW II1'1a i1PE 'I.:E I:'IP VI1If 111M" 4'1P:t MIll ...... IEIL ..-; , a-uII:IN 1m . ~ IIIN __ 1t9l!llJl' ~- . ... .,..- IIIIIUD L.EYEL. ~~---...- ~...... - ...,.. . ,. IIEU.I IlIIUnIHIIt 11 ... II: JÇII 13-GII'8 X 9-a1ll x 3-112 DD.. 15M NIP MLTIKNL. M:SY IÐAD ... .. ..... _ ,._U" I .... a..-.-- - ~ -, ...... .. -.. .............- I ~': Nikaitchuq #1 Testing PROC draft. doc . . :1· ··::::':::':1:.:':':':::':':':<::::':'·1<':·':«<:::<,,< , ,:::: '..':' , ':'."<>:': ql·.·.· . dlIBI' q ..... ...........:... ,£"....,.....,...11I' * FracCADE Initial Design - Rev.1 Operator Well Field Formation Well Location: County State Country Prepared for Proposal No. Date Prepared Dennis McDaniel 02-02-2004 Prepared by Phone E-Mail Address . Marl< of Schlumberger Kerr McGee Nikaitchuq #1 . Exploration Sag River North Slope Alaska United States Service Point Prudhoe Bay Business Phone: (907) 659-2434 FAX No. Brad Musgrove (907) 564-5097 musgrove@slb.com Disclaimer Notice: This infonnation Is presented in good faith, but no warranty is given by and Dowell assumes no liability for advice or recommendations made concerning resuits to be obtained from the use of any product or se<vfce. The results given are estimates based on calculations produced by a computer model including various assumptions on \he well, reservoir and treatment. The results depend on Input data provided by the Operator and estimates as to unknoWn data and can be no more accurate than the model, the assumptions and such input data. The Information presented Is Dowell's best estimate of \he actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of Input data. and hence results, may be Improved through the use of certain tests and procedures which Dowell cen assist In selecting. . The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If \he Operator Is aware of any conditions whereby a neighboring well or wells might be affected by \he treatment proposed herein It Is the Operator's responslblHty to notify the owner or aNIIer8 of \he well or wells accordingly. PrIces quoted are estimates only and are good for 30 days from the date of Issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perfonn these se<vfces. Freedom from Infringement of patents of Dowell or others Is not to be inferred. . . Client Well : Fonnation : District : Country : Loadcase : Kerr McGee Nikaitchuq #1 Sag River Prudhoe Bay United States KM Design Section 1: Definitions The following are definitions of terms used in this proposal. FRACTURE HALF-LENGTH refers to the length of one fracture wing from the well bore to the fracture tip. FLUID LENGTH refers to the fracture half-length occupied by fluid and may include length without proppant which does not contribute to production. PROPPED LENGTH refers to the fracture half-length occupied by proppant and may include length which does not contribute to production due to low proppant concentration, proppant damage or other effects. EFFECTIVE or APPARENT LENGTH refers to the fracture half-length through which formation fluid can be produced and which may be expected to contribute to well productivity improvement. 2 I·· ·.·"·:"""/""':Iì·/""n"""."'//"".'...:..... · . ,. .-:-: · . '.' · ." ..... :':"'":::\::»'/::i''' . . Client Well : Fonnation : District : Country : Loadcase : Kerr McGee Nikaltchuq #1 Sag River Prudhoe Bay United States KM Design ..1··.·": ' '//""'·1":"'1"'.'.'1:"·'1',:/:..........' . .:. >.':-:' . " . :::::;::::::::::::;:::::;::::::::::::::;:::::::::::;:;:;=;....:::::-::::::;:-. Section 2: Wellbore Configuration Bottom Hole Temperature .............160 degF Deviated Hole............._........____.. YES Treat Down..._............................ TUBING Flush Volume to 10516.0 ft 91.3 bbl ~"t¡~WM¡':_~X!;fti;'~m"m~~":,,.,t~"j';~".j$;!:ß;¡¡~ffi~:.-,: '" - .r-r'r'!fW;;<!!:;':;!I!."¡X'¡¡::¡illl¡¡:¡¡~._. r " :,!**4J;k'Wrr,(~ ~'Œ:,·,·({:1N*;:z::r,,<¡,·:~::·'ili·":·'· ~'&" ·'*iii··..·~';O: :"!©1'. ,. ;"'oom1 ..]",¡¡r'¡-¡¡"'!!I%w.S)i, ,,"" "':<;"':$h'1<"t¡¡h:@ l¡~~~~j~~l[&0.1ttl~ill~~i;{~¡t)~" . i1%0à:" ",' . '~. ,;Ri~¡§í~{r1lL/ . : :fu~>~":"_M~'i OD Weight ID Depth (in) (lb/ft) (in) (ft) 3.500 9.2 2.990 9400.0 OD Weight ID Depth (in) (lb/ft) (in) (ft) 5.500 17.0 4.892 9400.0 3.500 9.2 2.992 10911.0 Top Top Bottom Bottom Shot Number Diameter MD TVD MD TVD Density (ft) (ft) (ft) (ft) (shotlft) (in) 10516.0 8779.0 10576.0 8835.0 6.00 360 0.27 Section 3: Zone Data Zone Name Top MD Zone Frac Insitu Young's Poisson' Toughness (ft) Height Grad. Stress Modulus s Ratio (psLinO.5) (ft) (psilft) (psi) (psi) 279.0 0.880 7603 1.500E+06 61.0 0.720 6343 2.000E+06 300.0 0.880 7911 1.500E+06 Kingak Sag River Shublick 10195.8 10516.0 10581.0 0.35 0.20 0.35 1200 1200 1200 Kingak Sag River Shublick 10195.8 10516.0 10581.0 Net Height (ft) 0.0 61.0 0.0 0.001 15 0.001 2.0 18.0 2.0 Res. Pressure (psi) 4043 4488 4207 ...':'.;'~ Gas Oil Water Sat. Sat. Sat. (%) (~o) (~) 10.0 10.0 80.0 10.0 60.0 30.0 10.0 10.0 80.0 III:_~," Zone Name Top MD (ft) Perm (md) Porosity (~) 3 . . Client Well : Fonnation : District : Country : Loadcase : Kerr McGee Nlkaitchuq #1 Sag River Prudhoe Bay United States KM Design 1.·....··········11·····......··,···,·····,·, · ... . .......... ...... .... ."H ... ......... ···p···I·····..··········· · . . . 'C . , " · . . .. . ," i""""",:, """"""""""':""""".". /.'. ... p....> .....................-.. ... .... Section 4: Propped Fracture Schedule Pumping Schedule The following is the Pumping Schedule to achieve a propped fracture half-length (Xf) of 301.8 ft with an average conductivity (Kfw) of 7363 md.ft. .1.".lill'Y..lIr'&.....IIIIIJ.';'Y.ì~_..llf'.l.iIIilll Stage Pump Fluid Name Stage Gel Prop. Prop. Name Rate Fluid Cone. Type and Mesh Cone. (bbllmln) Volume (Ib/mgal) (PPA) (bbl) 300 100 150 150 200 200 91 PAD 1.0 PPA 2.0 PPA 4.0 PPA 6.0 PPA 8.0 PPA FLUSH 25.0 25.0 25.0 25.0 25.0 25.0 25.0 YF130LG YF130LG YF130LG YF130LG YF130LG YF130LG Slickwater 30.0 30.0 30.0 30.0 30.0 30.0 30.0 20/40 C-Lite 20/40 C-Lite 20/40 C-Lite 20/40 C-Lite 20/40 C-Lite 0.0 1.0 2.0 4.0 6.0 8.0 0.0 1100 bbl 91 bbl of of YF130LG Slickwater Ilit'~I¡~rr.I.._lI!lf~'í\!~\rl~J': 159600 Ib of 20/40 C-Lite Stage Stage Cum. Fluid Stage Cum. Stage Cum. Avg. Stage Cum. Name Fluid Volume Slurry Slurry Prop Prop. Surface Time Time Volume (gal) Volume Volume (Ib) (Ib) Pressure (min) (min) (bb) (bb) (bb) (psi) PAD 300 12600 300.0 300.0 0 0 5094 12.0 12.0 1.0 PPA 100 16800 104.4 404.4 4199 4199 5147 4.2 16.2 2.0 PPA 150 23100 163.2 567.6 12597 16796 5032 6.5 22.7 4.0 PPA 150 29400 176.3 743.9 25194 41991 4935 7.1 29.8 6.0 PPA 200 37800 252.7 996.5 50389 92380 4988 10.1 39.9 8.0 PPA 200 46200 270.2 1266.8 67199 159579 5325 10.8 50.7 FLUSH 91 50036 91.3 1358.1 0 159579 5736 3.7 54.3 4 . . Client Well : Formation: District : Country : Loadcase : Kerr McGee Nlkaltchuq #1 Sag River Prudhoe Bay United States KM Design ......... ···II·······/·I··:·····~I······I·········....··... II......'" :::::::::::::::::::::::'::::::::::::::::::::::::::;:::::::....;::::::>;::::::: ..................-,..-.......,.. ,....-.. Section 5: Propped Fracture Simulation The following are the results of the computer simulation of this Fracturing Proposal using a Pseudo 3-D Vertical model. Effective Conductivity and Effective Fcd are calculated based on perforated intervals with positive net heights. Initial Fracture Top TVD..................... 8779.0 ft Initial Fracture Bottom TVD............... 8840.0 ft Propped Fracture Half·Length........... 301.8 ft EOJ Hyd Height at Well,..................... 77.9 ft Average Propped Width..................... 0.334 In Average Gel Concentration............... 484.8 Ib/mgal Average Gel Fluid Retained Factor... 1.00 Net Pressure....................................... 1609 psi Efficiency,.............................. ............. 0.542 Effective Conductivity,....................... 8537 md.ft Effective Fcd ...................................... 1.9 Max Suñace Pressure........................ 5968 psi IIJ~ir~~~'~~~~illl~[I'~~fji[m¡¡ill,.._IRII.~~I.i..._rpœi~1~~¡!;'JI'~tlOOf'fll~~~~lmft~i From To Prop. Propped Propped Frac. Frae. Fracture (ft) (ft) Cone. Width Height Prop. Gel Cone. Conductivity at End of (in) (ft) Cone. (Ib/mgal) (md.ft) Pumping (lblft2) (PPA) 0.0 75.4 5.1 0.312 75.4 150.9 6.7 0.387 150.9 226.3 6.3 0.361 226.3 301.8 4.3 0.283 Fracture did not close completely during shut-in 69.3 72.2 67.4 63.1 2.80 3.47 3.24 2.54 520.5 421.6 443.4 553.7 6874 8525 7987 6203 5 . . Client Well : Fonnation : District : Country : Loadcase : Kerr McGee Nlkaltchuq #1 Sag River Prudhoe Bay United States KM Design 1.········..·..·..·1····················........... ... '" .... . ..........,. · '"' . ,....... ...-........... . ," · .. ········..p···I···I·····..····· · . ',' . ,.... · .. .. . ",-," · -.. ," . ... ..... . . '," · ... . ~ :.: :. <.::::::::::::: :::.: :.:::::>::>: :::::::: ::.::::::: :.: :.' .. ::::::: ::.:': :.:::: ......- .-,..-.... ... ...... . PJlBi1!f;f10fa'fillM18 ß1íf,- ··""Ei.'·'-!!;" ~:;~~;. ';j~-r.' till;. ~ ,> $41&@ffi;i~!.W ..w.. . .. . .., . .. , . "1~@:iw' '¡¡jr; ,", .. ìi Zone Name Top Top Gross Net Fractur Fractur Fracture MD TVD Height Height e Width e Conductivit (ft) (ft) (ft) (ft) (in) Length y (ft) (md.ft) Kingak 10195 8500.0 279.0 0.0 0.124 284.6 2734 .8 Sag River 10516 8779.0 61.0 61.0 0.388 301.8 8537 .0 Shublick 10581 8840.0 300.0 0.0 0.078 284.3 1722 .0 Stage Name Fluid Name Pump Fluid Perforation Exposure at Exposure Rate Volume Injection BHST of aboveWatch (bbl/min) (bb!) Temp. 160 degF Temp. of (degF) (min) 155 degF (min> PAD YF130LG 25.0 300 95 7.6 7.6 1.0 PPA YF130LG 25.0 100 85 28.0 28.0 2.0 PPA YF130LG 25.0 150 85 1.1 1.1 4.0 PPA YF130LG 25.0 150 85 0.0 0.0 6.0 PPA YF130LG 25.0 200 85 0.0 0.0 8.0 PPA YF130LG 25.0 200 85 0.0 0.0 FLUSH Slickwater 25.0 91 Section 6: Proppant Data Proppant Permeability is calculated based on the following parameters: BH Static Temperature: 160 degF Stress on Proppant: 6329 psi Propped Fracture Conc.: 1.00 Ib/ft2 Average Young's Modulus: 2.000E+06 psi 20/40 C-Lite ¡:"::;;.'.~~¡~"£' :. ·.·""",!iï!iilfÆ!i!im!\i,~:iii!jil"'",,·. Specific Mean Pack Gravity Diameter Porosity (in) (%) 2.73 0.028 35.0 'm" Permeability (md) Proppant Name 232322 6 . . Client Well : Fonnatlon : District : Country : Loadcase : Kerr McGee Nikaitchuq #1 Sag River Prudhoe Bay United States KM Design '.Iíll Section 7: Treatment Fluid Data Fluid data is given at 15 md. !=::~_.,~ j :.tI!!@iièl· '::flli!li'i!'CiJ!:R®lWJl!iiili}ln""':.J!ili1!... 2o/.~~g~IIIW~~:'~_""'" ,Jw~IIII~1.30~':4tW}" S.-,mlic',<Wat,:.. r_.::..~,,:J 111 . ·'i!',¡¡g·o¡mm. . . ",J!illi¡.,p, .8HillijJ1!.r!ð!""'"'Hþ,jii",,,,,,,,. . ·!!ffi,"!!é,m;t<,¡¡,· . '*"'"fr'~''' . ,i",,,,M0w ,. "'$'~"!'!&'=øi_. ' . . ·t. . .,,*~" '. . ,¿;' . , .:;~ '," ~¡¡iw~~ ~œj¡¡;W.L.~L:¡,N¡!.;J?W,i$!b~ø.::· ,,,"Ã;w$li~?0-jí, _ . R£¡~MlitÜij iw;:~Ü~W", . *lliW:_lli:1'~l1-¡,\Jff'cliJi.;::i*DH1j, , ,.' .@1~' .,...' ,*1*', v _",;: Rate Low (bbl/min) 2.4 1.0 2.8 Pressure Low (psi/100Qft) 10.0 60.0 10.0 Rate Pivot (bbl/min) 15.0 12.0 8.0 Pressure Pivot (psi/100OO) 300.0 80.0 40.0 Rate High (bbllmin) 28.0 90.0 90.0 Pressure 1000.0 1000.0 1000.0 Cw (ft/minO.5) 1.0E+0 2.0E-3 7.0E-3 Spurt (gal/1 00ft2) 4.7 1.0 2.0 inO. 1.9E-2 3.0E-3 5.8E-3 Temperature (degF) 160 160 Time (hr) 0.0 0.0 0.0 Behavior Index (N') 1.00 0.39 1.00 Consist. Index (K') (lbf.s^nlft2) 8.71 E-6 2.48E-1 2.09E-5 Viscosity @ Shear Rate (cP) 0.417 494.110 1.000 Shear Rate (1/s) 170 170 170 Section 8: Graphics 7 . . Client Well Fonnation : District Country Loadcase : Kerr McGee Nikaitchuq #1 Sag River Prudhoe Bay United States KM Design I.".,.........·,.""..""...............ïèl...... ............,.......,..... ...... . _ ......... ... ,...".. FracCADE* ACL Fracture Profile and Proppant Concentration Kerr McGee Nlkoltch~ #1 ~.s~1II\'4 8720 8780- < 0.0 Ibm 0.0 -0.61,112 0.6 -1.0 "'112 1.0-1.61,112 i 1.6 -2.0 Ibll2 8800- 2.0 - 2.6 1>112 ~ 2.6 - 3.0 1,112 3.0 - 3.6 hll2 3.6 - 4.0 11>112 > 4.0 IbIl2 8840- 8880 6000 72'00 StreS8· pai 840C .G,8 .ò.4 0 O~4 0.8 0 ACL WIdth 01 Wellbore -In 100 ~ ~o F18cture HolJ.Longth -. 400 Sttllderpp -Mark ~ Schlumberger Row CIpacIty - ~oppedWidth(ACL) - QmductMy-Klw -8000 -7000 0.3 -8000 .<; f 10.2 Æ -5000 -4000 -3000 0.1 -2000 -1000 100 200 Roctu.. Hof-Lenglh - It 300 o 400 8 Client We/I Formation : District Country Loadcase : Kerr McGee Nlkaitchuq #1 Sag River Prudhoe Bay United States KM Design Net Pre_ 1??oo 'ž. ; i 1000 ;! 100 1 Fract..... Geometry Hstory . . ·1.·· . ······1············· .." .. ."-,, .............. . . · ," . .. ..... ..........,. ....... · .. . .... ... ····p···I··'·············· · . . ..... · . .. ... . .. .. ... .....::. · ...." . "' .... o . _ ........ · - .... . ...::.::..:................:.....:.:::.:.::.::::.::::.:.::\ .--"'......-.............-....-....... .............. -".... - NatFte......(Fnootu...#1) - TSO(Fnoottn#1) - EDJ . 10 Treatment T...... . rrr. 100 - 25% EDJ - 50% B:>J - 75% B:>J - 100% B:>J C=:J R-op>Ont Coverage 8770' 8780 8790 8800 ¡ ~ 8810 8820 8830 8840 o 100 400 200 F_HBf-Length-ft 300 9 Client We/I Fonnation : District Country Loadcase : Kerr McGee Nikaitchuq #1 Sag River Prudhoe Bay United States KM Design B1d of StIge Temper8lure Trecklng 200 180 180' 140 t120 i 100_ I..... .... 80 eo 40 20 0 0 10 . End PAD End 8.0 I'PA End 1.0 I'PA End 8.0 I'PA . I " End 2.0 I'PA End 4.0 I'PA BHTeffP -.- e::>J 20 .~.--- 30 Treatrœnt Trre· rrin 40 10 1·...:..:·:::·::·::..11·::·::..·:::·::··:·::·.:::. .. ..... . ... p PP'~. ··1· .}.... . . [I ..P :::;:::'::::;:;::::::::::::::::::;:::::::::::::::::'::::::::....)::::::;::}) " ---- . 50 60 API Correction Skip, When the well permit number 204-018 was approved to drill well Nikaitchuq 1, the api number assigned was 029-23193-00 to the permit. We need you to correct your paper work for the well and correct your database with the correct api number so all future paper work is correct. The correct api number is 629-23193-00. Make this correction and place this email in the well file as official notification. Thanks for your assistance. Steve 1 of 1 3/9/20043:28 PM \ .-. .- FRANK H. MURKOWSKI, GOVERNOR AI/.4.SIiA OIL AND GAS CONSERVATION COMMISSION Todd Durkee ¡ Drilling Manager Kerr-McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage, Alaska 99503 333 W. 7'" AVENUE,SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nikaitchuq #1 (revised) Kerr-McGee Oil & Gas Corporation Permit No: 204-018 Surface Location: 1336' FWL & 404' FSL, Sec. 16, T14N, R9E, UM Bottomhole Location: 1500' FWL & 477' FSL, Sec. 9, T14N, R9E, UM Dear Mr. Durkee: 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, it is indicated that testing and stimulation of the productive intervals in the well may be performed. A Sundry Application (Form 403) detailing the planned activities should be submitted for approval. 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 esult in the revocation or suspension of the permit. Please provide at least twenty-four (24) h rs notice for a representative of the Commission to witness any required test. Contact the C . ion's North Slope petroleum field inspector at 659-3607 (pager). / ì J9»h L,../Chair BY ORDER O~~HE COMMISSION DATED this..,lt'Jay of February, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. · . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1 a. Type of work: Drill 0 Redrill U 11 b. Type of well. Exploratory 0 Stratigraphic Test 0 Re-entry DDeepen 0 Service 0 Development Gas 0 Single Zone 0 2. Name of Operator 2nd AMENDED APD 5. Datum elevation (DF or KB) Kerr McGee Oil & Gas Corporation 33 feet 6. Property Designation ADL 388580 / ADL 388582 7. Unit or property Name Nikaitchuq 8. Well number 1 9. Approximate spud ~:~ February 10, 20\fð' ij )1 14. Number of acres in property 3. Address 3900 "C" Street, Room 744, Anchorage, AK 99503 4. Location of well at surface 1336' FWL &w.ífSL, See 16 T14N R9E UM At top of productive interval Jì> 1500' FWL & 477' FSL, See 9 T14N R9E UM At total depth 1500' FWL & 477' FSL, See 9 T14N R9E UM 9150' TVD 12. Distance to nearest property line I 13. Distance to nearest well 477 feet BPXA, MPU-F33A, >~,OOO feet 16. To be completed for deviated wells Kickoff depth: 400' - MD 18. Casing program size 8779' TVD 2560 ß~/~ Development Oil 0 Multiple Zone 0 10. Field and Pool Exploration 11. Type Bond (see 20 MC 25.0251) Statewide Number 3-798-381 Amount $200,000 15. PrOpos?d depth (MO ;f'd TVO) 10890' MD /9150' TVD Maximum hole angle 39.5° j 17. Anticipated pressur7 (see 20 MC 25.035 (e)(2)) / Maximum surface 3386 psig At Sag River Depth (8779' TVD) = 4440 psi Setting Depth Hole Casing Weight 13-3/8" 68# 12-1/4" 9-5/8" 40# 8-112" 5-112" 17# 3-1/2" 9.2# Specifications Grade Coupling L-80 PE L-80 BTC L-80 BTC L-80 IBT-Mod Length 116 5668 3850 1490 Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 33 33 149 149 Drive Pipe 32 32 5700 4688.1 667 sx Permafrost L & 560 sx G 5550 4573 9400 7730 495 sx of Premium + Microlite & 9400 7730 10890 9150 560 sx Premium-Latex cement 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet true vertical feet Effective Depth: measured feet true vertical feet Casing Length Size Cemented Plugs (measured) Junk (measured) Measured depth Perforation depth: measured true vertical True Vertical depth RECEIVE£.) FEB 0 9 2004 Alaska Oìl & Gas Cons. Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot 0Refraction analysis 0 Seabed report 0 20 MC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge For questions call Skip Coyner 907-339-6269 ~ee cover letter for other requirements ..! Yes U No o Yes 0 No Signed ··~~-~~s~:··:::::;:""· Commission Use Only API number6z.-r - ¡. 3/éf'B -66 I Approval date 50- ~3193-00 ~b s req ired 0 Yes 0 No Mud log required o Yes 0 No Directional survey required D2M; 0 3M; 0 5M; 0 10M; 0 o Title: Kerr-McGee Oil & Gas Corp Permit Number Commissioner by order of the commission Form 10-401 Rev. 12/1/85· ORtGtNAL Date 1/23/2004 C,re ~¡fff Kerr McGee, Nikaitchuq # 1 e , Subject: Kerr McGee, Nikaitchuq #1 From: "Coyner, Skip" <Skip.Coyner@asrcenergy.com> Date: Tue, 03 Feb 2004 17:02:42 -0900 To: to~ maunder@admin.state.ak.us Welcome back. The ice road is about done. The first drilling pad is about done. We're drive pipe today & we plan to move 27E from its staging area (near Oliktok Dock) starting on Thursday evening. We should be ready for the Diverter function test on or about Sunday p.m. Spud should be sometime on Monday 2/9/04 - probably the 10th, though. Seeing is believing. Right now our company man is Gary Goerlich. Kirk White will be joining him tomorrow evening. The bag phone they have is: 907-943-5092 Over the weekend, we'll get the Sat phones hooked up: Kerr McGee office: Nabors office: HES (Baroid & Sperry): Camp line (galley): Camp/office fax line : 907-646-8021 907 -646-8024 907-646-8023 907-646-8067 907-646-8076 Skip Coyner ASRC Energy 907-339-6269 1 of 1 3/1/2004 2:32 PM . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 1b. Type of wen. Exploratory La stratigraphic Teat 0 Servloe 0 Development Gas 0 Single Zone 0 6. Datum elevation (DF or 1<8) 33 feet 8. Property Designation ADL 388580 '.$$'Øz..- ,,¿If; 7. Unit or property Name 11. Type Bond (aee 20 AAC 25,0251) Nlk8ltchuq Statewide 8. Well number Number 1 3-798-381 9. ApproxImate spud date Amount February 5, 2oot1"<'¡ $200,000 14. Number of acres In Joperty 16. Proposed depth (MO end 00) 2560 10911 'MO/9150'1VD 17. AntIcIpated II'888Ute (_ 20 AN; 25.035 (e)(2» MaxImum surface 3470 psIg At Sag River Depth (8685' TVD) = 4340 psi Setting l>epth Bottom TVD 200 4688 7730 9150 RECEIVED JAN 2 3 2004 Alaska Oil & Gas Cons. Convnission Anchorage . . . ,.... ,n . i.. Type Of work: . Drill 0 Redrlll U I AMENDED RHf!tIy ODeepen 0 2. N8me Of Operator . Kerr McGee 011 & Gas Corporation 8. AdcIre8a 3900 "C. Street, Room 744, Anchorage, At< 99503 it. location of well at 8urface 1486' FWl & 507' FSL, See 16 T14N R9E UM AI. tap of producllve Interval 2618' FWI. & 488' FSL, See 9 T14N R9E UM AI. '*' depth 2689'·FEL &.620' FSL, See 9 T14N R9E UM 12. ÞIstence to nearest property line I 13. DIstance to nearest well,' 488 feet SPXA. MPU-F33A, > 30,000 11. To be compIeted'for deviated wells I</cId depIh: 400' MO 18. CasIng'program size 8685' 1VD feet Maximum hole angle .39.5° Top 1VD 32 30 4573 7730 MD 200 5700 9400 10911 Hole Caslnø Weight 13-318" 68# 12-1/4" ~" 401 8-112" 5-112" 17# 3-112" 9.2# SøecIficatIcns Grade CouplIng K-55 PE L-80 STe L-80 STC L-80 IBT-Mod MD 32 30 5550 9400 LenøIh 168 5668 3900 1690 it. To be completed for RedrlR. Re-entry, and Deepen OperatIons. Pœlentwell condition summary Totaf Dep1h: . measured feet ~,~) tnJe verbl feet EfecIIw 0epIh: measured feet tnJe verbl feet Plugs (measured) Junk (measured) Calng Length SIze Cemented Measured depth PerforatIon depth: measured true vertical RECEIVED JAN 2 3 2004 Alaska Oil & Gas Cons. Commission . . Anchorage Development on U Multiple Zone 0 10. Field and Pool Exploration Quantity of Cement (InçIude stage data) DrIve Pipe 567sx Pennafrost L & 560 $X G 495 sx of Premium + MIcroIIte & 560 sx Plemlufn.latex cement True Vertical depth 20. AtRhollC.II6 Flllngfee 0 PropertyPlat 0 BOPSketch@ DlvefterSketch 0 DrIIIlngprogram0 DrIIIng IIuId program @TIme VI depIh plot ~ ana/yaI8 ø Seabed report ø 20 MC 26.060 requfre.men18 ø 21.1 hereby certify. that. ~ ~ Ie. true and correct. to the best of my ~ For que8liOn8 call S/{/p coyner 907-339-6269 - IS~!S. c.. -: _OI&GasO>lp Dolo ,_ ~u CommIssion Use Only . ¡¡ PennltNurnberZ.ø'l_O/f" I A n~q-;z.5/~.8~ I ApllOV8ldate 1.4>10 J, 1:::':::',';;'116 CcIndIIIoiIaOfepprovaJ Samp/eareq S'Y" 0 No Mud~requ:¡'; I'" ( W'Yes U No HydRIgen 8UIftcIe III888URI8 ~ 0 No Dll8CIIonaIsurvey required ßa' Yea 0 No Reqund pnI88UIe. ~-- 0 8M; 0 8M; 0 10M; 0 0 LT ~r:7~ S" .()O pst. by order of .. . ~OPtT(Arr "* ð0'ð}-I REi DA~ I BY I OK I -f DESCRIP1l0N IREV DATE - I ~i I CK I APP DESCRIP1l0N NOTES: :::0:::0 13 ~ ~ 18 17 16 15 14 1. COORDS SHOWN ARE AK. STATE PLANE ZONE 4, NAD27. 2. DATE OF SURVEY: 2/4/04-2/5/04, F.B. L04-03, pp 1-8. 3. BASIS OF LOCA 1l0N: MON DS3R SOU1H2, BY LH.D. &: ASSOC. 4. LOCA1l0NS AND ELEVA1l0N DETERMINED Wl1H LEICA 500 SERIES GPS UNITS, USING GEOID 99. 5. GEOGRAPHIC COORDINATES ARE NAD 27. 6. ALL DISTANCES ARE TRUE. 7. ELEVA1l0NS ARE B.P.M.S.L. 24 19 23 25 30 29 28 27 26 36 31 32 33 34 35 NIKAITCHUQ #1 CONDo AS-BUILT LOCA TED WITHIN PROTRACTED SEC. 16, T 14 N, & R 9 E, UMIAT MERIDIAN. 404' F.S.L, 1336' F. W.L. ./ LA T = 70' 33' 39.985" LONG = 149' 50' 23.590" Y = 6,054,881.08/ X = 519,518.28 / TOP OF CELLAR ELEV. = 2.34' OLlKTOK Oliktok Point 600CK ~ 4 ~~~ DS 3R T14N T13N 2 ,.d VICINITY MAP Scale: 1" = ? Miles . N ,¡ 1336' NIKAITCHUQ )1 #1 ~ c II. _ J "<t o "<t ~~6 20121 'f1 ~~~""" ~·~S OF /]/ ". ..';^:\ ........... (..A~.. . '\ .., '" ' 1. ~.. _.- .. ..... r........ ... ..:.. .-J~ *~ ~ . ... ... ~ ¡ J;!../ 49th \.* \ _.....:.........,II.,......,I..............~.....~ - - ~,.,........,..........,I........,...............", II".:-;Q~ :9::_ ~ ?, \ BRIAN G. MANGOLD .: .f5. 11:.,/-. .·w. ..... ú'", ". LS-8626 ..' ;is- . ..... ..<\ .. .' - ~ . ...... \~ -'. ..' c:y.. ...:. ~ .... .... ("'\ . _ ,0, ........... ~v.. ." :?OFtSSION/l.L \..~.. """~~.~ 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 8, 2004. ßl LOUNSBURY & ASSOCIATES, INC. SURVEYORS ENGINBERS PlANNERS , Conoc6Phillips Alaska, Inc. I DRAWING NO: 02/05/04 AREA: MODULE: NIKAITCHUQ #1 CONDUCTOR ASBUIL T UNIT: CADD FILE NO. LK601D542 NSK 6.01-d542 I PART: I REV: 0 1 OF 1 NikaitchuaNo. 1 Surface Loc'n in Section 16 T14N R9E 70° 33' 39.9854" N & 149050' 23.5896" W 1336' FWL & 404 FSL ¡I/ 6054881.08' N & 519518.28' E NAD Zone 4 Bottom Hole Loc'n in Sec 9 T14N R9E 70034' 32.6355" N & 149050' 19.1566" W 1350' FWL & 477' FSL 6060234.46' N & 519654.17' E NAD 4 8 ADL 388581 Armstrong 0 & G Kerr McGee 0 & G ADL 388583 Armstrong 0 & G Kerr McGee 0 & G 17 ADL 388580 (2560 Armstrong 0 Kerr McGee 0 & G ~1336' 9 " , , , , , , , , , , , , , , , , , , , , , , 16 1 (As Built Location) . . ~ KEllll-Ift:6EE CORPOIIA1IIJM Nikaitchuq #1 ~d Revision Drilling and Completion Plan I Type of Well: "S-Curve" I Drill, Case, Test and Abandon / ,/ 1336' FWL & 404' FSL of Section 16, T14N, R9E UM ~ & 477' FSL of Section 9. T14N, R9E UM / Sl>6' FtJL. \ ;óJ> I I Rig: I Nabors 27E Surface Location: Bottom Hole Location: I AFE Number: I I Estimated Spud Date: 12/11/04 I I PTD: 110,890 I I TVD: 19,150' I I Geologic Objectives: I Operating Rig days: 116 + 61 I Pad Elev: 12.5' DF: 133.5' 1 Sag River Sandstone, Ivishak, Nuiqsit and Kuparuk ,/ I Mud Proaram: 12-1/4" Surface Hole (0-5700'): Density FV (ppg) (seconds) Spud - 2500' 9.0 - 9.5 80 - 120 2500' - 5700' 9.5 - 10.0 50 - 80 8-1/2" Production Hole (5700'-10890'): Density PV (ppg) (cp) 9.6 -10.0.1 10 -15 10.0-10.6 15-20 10.4-11.0.1 15-25 5700' - 8600' 8600' - 9500' 9500' - 1 0890' KCL-Polymer Mud Yield Point API FL PH (lb/100fe) (mls/30min) 35 - 45 10 - 15 8.5 - 9.5 20 - 30 6 - 8 8.5 - 9.5 KCL-Polymer-CaC03 Mud Yield Point API FL PH (lb/10Ofe) (mls/30min) - 6-12 6-10 8.5-9.5 15 - 20 4 - 6 8.5 - 9.5 15 - 25 < 6 8.5 - 9.5 . . Bit Proaram: Interval Size Type Footage Hours ROP RPM WOB Surf - 5,700' 12-1/4" 1-1-7 5500' 44 125 200/300 5-30 5,700' - 10,890' 8-1/2" PDC 5190' 74 70 200/300 5-25 Surveys & MWD: While Drilling: At Surface Casing Point: AtTD: Mud Loaaina: Surface Hole [12-1/4"]: (Samples: 30' /10') Production Hole [8-1/2"]: (Samples: 30' /10') 12-114" & 8-1/2" Holes: MWD surveys every 90 to 300 ft Drop a Magnetic Multi-Shot Survey Before POOH Drop a Magnetic Multi-Shot Survey Before POOH Rig instrumentation spud to casing point PVT, Flow- Show, gas detectors, H2S detectors as required. Mud loggers from B/Permafrost to casing point. Rig instrumentation spud to casing point PVT, Flow- Show, gas detectors, H2S detectors as required. Mud loggers from casing point to total depth. Formation Markers: Formation Tops MD TVD B/Permafrost 1935' 1783' TlWest Sak 4138' 3483' T/Colville 5609' 4618' 9-5/8" Surface Casing 5700' 4688' L. Brookian Fan 7893' 6473' TlHRZ 8623' 7073' T/Kalubik 8684' 7123' T/Kuparuk 8842' 7253' Miluveach 8878' 7283' LCU/Kingak 9000' 7383' T/Nuiqsit 9485' 7783' T/Sag River 10519' 8779' T/Shublik 10543' 8803' T/lvishak 10793' 9053' PTD 10890' 9150' v v' Possible Heavy Oil Zone ,./ Hydrocarbon Bearing, 8.5 ppg EMW ,/ Hydrocarbon Bearing, 9.8 ppg EMW Hydrocarbon Bearing, 9.6 ppg EMW Hydrocarbon Bearing, 9.8 - 6.2 ppg EMW v Possible Hydrocarbons 9.4 ppg EMW / / . Proposed Logging Program: Surface Hole: Production Hole: MWD I LWD: Open Hole: E-Line: MWD I LWD: Open Hole: E-Line: Cased Hole: . MWD I GR I RES Gas Detection, Mud Logging & samples Quad-Combo + Sonic + MDT's + SWC's MWD I GR I RES I PWD Gas Detection, Mud Logging & samples Quad-Combo + Sonic + MDT's + SWC's FMI I CMR + Velocity Check Shot GRISCMT/CCL ./ ./ Casing/Tubing Program: Hole Csg I Lnr WtlFt Grade Cplg Length Top Bottom Size Tbg OD's MD MD n/a 13-3/8" 68.0# L-80 PIE 116' GL 149' 12-114" 9-518" 40.0# L-80 BTC 5667' 33' 5700' 8-1/2" 5-1/2" 17.0# L-80 IBT-M 3850' 5550' 9400' 3-1/2" 9.2# L-80 IBT-M 1500' 9400' 10890' n/a 3-1/2" 9.2# L-80 IBT-M 9370' 30' 9400' Cement Calculations: Hole Size: Casing Size: Basis for Calculations: I Volumes: Hole Size: Liner Size: Basis for Calculations: I Volumes: 12-1/4" 9-5/8" Lead: 225% excess through the Permafrost to 1950' MD and 30% excess Below the Permafrost. Lead slurry to fill from 4200' MD to Surface. Tail: Based on 1500' of annular fill + 30% excess + 80' shoe track volume. Tail TOC: at +/- 4200' Lead 667 sx of Permafrost L: 10.7 ppg, 4.15 cf/sx Tail 560 sx of Premium cement + additives 8-1/2" 5-112" x 3-1/2" Lead: 3700' (9400'-5700') of 8-1/2" x 5-1/2" annulus, 150' of over lap, & 100' above TOL. Open Hole excess is 30% (or caliper log volume + 15%). Tail: Based on 1500' of 8-1/2" x 3-1/2" annular volume + 30% excess (or caliper log volume + 15%) + 90' shoe track volume. Tail TOC: at +/- 9400' Lead 495 sx of "G" cement + 15# Microlite: 12.5 ppg & 2.34 cf/sx Tail 560 sx of "G" cmt + Latex & Super CBL: 15.8 ppg & 1.15 cf/sk . . Integritv Testing: Test Point Surface Casing Shoe Depth 20' of new hole Test Type LOT LOT: EMW 13.3 ppg Minimum expected 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 12-114" 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 (8735' TVO) and a 0.11 psi/ft gradient to surface is: / / 4440 psi - (8779 ft x 0.12 psi/ft) = 3386 psi Disposal of Drilling Waste: · Cuttings Handling: Cuttings generated from drilling operations will be ground if" 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 1R-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. · ¡,. DRILLING AND COMPLETION PROCEDURE Pre-Rig Work: 1. The 13-3/8" non-insulated conductor has been driven to :t. 149' 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 tool pusher and company man will witness the first ten (10) stands off bottom for all trips. Use the trip tank. Keep a detailed trip sheet. Keep the hole full. Watch for swabbing. 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 +1- 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. . . .; 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 ~n_~_set casing at +/-??go' 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 ./ 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. 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. 10. M/U 8-1/2" directional drilling assembly with MWD/GR/RES/PWD~nd 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 and POOH. 14. RU E-Line, riser and packoff. Log the hole as directed: Quad-Combo, FMI, CMR, MDT's / 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. RIH with a bit and BHA. Ream any tight spots. Circulate bottoms up at least twice. POOH. 16. Run the 5-1/2" x 3-1/2" liner, PBR, liner hanger, packer and setting tools on drill pipe. The PBR is to be run .:t 100' above the Nuiqsit Sd. Set the liner hanger and PKR .:t 150' above . . the 9-5/8" shoe. Circulate and set the liner hanger. Condition the mud prior to cementing the liner. Cement the liner as programmed. Bump the plug. Set the packer and dis-engage from the liner. Circulate B/U and test the packer to 500 psi ~ the 9-5/8" LOT pressure. 17. Displace the hole with a spacer and seawater. Pump the seawater at maximum rate, rotate and reciprocate the drill pipe to help clean the hole. Shut down the pumps and flow check the well for 30 minutes. LDDP. 18. Run the 3-1/2",9.2# L-80 completion string including: PBR seal nipple, (1) profile nipple, (1) GLM with dummy valve and a TRSSV with control line. Space out the tubing. Displace the tubing and annulus with diesel to freeze protect. Sting into the PBR and land the tubing hanger. Test the annulus and PBR seals to 3500 psi. Test the tubing to 4000 psi. 19. Install a BPV. NID BOP's. NU the tree. Replace the BPV with a TWC. Test the tree to v 4000 psi. Test the control lines to 5000 psi. Re-install the BPV and close the SSV. 20. RID and MORT pending well test(s). Post Rig Operations: 1. MIRU Test Equipment, tanks, scaffolding and wind walls, etc. Pull the BPV. Open the SSV. 2. R/U E-Line with lubricator & bleed tank. RIH and run a GRlCCLlSCMT from PBTD through the TOL. Perforate the well as directed with 2.5" HSC's, 6 spf. RID E-Line. 3. Test the well as directed. 4. After testing the well, bullhead the tubing & liner with 10 ppg mud. R/U E-Line and set an EZSV 50' above the top perforation and dump 25' of cement on same. RID E-Line. 5. Plug the well in accordance with AOGCC Regulations. 6. Cut off the tubing and casing in accordance with AOGCC Regulations. 7. Scrape and remove all dirty ice. Remove the cellar and back-fill the hole. 8. When appropriate, inspect the site with AOGCC field inspector for final clearance. Attachments: · AOGCC Permit issued 1/30/2004 · As Built plat · Revised Wellbore Schematics · Revised Directional Drilling Plan ;~ 'Ì!"Ì+; . Kerr McGee Oil & Gas Corp. ~~t" ~~'"d:,,"<> Western Nartl! ~1:_pê(~/,ska " NW Milr¡2;~qlqt~~B~ Island) f/ikå- . ,. q'#JJ?if(wp08) i;¡;:;;;¿ .. _-l!! Revi.: 7 February, 2004 ~;,~ ):~: Proposal Report 7 February, 2004 Your Ref: BHL @ 5250· Due N of Previous Planned SHL (2-7-04) ./ Surface Coordinates: 6054881.08 N,~519518.28 E (70033' 39.9854" N, 149050'23.5896" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Kelly Bushing Elevation: 33.00ft above Mean Sea Level Proposal Ref: pro2081 ./ Begin oir@ 3.0"/100ft / in 12-1/4" Hole: /400.00ft Mo, 400.00ft TVo End oir, Start Sail@39.5" : 1716.67ft Mo, 1614.82ft TVo //' ,#"'/ 1500 - 3000 - :::J (f) ::::>. è<? <'> II '- 0 0 ¡:¡: OJ ëš J:: õ.. () C\ ro ü :e 6000 - () > 9000 I 1500 Measured Incl. Depth Kick-Off Point Hold Angle Continue Hold Start Drop HoldAngle , Drop toY crtical j Hold Angle Total Depth Nikaitchuq #1 (wp08) Proposal Data Azim. Vertical Northings Eastings Vertical Dogleg D;¡pth Section Rate 0.000 0.000 0.000 0.000 1.605 1.605 1.605 1.605 1.605 0.000 0.000 8525.33 9150.00 Csg pt ... Drill out 8-112" Hole: S700.00ft MD, 4688.46ft TVD oir @4.0"/100ft : 6000.00lt Mo, 4919.95ft TVD End Dir, Start Sail @ 34.72": 6119.40ft Mo, 5015.13ft TVD I 7500 6000 - 0.000 3.000 0.000 0.000 4.000 0.000 4.000 0.000 4000 - 2000 - ! -2000 """',,- Be9inlJrop to Vertical @ 4.0"/1 00f: : 9397.48ft MD, 7709.40ft TVD End Dir, Start Sail @ 34.72" : 6119.40ft MD, 5015. 13ft TVD Begin Dir@4.0"1100ft: 6000.00ft MD. 4919.95ft TVD End Dir, Start Sail @ 39.5" : 1716.67ft MD, 1614.82ft TVD Dir @ 3.0"/100ft 12-1/4" Hole: 400.00ft MD. 400.00ft TVD I 2000 Well: Current Well Properties Nikaitchuq #1 Horizontal Coordinates: Ref. Global Coordinates: Ref. SHL of Nikaitchuq #1 : Ref. Geographical C90rdinates : North Reference: Units: (f) OJ c E t o - 6000 Z - 4000 § o o N " .c - 2000 ,~ iD ¡¡¡ () (f) Eastings Scale: 1 inch 2000ft Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wpOB) Your Ref: BHL @ 5250' Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings EastinQs Northings Comment (ft) (ft) (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -33.00 0.00 0.00 N 0.00 E 6054881.08 N 0.00 SHL (1336' FWL & 404' FSL, v Sec. 16 - T14N - R9E) . 100.00 0.000 0.000 67.00 100.00 0.00 N 6054881.08 N '1" 5 E 0.000 0.00 200.00 0.000 0.000 167.00 200.00 0.00 N 6054651.08 N' 519518.28 E 0.000 0.00 300.00 0.000 0.000 267.00 300.00 0.00 N ßºp4~1.08 N .q19518.28 E 0.000 0.00 ~ 400.00 0.000 0.000 367.00 400.00 0.00 N 50P4881.08 N 519518.28 E 0.000 0.00 Begin Dir @ 3.00/100ft in 12-1/' Hole: 400.00ft MD, 400.00ft TV[ 500.00 3.000 1.605 466.95 499.95 054883.70 N 519518.35 E 3.000 2.62 600.00 6.000 1.605 566.63 599.63 6054891.54 N 519518.55 E 3.000 10.46 700.00 9.000 1.605 665.77 698.77 6054904.59 N 519518.88 E 3.000 23.51 800.00 12.000 1.605 764.08 797.08 6054922.80 N 519519.34 E 3.000 41.74 900.00 15.000 1.605 861 .31 894.31 6054946.14 N 519519.93 E 3.000 65.08 1000.00 18.000 1.605 957.18 990. 2.62 E 6054974.53 N 519520.65 E 3.000 93.48 1100.00 21.000 1.605 1051.43 1084. 3.55 E 6055007.89 N 519521.50 E 3.000 126.85 1200.00 24.000 1.605 1143.81 '~:i.1 1'76. 4.62 E 6055046.14 N 519522.47 E 3.000 165.12 1300.00 27.000 1.605 1294.()ß "'''··¿1267.06 5.83 E 6055089.18 N 519523.56 E 3.000 208.16 1400.00 30.000 1.605 1321.93 1354.93 7.17 E 6055136.87 N 519524.77 E 3.000 255.87 1500.00 33.000 1·ß()9 \~;i. 14()7.18 1440.18 308.00 N 8.63 E 6055189.10 N 519526.10 E 3.000 308.12 1600.00 36.000 1.eÕ5 '1489.59 1522.59 364.61 N 10.22 E 6055245.71 N 519527.54 E 3.000 364.75 1700.00 39.000 60q.; ;1568.91 1601.91 425.45 N 11.92 E 6055306.56 N 519529.08 E 3.000 425.62 1716.67 39.500; .6Qj' 1581.82 1614.82 435.99 N 12.22 E 6055317.10 N 519529.35 E 3.000 436.16 End Dir, Start Sail @ 39.5°: . 1716.67ft MD, 1614.82ft TVD 1800.00. 39.500 .c;,;;"'. 1.605 1646.12 1679.12 488.98 N 13.70 E 6055370.09 N 519530.69 E 0.000 489.17 >i 1900~00 .. . 39.500" 1.605 1723.28 1756.28 552.56 N 15.48 E 6055433.68 N 519532.31 E 0.000 552.78 1934.~~ 39.500 1.605 1750.00 1783.00 574.58 N 16.10 E 6055455.70 N 519532.87 E 0.000 574.80 Base of Permafrost 2000.00 39.500 1.605 1800.45 1833.45 616.15 N 17 .26 E 6055497.27 N 519533.92 E 0.000 616.39 2100.00 39.500 1.605 1877.61 1910.61 679.73 N 19.05 E 6055560.86 N 519535.53 E 0.000 679.99 2200.00 39.500 1.605 1954.77 1987.77 743.31 N 20.83 E 6055624.44 N 519537.15 E 0.000 743.60 2300.00 39.500 1.605 2031.93 2064.93 806.89 N 22.61 E 6055688.03 N 519538.76 E 0.000 807.21 2400.00 39.500 1.605 2109.10 2142.10 870.48 N 24.39 E 6055751.62 N 519540.38 E 0.000 870.82 2500.00 39.500 1.605 2186.26 2219.26 934.06 N 26.17 E 6055815.21 N 519541.99 E 0.000 934.43 2600.00 39.500 1.605 2263.42 2296.42 997.64 N 27.95 E 6055878.79 N 519543.60 E 0.000 998.03 2700.00 39.500 1.605 2340.58 2373.58 1061.23 N 29.74 E 6055942.38 N 519545.22 E 0.000 1061.64 7 February, 2004· 17:17 Page 2 of9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· Nikaitchuq #1 (wpOB) Your Ref: BHL @ 5250· Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Western North Slope, Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastin9s Northings Eastin9¡¡ (ft) (ft) (ft) (ft) (ft) (ft) (ft\;i, 2800.00 39.500 1.605 2417.75 2450.75 1124.81 N 31.52 E 6056005.97 N 3E 2900.00 39.500 1.605 2494.91 2527.91 1188.39 N 33.30 E 6056069.55 ~fcJ\ .1\.5E 3000.00 39.500 1.605 2572.07 2605.07 1251.97 N 35.08 E 6056133. 14 Nt!i¡¡, 5 .06 E 3100.00 39.500 1.605 2649.23 2682.23 1315.56 N 36.86 E 60561i~6.73 N~ 519551.67 E 3200.00 39.500 1.605 2726.40 2759.40 1379.14N 38.64 E i60562~.~ 32 N ' ~19553.29 E \{,:;\~;, ;>~,:/': ~,. 3300.00 39.500 1.605 2803.56 2836.56 1442.72 N ~A:~O.4~i'<r. . 6~323'.90 N 519554.90 E 0.000 3400.00 39.500 1.605 2880.72 2913.72 1506.31 N 'Ý4.~,2l 5/": 6056387.49 N 519556.52 E 0.000 3500.00 39.500 1.605 2957.88 2990.88 1569.89 43.99IiL' 6056451.08 N 519558.13 E 0.000 3600.00 39.500 1.605 3035.05 3068.05 1633.47 45,77 E~ 6056514.67 N 519559.74 E 0.000 3700.00 39.500 1.605 3112.21 3145.21 \~.7.05 N 47.55 E 6056578.25 N 519561.36 E 0.000 3800.00 39.500 1.605 3189.37 3222.37 ~:tt176).64 N 49.33 E 6056641.84 N 519562.97 E 0.000 3900.00 39.500 1.605 3266.53 3299 .5~; .10: 1824.2? N 51.11 E 6056705.43 N 519564.59 E 0.000 4000.00 39.500 1.605 3343.70 33i6.!f-1J \<j~a7.8Ò N 52.90 E 6056769.02 N 519566.20 E 0.000 4100.00 39.500 1.605 3420.86 34~.~/ 1951.39 N 54.68 E 6056832.60 N 519567.82 E 0.000 4137.77 39.500 1.605 3450.00 .3. 34~.O~/ 1975.40 N 55.35 E 6056856.62 N 519568.42 E 0.000 ~::'~", .,< 4200.00 39.500 1.605 .3498:02'.,;, 3531.02 2014.97 N 56.46 E 6056896.19 N 519569.43 E 0.000 4300.00 39.500 1.605 3575.18 <i~ 3608.18 2078.55 N 58.24 E 6056959.78 N 519571.04 E 0.000 4400.00 39.500 1.605 3652.35" 3685.35 2142.13N 60.02 E 6057023.36 N 519572.66 E 0.000 4500.00 39.500 1·605 3729.51 3762.51 2205.72 N 61.80 E 6057086.95 N 519574.27 E 0.000 4600.00 39.500 ':\1.60$ ,3806.67 3839.67 2269.30 N 63.59 E 6057150.54 N 519575.89 E 0.000 ,. ';<;'i:';"<,: 4700.00 3g:SQO . ,. .5 3883.83 3916.83 2332.88 N 65.37 E 6057214.13 N 519577.50 E 0.000 4800.QO , 39.500 _v 1.605 3961.00 3994.00 2396.47 N 67.15 E 6057277.71 N 519579.11 E 0.000 4900.00 39.500 1.605 4038.16 4071.16 2460.05 N 68.93 E 6057341.30 N 519580.73 E 0.000 5000.QO 39.500;. 1.605 4115.32 4148.32 2523.63 N 70.71 E 6057404.89 N 519582.34 E 0.000 5100.00 39.500 1.605 4192.48 4225.48 2587.21 N 72.49 E 6057468.48 N 519583.96 E 0.000 ">' 5200.00 39.500 1.605 4269.65 4302.65 2650.80 N 74.27 E 6057532.06 N 519585.57 E 0.000 5300.00 39.500 1.605 4346.81 4379.81 2714.38 N 76.06 E 6057595.65 N 519587.18 E 0.000 5400.00 39.500 1.605 4423.97 4456.97 2777.96 N 77.84 E 6057659.24 N 519588.80 E 0.000 5500.00 39.500 1.605 4501.13 4534.13 2841.55 N 79.62 E 6057722.83 N 519590.41 E 0.000 5600.00 39.500 1.605 4578.30 4611.30 2905.13 N 81.40 E 6057786.41 N 519592.03 E 0.000 5608.69 39.500 1.605 4585.00 4618.00 2910.65 N 81.56 E 6057791.94 N 519592.17 E 0.000 5700.00 39.500 1.605 4655.46 4688.46 2968.71 N 83.18 E 6057850.00 N 519593.64 E 0.000 5800.00 39.500 1.605 4732.62 4765.62 3032.29 N 84.96 E 6057913.59 N 519595.25 E 0.000 7 February, 2004·17:17 Page 3 of9 Kerr McGee Vertical Section Comment 1125.25 1188.86 . 1252.47 1316.07 1379.68 1443.29 1506.90 1570.50 1634.11 1697.72 1761.33 1824.94 1888.54 1952.15 1976.17 Top of West Sak 2015.76 2079.37 2142.97 2206.58 2270.19 2333.80 e 2397.41 2461.01 2524.62 2588.23 2651.84 2715.45 2779.05 2842.66 2906.27 2911.80 Base of West Sak 2969.88 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5700.00ft MD, 4688.46ft TVD 9-5/8" Casing 3033.48 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wpOB) Your Ref: BHL @ 5250· Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Western North Slope, Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 5900.00 39.500 1.605 4809.78 4842.78 6000.00 39.500 1.605 4886.95 4919.95 6100.00 6119.40 6200.00 6300.00 6400.00 6500.00 6600.00 6700.00 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700£00 780alºo 7893~t7 7900.0.Q 8000.&ó 8100.00 8200.00 8300.00 8400.00 8500.00 8600.00 8623.18 8684.01 35.500 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724, 34.724 ,34.724 . ' ". ;34.724 . ~ ;j\ ,:.... 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 34.724 7 February, 2004· 17:17 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 4966.26 4982.13 5048.38 5130.57 5212.76 5294.95 5377.14 5459.33 5541.52 5623.71 4999.26 5015.13 5081.38 5163.57 5245.76 5327.95 5410.14 5492.33 5574.52 :Þ;+ 5~6.71 :, 57~.90.~::,"';"· , 5821.09 5900.28 5985.47 6067.66 1.605 5705.90 1.605 5788.09" 1.605 5870.28\ 1.605: "5952.47.:; 'lt1?.Q5 ,6034.66>"/ 'i";i?~:;,'.\ ';~f 1.605 "1.6,Oß ,,' 1·1305 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 1.605 t6116.86 6199.05 6281.24 6363.43 6440.00 6445.62 6527.81 6610.00 6692.19 6774.38 6856.57 6938.76 7020.95 7040.00 7090.00 6149.86 6232.05 6314.24 6396.43 6473.00 6478.62 6560.81 6643.00 6725.19 6807.38 6889.57 6971.76 7053.95 7073.00 7123.00 Local Coordinates Northin9s Eastings (ft) (ft) 3095.88 N 86.75 E 3159.46 N 88.53 E 3220.30 N 3231.45 N 90.23 E 90.55 E 3448.17 N 35ØP.11 N .35~,Q5 N }61ª.~ N '·W·93N 3732.87 N 3789.81 N 3846.75 N 3903.69 N 3960.63 N 4017.57 N 4074.51 N 4131.45 N 4188.39 N 4241.44 N 4245.33 N 4302.27 N 4359.21 N 4416.15 N 4473.09 N 4530.03 N 4586.97 N 4643.91 N 4657.11 N 4691.75 N Global Coordinates Northings Eastings (ft) (ft 6057977.17 ~" 6058040.76 !:oJ ¥ .83.E' , N 43~¡:/' 60 15.60 N .02 e/ 6058272.55 N \\J0:;':' .~. 96.G2 E 98.21 E 99.81 E 101.41 E 103.00 E 104.60 E 106.19E 107.79 E 109.38 E 110.98 E 112.58 E 114.17 E 115.77E 117.36 E 118.85 E 118.96 E 120.55 E 122.15E 123.75 E 125.34 E 126.94 E 128.53 E 130.13E 130.50 E 131.47 E Page 4 of 9 6058329.49 N 6058386.43 N 6058443.38 N 6058500.32 N 6058557.27 N 6058614.21 N 6058671.16 N 6058728.10 N 6058785.04 N 6058841.99 N 6058898.93 N 6058955.88 N 6059012.82 N 6059069.77 N 6059122.82 N 6059126.71 N 6059183.65 N 6059240.60 N 6059297.54 N 6059354.49 N 6059411.43 N 6059468.37 N 6059525.32 N 6059538.52 N 6059573.16 N 519600.03 E ~iÞ9600.31 E 519601.47 E 519602.92 E 519604.37 E 519605.81 E 519607.26 E 519608.70 E 519610.15 E 519611.59 E 519613.04 E 519614.49 E 519615.93 E 519617.38 E 519618.82 E 519620.27 E 519621.71 E 519623.16 E 519624.60 E 519625.95 E 519626.05 E 519627.50 E 519628.94 E 519630.39 E 519631.83 E 519633.28 E 519634.72 E 519636.17 E 519636.51 E 519637.38 E "D 'I~g Rate e Section (qtt\OOft)P ,';;0.000 3097.09 0.000 3160.70 "f." 4.000 3221.56 4.000 3232.72 0.000 3278.63 0.000 3335.60 0.000 3392.56 0.000 3449.52 0.000 3506.48 0.000 3563.45 0.000 3620.41 0.000 3677.37 0.000 3734.33 0.000 3791.30 0.000 3848.26 0.000 3905.22 0.000 3962.18 0.000 4019.15 0.000 4076.11 0.000 4133.07 0.000 4190.03 0.000 4243.10 0.000 4247.00 0.000 4303.96 0.000 4360.92 0.000 4417.88 0.000 4474.85 0.000 4531.81 0.000 4588.77 0.000 4645.73 0.000 4658.94 0.000 4693.59 Kerr McGee Comment Begin Dir @ 4.00/100ft : 6000.00ft MD, 4919.95ft TVD . End Dir, Start Sail @ 34.72° : 6119.40ft MD, 5015.13ft TVD e Top of Middle Brookian Fan Tof of HRZ Tof of Kalubik DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wp08) Your Ref: BHL @ 5250· Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth (ncl. Azim. Depth Depth Northings Eastings Northings Easting$, Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft~;,j, ~;~; 8700.00 34.724 1.605 7103.14 7136.14 4700.85 N 131.72 E 6059582.26 G1 .62. E 4702.70 8800.00 34.724 1.605 7185.33 7218.33 4757.79 N 133.32 E 6059639.21 '6;1,'. .Qß E 4759.66 . 8842.18 34.724 1.605 7220.00 7253.00 4781.81 N 133.99 E 6059663.23 519ij39.67 E 4783.69 Top of Kuparuk 8900.00 34.724 1.605 7267.52 7300.52 4814.73 N 134.92 E 60G .15 N 519640.51 E 4816.62 9000.00 34.724 1.605 7349.71 7382.71 4871.67 N 136.51 E 10 N .95 E 4873.58 9000.35 34.724 1.605 7350.00 7383.00 6 519641.96 E 0.000 4873.78 LCU 9100.00 34.724 1.605 7431.90 7464.90 60 10.04 N 519643.40 E 0.000 4930.55 9200.00 34.724 1.605 7514.09 7547.09 6059866.98 N 519644.84 E 0.000 4987.51 9300.00 34.724 1.605 7596.28 7629.28 6059923.93 N 519646.29 E 0.000 5044.47 9397.48 34.724 1.605 7676.40 7709.40 6059979.44 N 519647.70 E 0.000 5100.00 Begin Drop to Vertical @ 4.0o/100ft: 9397.48ft MD, 7709.40ft TVD 9400.00 34.623 1.605 142.89 E 6059980.87 N 519647.74 E 4.000 5101.43 9485.22 31.214 1.605 144.19E 6060027.16 N 519648.91 E 4.000 5147.74 Top of Nuiqsit 9500.00 30.623 1.605 144.40 E 6060034.75 N 519649.10 E 4.000 5155.33 9554.39 28.448 1.605 145.15E 6060061.55 N 519649.78 E 4.000 5182.14 Base of Nuiqsit 9600.00 26.623 1.605 145.75 E 6060082.63 N 519650.32 E 4.000 5203.23 p 9700.00 79 7974.33 5242.83 N 146.91 E 6060124.28 N 519651.38 E 4.000 5244.88 9800.00 ª034.90 8067.90 5278.03 N 147.90 E 6060159.48 N 519652.27 E 4.000 5280.10 9900.00 :8130.70 8163.70 5306.62 N 148.70 E 6060188.07 N 519653.00 E 4.000 5308.70 10000.00 8228.27 8261.27 5328.46 N 149.31 E 6060209.91 N 519653.55 E 4.000 5330.55 . 10100.~; 8327.12 8360.12 5343.44 N 149.73 E 6060224.90 N 519653.93 E 4.000 5345.54 ..~",£., 1 0200.60 '. 8426.77 8459.77 5351.50 N 149.96 E 6060232.96 N 519654.14 E 4.000 5353.60 102650158,> 8492.33 8525.33 5353.00 N 150.00 E 6060234.46 N 519654.17 E 4.000 5355.10 End Dir, Maintail Vertical to TO: 10265.58ft MD, 8525.33ft TVD 10300.00 0.000 0.000 8526.75 8559.75 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 10400.00 0.000 0.000 8626.75 8659.75 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 10500.00 0.000 0.000 8726.75 8759.75 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 10519.25 0.000 0.000 8746.00 8779.00 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 TARGET: 10519.25ft MD, 8779.00ft TVD (1500' FWL & 4i FSL, Sec. 9-T14N-R9E) Top of Sag River 10543.25 0.000 0.000 8770.00 8803.00 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 Top of Shublik 10600.00 0.000 0.000 8826.75 8859.75 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 10700.00 0.000 0.000 8926.75 8959.75 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 10793.25 0.000 0.000 9020.00 9053.00 5353.00 N 150.00 E 6060234.46 N 519654.17 E 0.000 5355.10 Top of Ivishak 7 February, 2004·17:17 Page 5 of9 DrillQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wpOB) Your Ref: BHL @ 5250' Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Kerr McGee Comment Western North Slope, Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northin9s Eastings Northings (ft) (ft) (ft) (ft) (ft) (ft) 10800.00 0.000 0.000 9026.75 9059.75 5353.00 N 150.00 E 6060234.46 .v 10890.25 0.000 0.000 9117.00 9150.00 ,,/ 5353.00 N 150.00 E 6060234.46 5355.10 5355.10 PBHL: 10890.25ft MD, 9150._ vTVD (1500' FWL & 477' FSL, Sec. 9 - T14N - R9Ef ' Target - Nikaitchuq #1 (Revised BHL, 100.00 Radius., Current Target All data is in Feet (US Survey) unless otherwise stated. Directions and coordinat~EJrEtre.l~ti Vertical depths are relative to Rig Floor = 33' MSL. Northings and Eastin s are re >404' Global Northings and Eastings are relative to NAD27 Alaska State Plan one 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 404' FSL, 1336' FWL and calculated along an 9f 1.605° (True). >.. ......p, - Based upon Minimum Curvature type calculations, at a Me~s4redD~th 0 10890.25ft., The Bottom Hole Displacement is 5355.10ft., in the 1:;)' ctiqr oft,~§DSo (True). The Along Hole Displacement is 5355.1 Of!. "Q!eTo~1 ri\ulated Dogleg is 79.000° The Planned Tortuosity is 1.233°/100ft.]he val Difficulty Index is 5.4. Comments Measured Depth"~ f (ft) ?'~ 0.00 400.00 1716.67 5700.00 6000.00 6119.40 9397.48 10265.58 10519.25 7 February, 2004 - 17:17 0.00 400.00 1614.82 4688.46 4919.95 5015.13 7709.40 8525.33 8779.00 ';;11'" tion Coordinates Northin9s Eastings (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E 436.00 N 12.22 E 2968.71 N 83.18 E 3159.46 N 88.53 E 3231.45 N 90.55 E 5098.00 N 142.85 E 5353.00 N 150.00 E 5353.00 N 150.00 E . Comment SHL (1336' FWL & 404' FSL, Sec. 16 - T14N - R9E) Begin Dir @ 3.00/100ft in 12-1/4" Hole: 400.00ft MD, 400.00ft TVD End Dir, Start Sail @ 39.5° : 1716.67ft MD, 1614.82ft TVD 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5700.00ft MD, 4688.46ft TVD Begin Dir@ 4.00/100ft : 6000.00ft MD, 4919.95ft TVD End Dir, Start Sail @ 34.72°: 6119.40ft MD, 5015.13ft TVD Begin Drop to Vertical @ 4.0o/100ft : 9397.48ft MD, 7709.40ft TVD End Dir, Maintail Vertical to TO: 10265.58ft MD, 8525.33ft TVD TARGET: 10519.25ft MD, 8779.00ft TVD (1500' FWL & 477' FSL, Sec. 9-T14N-R9E) Page 6 of 9 DrillQuest 3.03.05.005 Western North Slope, Formation Tops Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dirn. 1750.00 0.000 0.151 3450.00 0.000 0.151 4585.00 0.000 0.151 6440.00 0.000 0.151 7040.00 0.000 0.151 7090.00 0.000 0.151 7220.00 0.000 0.151 7350.00 0.000 0.151 7750.00 0.000 0.151 7810.00 0.000 0.151 8746.00 0.000 0.151 8770.00 0.000 0.151 9020.00 0.000 0.151 Casin{ details "<Ö .> "<"'.'. J;,?ffJ ;"ffji' ::;;;;;µ> r.om ~CI>~ Vertical pth Depth (ft) (ft) <Surface> <Surface> 7 February, 2004· 17:17 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wpOB) Your Ref: BHL @ 5250' Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Profile Measured Vertical Depth Depth (ft) (ft) 1934.62 4137.77 5608.69 7893.17 8623.18 1783.00 3483.00 4618.00 6473.00 7073.00 Penetration Point Sub-Sea Depth Northings (ft) (ft) 1750.00 3450.00 4585.00 6440.00 704 0 8684.01 7123.00 8842.18 7253.00 ~~~~:~~ ~~;:~~' 50: 9554.39 <~ 78'Q()~ß10.00 10519..2 87.7Q~0 8746.00 10543.25 88Ò3.00 8770.00 \1Ö79~tb' 9053.00 9020.00 \'0~ To Measured Vertical Depth Depth (ft) (ft) 5700.00 4688.46 1.75 N 4781.81 N 4871.87 N 5145.72 N 5180.11 N Base of Permafrost Top of West Sak Base of West Sak Top of Middle Brookian Fan Tof of HRZ 131.47E TofofKalubik 133.99 E Top of Kuparuk 136.52 E LCU 144.19 E Top of Nuiqsit 145.15 E Base of Nuiqsit 5353.00 N 5353.00 N 5353.00 N 150.00 E Top of Sag River 150.00 E Top of Shublik 150.00 E Top of Ivishak Casing Detail 9-5/8" Casing Page 7 of 9 Kerr McGee . . DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· Nikaitchuq #1 (wp08) Your Ref: BHL @ 5250' Due N of Previous Planned SHL (2-7-04) Revised: 7 February, 2004 Western North Slope, Targets associated with this wellpath Target Name Nikaitchuq #1 (Revised) BHL Mean Sea Level/Global Coordinates: Geographical Cqqrdinªtes: et;Rad' NW Milne pt BHL (3 mile Radius) 7 February, 2004· 17:17 Page 8 of9 Target TVD (ft) 15840.00ft 5353.00 N 150.00 E 6060234.46 N 519654.17 E 700 34' 32.6355" N 1490 50' 19.1566" W 3324.57 S 13568.50 E 6051592.28 N 533095.49 E 70033' 07.1640" N 149043' 43.0681" W Target Shape Circle Circle Kerr McGee Target Type . Current Target Current Target e Dril/Quest 3.03.05.005 Magnetic Model: BGGM2003 Magnetic North Date: 07-Feb-04 Declination: 24.905 Inclination/Dip: 80.903 Horizontal Component: 9098 nT Northerly Component: 8252 nT Easterly Component: 3831 nT Vertical Component: 56822 nT Total Field Strength: 57546 nT Kerr McGee Oil & Gas Corp. North Reference Sheet for Spy Island - Nikaitchuq #1 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 Spheroid is Clarke - 1866 Equatorial Radius: 6,378,206.400m. Polar Radius: 6,356,583.800m. Grid North True North Grid Coordinates of Well: 6054881.08 N, Geographical Coordinates of Well: 70° Surface Elevation of Well: 33.00ft Grid Convergence at Surface' Magnetic Declination at ~ Hole Direction Grid North is 0.151 ° East of True North (Grid Convergence) Magnetic North is 24.905° East of True North (Magnetic Declination) Magnetic North is 24.754° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.151 degrees To convert a Magnetic Direction to a True Direction, Add 24.905 degrees To convert a Magnetic Direction to a Grid Direction, Add 24.754 degrees 7 February, 2004·17:17 Page 90f9 Kerr McGee . . DrillQuest 3.03.05.005 5550' 5700' 9380'-9400' 10890' Proposed (Revised) & Liner Top Packer , 40#,L-80, Liner x x 4" PBR & Nuiqsit 9485' (Possible pay I test) X Nipple Sag Profile) 10519' TaU :::::: 5750 psi) x-o 5550' 5700' 9300'-9400' 10890' 60' RKB 9..5/8" 40# , , & Liner (Revised) (F¡= > 100' below tbe9"5!8" sboe x pay / test) (2.813" Profile) Sand Liner Tail x-o 5700' MD 10890' MD 100' RKB 160' 3-1/2" below , 40#, L-80, BTC 100' 9-5/8" shoe x 3-112" Liner Nuiqsitperforations & Dump Cement Sag River perforations Cut 5700' 10890' & Revised , 40#, L~80, BTC below the 9-5/8" x 3-1/2" x 4" PBR & 3~1I2" X-O Possible Nuiqsit perforations & Sag perforations 3~112" Tail . I.. I . Ii . I, .' I + 500' MD:I 0 0 I I .. I .'. I . I .. I I·..··.. I. . I .'. I.. I· .. I . I" 4200' MD ~....'..~'~~." f.'.:;.!,;; ./""'J'.... ...~.... ...".......... é~~~ ~~::;.~~ '"''.:;.~.." ...,:......."'.. c,.....~ J~~~~ .~..:::~ p.;.!:; '..,..."''''..... ..'\..'\.. \~~"; .,..,.."'.... .....'\.. . 5700' MD ~.....-:t ..."'........... i3. ~ 1-------1 . 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 10890' MD 5550' 5700' 9380' -9400' 10890' Hanger & Liner Top Packer 9-5/8",40#, L-80, BTC (Pi = 5750 psi) x 3-112" Liner 5-1/2" x 4" PBR & 3-112" X-O 9485' (Possible pay / test) X Nipple (2.813" Profile) Sag River Sand: 10519' 3-112" Liner Tail 5550' 5700' 9300'-9400' 10890' 60' RKB 75' RKB Proposed Top Packer & 9-5/8", 40#, L-80, (Pi = 5750 3-112" Sleeve> 100' below the 9-5/8" shoe x 3-112" Liner X Nipple Profile) 5-112" x 4" PBR & 3-1/2" X-O Sand (Possible pay I test) Nipple Profìle) Sag River Sand Tail Q > 5000 I- 10000 -1000 Niikaitchuq #1 o I KOP at 400' 1000 Build at 3°/100' 2000 3000 -- 4000 at 5700' MD 6000 - 7000 1\1 8000 Drop at 4°/100' 9000 o 3000 5000 6000 1000 2000 4000 Vertical Section 5550' 5700' 9380' -9400' 10890' Liner 9-5/8", 40#, L-80,BTC (Pi x 3-112" Liner x 4" PBR & 3-112" X-O Sand: 9485' (Possible pay ltest) x Nipple (2.813" Profile) Sag River Sand: 10519' Tail . I I.> I F I + 500' MD : ~c, 0 0 I." I":' I r 1 I..··:· I' r..· r··:·· r r> . I;...::.'. ,: 4200' MD f;~~{ t·····'· .~~§~ j~~ i:;(;:.<. a,~,:;,!..:; (~~:~~ t~~~ž .~~?g t-c···· ~~~ 5700' MD ~------I . Tam Port Collar Permafrost "L" lead slurry -1500' of "Premium" tail slurry 8-1/2" Hole into the Ivishak 10890' MD 5550' 5700' 9300' -9400' 10890' 60' RKB 75' RKB Hanger & Nikaitchuq#l Proposed (Revised) Top Packer 9-5/8", 40#, L-80,BTC (Pi = 5-112" x 3-112" Liner - 3-112" Sliding Sleeve > 100' below the 9-5/8" shoe Nipple (2.813" Profile) 5-112" X PBR & 3-112" X-O N uiqsit Sand (Possible pay / test) X Nipple (2.813" Profile) Sag Sand Liner Tail Cut 5700' 10890' GL 9-5/8", 40#, L-80, Nikaitchuq#l ProposedP .& Revised 3-112" Sliding Sleeve 100' below the 9-5/8" shoe x Liner x & 3-112" X-O Possible Nuiqsit perforations Cement River perforations Liner o o Well bore seg Annular Disposal Off _Program EXP OnlOff Shore todrilJioQ op~(ations._ [nADL3ß8580._ Well Name: NIKAITCHUQ 1-01L _GeoArea 890 Unit Not r~qJ.lir~d_aJ> _this. is ,¡¡ r~v[s~d appJication_ s.uÞmiUed Prior Surtac~ location in ADL 388582; interval and TD ---EXP Oil ~oot lS:uP'¡¡(uK River _top_ prod_ Exploratory well, located_ within Jhe_ QOJ.lod_aries oJ th_eMilne J=>Oiot N~ar~st property bou_ndary is with ADL 355021 (BP), Joc,¡¡t~d -2,67'0' toS_E. Near~st open we] bore is MP_U}=-42, ,¡¡bout 17,500' to SE. y~s y~s y~s y~s y~s Yes y~s y~s y~s y~s y~s Y~s Yes NA NA NA No Initial ClasslType Field & Pool Company KERR-MCGEE OIL & GAS CORP P~(mitfe~ aU_ached _Leas~ _number <!PRfOPJi,¡¡t~ in_ad_efined pool distance from drilling unit wells_ bound,¡¡r:y Jo_cated pr.op~r Jocated prop~r distance_ f(om_ other _SJ.lfficient ~ Jfd~viatec in _drilJiog unit included ...creage _avail,¡¡ble 1 2 3 4 5 6 7 8 9 PTD#: 2040180 Administration _U_ni5:lU~ weltn_alJ1e _and oumb~r Jocated WeJ WeJ WeJ is weJlbore plat only aff~cted party in Jorce_ conser\la.tion order adminis.trati\'e _approvaJ has _appropriate_ b9nd c<! 0 be Lss l!ed with o_ut c<!o be Lssu_ed witho_ut be approved before 15-day wait incomlJ1~ots)(for 10# WeJ AU wellsJ^!Ït!1i!l J¿4JIJile _are_a_of review ideotified (For s.ervice w~1J only) Pre_-produçed injector; dur,¡¡tion _of pre-production less_ than 3. months_ (for lojectioo Order # (put Jo_cated within area an_dstrata authori'zed by only) serviçe well o 11 12 13 14 15 16 17 Oper<!tor Oper<!tor Permit Permit Can permit Date 2/8/2004 Appr SFD 1{2J¿o4:ACMF' review not required, lS:ayeLaughlin, J~O, .' - i"\\.~, _I.":. \r.c.~s '\~ _ \<:t,,-~~ \.."-> J ~ I-\\...(. - \ðeo.\\C t-- -(;.. ~ ~~Œ..-~ - \":)6~,",~0èè,,~(è_ - !/X?fV("J/~ -0 t â)~ _? \-~':. No USDW, Adequate exces.s, Nab_ors27E. Neww~1 ._Oppg. Max MW_11 Te_st t050QO_ ps[.MSF' 3479 . -- required. H2S precautions "e_ mudlo~ged_. in Ivisha_k, _ Welt wìl! h shall_ow ~as b4 1eath perlJ1<!frost. n~arest_offset control is oot expected. minor_ No indicators Qn 3D seismic. I_VIJI_,~UVI~ I'!!'ly"'!sur.e hydrates _or -- Well is 7 to 9 milesJrom A.bnprJnaj &'"Ol" n"""""':"""" t"\,.o.~'; Possible 9 Surf<!ce 10 ¡ i Y IslaodJ 69 Js_ pres_ence oJ H2S gas pJob_able 18 19 20 21 22 23 24 25 26 27 '28 29 30 31 32 33 34 CMJwill cover _al C<!siog de_signs ad_equate. for Adequ,¡¡tetan(age_or reJ>erye pit Jf _a_re-drjll, bas a_ tOA03 for ,¡¡ba_ndonment Qe~o approved Adequ,¡¡t~ _welJÞ.ore_ s.eparation propos.ed reguJations_ Jistadequat~ does it meet ØrilJiog fluid_pJogram scnematlc&_ equip BOPEs,_do Jtdiver:ter re.quired. Date 1/27/2004 ~~d{~.d'\ Appr WGA i!l_commeots) they meetreguJatioo t9(P ut ,"" (May 84) withoutoperatio!lsb own y~s y~s y~s Yes y~s y~s y~s NA y~s Yes y~s y~s y~s Yes y~s No_ NA No_ Yes y~s NA y~s Consist~ocyh,¡¡S bE1en jssl,ledJQrtbis proj~ct AÇMPFindingof & surtcsg to Koown productive borizonJ> C,T, B _&perllJafrost tiE1-in long $tring to surf cs~_ Cooductor strjn~_provided protec!s_ all_known_ USDWs CMT _voL adequate to circul,¡¡teoncOOd).lctor CMT_voLa_dequate_ Surface _casing_ Engineering psig t~st _ChokellJanifold compJies_ w/.i\PLRF'-"...._ WOJK will occur ra!iOQ appropriate; .BOPE _pre_ss MechanLcalcoodjtLon ot wells wl!hin AOR VE1rifìed_ (For_s~rv[ce well onJy) - . Permitc<!o be Lssu_ed w{o_ hydr_ogens_ulfide measures 35 36 37 38 39 Geology _D<!la_preseoted on pote_ntial ovemres_sure 'zone:> off-shpre) nam_elp!1oneJorweekly progres.sreports [e1<plorator:y _ooly] _S~ismic_analysis of sbaJlow gaszpoes_ (if S~aQed _conditioo survey Contact Date 2/8/2004 Appr SFD Multiple target formations will be filed on 1/26/2004. 2/9/04: Revised Skip Coyoer Exploratory well, located within the boundaries of the Milne Point, Kuparuk River Oil Pool. drilled: Kuparuk, Nuiqusit, Sag River and Ivishak. Designation of Operator form (10-411) 10-401 filed, surface and BHL changes. SFD Date Public Commissioner Date Engineering Commissioner Date: 2/2/2004 Geologic Commissioner: DTS . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRJA Tit LETTER/P ARAGRAPHS TO BE INCLUDED IN T~'MITT ~L LE~TER WELL NAME ¡1(ll:.allt'-~ / PTD# ;20 L/--- D/8 V--'-L. ~ \ \:)çQ..\~O~ v::£L. '- \. CHECK WHAT ADD-ONS APPLIES (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" Tbe permit is for a new well bore segment of existing well Permit No, API No. Productionsbould continue to be reported as a function· of tbe original API number stated above. BOLE In accordance witb 20 AAC 25.005(:1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION ~ ~RY DITCH V SAMPLE Rev: 07/] 0/02 C\jody\templates Tbe permit is approved subject ·to fuD compliance witb 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. An dry ditch sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample iJitervals tbrough target zones. r 1 . rnJ} /Æ . FRANK H. MURKOWSKI, GOVERNOR AI,A.SHA ORAND GAS CONSERVATION COMMISSION Todd Durkee Drilling Manager Kerr-McGee Oil & Gas Corporation 3900 C Street Ste 744 Anchorage, Alaska 99503 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Nikaitchuq #1 Kerr-McGee Oil & Gas Corporation Permit No: 204-018 Surface Location: 1486' FWL & 507' FSL, Sec. 16, T14N, R9E, UM Bottomho1e Location: 2589' FEL & 620' FSL, Sec. 9, T14N, R9E, UM Dear Mr. Durkee: Enclosed is the approved application for permit to drill the above referenced development 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. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. P ase provide at least twenty-four (24) hours notice for a representative of the Commissio to w' tness any required test. Contact the Commission's North Slope petroleum~ct at 9- 607 (pager). ¡' ~co ely, ~~I I Jo &' C air BY ORDER OF:J'HE COMMISSION DATED thi~"'-aay of January, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ KERR-M&E CORPORATION . January 23, 2004 RECEIVED JAN 2 3 2004 Alaska Oil & Gas Cons. Commission Anchorage Commissioner Alaska Oil and Gas Conservation Commission 333 W ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq # 1 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 #1 exploration well located approximately four (4) miles north ofOliktok Point. The original APD was submitted on January 15, 2004, along with the $100.00 filing fee. The original APD package included the abnormal pressure survey, the shallow hazard survey, a comprehensive drilling hazard analysis, drilling program, directional drilling plan, drilling mud program and cementing program. All attachments have been revised. Subsequent to the original filing, both the surface and bottom hole locations have./ changed and this Amended APD reflects those changes. The surface location was moved south to conform with other permits which required the location to be on or inside of the barrier island. The bottom hole location was moved based upon re-processed 3-D seismic. ..- ./ Our anticipated spud date is now ± February 5th, 2004. If you have any questions or concerns about the APD or the drilling plan, please call me at 339-6269 and I will do my best to address your questions or concerns. Sincerely, s~~ ASRC Energy Services Project (Drilling) Mngr. 3900 C Street Suite 702, Rm 744 Anchorage, AK 99503 OQIGINAL (907)-339-6370 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill 0 Redrill U AMENDED Re-entry DDeepen D 2. Name of Operator Kerr McGee Oil & Gas Corporation 11 b. Type of well. Exploratory 0 Stratigraphic Test D Service D Development Gas D Single Zone D 5. Datum elevation (DF or KB) 33 feet 3. Address 3900 "C" Street, Room 744, Anchorage, AK 99503 4. Location of well at surface 1486' FWL & 50T FSL, See 16 T14N R9E UM ' At top of productive interval 2618' FWL & 488' FSL, See 9 T14N R9E UM At total depth 2589' FEL & 620' FSL, See 9 T14N R9E UM / 12. Distance to nearest property line I 13. Distance to nearest well 488 feet BPXA, MPU-F33A, > 30,000 16. To be completed for deviated wells Kickoff depth: 400' MD 18. Casing program size Maximum hole angle Hole Casing Weight 13-3/8" 68# 12-1/4" 9-5/8" 40# 8-112" 5-112" 17# 3-1/2" 9.2# Specifications Grade Coupling K-55 PE L-80 BTC L-80 BTC L-80 IBT-Mod 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet true vertical feet Effective Depth: measured feet true vertical feet Casing Length Size Cemented Perforation depth: measured true vertical Form 10-401 Rev. 12/1/85· 1 9. Approximate spud date February 5, 20Œf~ 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 3470 psig At Sag River Depth (8685' TVD) = 4340 psi Setting Depth 6. Property Designation ADL 388580 / :3i38~f.?2- 7. Unit or property Name Nikaitchuq 8. Well number 8685' TVD feet 39.5° . Wt)Æ t I l.1/WO'f RECEIVED JAN 2 3 2004 Alaska Oil & Gas Cons. Commission ^nchoraaa, Development Oil U Multiple Zone D 10. Field and Pool Exploration ..61> 11. Type Bond (see 20 AAC 25.0251) Statewide Number 3-798-381 Amount $200,000 15. Proposed depth (MD and lVD) /10911 ' MD / 9150 ' TVD ,/ Length 168 5668 3900 1690 Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 32 32 200 200 Drive Pipe 30 30 5700 4688 667 sx Permafrost L & 560 sx G /' 5550 4573 9400 7730 495 sx of Premium + Microlite & 9400 7730 10911 9150 560 sx Premium-Latex cement Plugs (measured) Junk (measured) Measured depth by order of Commissioner the commission Alaska Oil & Gas Cons, Commission Anchorage 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot 0Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21 I hereby certify that the fO~ng IS true and correct to the best of my knowledge For questions call Skip Coyner 907-339-6269 Signed Jd!:ið~ž. ........ .t!' C. Title: Kerr-McGee Oil & Gas Corp Date 1/23/2004 Todd Durkee > Commission Use Only Permit Number ~ / ('/" lAP number . Q /a "!2 ... I Approval da~e / / 20ï -O/ð 50-q¡st·-¿<) t---~-{YêJ 1/31? ()t.f- Conditions of approval ~.mPI~ ro~ p<t '~'.f,í No MOd'" "'0''''' f Hydrogen sulfilde measures ßj Yes r N'<r · Directional survey required .ø Yes Required worki ressur "or PE 2M; 0 3M; D 5M; 0 10M; D 0 Other:'~ ~ t.·. P '5DOO f~i. Approve - ........ \/ ORIGlf~AL True Vertical depth RECEIVED JAN 2 3 2004 see cover letter for other requirements ~ Yes U No o No Date ð~f4- NikaitchuQ No. SurlaceLoc'n in Section 16 T14N R9E 70033' 40.9970" N & 149050' 19.1712" W 1486' FWL &507 FSL / 6054984.32' N & Zone Bottom Hole Loc'n in 2589' FEL & 620' FSL 6060413.52' N & 520851.53' E 8 ADL Kerf McGee 4 17 FSL 9 Hole 16 ~ 620' 1 .. 1 e e GB KERB-IWCSEE CDRPORATIDII Nikaitchuq #1 Revised Drilling and Completion Plan I Type of Well: "S-Curve" I Drill, Case, Test and Abandon Surface Location: Bottom Hole Location: 1486' FWL & 501' FSL of Section 16, T14N, R9E UM ' 2589' FEL & 620' FSL of Section 9, T14N, R9E UM . I AFE Number: 1 Estimated Spud Date: 2/5/2004 I Rig: I Nabors 27E Operating Rig days: 16 + 6 I PTD: 110,911' 1 I TVD: 19,150' 1 < I Pad Elev: 13.0' 1 I RKB: 133.0' 1 I Geologic Objectives: Sag River Sandstone, Ivishak, Nuiqsit and Kuparuk I/" Mud Proaram: 12-1/4" Surface Hole (0-5700'): Density FV (ppg) (seconds) Spud - 2500' 9.0 - 9.5 80 - 120 2500' - 5700' 9.5 - 10.0 50 - 80 8-1/2" Production Hole (5700'-10911'): Density PV (ppg) (cp) 9.6 -10.0 10 -15 10.0 -10.6 15 - 20 10.4-11.0 15-25 5700' - 8600' 8600' - 9500' 9500' - 10911' KCL-Polymer Mud Yield Point API FL PH (lb/10Ofe) (mls/30min) 35-45 10-15 8.5-9.5 20 - 30 6 - 8 8.5 - 9.5 KCL-Polymer-CaC03 Mud Yield Point API FL PH (lb/10Ofe) (mls/30min) - 6 - 12 6 - 10 8.5 - 9.5 15 - 20 4 - 6 8.5 - 9.5 15 - 25 < 6 8.5 - 9.5 e e Bit Program: Interval Size Type Footage Hours ROP RPM WOB Surf - 5,700' 12-1/4" 1-1-7 5500' 44 125 200/300 5-30 5,700' -10,911' 8-1/2" PDC 5211' 70 70 200/300 5-25 Surveys & MWD: While Drilling: At Surface Casing Point: AtTD: Mud Logging: Surface Hole [12-1/4"]: (Samples: 30' /10') Production Hole [8-1/2"]: (Samples: 30' /10') 12-1/4" & 8-1/2" Holes: MWD surveys every 90 to 300 ft Drop a Magnetic Multi-Shot Survey Before POOH Drop a Magnetic Multi-Shot Survey Before POOH Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. .. Mud loggers from B/Permafrost to casing point../ Rig instrumentation spud to casing point: PVT, Flow- Show, gas detectors, H2S detectors as required. ' Mud loggers from casing point to total depth. ~ Formation Markers: Formation Tops MD TVD B/Permafrost 1935' 1783' TlWest Sak 4138' 3483' T/Colville 5609' 4618' 9-5/8" Suñace Casing 5700' 4688' M. Brookian Fan 8013' 6473' T/HRZ 8700' 7073' T/Kalubik 8754' 7123' T/Kuparuk 8892' 7253' Miluveach 8824' 7283' LCU/Kingak 9030' 7383' T/Nuiqsit 9456' 7783' T/Sag River 10516' 8779' T/Shublik 10542' 8803' T/lvishak 10808' 9053' PTD 10911 ' 9150' " Possible Heavy Oil Zone Hydrocarbon Bearing, 8.5 ppg EMW Hydrocarbon Bearing, 9.8 ppg EMW Hydrocarbon Bearing, 9.6 ppg EMW Hydrocarbon Bearing, 9.8 - 6.2 ppg EMW Possible Hydrocarbons 9.4 ppg EMW e Proposed Logging Program: Surface Hole: Production Hole: MWD I LWD: Open Hole: E-Line: MWD I LWD: Open Hole: E-Line: Cased Hole: e MWD / GR / RES Gas Detection & Mud Logging" Quad-Combo + Sonic + MDT's + SWC's MWD / GR / RES / PWD Gas Detection & Mud Logging Quad-Combo + Sonic + MDT's + SWC's .' FMI / CMR + Velocity Check Shots . GR/SCMT/CCL Casing/Tubing Program: Hole Csg I Lnr WtlFt Grade Cplg Length Top Bottom Size Tbg OD's MD/TVD MD/TVD n/a 13-3/8" 68.0# L-80 PIE 200' GL 200' 12-1/4" 9-5/8" 40.0# L-80 BTC 5612' 32' 5644' 8-1/2" 5-1/2" 17.0# L-80 IBT-M 3900' 5500' 9400' 3-1/2" 9.2# L-80 IBT-M 1690' 9400' -11"090' loQIl f,uGÆ- n/a 3-1/2" 9.2# L-80 IBT-M 5470' 30' 5500' Cement Calculations: Hole Size: Casing Size: Basis for Calculations: I Volumes: Hole Size: Liner Size: Basis for Calculations: I Volumes: 12-1/4" 9-5/8" Lead: 225% excess through the Permafrost to 1950' MD and 30% excess Below the Permafrost. Lead slurry to fill from 4200' MD to Surface. Tail: Based on 1500' of annular fill + 30% excess + 80' shoe track volume. Tail TOC: at +/- 4200' Lead 667 sx of Permafrost L: 10.7 ppg, 4.15 cf/sx Tail 560 sx of Premium cement + additives 8-1/2" 5-1/2" x 3-1/2" Lead: 3700' (9400'-5700') of 8-1/2" x 5-1/2" annulus, 150' of over lap, & 100' above TOL. Open Hole excess is 30% (or caliper log volume + 15%). Tail: Based on 1511' of 8-1/2" x 3-1/2" annular volume + 30% excess (or caliper log volume + 15%) + 90' shoe track volume. Tail TOC: at +/- 9400' Lead 495 sx of "G" cement + 15# Microlite: 12.5 ppg & 2.34 cf/sx Tail 567 sx of "G" cmt + Latex & Super CBL: 15.8 ppg & 1.15 cf/sk e e Intearitv Testina: Test Poi nt Surface Casing Shoe Depth 20' of new hole Test Type LOT LOT: EMW 13.3 ppg Minimum expected 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 (8735' TVD) and a 0.11 psi/ft gradient to surface is: 4440 psi - (8735 ft x 0.11 psi/ft) = 3479 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: located on DS-04, Prudhoe Bay pursuant to Ballot 9 approval. · 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. e e DRilLING AND COMPLETION PROCEDURE Pre-Rig Work: 1. The 13-3/8" non-insulated conductor will be driven to :t 200'. 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 onlnear 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 +/- 60 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. e e I 4. P/U a 12-114" 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 v 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 1 000' 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. 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. 10. M/U 8-1/2" directional drilling assembly with MWD/GR/RES/PWDvand a bent-housing motor. P/U +1- 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, 9.6 ppg 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 and POOH. 14. RU E-Line, riser and packoff. Log the hole as directed: Quad-Combo, FMI, CMR, MDT's ... 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. RIH with a bit and BHA. Ream any tight spots. Circulate bottoms up at least twice. POOH. 16. Run the 5-1/2" x 3-1/2" liner, PBR, liner hanger, packer and setting tools on drill pipe. The PBR is to be run ~ 100' above the Nuiqsit Sd. Set the liner hanger and PKR ~ 150' above e e the 9-5/8" shoe. Circulate and set the liner hanger. Condition the mud prior to cementing the liner. Cement the liner as programmed. Bump the plug. Set the packer and dis-engage from the liner. Circulate B/U and test the packer to 500 psi ~ the 9-5/8" LOT pressure. 17. Displace the hole with a spacer and seawater. Pump the seawater at maximum rate, rotate and reciprocate the drill pipe to help clean the hole. Shut down the pumps and flow check the well for 30 minutes. LDDP. 18. Run the 3-1/2", 9.2# L-80 completion string including: PBR seal nipple, (1) profile nipple, (1) GLM with dummy valve and a TRSSV with control line. Space out the tubing. Displace the tubing and annulus with diesel to freeze protect. Sting into the PBR and land the tubing hanger. Test the annulus and PBR seals to 3500 psi. Test the tubing to 4000 psi. 19. Install a BPV. NID BOP's. NU the tree. Replace the BPV with a TWC. Test the tree to 4000 psi. Test the control lines to 5000 psi. Re-install the BPV and close the SSV. 20. RID and MORT pending well test(s). Post Rig Operations: 1. MIRU Test Equipment, tanks, scaffolding and wind walls, etc. Pull the BPV. Open the SSV. 2. R/U E-Line with lubricator & bleed tank. RIH and run a GRlCCUSCMT from PBTD throughv the TOL. Perforate the well as directed with 2.5" HSC's, 6 spf. RID E-Line. 3. Test the well as directed. 4. After testing the well, bullhead the tubing & liner with 10 ppg mud. R/U E-Line and set an EZSV 50' above the top perforation and dump 25' of cement on same. RID E-Line. 5. Plug the well in accordance with AOGCC Regulations. 6. Cut off the tubing and casing in accordance with AOGCC Regulations. 7. Scrape and remove all dirty ice. Remove the cellar and back-fill the hole. 8. When appropriate, inspect the site with AOGCC field inspector for final clearance. Attachments: · Wellbore Schematics · Drilling Curve: Days -v- Depth · Frac Gradient Plot (from offset data) · Diverter & BOP Schematics · Directional Drilling program · Drilling Mud Program · Cementing Program 5550' 5700' 9380' -9400' 10911' & , 40#, L-80, - x Nuiqsit Sand: (Possible pay I test) 10597' Tail 5550' 5700' 9300' -9400' 10911' (Revised) Liner Hanger & , 40#, (Pi = 5750 2:: 100' below x 3-1/2" x 4" & 3-1/2" Sand (Possible pay / test) X Nipple (2.813" ProfHe) Sag Sand 3-1/2" Liner 5700' 10911 ' 160' 9-5/8", 40#, L-80, 3-112" x Liner x 4" 100' 3-112" 3-112" Cut 1 5700' , 40#, & x 0 1000 -'- -.....;- - -- 2000 3000 .. - - -- - - 4000· SOOO ' -~---- 6000 "'C m II.. :::J 1000 . m m m :liE 8000 9000 10000 11000 .. 12000 - - -,- - ....., - 13000 0.0 Nikaitchuq #1 - ---'-- -- -~-- - --~ - -- - ----- - -- I E~Line Logging. Set and Cmt I 9~5/8" Casing at 5100' MD -----,--~-- - -,-----~--~- ------- _ _ _ i--_ - - ~,- - - -'10911' MD I I Logs, SWC's, MDT's, Check Shot: I Run Liner and Completion - -r- --- - - --- 10.0 Rig Days 15.0 20.0 Nikaitchuq #1 o I 1000 ~ 2000 3000 4000 9-5/8" at 5700' MD 5000 6000 5-1/2" x 3-1/2" Tapered liner at 10911' MD 7000 8000 9000 10000 -1000 1000 2000 4000 5000 6000 o 3000 Vertical Section sc 1000 2000 3000 4000 5000 6000 7000 8000 . 10.0 set L Tlls (Frac Gradient) o d 11.0 14.0 17.0 18.0 12.0 15.0 16.0 13.0 EMW (ppg) 9/02 Kerr McGee Oil & Gas Corp. Western North Slope, Alaska NW Milne Point (Spy Island) Nikaitchuq #1 (wp04) e Revised: 21 January, 2004 Proposal Report 21 January, 2004 Your Ref: Generated January 20, 2004 (Revised Target Depth) /Surface Coordinates: 6054984.32 N, 519667.62 E (70033' 40.9970" N, 149050'19.1712" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 e Kelly Bushing Elevation: 33.00ft above Mean Sea Level ·p·...,...,v-·ul1 ~..... . INN .I""'...VI,.....- A Halliburton Company Proposal Ref: pro2071 Begin Dir @ 3.0"/100ft _______ in 12·114" Hole: 400.00ft MD, 400.00ft TVD 7500 1500.... Nikaitchuq #1 (wp04) Proposal Data Measured Incl. Depth 0.000 Northings Eastings Vertical Dogleg Section Rate 3000 :::¡ r./) ::¡¡ 00 (V") If CD 4500 )é ~ £; a. () Q ro <.:> 12 ~ 6000 .... CurrentWell PropE)rties WEt]!: RKBElevatíofl ; 33.0Oft abQve Mean Sea Level '" o o "' Eastings Scale: 1 inch 1000ft I P~HL: 10910.77911 MIp. 9150.00ft TVD V (2589' FEL 8. 620' FSI., Sec. 9 . T14N ! 1000 I 0.000 3.000 O.()(){) 4.000 I).()OO 0.000 4000 .... 9·5/8" 3000 2000 .... 1000.... End Dir. Start Sail @ 39.5" : ./1716.67ftMD,1614.82ftTVD 3.0'1100ft in 12·114" Hoie: .... 5000 .... 4000 .... 3000 (/) OJ <:: 1: t o Z .... 2000 .... 1000 '" o o o t .£ (/) Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nlkaitchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Western North Slope, Kerr McGee Measured 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 -33.00 0.00 O,OON 0.00 E '/6054984.32 N 519667.62 E 0.00 SHL (1486' FWL & 507' FSL, Se . 16 - T14N - R9E) 100.00 0.000 0.000 67.00 100.00 0.00 N 0.00 E 6054984.32 N 519667.62 E 0.000 0.00 200.00 0.000 0.000 167.00 200.00 O.OON 0.00 E 6054984.32 N 519667.62 E 0.000 0.00 300.00 0.000 0.000 267.00 300.00 0.00 N 0.00 E 6054984.32 N 519667.62 E 0.000 0.00 /400.00 0.000 0.000 367.00 400.00 0.00 N 0.00 E 6054984.32 N 519667.62 E 0.000 0.00 Begin Dir @ 3.0·/100ft in 12-1/4 Hole: 400.00ft MD, 400.00ft _ 500.00 3.000 12.454 466.95 499.95 2.56 N 0.56 E 6054986.88 N 519668.18 E 3.000 2.62 600.00 6.000 12.454 566.63 599.63 10.22 N 2.26 E 6054994.54 N 519669.85 E 3.000 10.46 700.00 9.000 12.454 665.77 698.77 22.96 N 5.07 E 6055007.29 N 519672.63 E 3.000 23.51 800.00 12.000 12.454 764.08 797.08 40.75 N 9.00 E 6055025.10 N 519676.51 E 3.000 41.74 900.00 15.000 12.454 861 .31 894.31 63.55 N 14.03 E 6055047.90 N 519681.49 E 3.000 65.08 1000.00 18.000 12.454 957.18 990.18 91.28 N 20.16 E 6055075.65 N 519687.54 E 3.000 93.48 1100.00 21.000 12.454 1051.43 1084.43 123.87 N 27.36 E 6055108.26 N 519694.65 E 3.000 126.85 1200.00 24.000 12.454 1143.81 1176.61 161.23 N 35.61 E 6055145.64 N 519702.80 E 3.000 165.12 1300.00 27.000 12.454 1234.06 1267.06 203.26 N 44.89 E 6055187.70 N 519711.97 E 3.000 208.16 1400.00 30.000 12.454 1321.93 1354.93 249.85 N 55.18 E 6055234.32 N 519722.14 E 3.000 255.87 1500.00 33.000 12.454 1407.18 1440.18 300.87 N 66.45 E 6055285.36 N 519733.27 E 3.000 308.12 1600.00 36.000 12.454 1489.59 1522.59 356.17 N 78.66 E 6055340.70 N 519745.33 E 3.000 364.75 1700.00 39.000 12.454 1568.91 1601.91 415.60 N 91.79E 6055400.17 N 519758.30 E 3.000 425.62 1716.67 39.500 12.454 1581.82 1614.82 425.90 N 94.06 E 6055410.47 N 519760.55 E 3.000 436.16 End Dir, Start Sail @ 39.5· : 1716.67ft MD, 1614.82ftTVD 1800.00 39.500 12.454 1646.12 1679.12 477.66 N 105.49 E 6055462.26 N 519771.84 E 0.000 489.17 1900.00 39.500 12.454 1723.28 1756.28 539.77 N 119.21 E 6055524.41 N 519785.40 E 0.000 552.78 e 1934.62 39.500 12.454 1750.00 1783.00 561.28 N 123.96 E 6055545.92 N 519790.09 E 0.000 574.80 Base of Permafrost 2000.00 39.500 12.454 1800.45 1833.45 601.88 N 132.93 E 6055586.55 N 519798.95 E 0.000 616.39 2100.00 39.500 12.454 1877.61 1910.61 663.99 N 146.64 E 6055648.70 N 519812.50 E 0.000 679.99 2200.00 39.500 12.454 1954.77 1987.77 726.11 N 160.36 E 6055710.85 N 519826.05 E 0.000 743.60 2300.00 39.500 12.454 2031.93 2064.93 788.22 N 174.08 E 6055773.00 N 519839.61 E 0.000 807.21 2400.00 39.500 12.454 2109.10 2142.10 850.33 N 187.80 E 6055835.14 N 519853.16 E 0.000 870.82 2500.00 39.500 12.454 2186.26 2219.26 912.44 N 201.51 E 6055897.29 N 519866.71 E 0.000 934.43 2600.00 39.500 12.454 2263.42 2296.42 974.55 N 215.23 E 6055959.44 N 519880.26 E 0.000 998.03 2700.00 39.500 12.454 2340.58 2373.58 1036.66 N 228.95 E 6056021.59 N 519893.82 E 0.000 1061.64 21 J.nu.ry, 2004 . 1:31 P'Q' 2 of 9 DrI1lQu..t 3,03.05,005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaitchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Western North Slope, Kerr McGee Measured 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) 2800.00 39.500 12.454 2417.75 2450.75 1098.77 N 242.67 E 6056083.73 N 519907.37 E 0.000 1125.25 2900.00 39.500 12.454 2494.91 2527.91 1160.88 N 256.38 E 6056145.88 N 519920.92 E 0.000 1188.86 3000.00 39.500 12.454 2572.07 2605.07 1222.99 N 270.10 E 6056208.03 N 519934.47 E 0.000 1252.47 3100.00 39.500 12.454 2649.23 2682.23 1285.11 N 283.82 E 6056270.17 N 519948.03 E 0.000 1316.07 3200.00 39.500 12.454 2726.40 2759.40 1347.22 N 297.54 E 6056332.32 N 519961.58 E 0.000 1379.68 3300.00 39.500 12.454 2803.56 2836.56 1409.33 N 311.25 E 6056394.47 N 519975.13 E 0.000 1443.29 e 3400.00 39.500 12.454 2880.72 2913.72 1471.44 N 324.97 E 6056456.62 N 519988.68 E 0.000 1506.90 3500.00 39.500 12.454 2957.88 2990.88 1533.55 N 338.69 E 6056518.76 N 520002.23 E 0.000 1570.50 3600.00 39.500 12.454 3035.05 3068.05 1595.66 N 352.41 E 6056580.91 N 520015.79 E 0.000 1634.11 3700.00 39.500 12.454 3112.21 3145.21 1657.77 N 366.12 E 6056643.06 N 520029.34 E 0.000 1697.72 3800.00 39.500 12.454 3189.37 3222.37 1719.88N 379.84 E 6056705.21 N 520042.89 E 0.000 1761.33 3900.00 39.500 12.454 3266.53 3299.53 1781.99 N 393.56 E 6056767.35 N 520056.44 E 0.000 1824.94 4000.00 39.500 12.454 3343.70 3376.70 1844.11 N 407.28 E 6056829.50 N 520070.00 E 0.000 1888.54 4100.00 39.500 12.454 3420.86 3453.86 1906.22 N 420.99 E 6056891.65 N 520083.55 E 0.000 1952.15 4137.77 39.500 12.454 3450.00 3483.00 1929.67 N 426.17 E 6056915.12 N 520088.67 E 0.000 1976.17 Top of West Sak 4200.00 39.500 12.454 3498.02 3531.02 1968.33 N 434.71 E 6056953.79 N 520097.10 E 0.000 2015.76 4300.00 39.500 12.454 3575.18 3608.18 2030.44 N 448.43 E 6057015.94 N 520110.65E 0.000 2079.37 4400.00 39.500 12.454 3652.35 3685.35 2092.55 N 462.14 E 6057078.09 N 520124.21 E 0.000 2142.97 4500.00 39.500 12.454 3729.51 3762.51 2154.66 N 475.86 E 6057140.24 N 520137.76 E 0.000 2206.58 4600.00 39.500 12.454 3806.67 3839.67 2216.77 N 489.58 E 6057202.38 N 520151.31 E 0.000 2270.19 4700.00 39.500 12.454 3883.83 3916.83 2278.88 N 503.30 E 6057264.53 N 520164.86 E 0.000 2333.80 4800.00 39.500 12.454 3961.00 3994.00 2340.99 N 517.01 E 6057326.68 N 520178.42 E 0.000 2397.41 4900.00 39.500 12.454 4038.16 4071.16 2403.10 N 530.73 E 6057388.83 N 520191.97 E 0.000 2461.01 5000.00 39.500 12.454 4115.32 4148.32 2465.22 N 544.45 E 6057450.97 N 520205.52 E 0.000 2524.62 e 5100.00 39.500 12.454 4192.48 4225.48 2527.33 N 558.17 E 6057513.12 N 520219.07 E 0.000 2588.23 5200.00 39.500 12.454 4269.65 4302.65 2589.44 N 571.88 E 6057575.27 N 520232.63 E 0.000 2651.84 5300.00 39.500 12.454 4346.81 4379.81 2651.55 N 585.60 E 6057637.41 N 520246.18 E 0.000 2715.45 5400.00 39.500 12.454 4423.97 4456.97 2713.66 N 599.32 E 6057699.56 N 520259.73 E 0.000 2779.05 5500.00 39.500 12.454 4501.13 4534.13 2775.77 N 613.04 E 6057761.71 N 520273.28 E 0.000 2842.66 5600.00 39.500 12.454 4578.30 4611.30 2837.88 N 626.75 E 6057823.86 N 520286.84 E 0.000 2906.27 5608.69 39.500 12.454 4585.00 4618.00 2843.28 N 627.95 E 6057829.26 N 520288.01 E 0.000 2911.80 Base of West Sak 5700.00 39.500 12.454 4655.46 4688.46 2899.99 N 640.47 E 6057886.00 N 520300.39 E 0.000 2969.88 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5700.00ft MD, 4688.46ft TVD 9-5/8" Casing 5800.00 39.500 12.454 4732.62 4765.62 2962.10 N 654.19 E 6057948.15 N 520313.94 E 0.000 3033.48 21 January, 2004·8:31 Page 3 of 9 DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Is/and - Nikaltchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Western North Slope, Kerr McGee Measured 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) 5900.00 39.500 12.454 4809.78 4842.78 3024.22 N 667.91 E 6058010.30 N 520327.49 E 0.000 3097.09 6000.00 39.500 12.454 4886.95 4919.95 3086.33 N 681.62 E 6058072.45 N 520341.05 E 0.000 3160.70 6100.00 39.500 12.454 4964.11 4997.11 3148.44 N 695.34 E 6058134.59 N 520354.60 E 0.000 3224.31 6200.00 39.500 12.454 5041 .27 5074.27 3210.55 N 709.06 E 6058196.74 N 520368.15 E 0.000 3287.92 6300.00 39.500 12.454 5118.43 5151.43 3272.66 N 722.78 E 6058258.89 N 520381.70 E 0.000 3351.52 e 6400.00 39.500 12.454 5195.60 5228.60 3334.77 N 736.49 E 6058321.04 N 520395.25 E 0.000 3415.13 6500.00 39.500 12.454 5272. 76 5305.76 3396.88 N 750.21 E 6058383.18 N 520408.81 E 0.000 3478.74 6600.00 39.500 12.454 5349.92 5382.92 3458.99 N 763.93 E 6058445.33 N 520422.36 E 0.000 3542.35 6700.00 39.500 12.454 5427.08 5460.08 3521.10 N 777.64 E 6058507.48 N 520435.91 E 0.000 3605.95 6800.00 39.500 12.454 5504.24 5537.24 3583.22 N 791.36 E 6058569.62 N 520449.46 E 0.000 3669.56 6900.00 39.500 12.454 5581.41 5614.41 3645.33 N 805.08 E 6058631 .77 N 520463.02 E 0.000 3733.17 7000.00 39.500 12.454 5658.57 5691.57 3707.44 N 818.80 E 6058693.92 N 520476.57 E 0.000 3796.78 7100.00 39.500 12.454 5735.73 5768.73 3769.55 N 832.51 E 6058756.07 N 520490.12 E 0.000 3860.39 7200.00 39.500 12.454 5812.89 5845.89 3831.66 N 846.23 E 6058818.21 N 520503.67 E 0.000 3923.99 7300.00 39.500 12.454 5890.06 5923.06 3893.77 N 859.95 E 6058880.36 N 520517.23 E 0.000 3987.60 7400.00 39.500 12.454 5967.22 6000.22 3955.88 N 873.67 E 6058942.51 N 520530.78 E 0.000 4051.21 7500.00 39.500 12.454 6044.38 6077.38 4017.99 N 887.38 E 6059004.66 N 520544.33 E 0.000 4114.82 7600.00 39.500 12.454 6121.54 6154.54 4080.10 N 901.10 E 6059066.80 N 520557.88 E 0.000 4178.43 7700.00 39.500 12.454 6198.71 6231.71 4142.22 N 914.82 E 6059128.95 N 520571.44 E 0.000 4242.03 7800.00 39.500 12.454 6275.87 6308.87 4204.33 N 928.54 E 6059191.10 N 520584.99 E 0.000 4305.64 7900.00 39.500 12.454 6353.03 6386.03 4266.44 N 942.25 E 6059253.24 N 520598.54 E 0.000 4369.25 8000.00 39.500 12.454 6430.19 6463.19 4328.55 N 955.97 E 6059315.39 N 520612.09 E 0.000 4432.86 8012.71 39.500 12.454 6440.00 6473.00 4336.44 N 957.71 E 6059323.29 N 520613.82 E 0.000 4440.94 Top of Middle Brookian Fan e 8068.60 39.500 12.454 6483.12 6516.12 4371.15 N 965.38 E 6059358.02 N 520621.39 E 0.000 4476.49 Begin Dir @ 4.00/100ft: 80 MD,6516.13ftTVD 8100.00 38.244 12.454 6507.57 6540.57 4390.40 N 969.63 E 6059377.28 N 520625.59 E 4.000 4496.20 8200.00 34.244 12.454 6588.21 6621.21 4448.12 N 982.38 E 6059435.03 N 520638.18 E 4.000 4555.31 8300.00 30.244 12.453 6672.77 6705.77 4500.20 N 993.88 E 6059487.15 N 520649.55 E 4.000 4608.65 8400.00 26.244 12.453 6760.85 6793.85 4546.40 N 1004.08 E 6059533.37 N 520659.63 E 4.000 4655.96 8500.00 22.244 12.453 6852.01 6885.01 4586.49 N 1012.94 E 6059573.49 N 520668.37 E 4.000 4697.02 8556.10 20.000 12.452 6904.33 6937.33 4606.23 N 1017.29 E 6059593.23 N 520672.68 E 4.000 4717.23 End Dir, Start Sail @ 20.0° : 8556.1 Oft MD, 6937.34ft TVD 8600.00 20.000 12.452 6945.59 6978.59 4620.89 N 1020.53 E 6059607.91 N 520675.88 E 0.000 4732.24 8700.00 20.000 12.452 7039.56 7072.56 4654.29 N 1027.91 E 6059641.32 N 520683.17 E 0.000 4766.45 21 January, 2004· B:31 Pall' 4 of 9 DrIllQu..t 3.03.05,005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nlkaitchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Western North Slope, Kerr McGee Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8700.47 20.000 12.452 7040.00 7073.00 4654.45 N 1027.94 E 6059641 .48 N 520683.20 E 0.000 4766.61 Tof of HRZ 8753.68 20.000 12.452 7090.00 7123.00 4672.22 N 1031.87E 6059659.26 N 520687.08 E 0.000 4784.81 Tof of Kalubik 8800.00 20.000 12.452 7133.53 7166.53 4687.69 N 1035.28 E 6059674.74 N 520690.45 E 0.000 4800.65 8892.02 20.000 12.452 7220.00 7253.00 4718.42 N 1042.07 E 6059705.49 N 520697.16 E 0.000 4832.12 Top of Kuparuk 8900.00 20.000 12.452 7227.50 7260.50 4721.08 N 1042.66 E 6059708.16 N 520697.74 E 0.000 4834.85 9000.00 20.000 12.452 7321.47 7354.47 4754.48 N 1050.03 E 6059741.57 N 520705.02 E 0.000 4869.05 e 9030.37 20.000 12.452 7350.00 7383.00 4764.62 N 1052.27 E 6059751.72 N 520707.24 E 0.000 4879.44 LCU 9100.00 20.000 12.452 7415.43 7448.43 4787.88 N 1057.41 E 6059774.99 N 520712.31 E 0.000 4903.25 9200.00 20.000 12.452 7509.40 7542.40 4821.28 N 1064.78 E 6059808.41 N 520719.60 E 0.000 4937.46 9300.00 20.000 12.452 7603.37 7636.37 4854.67 N 1072.16 E 6059841.82 N 520726.88 E 0.000 4971.66 9400.00 20.000 12.452 7697.34 7730.34 4888.07 N 1079.53 E 6059875.24 N 520734.17 E 0.000 5005.86 9456.04 20.000 12.452 7750.00 7783.00 4906.79 N 1083.67 E 6059893.97 N 520738.25 E 0.000 5025.03 Top of Nuiqsit 9500.00 20.000 12.452 7791.31 7824.31 4921.47 N 1086.91 E 6059908.66 N 520741.45 E 0.000 5040.06 9519.89 20.000 12.452 7810.00 7843.00 4928.11 N 1088.37 E 6059915.30 N 520742.90 E 0.000 5046.86 Sase of Nuiqsit 9600.00 20.000 12.452 7885.28 7918.28 4954.87 N 1094.28 E 6059942.08 N 520748.74 E 0.000 5074.26 9700.00 20.000 12.452 7979.25 8012.25 4988.26 N 1101.66 E 6059975.49 N 520756.03 E 0.000 5108.47 9800.00 20.000 12.452 8073.22 8106.22 5021.66 N 1109.03E 6060008.91 N 520763.31 E 0.000 5142.67 9900.00 20.000 12.452 8167.19 8200.19 5055.06 N 1116.41 E 6060042.33 N 520770.60 E 0.000 5176.87 10000.00 20.000 12.452 8261.16 8294.16 5088.46 N 1123.78 E 6060075.74 N . 520777.89 E 0.000 5211.07 10100.00 20.000 12.452 8355.13 8388.13 5121.85N 1131.16 E 6060109.16 N 520785.17 E 0.000 5245.27 10200.00 20.000 12.452 8449.10 8482.10 5155.25 N 1138.53 E 6060142.58 N 520792.46 E 0.000 5279.48 10300.00 20.000 12.452 8543.07 8576.07 5188.65 N 1145.91 E 6060175.99 N 520799.74 E 0.000 5313.68 10400.00 20.000 12.452 8637.04 8670.04 5222.05 N 1153.28 E 6060209.41 N 520807.03 E 0.000 5347.88 10500.00 20.000 12.452 8731.00 8764.00 5255.44 N 1160.66 E 6060242.83 N 520814.32 E 0.000 5382.08 10515.96 20.000 12.452 8746.00 8779.00 5260.77 N 1161.83 E 6060248.16 N 520815.48 E 0.000 5387.54 TARGET: 10515.96ft MD, . 8779.00ft TVD (2618' FEL & FSL, Sec. 9-T14N-R9E) Top of Sag River Nikaitchuq #1 Target, 100.00 Radius., Current Target 10541.50 20.000 12.452 8770.00 8803.00 5269.30 N 1163.72 E 6060256.69 N 520817.34 E 0.000 5396.28 Top of Shublik 10600.00 20.000 12.452 8824.97 8857.97 5288.84 N 1168.03 E 6060276.24 N 520821.60 E 0.000 5416.28 10700.00 20.000 12.452 8918.94 8951.94 5322.24 N 1175.41 E 6060309.66 N 520828.89 E 0.000 5450.49 10800.00 20.000 12.452 9012.91 9045.91 5355.64 N 1182.78E 6060343.08 N 520836.18 E 0.000 5484.69 10807.54 20.000 12.452 9020.00 9053.00 5358.16 N 1183.34 E 6060345.60 N 520836.73 E 0.000 5487.27 Top of Ivishak 21 January, 2004·8:31 Page 5 of 9 DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island· Nikaitchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Kerr McGee Dogleg Rate (o/100ft) Vertical Section Comment Western North Slope, Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10900.00 20.000 12.452 9106.88 9139.88 5389.03 N 1190.16 E 6060376.49 N 520843.46 E .-- 10910.77 20.000 12.452 9117.00 9150.00 - 5392.63 N 1190.95E 6060380.09 N 520844.25 E 0.000 0.000 5518.89 5522.57 PBHL: 10910.779ft MD, 9150.00ft TVD (2589' FEL & 62C ,,/ FSL, Sec. 9 - 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 @ 33' MSL. Northings and Eastings are relative to 50T FSL, 1486' FWL. ~ Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. "" e The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 50T FSL, 1486' FWL and calculated along an Azimuth of 12.454° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10910.77ft., The Bottom Hole Displacement is 5522.57ft., in the Direction of 12.454° (True). The Along Hole Displacement is 5522.57ft. The Total Accumulated Dogleg is 59.000° The Planned Tortuosity is 1.035°/100ft. The Directional Difficulty Index is 5.4. Comments Measured Depth (ft) 0.00 400.00 1716.67 5700.00 8068.60 8556.10 10515.96 10910.77 21 J.nu.ry, 2004 . 8:31 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 400.00 1614.82 4688.46 6516.13 6937.34 8779.00 9150.00 0.00 N 0.00 N 425.90 N 2899.99 N 4371.16 N 4606.23 N 5260.77 N 5392.63 N 0.00 E 0.00 E 94.06 E 640.47 E 965.38 E 1017.30E 1161.83 E 1190.95E Comment SHL (1486' FWL & 50T FSL, Sec. 16 - T14N - R9E) Begin Dir@ 3.00/100ft in 12-1/4" Hole: 400.00ft MD, 400.00ft TVD End Dir, Start Sail @ 39.5° : 1716.67ft MD, 1614.82ft TVD 9-5/8" Csg pt ... Drill out 8-1/2" Hole: 5700.00ft MD, 4688.46ft TVD Begin Dir @ 4.0°/1 OOft : 8068.60ft MD, 6516.13ft TVD End Dir, Start Sail @ 20.0° : 8556.1 Oft MD, 6937.34ft TVD TARGET: 1 0515.96ft MD, 8779.00ft TVD (2618' FEL & 488' FSL, Sec. 9-T14N-R9E) PBHL: 10910.779ft MD, 9150,00ft TVD (2589' FEL & 620' FSL, Sec. 9 - T14N - R9E) e P'Q' 6 of 9 DrI1lQu..t 3.03.05.005 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Island - Nikaltchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Western North Slope, Kerr McGee Formation TO/Js Formati on Plane (Below Well Origin) Sub-Sea Dip Up-Dip (ft) Angle Dim. Profile Measured Vertical Depth Depth (ft) (ft) Penetration Sub-Sea Depth (ft) Poi n t Northings (ft) Eastings (ft) Formation Name 1750.00 0.000 0.152 1934.62 1783.00 1750.00 561.28 N 123.96 E Base of Permafrost 3450.00 0.000 0.152 4137.77 3483.00 3450.00 1929.67 N 426.17 E Top of West Sak 4585.00 0.000 0.152 5608.69 4618.00 4585.00 2843.28 N 627.95 E Base of West Sak 6440.00 0.000 0.152 8012.71 6473.00 6440.00 4336.44 N 957.71 E Top of Middle Brookian Fan 7040.00 0.000 0.152 8700.47 7073.00 7040.00 4654.45 N 1027.94 E Tof of HRZ 7090.00 0.000 0.152 8753.68 7123.00 7090.00 4672.22 N 1031.87E Tof of Kalubik 7220.00 0.000 0.152 8892.02 7253.00 7220.00 4718.42 N 1042.07 E Top of Kuparuk 7350.00 0.000 0.152 9030.37 7383.00 7350.00 4764.62 N 1052.27 E LCU 7750.00 0.000 0.152 9456.04 7783.00 7750.00 4906.79 N 1083.67 E Top of Nuiqsit 7810.00 0.000 0.152 9519.89 7843.00 7810.00 4928.11 N 1088.37 E Base of Nuiqsit 8746.00 0.000 0.152 10515.96 8779.00 8746.00 5260.77 N 1161.83 E Top of Sag River 8770.00 0.000 0.152 10541.50 8803.00 8770.00 5269.30 N 1163.72E Top of Shublik 9020.00 0.000 0.152 10807.54 9053.00 9020.00 5358.16 N 1183.34 E Top of Ivishak Casinø details Fro m To Measured Vertical Measured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) (ft) <Surface> <Surface> 5700.00 4688.46 9-518" Casing e e 21 J.nu.ry, 2004 . 8:31 P.ge 7 of 9 DrlllQue.t 3,03.05.005 Western North Slope, Taraets associated with this wel/IJath Target Name Nikaitchuq #1 Target 21 January, 2004·8:31 Kerr McGee Oil & Gas Corp. Proposal Report for Spy Is/and· Nlkaitchuq #1 (wp04) Your Ref: Generated January 20, 2004 (Revised Target Depth) Revised: 21 January, 2004 Mean Sea Level/Global Coordinates: Geographical Coordinates: Target Radius: Page 8 of 9 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 8779.00 5260.77 N 1161.83 E 8746.00 6060248.16 N 520815.48 E 70034' 32.7391" N 149049' 44.8353" W 100.00ft Target Shape Circle Kerr McGee Target Type Current Target e e DrlllQuest 3.03.05.005 Kerr McGee Oil & Gas Corp. North Reference Sheet for Spy Island· Nikaitchuq #1 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 Canada) Spheroid is Clarke - 1866 Equatorial Radius: 6,378,206.400m. Polar Radius: 6,356,583.800m. Grid Coordinates of Well: 6054984.32 N, 519667.62 E Geographical Coordinates of Well: 70· 33' 40.9970" N, 149· 50' 19.1712" W Surface Elevation of Well: 33.00ft Grid Convergence at Surface is 0.152· Magnetic Declination at Surface is 24.926· (21 January, 2004) 21 January, 2004·8:31 True North Grid North Magnetic Model: Date: Declination: Inclinatìon/Dip: Horizontal Component: Northerty Component: Easterty Component: Vertical Component: Total Field Strength: Magnetic North ... Hole Direction Grid North is 0.152· East of True North (Grid Convergence) Magnetic North is 24.926° East of True North (Magnetic Declination) Magnetic North is 24.774° East of Grid North (Magnetic Convergence) To convert a True Direction to a Grid Direction, Subtract 0.152 degrees To convert a Magnetic Direction to a True Direction. Add 24.926 degrees To convert a Magnetic Direction to a Grid Direction. Add 24.774 degrees Page 9 of 9 Kerr McGee e BGGM2003 21-Jan-04 24.926 80.903 9099 nT 8251 nT 3835 nT 56821 nT 57545 nT e DrlllQuest 3.03.05.005 e @ KERB-MCBEE CORPORATlDII e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Kerr-McGee Corporation Nikaitchuq #1 Alaska; USA OptiC em 9 5/8" Cement Surface Casing Revision #3 Prepared for: Skip Coyner January 20, 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-MCGEE COIPORATlOII e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Well Conditions Casing Size & WI. Hole Size MD TVD Top of Lead (MD) 95/8" 47#/ft 12 1/4" 5,700' 4,688' 0' Volume Excess Mud WI. 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 bbllO.5 ppg NSCI Spacer Lead Slurry: 667 Sks. (2,768 Ft3) PERMAFROST L (493 bbl) (115 bbl) (412 bbl) Tail Slurry: 560 Sks. (645 Fe) Premium Cement, 2% Calcium Chloride Displacement: 412 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 12hr(est.) 24 hr (est.) Spacer 8.34 I 10.5 Lead Slurry 10.7 4.15 20.3 Tail Slurry 15.8 1.15 5.00 6:00+ 3:00 (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 plus 225% excess through base of permafrost at 1950 ft MD + 3750 ft open hole below permafrost + 30% excess. Top of Tail slurry 1500 feet above shoe - TOC 4,200' 1500' calculated annulus volume +30% excess + 80 foot shoe joint. HALLIBURTON ISO 14001 Certified Alaska Green Star Certified e ~ K£RR..MCBEE COIIPORATlOM e NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) Kerr-McGee Corporation Nikaitchuq #1 Alaska; USA OptiC em 5 ~" X 3 ~" Cement Production Liner Revision #3 Prepared for: Skip Coyner January 20, 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 e ~ KERR-MCBEE ctJRPtJRATI. Well Conditions Liner Size & Wt. Previous Casing: Drill Pipe: Volume Excess Hole Size MD TVD Top of Tail (MD) Slurry Recommendation: NW Milne Point Exploration Project 2004 Cementing Services (Revision #3) 5-1/2" 15.5#/ft Liner - 5,550 ft to 9,400 ft MD. 3-1/2" 9.2#/ft. Liner - 9,400 ft to 10,920 ft MD 9-5/8" 47#/ft - 0 to 5,700 ft MD 5" 19.5 #/ft 30% 8-l/2" 10,920' 9,150' 9,400' Mud Wt. BHST BHCT 10.3 ppg 190°F 130°F Preflush I Spacer 10 bbl Water, 30 bb112.5 ppg NSCI Spacer Lead Slurry: Tail Slurry: Displacement: 495 Sks. (1,168 Ft3) Premium Cement + 15 LB/SK. Microlite, + 0.2% CFR-3 (Friction Reducer), + 0.75% Halad 344 (Fluid Loss Additive), + 0.05 gisk D-Air-3 (Anti-foam), + HR-5 (Retarder) as required (208 bbls) 567 Sks. (651 Fe) Premium Cement+ 0.6% LAP 1, + 0.3 LB/SK. Super CBL, + 0.5% DCS (Friction Reducer), + 0.6% HR-5 (Retarder) as required (116 bbls) 200 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.) Volumes based on: Lead slurry: Spacer Lead Slurry Tail Slurry 8.34 1 12.5 12.5 15.8 2.34 1.16 13.14 5.06 <75 <50 0 0 >3:00 +1- 3:00 350 @ 90°F >1,000 @190°F 625 @ 90°F >2,000 @ 190°F 1,440 @165°F Top of Lead cement @ 100 ft above Liner with drill pipe in or 5,450 ft. 150 ft liner by previous casing lap with no excess (5550 ft - 5700ft). Open hole below previous casing to top of Tail or from 5,700 ft. to 9,400 ft plus 30% excess Top of Tail slurry 9,400' 1,520 ft. calculated annulus volume +30% excess + 80 foot shoe joint. Tail slurry: HALLIBURTON ISO 14001 Certified Alaska Green Star Certified e e ~KER1I-MC6EE CORPORATION Nikaitchuq #1 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 OIiktok Point on the North Slope of Alaska. The well will be drilled as an "s" shaped hole building to 400 in the 12 Ij.¡"surface hole and drilled to a surface hole TD of ± 5700' TMD where 9 5/8" casing will be run and cemented. An 8 W' hole will then be drilled holding this angle to 8165' MD where a drop to 200 will begin. This angle will be then be held to TD at ± 10911' TMD where 5 W' X 3 W' casing will be run and cemented. Primary targets for this well will include the Kuparuk, Sag 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. 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 (KC!) 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 KC1 concentration is dependent upon MWD and logging 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 mud additives, which may be required to support this drilling program. Nikaitchuq #1 V2 Page 1 1/22/2004 Formation Tops/Casine: Proe:ram Spud Base Permafrost Top West Sak Base West Sak 9 5/8" casing point Middle Brookian Top HRZ Kalubik Kuparuk Top LCU/Kingak Top Nuiqsit Top Sag Top Shublik Top Ivishak TD TMD 0' 1935' 4138' 5609' 5709' 8012' 8718' 8771 ' 8909' 9048' 9473' 10431 ' 10559' 1 0825' 10928' e TVD 0' 1783' 3483' 4618' 4695' 6473' 7073' 7123' 7253' 7383' 7783' 8683' 8803' 9053' 9150' e Comments Mud Wt 9.0 ppg density 9.0 9.0-10.0 9.0-10.0 9.0-10.0 9.0-10.0 9.6-9.8 10.4 10.4 10.4 10.6 10.6 10.6 10.6 10.6 10.6 String in LCM Stop LCM treatment Condition for casing occasional shale instability occasional shale instability String in LCM shale instability occasional shale instability target sands String in LCM Spot STEEL SEAL Surface Hole Mud Properties (12 v,." Hole f/Spud to 9 5/8" Casing Point at 5709' TMD) Mud Density Viscosity YP PV 10 S. Gel API FL Properties (ppg) (sec/qt) (cc's/30 min) Initial 9.0 80-120 35-45 13-21 10-15 <15 Final 9.0-10.0 50-80 15-30 15-23 10-15 6-8 Surface Interval (1214" Hole to 5.700' TMD) The surface interval of this well will be drilled with a 12% KCl/Polymer mud as formulated below: 9.0 ppg Formulation Fresh Water KCl NaCl EZ Mud DP PAC-L/R Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav D .95 bbl 37 ppb o .75 ppb .5 ppb 1-2 ppb .1 ppb .2 ppb o 1.0 ppb .5 ppb (ionic inhibition/50.5K ppm chlorides) (polymer encapsulation) (API filtrate of6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) (X-Cide 207 for rig maintenance) (as needed) ( corrosion inhibitor) (to be added at rig) Spud the well with maximum flow rates (600-750 gpm assuming 12 V,¡" 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. Nikaitchuq #1 V2 Page 2 1/22/2004 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 Yz% by volume BDF-263. 4. Maintain the mud as cool as possible (under 60°F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of fluid for the spud. Make every effort to maintain the system as clean as possible through the nonnal 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 KCl water to maintain volume while drilling ahead. The density of the KCl solution should be based upon mud weight requirements at any given point of the well. 2. Use PAC's for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6 cc range prior to running casing at the surface 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 ofX-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 pennafrost that could require additions of BDF-263 and/or ConDet to reduce BRA 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 Yz" Hole f/Base Surface Casing to Well TD at 10,911' TMD) Mud Density YP PV 10 S. Gel API FL PH Properties (ppg) (cc's/30 min) Initial 9.6 10-15 6-12 2-5 6-10 9-9.5 Final 10.4-10.6 15-25 15-25 2-6 <6 «10 THP) 9-9.5 Production Interval (8 Yz" Hole to 11.187' 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 tenns of re-adjusting the properties of the mud to insure a quality fluid for the initial drilling operations of the 8 Yz" hole). Nikaitchuq #1 V2 Page 3 1/22/2004 e e As in the surface hole, KCl 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, acheive 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 ,/ 9040'. While drilling to the core point, maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 with PAC's and Dextrid. The HTHP filtrate should be lowered 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. After circulating and short tripping at TD, 15-20 ppb of Steel Seal 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 running the casing. This will reduce the chances of inducing lost circulation while running the 5 "'12"/3 Yz" Liner. Risks and Contin!!encies: Lost Circulation: Preventing the initiation oflost 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 underpressured. 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. Well bore 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. Nikaitchuq #1 V2 Page 4 1/22/2004 · e Stuck pipe: Two fonns 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 fonns, 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. Ifpossible, reducing the fluid density by a minimum of 0.5 ppg may provide some relief. Corrosion Mitigation Barascav D and Baracor 700 will be run in 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 Fann 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 bit/BRA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. High speed pipe rotation is the most critical factor for hole cleaning. Nikaitchuq #1 V2 Page 5 1/22/2004 ~~ Field & Pool Well Name: NIKAITCHUQ 1 Program EXP PTD#: 2040180 Company KERR-MCGEE OIL & GAS CORP Initial ClasslType EXP I PEND GeoArea 890 Unit OnlOff Shore Off Administration 1 P~rmitfee attacheJ::L _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ ~oLreq_uired_a_s_thi¡¡ i~Huevjsed appJicatioru~uÞmitted prjor todrilliog oPj;¡rations, 2 _Leasj;¡_n!Jmberappropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ Surface location in ADJ..388582;_top prod iote(VaLand TD inAQL_38858_0, _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 _U_niq!Je weltl1arn~_aod oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 4 WeJUocat~d ina definep-ppol_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ Exploratory welt located withintbe bOJJodaries of the Milne Poiot, Kuparuk River Oil F'ool. _ _ _ _ _ _ _ _ _ _ _ 5 WeJUocated pr_operdistance from driJling !Jnitb_o!Jnd_ary_ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ ~earest prppe_rty þoundary is with ADL 355021 (BP),Iocated -2,6IO' toSE _ 6 WellJocat~d pr_oper _distance_ from otber welJs_ _ _ _ _ _ _ _ Y~s _ _ _ ~earest open welJ bore is MP_U ¡::-42, about 1I,500'Jo SE._ _ _ _ _ _ _ _ _ _ _ _ _ 7 _Sufficient _acreage_ayailable in_drilJiog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yj;¡S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 8 Jtdeviated, js weJlbore platiocJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 9 _O-perator only affected party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 10 _O-perator has_appropriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡S _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 Permit ~ao be issued wjtbout conservation order _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 12 pj;¡rmit ~ao be issued wjthout ad_mioi¡¡tratÌ\le_approvaJ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 1/26/2004 13 Can permit be approved before 15-day wait Yes 14 WelUocatj;¡d within area and_strata _authorized byJojectipo Order # (p!JUotI in_commj;¡ots)(For_ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 _AJlwelJs_witJ1inJI4J1Jile_area_ofreyiewjdeotified(For¡¡eNjc_ew_ellonl~i>_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 16 Pre-produJ:;ed injector; _duratio_n_of pre--propuctipn Ij;¡Ss thal13 months (Forse(Vice well onJy) _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _AÇMP}::¡ndjngofConsisteocy_hasbeeniss!Jed_forJhispr_oiect _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _Kaye_Laug]1ljn.JF'O,J{2JI0~:_ACMF'reyiewnolJequired, __ Engineering Appr Date WGA 1/27/2004 Geology Appr SFD Date 1/20/2004 Geologic Commissioner: Well bore seg Annular Disposal D D - - - - - - - - - - - - - - - - - - - - ~ ~ 18 _C_ondu_cton¡tringprovided _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ 19 $_ud'aœ_casing_prote~ts alLknowl1 USQW¡¡ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yj;¡s _ _ _ _ _ _ _ ~o USDW. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 _CMTv_oladeQuateJocirc_ulate_oJl_cond_uctor_&surtcsg _ _ Yj;¡s _ _8deJ:uateexcess. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 21 _CMT v_ol adeQu_ateJo tie-in Jong string tos!Jd' csg_ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 _CMTwill coyer_aU known_pro_d!Jctiye horilOI1S_ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 23 _C_asing design¡¡ ad_equate for C,_T. B_&_permafrost _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡S _ _ _ _ _ _ _ _ _ _ _ _ _ 24 _Mequatetankage_or re_se(Ve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ _ _ _ _ _ _ ~abors27E:._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 25 JtaJe-prilt has_a_ tOAO;3 for abandonme_nt beeo approved _ NA _ _ ~ew welt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Apequatewellbore Sep¡¡uatjOJl_pro-po¡¡ed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdjverter required, does jLmeet reguJatioos_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 _Drilliogf]ujd_programschema!ic&equipJistadequate_ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _MaxMWJ_1,O_ppg._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 29 _BOPEs, do they meetreguJation _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~s _ 30 _BOPE_press ratiog ap-propriate;_test to_(pu_t psig in_commeots) Yj;¡s _ _ 31Chokemanjfold compJies w/APtRF'-53 (May 84) Yes _ 32 Work wiU occ_ur withoutoperation _shutdown_ _ _ _ _ _ _ _ _ Yes _ 33 Jspresence_ofH2Sgas_probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ 34 Mecba_nicaLcondiUon of wells withio 80R yerified (for_serviœ we] only) _NA _ _ - - - - - -- ~ - - - - - - - - - - - - - - - e _ Test to _50QO_ psi. _MSF' 3479 - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - -- - - - - - - -- 35 Permit c_an be tssued w{o_ hyd(ogen_ sulfide meas_ures _ No We] is no 9 rnilesJro(l1_ n_earestoffset çontrotatlvishak, _H2S -pre_cautionsJequJred. _ _ _ _ _ _ _ _ _ _ _ 36D_atapreseoted on_ pote_ntial overpress!Jre _zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yj;¡s _ 8bno(maJformation pressure is oot e~p~cted. _ _ _ _ _ _ _ _ _ _ . _ 37 _Setsmic_analysjs_ of sbaJlow gaszooes _ _ Yj;¡s . _ PQssible _occurrenœ _of hyprate_s _or minor_ shallow_gas beneath perm_afrost. _ No indica_tions_ 0_n_3D _seismic. 38 _Seabepcoodjtioo survey (if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ Surface loca_tion is 90 Spy Island_. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 39 . Conta_ct nam_elpJ1oneJorwee~ly progress_reports [exploratory _onlyt _ _ _ _ _ _ _ _ _ Yj;¡s _ _ _ _ Skip Coyner, 907-3_39-6269. . - - - - - - - - - - - -- Date: Engineering Commissioner: Public Commissioner Date Exploratory well, located within the boundaries of the Milne Point, Kuparuk River Oil Pool. Multiple target formations will be drilled: Kuparuk, Nuiqusit, Sag River and Ivishak. Designation of Operator form (10-411) filed on 1/26/2004. SFD Date e e ~ KEllR-MCSEE CORPORA 11011 January 15,2004 Commissioner Alaska Oil and Gas Conservation Commission 333 W ih Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Nikaitchuq # 1 Kerr McGee Oil & Gas Corporation Application for Permit to Drill (10-401) Attached for your review is our Application for Permit to Drill the Nikaitchuq # 1 exploration well located approximately four (4) miles north ofOliktok Point. This is the first of two (2) exploration wells planned for this season. The APD for the second well will be submitted in the near future. This original APD is submitted along with two (2) copies and the $100.00 filing fee. The APD packages include form 10-401, an abnormal pressure survey, a shallow hazard survey, a comprehensive drilling hazard analysis, drilling program, directional drilling plan, drilling mud program and cementing program. The package includes a rudimentary location plat which will be followed by an "as built" plat when available. Our anticipated spud date is on (or soon after) February 1st, 2004. If you have any questions or concerns about the APD or the drilling plan, please call me at 339-6269 and I will do my best to address your questions or concerns. Your timely review of our APD and the accompanying data is greatly appreciated. Sincerely, dfe,er ASRC Energy Services Project (Drilling) Mngr. RECEIVED JAN 1 5 2004 Alaska Oil & Gas Cons. Commission Anchorage 3900 C Street Suite 702, Rrn 744 Anchorage, AK 99503 (907)-339-6370 ORIGINAL 1b. Type of well. Exploratory [;] Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (OF or KB) 33 feet 6. Property Designation ADL 388580 I ,~z... pI:, 7. Unit or property Name Nikaitchuq 8. Well number 1 9. Approximate spud date Amount February 1, 20oð"~ $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 '" 11090 ' MD I 9150 ' TVD ~ 17. Anticipated pressure ee 20 MC 25.035 (e)(2)) Maximum surface 347 psig" At Sag River Depth (8685' TVD) = 4340 psi Setting epth . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work: Drill [;] Redrill 0 Re-entry DDeepen 0 2. Name of Operator Kerr McGee Oil & Gas Corporation 3. Address 3900 "C" Street, Room 744, Anchorage, AK 99503 4. Location of well at surface 1490' FWL & 1320' FSL, See 16 T14N R9E UM I At top of productive interval 363' FWL & 1724' FSL, See 9 T14N R9E UM At total depth ,."'. .6Þ 330' FWL & j,8S(Ý FSL, See 9 T14N R9E UM 12. Distance to nearest property line I 13. Distance to nearest well 330 feet BPXA, NW Milne #1, > 23,000 16. To be completed for deviated wells Kickoff depth: 400', MD 18. Casing program size 8685' TVD feet Maximum hole angle 37.8° Top Hole Casing Weight 13-3/8" 68# 12-1/4" 9-518" 40# 8-112" 5-1/2" 17# 3-1/2" 9.2# Specifications Grade Coupling K-55 PE L-80 BTC L-80 BTC L-80 IBT-Mod Length 168 5614 3900 1690 MD 200 5644 9400 11090 ! 19. To be completed for Redrill, Re-entry, and Deepen Operations. \ ~ Present well condition summary ,_\ Total Dopth, _"'"' ~ Effective Depth: ::::::al \ ~ ::et 0 true vertical ð feet Casing Length SiZ: ~e teM- ¡CI f)¡ Q) \' hJ' Perforation depth: ./ mea Plugs (measured) P Junk (measured) I . Bottom TVD 200 " 4720 .I 7690 9150 Measured depth Development Oil 0 Multiple Zone 0 10. Field and Pool Quantity of Cement (include stage data) Drive Pipe 660 sx Permafrost L & 560 sx G 517 sx of Premium + Microlite & 625 sx Premium-Latex cement True Vertical depth RECEIVED JAN 1 5 2004 Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments Filing fee [;] Property Plat [;] BOP Sketch [;] Diverter Sketch [;] Drilling program [;] Drilling fluid program [;] Time vs depth plot ~efraction analysis [;] Seabed report [;] 20 MC 25.050 requirements [;] 21. I hereby certify that t ~o going is true and correct to the best ~f my knowledge For questions call Skip Coyner 907-339-6269 Signed tll\lI.: ~-- Title: Kerr-McGee Oil & Gas Corp Date 1/14/2004 Cha' es Summers Commission Use Only Permit Number./",..., / 0 1'0 I API number ... ~ a-!:J I Approval date ~"... P 50- b.z.P/,. ~I J :J -00 Conditions f approval Samples required ~ Yes 0 No Mud log required Hydrog sulfide measures 0 Yes ~ No Directional survey required Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: Approved by by order of the commission Commissioner ORIGI~jAL Form 10-401 Rev. 12/1/85· ~Yes see cover letter for other requirements ~ Yes U No o No Date Submit in triplicate Loc'n in 70° 33' 48.9950" 1490' FWL & N& W j 8 Kerf 17 VI 1 1 w e .¿¿ e ~v 22 23 20 20 10 4 5 15 ,}.:::::::~:;.;:c:::::=== 14 16 18 15 16 14 7.<:>··~\ 2 21 16 17 10 17 13 9 S 14 Sv:.° 3 SURVEY TARGET 8: 1 4 3 18 10 (Ruins) 9 13 5 S 16 10 10 19 5 4 3 6 11 S 8 6 a 6 17 14 3 10 7 , 6 8 8 3 S 6 7 7 6 5 \8 S 15 9 2. : 5 8 8 2 :.... 8 7. 7 3 Shoal 5 M 7 6 4 11 8 14 3 5 5 4 2 5 8 7 8 15 9 9 7 7 5 4/12 ' 2 6 4 8 5 4 7 B 7 10 8 5 9 8 6 6 9 5 4 8 9 9 7 8 5 10 7 6 7 7 6 7 9 4 7 6 10 9 7 6 7 7 8 10 9 M 8 7 8 4 10 10 8 7 7 8 4 a M 8 8 7 9 a 8 10 8 8 M 8 8 8 10 'CI 8 9. a .. 8 8 7 ~ M CII 8 11 u a 10 7 ~ 9 9 8 7 6 8 S B M 8 7 7 10 7 7 6 7 a 7 7 7 7 7 M 10 M 7 7 7 6 8 6 7 M 7 6 6 6 7 7 7 7 7 6 8 6 6 MS 7 5 M 7 6 5 7 6 4 6 5 5 6 6 5 6 6 6 5 3 7 6 6 M 3 5 4 6 3 4 6 3 ... 6 6 5 3 4 4 4 4 ..../M 5 4 3 ~..., í\ 7 6 5 5 5 Shoal ...... B\\ 6 4 3 3 : Q J 6 .' ........ , " 7 4 4 ........ . Me. /' I 3 3 :.' I I 3 : C!1 \ I 7 3 ¡ 0 Pond8......' . Marsh ~' 7 7 -_........,~ } .....----/ 2 7 3 6 Numerous ponds 3 ~ 4 ---- ) 0STACK 7 4 5 4 I'D' 6 ,J,~ " 2 / /" \ c/ I ,/ ,. ,- ,- 0 1490 55' 00·· W 1490 50· 00" W 149045' 00·' W e e f 1(íø1 KERll-MCBEE COBPORATlOII '- NW Milne Point Exploration Program Winter 2003/2004 Drilling Plan & Well Design January 14, 2004 S. Coyner ASRC Energy Services E & P Technology NW Milne Point Drilling Plan & Well Design Page 1 e e ( ..) KERR-MCBEE CORPORA nOlI NW Milne Point Exploration Program Rig Days: 1st Well = 22 2nd Well = 16 Rig Move = 2 Drill, Case, Test and abandon Well #1. Drill, evaluate and plug Well #2. First Spud: February 1 2004 Prepared By: Skip Coyner EXPLORA TION OBJECTIVES: 1. Drill the 1st well to the Sag River and core as/if directed. - 2. Drill to PTD, Run open-hole logs, MRI's, CMR's, RFT's & VSP. 3. Run the completion. MORT. 4. Perforate and test the well - without the rig. 5. Drill and evaluate the 2nd well. P & A the 2nd well. 6. After testing the 1st well, properly P & A the well. HSE OBJECTIVES FOR WELL: 1. No Lost time Accidents. 2. No Spills. 3. No environmental damage NW Milne Point Drilling Plan & Well Design Page 2 e e NW Milne Point Exploration Program Preliminary Drilling Plan The Nikaitchuq wells are exploratory wells to be drilled from an Ice island built in shallow water near Spy Island or on the island itself. The first drill site is located approximately 4 miles north of Oliktok point and will be accessed by building 4 miles of grounded ice road across the narrow lagoon. As such, no tundra travel will be required. The water between Oliktok Point and Spy Island is no more than 8 feet deep in the middle and grounding the road should a manageable construction project weather permitting. The road should be grounded and ±. 3 feet of freeboard built well in advance of the rig move, thus allowing the road and sea bed below to freeze thoroughly into a solid, weight-supporting structure. The preliminary well design takes into account many critical factors. · First and foremost: safety and the environment. · Managing the mechanical risks involved. · Coordinating the well design with available rig. · Planning the wells to avoid problems in the Kingak, caused by deviation and MW. · Planning the wells to avoid mud losses, differential sticking, etc. · Designing the casing, liner and tubing to allow flexibility and to insure success. · Planning the wells to minimize drilling waste. o We have to drill 12-1/4" hole (for 9-5/8" casing) o We will drill and 8-1/2" hole (wI 5" DP) The keys to success for this project are simple: · Closely manage the ECD and hole cleaning. o High-KCULow-Solids mud design o Reduced PV, MBT, SPP and minimum ECD. · Inhibit the clays and shales with KCLlPolymer mud, etc. · Drill through the Kingak Shale at 20° or less hole angle. · Prepare for differential sticking, mud losses and high torque. NW Milne Point Drilling Plan & Well Design Page 3 e e As such, the well design takes into account the four Pre-Jurassic penetrations in the ./ same fault trend. Those four Milne Point wells are: C-23, E13, F33 and F-73A. These wells demonstrate that it is possible to drill all the way from the top of the Colville into the Sag River and Ivishak without setting an intermediate casing string (or drilling liner) above the Sag River. Given the high angles in the existing wells, the Kingak did not slough, heave or cave in as would normally be expected. Even so, the ~ 11 ppg mud weight used to drill the Kingak caused high ECO's, hole "breathing" and substantial mud ~ losses in the permeable sands above and below the Kingak. This drilling plan uses directional drilling designs that minimize the hole angle while drilling the Kingak. Therefore these designs minimize the necessity for increased mud weight as typically used to promote shale stability on the North Slope. Steps will also be taken to minimize the ECO: 9-5/8" surface casing, 8-1/2" production hole, good solids control equipment, good mud rheology, and excellent mud chemistry. This comprehensive well plan is very "do-able" by the available rigs on the slope. This comprehensive well plan gives us an excellent chance for success, and this plan is the most economical of the available options. Our comprehensive well plan starts with 13-3/8" drive pipe as was used at NW Kuparuk last season. The 13-3/8" will be driven to refusal estimated to be at ± 200 ft below surface. The 13-5/8" wellhead will be installed directly onto the drive pipe. A diverter "T" and the 13-5/8" stack will be installed directly on the wellhead and the annular will be used as the diverter. The surface hole can be drilled all the way into the Colville mudstones using only the diverter system. This is normal practice in the West Sak and Schrader Bluff development areas nearby. The surface hole will be 12-1/4", and the surface casing will be 9-5/8", 40#. This bit and casing size combination was selected for these reasons: 1. The 7-5/8" casing used last year would cause the ECD's to be too high, and the 7 -5/8" casing would leave us with no reasonable option for a drilling liner if needed. The, larger surface casing is required for these exploratory wells. 2. The 9-5/8" casing will be used, in the 12-1/4" hole. The 9-5/8" casing accommodates the (5") drill pipe. More cuttings will be generated. NW Milne Point Drilling Plan & Well Design Page 4 e e The 9-5/8" surface casing allows the hole below to be drilled using standard 8-1/2" bits. - This hole size is preferred over last year's 6-3/4" hole size for the following reasons: 1. Drilling ECD's will be substantially reduced with the larger annulus area. 2. Packing off will be reduced assuming that hole cleaning properties are good. 3. The 8-1/2" hole allows a 7" "emerqencv" liner to be run, if needed, and 4. If a 7" liner is required, the resulting 6-1/8" drift diameter allows drilling into the Sag River and into the Ivishak below using a tapered 5" x 3-1/2" drill string along with standard 4-3/4" LWD tools, etc. There is a high probability that these wells can be successfully drilled from surface casing to the Ivishak without much difficulty. Success depends upon the execution of this comprehensive drilling plan. By following the plan, we should be able to drill to ,/ PTO with 10.4 - 10.6 ppg mud and minimal ECO's. As such, lost returns, seepage and "breathing" will be minimized. Losses may still occur in the permeable sands of the Sag River and the Ivishak formations (if penetrated). Expected losses in the Sag River can be dealt with and the well can be logged and completed as required with proper planning and action. Once the well is drilled to PTO, it will be logged and evaluated by Schlumberger E-Line. ./ The completion will be the same "multi-purpose" completion as used at NW Kuparuk last year. A tapered liner will be run and cemented with the 3-1/2" "lower liner" covering any potential "test" zones and the 5-1/2" "upper liner" tying back into the surface casing. As was the case last year, 3-1/2" tubing will be run and stung into the CSR located at the cross-over in liner. The resulting mono-bore completion is fully E-Line accessible, re-complete-able and pluggable without bringing the rig back. Potential Hazards . As in any arctic exploration project carried out in the winter months, the weather is a potential hazard. Phase III conditions can shut the rig down and stop all traffic to and from the rig, including: Medivac, fuel, water, food and materials. For this reason, the camp must be well stocked with basic supplies. Both the camp and the rig must be stocked with at least a 7 -day fuel supply at all times. NW Milne Point Drilling Plan & Well Design Page 5 Work on rig must during ~ conditions for safety reasons. up communication systems are required. . The Kingak shale is notorious on the North Slope for caving, sloughing, swelling and heaving when high The "Polar Plot" below was developed by and is the best guideline for controlling Kingak shale with a combination angle, mud weight. "Polar Plot" was developed for Prudhoe WOA, but it will be used as a guide for this project. . Differential sticking is a particularly in Well #2. Well is in close proximity to Unit wells in the Milne Point Unit. Schrader Bluff and the Kuparuk have the potential under pressured and cause differential sticking. Also, the Sag River producers on MPU are both currently to the any support from injection. such, the River could potentially a differential sticking hazard. In case of uncontrollable lost circulation, shale problems or any unforeseen well control problems, an liner will run and hung off the casing. If the 7" liner is the remaining hole will be drilled using a 6-1/8" bit after finishing hole, a 3-1/2" liner will and cemented through the pay NW Milne Point Drilling Plan & Well Design 6 below 7" liner. 3-1/2" tubing will then used as a tie-back string: thus creating the same mono-bore completion as in the primary plan. 1000 2000 3000 4000· 5000 6000 7000 8000 10.0 at L Tits (Frac Gradient) o I I , - -I _ L l- I I I I -, I I I I -t - ¡,.., -I - - - l- I I I I I I I I I ]] I I I I I T-r I I ~ ~ L ~~_! ~~ L_~__L ~J ~_+ i _:_+ j I I I ¡ I the offset wells in this block 1_ + I were all drilled through the Kingak I ~ & Sag River with,::, 11.1 ppg mud. I I .J ~ ~ _1.._ ..J_ I J I I I I I _I_._I_L I I I I I .J_L_ I I I I 1- :]' I I .L _1_ -.1 1- _ _..J I I I I I I --I i-¡ l _ I I I I I - -I - T - 1- -I I I I I I I 1- _I _. I __I_~I_l._L I I I I I , - 1- -I - T I I I I I 1. L I I , I I T - ¡--I I , I I I , I I I 1- J. I I T- I .'.- I I I -J- l' - r- I I NW Milne Point. #1 I I I I- I I I I I - -I-- I I -1--1 1---1' r- I I I I I ¡ 1__1 ..L_L_ .1 L I I I I I I I I I I I I j ¡ 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 ) I I ¡ I I I I I I I I I I ] I I I I I I J I ] I I I I I J '--r~ T-r T-r-I ~ ~ _ OJiktok State #1 :_ _ ~ ~ _: ~ I I I I ] I T I -j I I T- I ~- I I .+ - ¡- I _L_I_J_l- I , I - -, I I --1-+ I I I I I I I -¡-T I , I I I ~I_ J. I I I I ï' - ¡ I I I - -J- T - r -1-- I ) I I Þ -1- -r - l- I I I I I I I I ] I I I I I I , , 'T - r -I- I I I ~_L NW Milne Point. #1 - Jones Island #1 ] J I I 1-1 ï ï I I I I I ] I I I 1 ~ J I I I I I I I I I ì ,-I---r --r r 1 1 I 1 1 I I - _1- .l _ L _1_ _ _ L _1_ .J _ L I I I 1 1 1 I I I I 1 I I 1 I I I 1 I 1 1 I I 1 I -1- + I- l- I I I I MPE-13 I T - r -I T I I 1 1 I 1_ _J._L_J_J._ 1 1 I I I I I I I I 1 J ¡ I 1 I I I ¡ ¡ 1 I--¡-+~I---+~¡""'-I +_ J I I I 1 j I I I I I I I --~~ T -~~- I 1 I ¡ ) I I I 1--1-T-I---i"-I---¡ --r- I I I I I I I I 1 I I I I T-r-I-T- ) I I I 1 -J---+-_k_I_..J.- I I 1 I I I ,- I I I ,-r , 4- I I I , ,- I -'- I -1- T I- I I I I I I , I I I 1 I I --I-ì-r-¡-- I I I-- _I_ I I --r I I I I r I _ L I I - -I I I I , I ,-r I , --I I I I I I , r- I I --> - I- I I T I , I 11.0 12.0 130 14.0 15.0 16.0 17.0 18.0 EMW (ppg) NW Milne Point Drilling Plan & Well Design - 7 e e ~ KERR-MCBEE CDIII'ORATlOII Nikaitchuq #1 Drilling and Completion Plan I Type of Well: "S-Curve" 1 Drill, Case, Test and Abandon Surface Location: Bottom Hole Location: 1490' FWL & 1320' FSL of Section 16, T14N, R9E UM ,/ 330' FWL & 1890' FSL of Section 9, T14N, R9E UM ./ I AFE Number: 1 1 Estimated Spud Date: 12/1/2004 I Rig: I Nabors 27E ,/ I Operating Rig days: 116 + 6 1 I PTD: 111,090' I I TVD: 19,150' 1 / I Pad Elev: 15.0' 1 I RKB: 135.0' I I Geologic Objectives: Sag River Sandstone, Ivishak, Nuiqsit and Kuparuk I ,; Mud Proaram: 12-1/4" Surface Hole (0-5644'): Densitv (ppg) 9.0-9.5 9.5 -10.0 FV (secOnds) 80 - 120 50 - 80 Spud - 2500' 2500' - 5644' 8-1/2" Production Hole (5644'-11090'): Density PV (ppg) (cp) 9.6-10.0 10-15 10.0 _&0. 15 - 20 10.4-. 15-25 J 5644' - 8500' 8500' - 9500' 9500' - 11 090' KCL-Polymer Mud Yield Point API FL PH (lb/10Ofe) (mls/30min) 35 - 45 10- 15 8.5 - 9.5 20 - 30 6 - 8 8.5 - 9.5 KCL-Polymer-CaC03 Mud Yield Point API FL (lb/10Ofe) (mls/30min) 6-12 6-10 15 - 20 4 - 6 15 - 25 < 6 PH 8.5-9.5 8.5-9.5 8.5-9.5 e e Bit Proaram: Interval Size Type Footage Hours ROP RPM WOB Surf - 5,644' 12-1/4" 1-1-7 5600' 45 125 200/300 5-30 5,644' - 11,090' 8-1/2" PDC 5446' 78 70 200/300 5-25 Surveys & MWD: While Drilling: At Suñace Casing Point: AtTD: 12-1/4" & 8-1/2" Holes: MWD surveys every 90 to 300 ft Drop a Magnetic Multi-Shot Survey Before POOH Drop a Magnetic Multi-Shot Survey Before POOH Corina Proaram: I (none planned) Formation Markers: Formation Tops MD TVD B/Permafrost 1932' 1785' TlWest Sak 4081' 3485' Possible Heavy Oil Zone T/Colville 5517' 4620' 9-5/8" Suñace Csg 5644' 4720' 1,(.. Brookian 7863' 6475' Hydrocarbon Bearing, 8.5 ppg EMW T/HRZ 8623' 7075' T/Kalubik 8686' 7125' T/Kuparuk 8850' 7255' Hydrocarbon Bearing, 9.8 ppg EMW .v Miluveach 8887' 7285' LCU/Kingak 9014' 7385' T/Nuiqsit 9520' 7785' Hydrocarbon Bearing, 9.6 ppg EMW 10."¡ T/Sag River 10597' 8685' Hydrocarbon Bearing, 9.8 - 6.2 ppg EMW ./ T/Shublik 10725' 8805' T/lvishak 1 0991 ' 9055' Possible Hydrocarbons 9.4 ppg EMW ./ PTD 11090' 9150' e e Recommended LO~U:JinQ ProQram: Surface Hole: Production Hole: MWD I LWD: Open Hole: E-Line: MWD I LWD: Open Hole: E-Line: Cased Hole: MWD I GR I RES (West Sak) Gas Detection Quad-Combo + Sonic + MDT's + SWC's MWD/GR/RES/NEU/DEN/PWD Gas Detection, cuttings samples v" Quad-Combo + Sonic + MDT's + SWC's FMII CMR + Velocity Check Shots GRISCMT/CCL v ./ CasinQ/TubinQ PrOQram: Hole Size Csg I Lnr WtlFt Gr~e Cplg Length Top Bottom Tbg OD's ./ MD/TVD MDITVD n/a 13-3/8 " 61.0# J-55 PIE 200' GL 200' 12-114" 9-5/8" 40.0# L-80 BTC 5612' 32' 5644' 8-1/2" 5-1/2" 15.5# L-80 BTC 3900' 5500' 9400' 3-1/2" 9.2# L-80 IBT-M 1690' 9400' 11 090' Tubing 3-1/2" 9.2# L-80 IBT-M 5470' 30' 5500' Cement Calculations: Hole Size: Casing Size: Basis for Calculations: I Volumes: Hole Size: Liner Size: Basis for Calculations: I Volumes: 12-1/4" 9-5/8" Lead: Based on 225% excess through the Permafrost to 1950' MD and 30% excess Below the Permafrost. Lead slurry to fill from 4144' MD to Surface. Tail: Based on 1500' of annular volume + 30% excess + 80' shoe track volume. Tail TOC: at +/- 1500' Lead 675 sx of Permafrost L: 10.7 ppg, 4.15 cf/sx Tail 560 sx of Premium cement + additives 8..1/2" 5-1/2" x 3-1/2" Lead: 3756' (9400'-5644') of 8-1/2" x 5-112" annulus, 150' of over lap, 100' above TOL & 120'. Open Hole excess is 30% - or caliper log volume + 15%. Tail: Based on 1790' of 8-1/2" x 3-1/2" annular volume + 30% excess + 80' shoe track volume - or caliper log volume + 15%. Tail TOC: at +1- 9400' Lead 517 sx of Premium cement + 15# Microlite: 12.5 ppg & 2.34 cf/sx Tail 625 sx Premium cmt + Latex & Super CBL: 15.8 ppg & 1.15 cf/sk e e I nteQ rity T esti nQ: Test Point Surface Casing Shoe Depth 20' of new hole Test Type LOT LOT: EMW 13.3 ppg Minimum 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 12-114" 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 (8735' TVO) and a 0.11 psi/ft gradient to surface is: 4440 psi - (8735 ft x 0.11 psi/ft) = &Si ". Disposal of DrillinQ 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 1R-18 will be hauled to G & I #3: located on OS-04, Prudhoe Bay pursuant to Ballot 9 approval. · 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. v 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. e e DRilLING AND COMPLETION PROCEDURE Pre-Rig Work: 1. The 13-3/8" non-insulated conductor will be driven to .:!:. 200'. 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 onlnear 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 drillslkick 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 +1- 60 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 I and diverter lines. Function test the diverter system. Note: the AOGCC field inspector must witness the function test. e e ~ 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 +/- 5644' 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/ 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 v~e and diverter lines. N/U the 13-5/8" ~d 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/GRlRES/PWD and a bent-housing motor. P/U +/- 58 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, 9.6 ppg 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 aslif 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 and POOH. 14. RU E-Line, riser and packoff. Log the hole as directed: Quad-Combo, FMI, CMR, MDT's .I 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. RIH with a bit and BHA. Ream any tight spots. Circulate bottoms up at least twice. POOH. 16. Run the 5-1/2" x 3-1/2" liner, PBR, liner hanger, packer and setting tools on drill pipe. The PBR is to be run :t 150' above the Kuparuk "C". Set the liner hanger and ZXP :t 140' above / / e e the 9-5/8" shoe. Circulate and set the liner hanger. Condition the mud prior to cementing the liner. Cement the liner as programmed. Bump the plug. Set the packer and dis-engage /". from the liner. Circulate B/U and test the packer to 500 psi ~ the 9-5/8" LOT pressure. 17. Displace the hole with a spacer and seawater. Pump the seawater at maximum rate, rotate and reciprocate the drill pipe to help clean the hole. Shut down the pumps and flow check the well for 30 minutes. LDDP. 18. Run the 3-1/2",9.2# L-80 completion string including: PBR seal nipple, (1) profile nipple, (1) GLM with dummy valve and a TRSSV with control line. Space out the tubing. Displace the tubing and annulus with diesel to freeze protect. Sting into the PBR and land the tubing / hanger. Test the annulus and PBR seals to 3500 psi. Test the tubing to 4000 psi. 19. Install a BPV. NID BOP's. NU the tree. Replace the BPV with a TWC. Test the tree to 4000 psi. Test the control lines to 5000 psi. Re-install the BPV and close the SSV. 20. RID and MORT pending well test(s). Post Rig Operations: 1. MIRU Test Equipment, tanks, scaffolding and wind walls, etc. Pull the BPV. Open the SSV. 2. R/U E-Line with lubricator & bleed tank. RIH and run a GRlCCUSCMT from PBTD through the TOL. Perforate the well as directed with Ener Jets in 2.5" HSC's, 6 spf. RID E-Line. 3. Test the well as directed. 4. After testing the well, bullhead the tubing & liner with 10 ppg mud. R/U E-Line and set an EZSV 50' above the top perforation and dump 25' of cement on same. RID E-Line. 5. Plug the well in accordance with AOGCC Regulations. 6. Cut off the tubing and casing in accordance with AOGCC Regulations. 7. Scrape and remove all dirty ice. Remove the cellar and back-fill the hole. 8. When appropriate, inspect the site with AOGCC field inspector for final clearance. Attachments: · Wellbore Schematics · Drilling Curve: Days -v- Depth · Frac Gradient Plot (from offset data) · Diverter & BOP Schematics · Directional Drilling program · Drilling Mud Program · Cementing Program 9400' 11090' x " ,/ 5500' 5644 ' 9400' 11090' 00 ( - 100' 160' RKB ikaitchuq Proposed Schematic Liner Hanger & Top Packer 9-5/8", 40#, L-80, BTC (Pi = psi) 3-1/2" Sliding Sleeve ~ 100' below the 9-5/8" shoe 5-112" x 3-112" Liner x PBR & 3-112" X-O } Nuiqsit Sand: 9520' (Possible pay / test) Sag River Sand: 10597' Liner Tail 5644' 9400' 11090' 100' 160' 9-5/8", 40#, L-80, BTC Nikaitchuq #1 Proposed Plugs 3-1/2" Sliding Sleeve 100' below 9-5/8" shoe x 3-1/2" Liner 5-1/2" x 4" PBR & x-o Possible Nuiqsit perforations EZSV & Dump Bail 25' Cement Sag River perforations 3-1/2" Liner Tail 5644' 9400' 11090' > 5 below GL Nikaitchuq #1 Proposed P & A 9-5/8", 40#, L-80, BTC Sliding Sleeve 100' below the 9-5/8" 5-112" x Liner x 4" & 3-112" X-O Possible Nuiqsit perforations EZSV & Dump Bail Cement Sag River perforations 3-112" Liner Tail 1000 ' 2000· 3000 . 4000· 5000··· 6000 7000 8000 9000· 10000 . 11000 12000 . 13000 0.0 () -- -~- Nikaitchuq -----:-~ -<---..- "~- -- :- -,----- - - ---------- ---- - -'-- - ~--~ - ---- ---"- '----:--- -- ---- ----- -- IE-Line logging. and Cmt I 9-5/8" Casing at 5644' MD -----,- -- ---~- - - - - - - ---- - - -,- - - "'"- -- - '-- .. ------ -- ---- -- --- - - -- - I logs. SWC's, MDT's, Check Shot_, Run liner and Completion - - - r - - - -, -'~ - ',' -- . ...., 10.0 1 Days 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 -1000 o Nikaitchuq I ,." ... ..." . '" o 1000 2000 3000 4000 5000 6000 7000 Vertical Section sc 3000 4000 5000 6000 7000 8000 10.0 et 's (Frac Gradient) o 1000 2000 11.0 12.0 13.0 14.0 15.0 16.0 17.0 18.0 EMW (ppg) 9/02 . ~----- ~' r III" w~- rill" + '" to I!r r w[ rill" '-þ ~ J 71" e Fl ) ( f \ - I <T: - = I r-_......... ~ r""" ... '-:~-;-_ - = - (\ - - I ~~OW<I: . - -.( - - .I!' L'~ \ ~" BOP MODE · Annular: Normal Operation · Rams: Normal Operation · 13-5/8" Blind Flange over the outlet l . ~abors 27E 1.. 13 sir SIIODf tMJRL ANNWR BOP / f - I BOLD FlMØE ~ SINCI.E 13 sir SIIODf HYÐRL MPL PIPE RMI / r . I BOLD FlMØE ~ SINCI.E "3 s¡r 5IIIIOf HYÐRL MPL lUG .,/ .~ BOLD FINtGE , Dc-.- 5IIIIOf HCR VALVE ~~~þ . .- CHOICE LIE I" :;..~ WoVE ~ SINCI.E '3 s¡r SIIODf HYDRL MPL PIPE RMI / I BOLD F1MGE ç,c:... ..,' 13-5/8" x 5000# Diverter "T" DIVERTER MODE · Annular: Diverter Operation · Rams: Locked Open · 13-5/8" X 16" Adapter, 16" Knife Valve & 16" Diverter Line " ~Z' - - .,;" ~, -.... . , - ....' ..... 16" Diverter Line / q Description 3-1/16" 10,000# Remote Hydraulic Operated Choke 3-1/16" 10,000# Adjustable Choke 4-1/16" 10,000# Manual Gate Valve ) 3-1/16" 10,000# Manual Gate Valve 2-1/16" 10,000# Manual Gate Valve '"""r\ White Handle Valves \Jormally Open Red Handle Valves \Jormally Closed 8-00 Rev. 2 Halliburton Sperry-Sun Western North Slope, NW Milne POInt Nikaitchuq #1 (wp02) e Revised: 6 January, 2004 Proposal Report 6 January, 2004 '" " Surface Coordinates: 6055797.49 H, 519669.03 E (70° 33' 48.9950" H, 149° 50' 19.0658" W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 35.00ft above Mean Sea Level e ~V-1IUI1 n"U JNr .¡ hVh /11I11 A Halliburton Company Proposal Ref: pro2065 ~ I Western North Slope, \'J,.).....,"~I1m'l'....~ . ..--., , ~ NW Milne Point Nlkaltchuq #1 (wp02) I DrillQuesf o Well: HorIzonIOl Coollllnlll8O: Ref. GIobeJ CoonIIn8Ies : Ref. SHl of NIIœItchuq., : Ref. Geographlcel Coordlnetes : current Wen Properties Nlkallchuq" WP02 3000 - RKB ElovetIon : 8056707.40 N, 518888.03 E 0.00 N, 0.00 E 70' 33' 48.9950" N, 149" 50' 10.0658" W 35.001I e_ Me8n seal.... 30.001I ebove G.l. EII@ 5' MSl True NOIth Feet (US Survey) PBHL : 11091.95ft MD, 9150.0Oft TVD (330' FWL & 1890' FSL, Sec. 9 - T14N - R9E) Eastin9s Scale: 1inch = 10001I -1000 I r 1 NIúJIdo",,,, Tøpt I Chde, 1tMhø: 11IA1I/I1 1615... TnJ. ~ )«»JI056U..J1N, 1117.11 W \ N_", '" rBHL ./ PølIII Tøpt , '114" J1I.Ð, 5'14" N, llfl... W - 6000 SHL (1490' FWL & 1320' FSL, Sec. 16 - T14N - R9E) Begin Dlr @ 3.00/100ft : 400.00ft MD, 400.000 TVD End Dlr, Start Sail @ 37.76° : 1658.5311 MD, 1569.400 TVD Begin Dir @ 3.0°/1000 : 10004.100 MD, 8167.62ft TVD North Reference: Unlls: TARGET: Start Sail @ 19.W : 10597.23ft MD, 8685.0Oft TVD (1724' FSL & 363' FWL, Sec. 9-T14N-R9E) - 5000 .]3CIO.OO I ~w."5ak~Y¡;-- 1 t I ~4500-~___ ~ I... tfWO$! Sat. 4620.20 ft TVI) 9 SlBln t: 5644 II MD CD 4720.42 II TVD > 1 I 1 6000 - I Nlkeltchuq.1 (wp02) Propoul De" ==:In: ~g~Sf~9~FWL MtaluNmlflllJnitl: ft North ReftrwIce : True North =. =:-....: ~r;::.P" 1001o?i (US Sutvoy) ___'320' FSL.'...·FWl --00IIn: o.oÐN.O.ooe MnsuNCI Incl. Aalm. V.....cal NorthJng. ~.~ ~ 0.00 ....JIO 16$8.$3 10004.10 10597.23 11091.95 ,. 0.000 0.000 0.00 OJlON 0.000 0.... ....00 o.oOH 37.756 348.784 1569.41 392.24 N 37.756 348.18' 1167.62 540U4N 19.962 348.794 8685.00 5614.32 N 19.962 ''''794 9UO.OO 5850.00 N O.OOE D.OOe 71.1IW IOll.13W 1127.IIW I 160.00 W V....., ....100 - - 0.00 0.00 0.000 399.88 3.000 ~~09.87 0.000 ~195.00 3.000 5963.90 0.000 ®1i .' , '" . \ \ " . -~~" JfØJJIO .' - 4000 e.._ .JIOO.OO Nlkeltchuq IJ1 Target Dale 9-518" Csg Pt ... Drill out 8-112" Hole: 5644.00ft MD, 4720.42ft TV~ 9 5f8n ....... 5644.00 II TVO 4720.42 II MD .p1»JIO '" C) c: - 3000 € o z 9-518" Csg Pt ... Drill out 8-112" Hole: 5644.0Oft MD, 4720.42ft TVD ITopof~~~- LorofHRZ. 7075.40ftWI) I ToforKa-;;;;;;-;;;:;OftlVD ==== ~K~.4õ'iiTVi)======== 7500 _ I.~· _~385 ou ft rVD ITapofN~~_____ II!as·orN~I~---="'#lT""" - 1 Qrde, RII1Ihø: llIAHft 8 '615." TYD, 5flM1 N, IIZ7.11 W ~...... PBHL : 11091.95ft MD, 9150.0Oft TVD :2 0 ~s~-=============== _ (330' FWL & 1890' FSL, Sec. 9 - T14N - R9E) H fop ofShuhllk. ~805.00 ft "IVD -.... '¡:¡9000~________ ~ Topøflvl"hak. 9055 no flTVJ) NlIuIitdIIIf#I,aRL iD I Nlkallchuq Ø1 (wp02) ---- Pøløl Tøpt ! I I , 915.... TnJ, 515.... N, IlfI... W o 1500 3000 4500 6000 Scale: 11nch = 1500ft Vertical Section SectIon AzImuth: 346.784' (True North) Mus\nmInt Units: ft r..... Cootd_ TYD r::'~ 1~~1t TYD N~ e.:..'"'l' r..... N.... Point Type RllllloI. MSL - 31' M8L ,.... FWL 1.wcrFWL .(R) (R) (R) (R) (R) (II) Nibitchuq'tTar¡ct ....,.P.... .....00 ~684.32N 1127.18W .650JIO 606J.478.80 N SIIS26.76E Cùdo Nikakc:huq,1 PBHL Ealry Point 9Iso.oo 5&$0.00 N 1160.00 W 9115.00 606164U9 N SI8493.~0 E Po" ~JIO -2000 ~,oo.oo e Begin Dir @ 3.0°/1000 : 1 0004. 10ft MD, 8167.62ft TVD End Dir, Start Sail @ 37.76° : 1658.5311 MD, 1569.400 TVD Begin Dir @ 3.0°/1000 : 400.000 MD, 400.000 TVD 1 - 1000 I ~ AtŒ 0 S! " ~ 1Ií 0 rJ '" TARGET: Start Sail @ 19.96' : 10597.2311 MD, 8685.00ft TVD (1724' FSL & 363' FWL, Sec. 9-T14N-R9E) SHL (1490' FWL & 1320' FSL, Sec. 16 - T14N - R9E) '"'.II"'........~I\'!tt\C I'",,1t Halliburton Sperry-Sun Proposal Report for Spy Island - Nlka1tchuq #1 (wp02) Revised: 6 January, 2004 Western North Slope, Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastings Northings Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -35.00 0.00 O.OON O.OOE 6055797.49 N 519669.03 E 0.00 SHL (1490' FWL & 1320' FSL, Sec. 16 - T14N - R9E) 100.00 0.000 0.000 65.00 100.00 O.ooN O.ooE 6055797.49 N 519669.03 E 0.000 0.00 200.00 0.000 0.000 165.00 200.00 O.OON O.OOE 6055797.49 N 519669.03 E 0.000 0.00 300.00 0.000 0.000 265.00 300.00 O.OON O.OOE 6055797.49 N 519669.03 E 0.000 0.00 - 400.00 0.000 0.000 365.00 400.00 O.OON O.OOE 6055797.49 N 519669.03 E 0.000 0.00 - Begin Dir@3.00/10OO:400. MD, 400.000 TVD 500.00 3.000 348.784 464.95 499.95 2.57N 0.51 W 6055800.06 N 519668.51 E 3.000 2.62 . 600.00 6.000 348.784 564.63 599.63 10.26 N 2.04W 6055807.75 N 519666.97 E 3.000 10.46 700.00 9.000 348.784 663.77 698.77 23.06 N 4.57W 6055820.54 N 519664.40 E 3.000 23.51 . 800.00 12.000 348.784 762.08 797.08 40.94 N 8.12W 6055838.41 N 519660.80 E 3.000 41.74 900.00 15.000 348.784 859.31 894.31 63.83 N 12.66 W 6055861.29 N 519656.20 E 3.000 65.08 .1000.00 18.000 348.784 955.18 990.18 91.69 N 18.18W 6055889.13 N 519650.60 E 3.000 93.48 1100.00 21.000 348.784 1049.43 1084.43 124.43 N 24.67 W 6055921.85 N 519644.03 E 3.000 126.85 '1200.00 24.000 348.784 1141.81 1176.81 161.96 N 32.12 W 6055959.37 N 519636.48 E 3.000 165.12 1300.00 27.000 348.784 1232.06 1267.06 204.19 N 40.49 W 6056001.57 N 519628.00 E 3.000 208.16 .1400.00 30.000 348.784 1319.93 1354.93 250.99 N 49.77 W 6056048.34 N 519618.59 E 3.000 255.87 1500.00 33.000 348.784 1405.18 1440.18 302.23 N 59.93 W 6056099.56 N 519608.30 E 3.000 308.12 . '1600.00 36.000 348.784 1487.59 1522.59 357.78 N 70.95 W 6056155.08 N 519597.13 E 3.000 364.75 1658.53 37.756 348.784 1534.41 1569.41 392.24 N 77. 78 W 6056189.52 N 519590.21 E 3.000 399.88 End Dir, Start Sail @ 37.760 : 1658.53ft MD, 1569.400 TVD '1700.00 37.756 '348.784 1567.19 1602.19 417.14 N 82.72 W 6056214.41 N 519585.20 E 0.000 425.27 1800.00 37.756 348.784 1646.25 1681.25 477.20 N 94.63 W 6056274.44 N 519573.13 E 0.000 486.50 . 1900.00 37.756 348.784 1725.32 1760.32 537.26 N 106.54 W 6056334.47 N 519561.06 E 0.000 547.73 It 1932.23 37.756 348.784 1750.80 1785.80 556.62 N 110.38W 6056353.82 N 519557.17 E 0.000 567.46 Base of Permafrost 2000.00 37.756 348.784 1804.38 1839.38 597.33 N 118.45W 6056394.50 N 519549.00 E 0.000 608.96 2100.00 37.756 348.784 1883.44 1918.44 657.39 N 130.36W 6056454.53 N 519536.93 E 0.000 670.19 2200.00 37.756 348.784 1962.50 1997.50 717.45 N 142.27W 6056514.56 N 519524.86 E 0.000 731.42 2300.00 37.756 348.784 2041.57 2076.57 777.51 N 154.18 W 6056574.58 N 519512.79 E 0.000 792.65 2400.00 37.756 348.784 2120.63 2155.63 837.57 N 166.09 W 6056634.61 N 519500.72 E 0.000 853.88 2500.00 37.756 348.784 2199.69 2234.69 897.63 N 178.00 W 6056694.64 N 519488.65 E 0.000 915.11 2600.00 37.756 348.784 2278.75 2313.75 957.69 N 189.91 W 6056754.67 N 519476.58 E 0.000 976.34 2700.00 37.756 348.784 2357.82 2392.82 1017.75 N 201.82 W 6056814.70 N 519464.51 E 0.000 1037.57 6 January, 2004 -13:27 Page2of8 DrlIlQuest 3.03.05.005 Halliburton Sperry-Sun Proposal Report for Spy Island· Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 Western North Slope, Measured 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) (0/100ft) 2800.00 37.756 348.784 2436.88 2471.88 1077.81 N 213.73 W 6056874.73 N 519452.44 E 0.000 1098.80 2900.00 37.756 348.784 2515.94 2550.94 1137.87 N 225.64 W 6056934.76 N 519440.37 E 0.000 1160.03 3000.00 37.756 348.784 2595.00 2630.00 1197.93 N 237.55 W 6056994.79 N 519428.30 E 0.000 1221.26 3100.00 37.756 '348.784 2674.07 2709.07 1257.99 N 249.46 W 6057054.81 N 519416.23 E 0.000 1282.49 3200.00 37.756 348.784 2753.13 2788.13 1318.05 N 261.37 W 6057114.84 N 519404.16 E 0.000 1343.72 3300.00 37.756 348.784 2832.19 2867.19 1378.11 N 273.28 W 6057174.87 N 519392.09 E 0.000 1404.95 e 3400.00 37.756 348.784 2911.25 2946.25 1438.17 N 285.19 W 6057234.90 N 519380.02 E 0.000 1466.18 3500.00 37.756 348.784 2990.32 3025.32 1498.23 N 297.10W 6057294.93 N 519367.95 E 0.000 1527.41 3800.00 37.756 348.784 3069.38 3104.38 1558.29 N 309.01 W 6057354.96 N 519355.88 E 0.000 1588.64 3700.00 37.756 348.784 3148.44 3183.44 1618.36 N 320.92 W 6057414.99 N 519343.82 E 0.000 1649.87 3800.00 37.756 348.784 3227.50 3262.50 1678.42 N 332.83 W 6057475.02 N 519331.75 E 0.000 1711.10 3900.00 37.756 348.784 3306.57 3341.57 1738.48 N 344.74 W 6057535.04 N 519319.68 E 0.000 1772.33 4000.00 37.756 348.784 3385.63 3420.63 1798.54 N 356.65 W 6057595.07 N 519307.61 E 0.000 1833.56 4081.29 37.756 348.784 3449.90 3484.90 1847.36 N 366.33 W 6057643.87 N 519297.80 E 0.000 1883.33 Top of West Sak 4100.00 37.756 348.784 3464.69 3499.69 1858.60 N 368.56 W 6057655.10 N 519295.54 E 0.000 1894.79 4200.00 37.756 348.784 3543.75 3578.75 1918.66 N 380.47 W 6057715.13 N 519283.47 E 0.000 1956.02 4300.00 37.756 348.784 3622.82 3657.82 1978.72 N 392.38 W 6057775.16 N 519271.40 E 0.000 2017.25 4400.00 37.756 348.784 3701.88 3736.88 2038.78 N 404.29 W 6057835.19 N 519259.33 E 0.000 2078.48 4500.00 37.756 348.784 3780.94 3815.94 2098.84 N 416.20W 6057895.22 N 519247.26 E 0.000 2139.71 4600.00 37.756 348.784 3860.00 3895.00 2158.90 N 428.11 W 6057955.25 N 519235.19 E 0.000 2200.94 4700.00 37.756 348.784 3939.07 3974.07 2218.96 N 440.02 W 6058015.27 N 519223.12 E 0.000 2262.17 4800.00 37.756 348.784 4018.13 4053.13 2279.02 N 451.93 W 6058075.30 N 519211.05 E 0.000 2323.40 4900.00 37.756 348.784 4097.19 4132.19 2339.08 N 463.84 W 6058135.33 N 519198.98 E 0.000 2384.63 . 5000.00 37.756 348.784 4176.25 4211.25 2399.14 N 475.75 W 6058195.36 N 519186.91 E 0.000 2445.86 It 5100.00 37.756 348.784 4255.32 4290.32 2459.20 N 487.66 W 6058255.39 N 519174.84 E 0.000 2507.09 5200.00 37.756 348.784 4334.38 4369.38 2519.26 N 499.57 W 6058315.42 N 519162.77 E 0.000 2568.32 5300.00 37.756 348.784 4413.44 4448.44 2579.32 N 511.48 W 6056375.45 N 519150.70 E 0.000 2629.55 5400.00 37.756 348.784 4492.50 4527.50 2639.39 N 523.39 W 6058435.48 N 519138.64 E 0.000 2690.78 5500.00 37.756 348.784 4571.57 4606.57 2699.45 N 535.30 W 6058495.50 N 519126.57 E 0.000 2752.01 5517.24 37.756 348.784 4585.20 4620.20 2709.80 N 537.35 W 6058505.86 N 519124.48 E 0.000 2762.57 Base of West Sak 5600.00 37.756 348.784 4650.63 4685.63 2759.51 N 547.21 W 6058555.53 N 519114.50 E 0.000 2813.24 5644.00 37.756 348.784 4685.42 472Q.42 2785.93 N 552.45 W 6058581.95 N 519109.19 E 0.000 2840.18 9-5/8" Csg Pt... Drill out 8-1/2" Hole: 5644.000 MD. 4720.42ft TVD 9-5/8" Casing 5700.00 37.756 348.784 4729.69 4764.69 2819.57 N 559.12 W 6058615.56 N 519102.43 E 0.000 2874.47 6 January, 2004 . 13:27 Page 3 0" DrlIlQuest 3.03.05.005 Halliburton Sperry-Sun Proposal Report for Spy Island· Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 .- Western North Slope, Measured Sub-$ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs I!astlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 5800.00 37.756 348.784 4808.75 4843.75 2879.63 N 571.03 W 6058675.59 N 519090.36 E 0.000 2935.70 5900.00 37.756 348.784 4887.82 4922.82 2939.69 N 582.94 W 6058735.62 N 519078.29 E 0.000 2996.93 6000.00 37.756 348.784 4966.88 5001.88 2999.75 N 594.85 W 6058795.65 N 519066.22 E 0.000 3058.16 6100.00 37.756 348.784 5045.94 5080.94 3059.81 N 606.76 W 6058855.68 N 519054.15 E 0.000 3119.39 6200.00 37.756 348.784 5125.00 5160.00 3119.87 N 618.67 W 6058915.71 N 519042.08 E 0.000 3180.62 6300.00 37.756 348.784 5204.07 5239.07 3179.93 N 630.58 W 6058975.73 N 519030.01 E 0.000 3241.85 e 6400.00 37.756 348.784 5283.13 5318.13 3239.99 N 642.49 W 6059035.76 N 519017.94 E 0.000 3303.08 6500.00 37.756 348.784 5362.19 5397.19 3300.05 N 654.40 W 6059095.79 N 519005.87 E 0.000 3364.31 6600.00 37.756 348.784 5441.25 5476.25 3360.11 N 666.31 W 6059155.82 N 518993.80 E 0.000 3425.54 6700.00 37.756 348.784 5520.32 5555.32 3420.17 N 678.22 W 6059215.85 N 518981.73 E 0.000 3486.77 6800.00 37.756 348.784 5599.38 5634.38 3480.23 N 690.13 W 6059275.88 N 518969.66 E 0.000 3548.00 6900.00 37.756 348.784 5678.44 5713.44 3540.29 N 702.04 W 6059335.91 N 518957.59 E 0.000 3609.23 7000.00 37.756 348.784 5757.50 5792.50 3600.35 N 713.95 W 6059395.94 N 518945.52 E 0.000 3670.46 7100.00 37.756 348.784 5836.57 5871.57 3660.42 N 725.86 W 6059455.96 N 518933.46 E 0.000 3731.69 7200.00 37.756 348.784 5915.63 5950.63 3720.48 N 737.77 W 6059515.99 N 518921.39 E 0.000 3792.92 7300.00 37.756 348.784 5994.69 6029.69 3780.54 N 749.68 W 6059576.02 N 518909.32 E 0.000 3854.15 7400.00 37.756 348.784 6073.75 6108.75 3840.60 N 761.59W 6059636.05 N 518897.25 E 0.000 3915.38 7500.00 37.756 348.784 6152.82 6187.82 3900.66 N 773.50 W 6059696.08 N 518885.18 E 0.000 3976.61 7600.00 37.756 348.784 6231.88 6266.88 3960.72 N 785.41 W 6059756.11 N 518873.11 E 0.000 4037.84 7700.00 37.756 348.784 6310.94 6345.94 4020.78 N 797.32 W 6059816.14 N 518861.04 E 0.000 4099.07 7800.00 37.756 348.784 6390.00 6425.00 4080.84 N 809.23 W 6059876.17 N 518848.97 E 0.000 4160.30 7863.24 37.756 348.784 6440.00 6475.00 4118.82 N 816.76W 6059914.13 N 518841.34 E 0.000 4199.02 Top of Middle Brookian Fan 7900.00 37.756 348.784 6469.07 6504.07 4140.90 N 821.14 W 6059936.19 N 516836.90 E 0.000 4221.53 . 8000.00 37.756 348.784 6548.13 6583.13 4200.96 N 833.04 W 6059996.22 N 516624.83 E 0.000 4282.76 e 8100.00 37.756 348.784 6627.19 6662.19 4261.02 N 844.95 W 6060056.25 N 518812.76 E 0.000 4343.99 8200.00 37.756 348.784 6706.25 6741.25 4321.08 N 856.86 W 6060116.26 N 518800.69 E 0.000 4405.22 8300.00 37.756 348.784 6785.32 6820.32 4381.14N 868.77 W 6060176.31 N 516768.62 E 0.000 4466.45 8400.00 37.756 348.784 6864.38 6899.38 4441.20 N 880.68 W 6060236.34 N 518776.55 E 0.000 4527.68 8500.00 37.756 348.784 6943.44 6978.44 4501.26 N 892.59 W 6060296.37 N 518764.48 E 0.000 4588.91 8600.00 37.756 348.784 7022.50 7057.50 4561.32 N 904.50 W 6060356.40 N 516752.41 E 0.000 4650.14 8622.64 37.756 348.784 7040.40 7075.40 4574.92 N 907.20W 6060369.96 N 518749.68 E 0.000 4664.00 Tof of HRZ 8685.50 37.756 348.784 7090.10 7125.10 4612.67 N 914.69 W 6060407.72 N 518742.10 E 0.000 4702.49 T of of Kalubik " January, 2O(J4 . 13:27 Page 4 ofB Dril/Quest 3.03.05.005 Halliburton Sperry-Sun Proposal Report for Spy Island - Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 Westem North Slope, Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8700.00 37.756 348.784 7101.57 7136.57 4621.38 N 916.41 W 6060416.42 N 518740.34 E 0.000 4711.37 8800.00 37.756 348.784 7180.63 7215.63 4681.45 N 928.32 W 6060476.45 N 518728.28 E 0.000 4772.60 8850.30 37.756 348.784 7220.40 7255.40 4711.66 N 934.32 W 6060506.65 N 518722.20 E 0.000 4803.40 Top of Kuparuk 8900.00 37.756 348.784 7259.69 7294.69 4741.51 N 940.23 W 6060536.46 N 518716.21 E 0.000 4833.83 9000.00 37.756 348.784 7338.75 7373.75 4801.57 N 952.14 W 6060596.51 N 518704.14 E 0.000 4895.06 9014.22 37.756 348.784 7350.00 7385.00 4810.11 N 953.84 W 6060605.05 N 518702.42 E 0.000 4903.77 LCU e 9100.00 37.756 348.784 7417.82 7452.82 4861.63 N 984.05 W 6060656.54 N 518692.07 E 0.000 4956.29 9200.00 37.756 348.784 7496.88 7531.88 4921.69 N 975.96 W 6060716.57 N 518680.00 E 0.000 5017.52 9300.00 37.756 348.784 7575.94 7610.94 4981.75 N 987.87 W 6060776.60 N 518667.93 E 0.000 5078.75 9400.00 37.756 348.784 7655.00 7690.00 5041.81 N 999.78 W 6060836.63 N 518655.86 E 0.000 5139.98 9500.00 37.756 348.784 7734.07 7769.07 5101.87 N 1011.69 W 6060896.65 N 518843.79 E 0.000 5201.21 9520.15 37.756 348.784 7750.00 7785.00 5113.97 N 1014.09 W 6060908.75 N 518841.36 E 0.000 5213.55 Top of Nuiqsit 9598.70 37.756 348.784 7812.10 7847.10 5161.15 N 1023.45 W 6060955.90 N 518631.88 E 0.000 5261.64 Base of Nuiqsit 9600.00 37.756 348.784 7813.13 7848.13 5161.93 N 1023.60 W 6060956.68 N 518631.72 E 0.000 5262.44 9700.00 37.756 348.784 7892.19 7927.19 5221.99 N 1035.51 W 6061016.71 N 518619.65 E 0.000 5323.67 9800.00 37.756 348.784 7971.25 8006.25 5282.05 N 1047.42 W 6061076.74 N 518607.58 E 0.000 5384.90 9900.00 37.756 348.784 8050.32 8085.32 5342.11 N 1059.33 W 6061136.77 N 518595.51 E 0.000 5446.13 10000.00 37.756 348.784 8129.38 8164.38 5402.17 N 1071.24 W 6061196.80 N 518583.44 E 0.000 5507.36 10004.10 37.756 348.784 8132.62 8167.62 5404.64 N 1071.73 W 6061199.26 N 518582.95 E 0.000 5509.87 Begin Dir @ 3.00/10Oft: 1 0004.1 Oft MD, 8167.62ft TVD 10100.00 34.879 348.785 8209.88 8244.88 5460.34 N 1082.78 W 6061254.94 N 518571.75 E 3.000 5566.66 10200.00 31.879 348.786 8293.38 8328.38 5514.30 N 1093.48 W 6061308.87 N 518560.91 E 3.000 5621.68 10300.00 28.879 348.787 8379.64 8414.64 5563.90 N 1103.31 W 6061358.44 N 518550.95 E 3.000 5672.24 10400.00 25.879 348.789 8468.43 8503.43 5609.01 N 1112.25 W 6061403.52 N 518541.89 E 3.000 5718.22 TARGET: Start Sail @ 19.96° . 10500.00 22.879 348.791 8559.50 8594.50 5649.49 N 1120.27 W 6061443.99 N 518533.75 E 3.000 5759.50 10597.23 19.962 348.794 8650.00 8685.00 5684.32 N 1127.18 W 6061478.80 N 518526.76 E 3.000 5795.00 10597.23ft MD, 8685.0Oft TVD (1724' FSL & 363' FWL, Sec. 9- T14N-R9E) Top of Sag River Nikaitchuq #1 Target, 100.00 Radius., Current Target 6 January, 2004 -13:27 Page 5 0" DrlIIQuest 3.03.05.005 Halliburton Sperry-Sun Proposal Reporl for Spy Island· Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 Western Norlh Slope, Measured Sub-8ea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 10600.00 19.962 348.794 8652.61 8687.61 5685.25 N 1127.36 W 6061479.73 N 518526.57 E 0.000 /10700.00 19.962 348.794 8746.60 8781.60 5718.74 N 1133.99 W 6061513.20 N 518519.85 E 0.000 10724.90 19.962 348.794 8770.00 8805.00 5727.08 N 1135.65 W 6061521.53 N 518518.18 E 0.000 10800.00 19.962 348.794 8840.59 8875.59 5752.23 N 1140.63 W 6061546.67 N 518513.13 E 0.000 10900.00 19.962 348.794 8934.58 8969.58 5785.72 N 1147.26 W 6061580.14 N 518506.40 E 0.000 10990.88 19.962 348.794 9020.00 9055.00 5816.15 N 1153.29 W 6061610.56 N 518500.29 E 0.000 11000.00 19.962 348.794 9028.57 9063.57 5819.21 N 1153.90 W 6061613.61 N 518499.68 E 0.000 . 11091.95 19.962 348.794 9115.00 9150.00 . 5850.00 N 1160.00W 6061644.39 N ." 518493.50 E 0.000 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 Eastlngs are relative to 1320' FSL, 1490' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity Is in Degrees per 100 feet (US Survey). Vertical Section is from 1320' FSL, 1490' FWL and calculated along an Azimuth of 348.7840 (True). Magnetic Declination at Surface is 24.945· (06-Jan-04) Based upon Minimum Curv;¡ature type calculations, at a Measured Depth of 11091.95ft., The Bottom Hole Displacement is 5963.900., in the Direction of 348.784· (True). The Along Hole Displacement Is 5963.90ft. The Total Accumulated Dogleg is 55.550· The Planned Tortuosity is 0.943·/1000. The Directional Difficulty Index is 5.4. 6 January, 2004· 13:27 Page 6 ofB Vertical Section 5795.95 5830.09 5838.59 5864.23 5898.37 5929.39 5932.51 5963.90 Comment Top of Shublik Top of Ivishak e PBHL: 11091.95ft MD, 915O.0C TVD (330' FWL & 1890' FSL, Sec. 9· T14N - R9E) Target - Nikaitchuq #1 PBHL, Current Target ~ e DrlllQuest 3.03.05.005 Western North Slope, Comments Measured Depth (ft) 0.00 400.00 1658.53 5644.00 10004.10 10597.23 11091.95 Halliburton Sperry-Sun Proposal Report for Spy Island· Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 Station Coordinates TVD Northlngs Eastlngs (ft) (ft) (ft) 0.00 O.OON O.OOE 400.00 O.OON 0.00 E 1569.40 392.24 N 77.78 W 4720.42 2785.93 N 552.45 W 8167.62 5404.64 N 1071.73 W 8685.00 5684.32 N 1127.18 W 9150.00 5850.00 N 1160.00 W Comment SHL (1490' FWL & 1320' FSL, Sec. 16· T14N . R9E) Begin Dir @ 3.00/100ft : 400.000 MD, 400.00ft TVD End Dir, Start Sail @ 37.76°: 1658.53ft MD, 1569.40ft TVD 9-518" Csg Pt ... Drill out 8-1/2" Hole: 5644.00ft MD, 4720.42ft TVD Begin Dir@ 3.00/100ft: 10004.100 MD, 8167.62ftTVD TARGET: Start Sail @ 19.96°: 10597.23ft MD, 8685.000 TVD (1724' FSL & 363' FWL, Sec. 9-T14N-R9E) PBHL : 11091.95ft MD, 9150.000 TVD (330' FWL & 1890' FSL, Sec. 9 - T14N - R9E) e Formation To"s Formation Plane Profile Penetration Pol n t (Below Well Origin) Measured Vertical Sub-8ea Sub-8ea Dip Up-Dlp Depth Depth Depth Northlngs Eastlngs Formation Name (ft) Angle Dim. (ft) (ft) (ft) (ft) (ft) 1750.80 0.000 0.152 1932.23 1785.80 1750.80 556.62 N 110.38 W Base of Permafrost 3449.90 0.000 0.152 4081.29 3484.90 3449.90 1847.36 N 366.33 W Top of West Sak 4585.20 0.000 0.152 5517.24 4620.20 4585.20 2709.80 N 537.35 W Base of West Sak 6440.00 0.000 0.152 7863.24 6475.00 6440.00 4118.82 N 816.76 W Top of Middle Brookian Fan 7040.40 0.000 0.152 8622.64 7075.40 7040.40 4574.92 N 907.20 W Tof of HRZ 7090.10 0.000 0.152 8685.50 7125.10 7090.10 4612.67 N 914.69 W T of of Kalubik - 7220.40 0.000 0.152 8850.30 7255.40 7220.40 4711.66 N 934.32 W Top of Kuparuk 7350.00 0.000 0.152 9014.22 7385.00 7350.00 4810.11 N 953.84 W LCU 7750.00 0.000 0.152 9520.15 7785.00 7750.00 5113.97 N 1014.09 W Top of Nuiqsit 7812.10 0.000 0.152 9598.70 7847.10 7812.10 5161.15 N 1023.45 W Base of Nuiqsit 8650.00 0.000 0.152 10597.23 8685.00 8650.00 5684.32 N 1127.18 W Top of Sag River 8770.00 0.000 0.152 10724.90 8805.00 8770.00 5727.08 N 1135.65 W Top of Shublik 9020.00 0.000 0.152 10990.88 9055.00 9020.00 5816.15 N 1153.29 W Top of Ivishak 6 January, 2004 . 13:21 Page 70" DrlllQuest 3.03.05.005 Western North Slope, Caslnø details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> To Measured Vertical Depth Depth (ft) (ft) 5644.00 472Q.42 Tarøets associated with this welloath Target Name Nikaitchuq #1 Target (Circle) Nikaitchuq #1 PBHL (Point) 6 January, 2004 -13:27 Halliburton Sperry-Sun Proposal Report for Spy Island - Nlkaltchuq #1 (wp02) Revised: 6 January, 2004 Casing Detail 9-5/8" Casing e Target Entry Coordinates TVD Northings Eastings Distance Direction (ft) (ft) (ft) (ft) (O"frue) 8685.00 5684.32 N 1127.18W 5795.00 348.784 Mean Sea Level/Global Coordinates: 8650.00 6061478.80 N 518526.76 E Geographical Coordinates: 70· 34' 44.9029" N 149· 50' 52.3830" W Target Radius: 1oo.00ft 9150.00 5850.00 N 1160.00 W 5963.90 348.784 Mean Sea Level/Global Coordinates: 9115.00 6061644.39 N 518493.50 E Geographical Coordinates: 70· 34' 46.5325" N 149· 50' 53.3540· W - Page 8 0" DrIllQuest 3.03.05.005 · e Kerr McGee Nikaitchuq #1 Mud Program Baroid Drilling Fluids General Discussion This exploration well will be drilled fi'om an off-shore ice pad near the Spy Islands, basically due north of Oliktok Point on the North Slope of Alaska. The well will be drilled as an "s" shaped hole building to 400 in the 12 y.."surface hole and drilled to a surface hole TD of -5780' TMD where 9 5/8" casing will be run and cemented. An 8 W' hole will then be drilled holding this angle to 9300' where a drop to 200 will begin. This angle will then be held to TD at -11187' TMD where 5 W' X 3 !/z" casing will be run and cemented. Primary targets for this well will include the Kuparuk, Sag and Ivishak sands with other possible oil bearing sands being present. An inhibited KClIPolymer mud will be used to drill this well fi'om spud to TD. As a general drilling fluids plan, spud the well with inhibited 9.0 ppg 12% KClIPolymer 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 fonnulated with mechanisms to provide effective wellbore stabilization and to reduce drilling waste, i.e., ionic inhibition (KCl) and polymer encapsulation (PHP A). From the surface shoe to the core point at -11691', the continued use of the inhibited 9.6 ppg KClIPolymer 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. At the core point, it is planned (MBT and solids dependent) to use the existing mud system for coring. A new 9.8 ppg core fluid (35K ppm salinity BaraDril-N System) would be used only if the existing system is deemed unfit. After coring the well, the fluid can be maintained as the KCl/Polymer mud to the final well TD. The mud weight for this interval of the well will range fi'om 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 (KCl) to allow maximum application of mechanical solids control support. This being the case, the mud filtrate salinity may range in the 80K-IOOK ppm range when drilling the other target sands on this well. The KCl concentration is dependent upon MWD and logging restrictions and could vary fi'om this recommendation. SDeCial Considerations 1. Waste minimin\tion 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 Sulfand 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 ofLCM and the other mud additives, which may be required to support this drilling program. Nikaitchuq #1 V2 Page 1 11712004 e Formation Tops/Casin2 Pro2ram Spud Base Pennaftost Top Schrader Bluff Base Schrader Bluff 9 5/8" casing point Middle Brookian Top HRZ Kalubik Kuparuk Top LCUlKingak Top Nuiqsit Top Sag Top Shublik Top Ivishak TD TMD 0' 1950' 4168' 5650' 5780' 8071' 8855' 8920' 9090' 9259' 9733' 10692' 10819' 11086' 11187' TVD 0' 1786' 3485' 4620' 4720' 6475' 7075' 7125' 7255' 7385' 7785' 8685' 8805' 9055' 9150' e Comments 9.0 ppg density Mud Wt 9.0 9.0-10.0 9.0-10.0 9.0-10.0 9.0-10.0 9.6-9.8 lOA lOA lOA 10.6 10.6 10.6 10.6 10.6 10.6 String in LCM Stop LCM treatment Condition for casing occasional shale instability occasional shale instability String in LCM shale instability occasional shale instability target sands String in LCM Spot STEELSEAL Surface Hole Mud Properties (12 %" Hole f/Spud to 9 5/8" Casinß Point at 5780' TMD) Mud Density Viscosity YP PV 10 S. Gel API FL Properties (ppg) (sec/qt) (cc's/30 min) Initial 9.0 80-120 35-45 13-21 10-15 <15 Final 9.0-10.0 50-80 15-30 15-23 10-15 6-8 Suñace Interval 02 %" Hole to 5.780' TMD) The surface interval of this well will be drilled with a 12% KCVPolymer mud as fonnulated below: 9.0 ppg Fonnulation Fresh Water KCI NaCl EZ Mud DP PAC-LIR Barazan-D KOH Aldacide-G Baroid Baracor 700 Barascav D .95 bbl 37 ppb o .75 ppb .5ppb 1-2 ppb .1 ppb .2ppb o 1.0 ppb .5ppb (ionic inhibition/50.5K ppm chlorides) (polymer encapsulation) (API filtrate of6-12 cc's) (as required for an initial 35 YP) (pH = 8.5-9) (X-Cide 207 for rig maintenance) (as needed) (colTosion inhibitor) (to be added at rig) Spud the well with maximum flow rates (600-750 gpm assuming 12 W' holew/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 fonn 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 (Sweepwate )/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 ofDriltreat (Lecithin) and ~% by volume BDF-263. Nikaitchuq #1 V2 Page 2 1/7/2004 e e 4. Maintain the mud as cool as possible (under 60°F if possible). Efforts to keep the fluid cool include mudding up with cold water and diluting the mud with cold water. The Baroid mud plant in Prudhoe Bay can be utilized to supply the initial volume of fluid for the spud. Make every effort to maintain the system as clean as possible through the normal dilution process and maximization of solids control equipment application. Mud maintenance issues for this interval of the well are as follows: 1. If possible, use pre-mixed KCI water to maintain volume while drilling ahead. The density of the KCI solution should be based upon mud weight requirements at any given point of the well. 2. Use PAC's for API filtration control. Target 6-12 cc's initially, dropping the fluid loss to the 6cc 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 ofX-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. Ifpossible, reduce the fluids rheology to <20 yP after the casing is on bottom prior to starting the cement job. Production Hole (8 Yz" Hole f/Base Surface Casin2 to Well TD at 11,187' TMD) Mud Density YP PV 10 S. Gel API FL PH Properties (ppg) (cc's/30 min) 6-10 9-9.5 <6 «10 9-9.5 HTHP) Initial Final 9.6 10.4-10.6 10-15 15-25 6-12 15-25 2-5 2-6 Production Interval (8 Yz" Hole to 11.187' 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 ofre-adjusting the properties of the mud to insure a quality fluid for the initial drilling operations of the 8 Yz" hole). As in the surface hole, KCl will be used for ionic inhibition and for the basic density requirements of the system. Increase the mud weight as needed with KCl 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 witb tbe MWD personnel on site to run tbe bigbest possible cbloride concentration which will still allow their tools to read properly. Should the brine phase density be limited for the MWD, acheive 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 ÍÌ'om heavy clays is a problem, use BDF-263 and/or ConDet treatments. Regular sweeping of the hole with weightedlhigh 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 -8800' (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 9259'. Nikaitchuq #1 V2 Page 3 11712004 e e While drilling to the core point, maintain the mud as clean as possible through the use of solids control equipment and dilution as required. Maintain the API filtrate <6 with PAC's and Dextrid. The HTHP filtrate should be lowered to <10 with a 4-6 ppb Baranex addition prior to entering the HRZ at 8,800' TMD and maintained there until TO of the well. String in 2-3 ppb of Baracarb 50 while drilling the Kuparuk to help bridge/seal this zone. Use KCl 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. Sal!: Sand Corinl!: 00692') NOTE: Whether using a special core fluid or the base system, 4-5 sacks an hour of Baracarb 50 should be strung into the system anytime coring is occurring. A specifically designed core fluid (BaraDril-N System) should not be required to satisfy the coring objectives of the Sag target on this well. However, if the KCl/polymer fluid is deemed unfit, the core fluid would be used and be very similar in chemical design to the KCl/Polymer mud used to drill to core point and should be compatible with the displacement objectives of the well. The core fluid design would include KCl for ionic inhibition, starch and "specially" sized calcium carbonates for effective filtration control/bridging and "clean" bio-polymers for effective rheological support. While there are details to work, the basic core fluid formulation is as follows: 1 Barrel 00.6 ppg) 7% KCl Core Fluid Water Soda Ash Aldacide G Aquagel Dextrid PAC L N- Vis KCl Baracarb KOH Baroid .872 bbls .1 ppb .25 ppb (X-Cide 207 for rig maintenance) 5ppb 8ppb 1.75 ppb .5-.75 ppb (as required for a 15-25 YP) 23.6 ppb (35K ppm salinity) 76 ppb (blending specific to target sand perm) as needed for an 8.0 pH. as needed for a 10.6 ppg Tartzet Properties Density HTHP (200 deg. F) yp PH 10.6 ppg or as required. <7.5 cc's 15-25 Ibs/IOO sq. ft. 7.5-8.5 Drill to the core point with the KCl/Polymer mud and displace to the new core fluid as follows: 1. Reduce the yield point of the KCl/Polymer mud as allowed on this final circulation and prepare the rig pit system to receive the coring fluid from the Baroid mud plant and to build the low viscosity and high viscosity spacers. Dump and clean the rig pits and flush all pumps, solids control equipment, and lines with fresh water and discard this water. It is very important to get everything extremely clean and dry before bringing the core fluid into the pits. Take the coring fluid into the pits and proceed with the displacement. 2. PuInp a 30 barrel low viscosity sweep consisting of mud from the previous section which has had the YP reduced to the 6 to 9 range through additions of Therma- Thin/SAPP and dilution. This spacer should be weighted to the equivalent mud weight as the base mud. 3. Pump a 30 barrel freshwater high viscosity spacer consisting of N-Vis mixed to a yP of 45 to 65 (approximately 2.5 ppb N-Vis) and weighted to the equivalent density of the base mud with Baroid. Manipulation of the pH to ensure proper polymer dispersion and hydration along with slow mixing of the polymer will prevent the formation of polymer fish eyes. Nikaitchuq #1 V2 Page 4 11712004 e e 4. Once the high viscosity spacer is away, begin displacing with the coring fluid. Pump at rates of no less than 300 gpm, which should allow for efficient displacement. The drill string should be rotated while displacing to disturb any solids. Once displacement has started, the pumps should remain on until clean returns are seen. 5. Ensure the bit is on bottom as the new fluid exits the drill string. 6. Monitor the flow line for break through of the spacers and the new coring fluid. Discard the low viscosity and high viscosity spacers as they will be contaminated with unwanted drilled solids and cuttings which would compromise the integrity of the coring system. 7. Pull inside the casing and clean the possum bellies, under the shakers, and any pits which were taking the dirty returns. Mud maintenance of the core fluid should focus on the following: 1. Maintain mud weight as needed with Baracarb(s) and/or KCl. 2. Do not let low gravity drilled solids (LOS) exceed 2% by volume. 3. Do not let MBT exceed 8 ppb. 4. If liquid additions are required, add 7% KCI brine or new 7% KCI Core Fluid. Do not add ITesh water. 5. Do not add any mud additives outside those in the base mud fonnulation without approval from the operator. 6. Maintain the mud salinity at 35K ppm. 7. Control API filtrate and the HTHP with Dextrid/PAC L additions. 8. Use N- Vis as required to adjust yP for good hole cleaning. 9. The pH should remain in the 7.5-8.5 range. 10. Continue with aggressive X-Cide 207 treatments to control bacterial activity. 11. Dry jobs should be mixed using Baracarb 50. 12. The need for filtrate tracers needs to be confinned. After the coring work is complete, the core fluid can be treated/maintained as a conventional KClIPolymer mud to TO of the well. After circulating and short tripping at TO, 15-20 ppb of Steel Seal should be spotted ITom TO 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 running the casing. This will reduce the chances of inducing lost circulation while running the 5 1h.» /3 W' casing. Risks and Contine:encies: Lost Circulation: Preventing the initiation oflost 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 underpressured. 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 lOA 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 fonns of stuck pipe are possible. One is ITom hole pack-off as related to poor hole cleaning, i.e. cuttings bed. Stuck pipe can occur if a cuttings bed fonns, 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. Nikaitchuq #1 V2 Page 5 1/7/2004 · e Backreaming a large cuttings bed is an invitation to packing off and resulting stuck pipe, and backreaming must be done with care and only when necessary. If stuck pipe occurs across a sand and there are indications of differential sticking, there are drilling fluid solutions. If possible, reducing the fluid density by a minimum of 0.5 ppg may provide some relief. Corrosion Mitigation Barascav D and Baracor 700 will be run in 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 Fånn 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 (FWD increases, drag, torque, partial packing oft) 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 bitIBHA are in one of the mudstone/clay sections. Pipe should be kept moving at all times during this circulation period. High speed pipe rotation is the most critical factor for hole cleaning. Nikaitchuq #1 V2 Page 6 1m2004 e Product UsaJJe: e The following represents an estimate of the quantities of products to be used on each interval. Product Aldacide G Aquagel Baracor 700 Baradefoam Baranex Barascav D Barazan D+ 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 Thenna Thin X-Cide 207 Surface Interval 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 Nikaitchuq #1 V2 Page 11 Production Interval 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 Total Well 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 1/7/2004 e NW Milne point.>loration Project 2004 Cementing Services @ KERB-MCBEE CORPBRATIOII Nikaitchuq #1 Alaska; USA OptiCem 9.625 in Cement Surface Casing Prepared for: Skip Coyner January 13, 2004 Prepared by: Mark Wedman Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-275-2610 C:;HAlLlBURTON The Future Is Working Together. HALLIBURTON ISO 14001 Certified Alaska Green Star Certified e NW Milne Point_loration Project 2004 Cementing Services Well Conditions Casing Size & Wt. Hole Size MD TVD Top of Tail (MD) 9 5/8" 40# 12 1I4" 5,644' 4,720' 4,144' Volume Excess Mud Wt. BHST BHCT Previous Casing Depth 225% I 30% 9.5 ppg 90°F 80°F 200' Slurry Recommendation: Preflush 1 Spacer 10 bbl Water, 75 bbl 10.5 ppg NSCI Spacer Lead Slurry: 660 Sks. (2,742 Ft3) PERMAFROST L Tail Slurry: 560 Sks. ( 644 Ft3) Premium Cement, 2% Calcium Chloride Displacement: 417.2 bbls. Mud Density (ppg) Yield (cu ft 1 sk) Water requirements (gal/sk) Fluid Loss (cc/30 min.) Free Water % Soacer 8.34 1 10.5 Lead Slurrv Tail Slurrv 10.7 15.8 4.15 1.15 20.3 5.00 Thickening Time Hr: min. Compressive Strength - PSI 12 hr (est.) 24 hr (est.) 6:00+ 3:00 (48 Hr.) 25 1650 (72Hr.) 260 1800 Volumes based on: Lead slurry: Tail slurry: Top of Lead cement @ Surface 200 feet 13-3/8" 68#/ft cased hole @ 0% excess, 1750 ft of open hole plus 225% excess through base of pennafrost at 1950 ft MD + 2194 ft open hole below pennafrost + 30% excess. Top of Tail slurry 1500 feet above shoe - TOC 4,144' 1500' calculated annulus volume +30% excess + 80 foot shoe joint. HALLIBURTON ISO 14001 Certified Alaska Green Star Certified e NW Milne POint&loration Project 2004 Cementing Services fß KfRR..MCIJEE ClJlPtJllA1Ø Nikaitchuq #1 Alaska; USA OptiCem 5.5 in x 3.5 in Cement Production Liner Prepared for: Skip Coyner January 13, 2004 Prepared by: Mark Wedman Halliburton Energy Services 6900 Arctic Blvd. Anchorage, AK 99518 907-275-2610 OHALLlBURTON The Future Is Working Together. HALLIBURTON ISO 14001 Certified Alaska Green Star Certified Cementing Program Well Conditions Liner Size & Wt. Previous Casing: Drill Pipe: Volume Excess Hole Size MD TVD Top of Tail (MD) Slurry Recommendation: . NW Milne Point&loration Project 2004 Cementing Services 5-1/2" 17#/ft Liner - 5,500 ft to 9,400 ft 3-1/2" 9.2#/ft. Liner - 9,400 ft to 11,090 ft. 9-518" 40#/ft - 0 to 5,644 ft. 5" 19.5#/ft 30% (will use caliper + 15%) 8-1/2" Mud Wt. 11,092' BHST 9,150' BHCT 9,400' 10.6 ppg 190°F 130°F Preflush I Spacer 10 bbl Water, 30 bb112.5 ppg NSCI Spacer Lead Slurry: Tail Slurry: 517 Sx Premium Cement + 15 LB/SK. Microlite, + 0.2% CFR-3 (Friction Reducer), + 0.75% Halad 344 (Fluid Loss Additive), + 0.05 glsk D-Air-3 (Anti-foam), + HR-5 (Retarder) as required (211.1 bbls) 625 Sx Premium Cement+ 0.6% LAP I, + 0.3 LB/SK. Super CBL, + 0.5% UCS (Friction Reducer), + 0.6% HR-5 (Retarder) as required ( 129.2 bbl) 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.) Volumes based on: Soacer Lead Slurrv Tail Slurrv 8.34 1 12.5 12.5 15.8 2.36 U5 13.14 5.06 <75 <50 0 0 >3:00 +1- 3:00 350 @ 90°F >1,000 @190°F 625 @ 90°F >2,000 @ 190°F 1,440 @165°F Top of Lead cement @ 100 ft above Liner with drill pipe in or 5,400 ft. 144 ft liner by previous casing lap with no excess (5,500 ft - 5,644 ft). Open hole below previous casing to top of Tail or rrom 5,644 ft. to 9,400 ft plus 30% excess Top of Tail slurry 9,400' 1,692 ft. calculated annulus volume +30% excess + 120 foot shoe joint. Lead slurry: Tail slurry: HALLIBURTON ISO 14001 Certified Alaska Green Star Certified , , 99503 3900 C STREET ANCHORAGE, ALASKA (907) 339-6200 ",. PAY. ONE HUNDRED DOLLARS AND IJ() CENTS ........................... .......................................................... VOID OVER $100.00 e ********** STATE OF ALASKA ~~JÆ~oFOIL & GAS CONSERVATION COMMISION 333 W 7TH AVE STE 100 ANCHORAGE I 99501 AK * o z if 5' -- 7 B 2 7 . .,,- J 7.. .: . 25 200057.: ,,- . U.o qB,,- RECEIVED JAN 1 5 2004 & Gas Cons. Commission AnChorage Alaska Oil e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME AI/'k~il-cl.ÞL¿-- / PTD# 20 c.( -- 0/& . CHECK WBA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). PD...OT (PH) SPACING EXCEPTION / ./ DRY DITCH SAMPLE Rev: 07/] 0102 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. 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 hitervals through target zones. Administration Well Name: NIKAITCHUQ 1 Program EXP PTD#: 2040180 Company KERR-MCGEE OIL & GAS CORP Initial ClasslType EXP / PEND GeoArea 890 Unit OnlOff Shore Off 1 Permitfe~ attached. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Lease number appropriate. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . . . . . . . . . . . . . . . . . . .. .......................... 3 .Uni~ue we/tn.ame .aod rwmb~r . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. .......... _ . . . 4 WeJIJo.cated inad.efil1ed pool . . . . . . . .. ..... . . . .Y~s . . ExploratQry well, Ipçated. witJ1in.the. bouod.aries oJ th.e .Miloe Poio!, Kuparuk River. Qitf>oot . . . . . . . . . . 5 WeJI Jo.cated prop~r distaoce. from drilliog ul1itboul1dary. . . . . . . . . . . . . . . . . . . . Yes. . . . . . . Targets. are Kuparuk, Nuiqusit, .S.ag River.a.nd Ivjshak. . . . . . . . . . . . . . . . . .. ........ 6 WeJI JQcated prop~r distaoceJrom other wells. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s .. .... Near~st welUs I'JW.Milne #1. whicb is.17,000' to. SE. . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 .Sufficiel1t acreaQ.e.ayailable in.drilJioQ. unil. . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jf.deviated, is.weJlbore p/¡¡¡tJncluded . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............ 9 .operator only aff~cted pa.rty. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .Operator bas_appropriate.b.ood inJorce. . . . . _ . _ _ _ _ . . . . . . . . . _ . . . . . . . . . . . _ . Y~s . . . . . . . . _ . . . . . . . . _ _ _ . . . . . . . . _ . . . _ _ _ . . . . . . . _ . . . . . . . . . . . . . . _ _ _ . . . . . . . . . . _ _ . . . 11 Permitcao be issu.ed witho.ut conservatiOI1 order. . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ......... 12 Permitcao be issu.ed witho.ut ¡¡¡dministratille.approvaJ . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1/23/2004 13 Can permit be approved before 15-day wait Yes 14 WeJIJQcatedwithjl1areaan.d.str¡¡¡taautboril:edbyJojectiooOrder:# (puUO# in.commeots) (For. NA... ...................... .................................. 15 AU wells.wit!1in Jl4.l1Jil~.are.a.of review ideotified (For s.ervice w~1J C;>I1ly). . . . _ . . . . . . . . . _ NA . . . . . . . . _ . _ . . . . . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . 16 Pre.-produçed iojector; duratjo.nof pre-productionlesstban.3 mOl1ths(For.serviçe well Qnly) . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . _ 17 ACMP.FJndlng .of CQnsisteocy.has been JssuedJorJbis proj~ct .................. .Np. . . . . . . . KayeL¡¡¡ug!1ljn, Jf>Q,.1l2Jl04:ACMf> review ootrequir~d, . . . . . . . . . . . . . . . . . . 18 Çpoduçtor strJn.Q.prQvided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 Surface.casJn-9.prQtects.aILk!lQwn.USQWs.. .................... . Y~s...... .I'JoUSDW,............................. _ ....... .................. 20CMT.vota.dequateJo circulate.oncond.uctor.& su.rf.csg . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . Ade!:uate ex.cess, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21CMTvota.dequ.ateJo tie-in .long .stri!lg tosurj' CS-9. . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ....... 22 ÇMTwill coyer.all kl1ownpropuctiye bQrilQn.s. . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 23 Çasiog desigos ad.equat~ for C,T, B .&.p.ermafrosL . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Adequat~Jank¡¡¡ge.or re.serve pit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . l'Jabprs.27E.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Jtare-drill, bas.a. to-403 for aba.ndonment beeo approved. . . . . . . . . . . . . . . . . . . .NA . . . . . New well. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 Adequat~wellbore.s.ep¡¡¡rationproposed.... _ . . . . . . . . _ . _ . . . . . . . . . _ _ _ . . . . . Yes _ _ _ . . . . . . . . . . _ . . . . . . . . . _ _ _ _ . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Jtdiverter required, do.es it meetreguJa.tions. . . . . . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 28 .DrilJiogfluid.programscJ1em¡¡¡tic.&.equipJisLadequate......................... Yes. . .... .M¡¡¡x.MW.11..0.ppg... .. . . . . . . . . .. . . . . . . . . . . . . . . . .. . .. . . . . . . WGA 1/22/2004 29 BOPEs,.do.they meetreguJa.tion . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............... ......... 30 .BOPEpressratiogappropriate;t~sttp.(putpsigincomments).................... Y~s...... .Te.stto.5000psl.MSf>.34JOpsi...................................... ...... 31CJ1oke.manifold cQmpJies w/APtRf>.-53 (May 84). . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will occur withouLoper¡¡¡tlo!l.sbutdown . . . . . . . .. .................. _ _ Yes. . . . . . . . . . . . . . . . . . . . . . . . . . .. ..................................... 33 .Is. pres.e!lce. oJ H2S gas prob.able. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Np. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............. _ . . . . . . . . . . . 34 MechanicalcoodJtioo of wells withJn AQR verified (For.s~rvice welJ onJy) . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Field & Pool Well bore seg Annular Disposal D D Appr SFD Date . Engineering e- Geology Appr SFD Date 1/20/2004 35 Permitcao be issu.ed wlo. hydrpg~n.s.ulfide meaSures. . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . Non~ .obseNed intbis section. io offset explprato.ry wells. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36 .Datapreseoted on. potential overpres.sure zones. . . . . . . . . . . . . . . . . . . Yes. . . . . . . AbnormaJforma.tion pressure.is oo.t expected.. . . . . . . . . . . . . . . . . . . .. ........... 37 Seismic a!l¡¡¡lysjs.Qf shaJIQW gas zooes. ................................. Y~s... . .PQsSible.occ.urrel1cepfhydratesorminor.s.h¡¡¡lI.ow.Qasbene¡¡¡tbpermafrQst..NQiodicatiol1s.on.3D.seismi.c. 38 Se¡¡¡bed .conditioo survey -<if off-shore) . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . . . . Surta~ locaíiol1 is 00 Spy. Island, . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . 39 _Co.ntaçtnam~á>!1oneJQrweeklyprogressJeports[e)(ploratory.ooIyl................ Yes. .. .SkipCOY!ler,90J:3~9-626.9,.................. _.. .............. _ ........ Geologic Commissioner: Date: Engineering Commissioner: Date Public Commissioner Date aT$' ( ê,p/~ 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. HALLIBURTON Sperry-Sun Kerr McGee Corporation END OF WELL REPORT Nikaitchuq 1 ~D~(-Olg o 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:J R I L..L..I N t=õ 5 E Fi \J I c: E 5 I I I I I I I I I I I I I I I I I I I GENERAL WELL INFORMATION Company: Rig: Well: Field: Borough: State: Country: API Number: Sperry-Sun Job Number: Job Start Date: Job End Date (TD): North Reference: Declination: Dip Angle: Total Field Strength: Date Of Magnetic Data: Wellhead Coordinates N: Wellhead Coordinates W: SDL Engineers: Company Geologist: SSDS Unit Number: Kerr Mcgee Corporation Nabors N27E Nikaitchuq 1 N. Milne Pt. North Slope Alaska United States 50-629-23193-00 AKAM0002893103 16th February 2004 2nd March 2004 True 24.897 deg 80.903 deg 57547 NT February, 2004 North 70 deg 33 min 39.99 sec East 149 deg 46 min 23.59 sec Doug Wilson Jason Powers David Hutchins R. Geesaman 101/117 spe.....r'v-sun [;:JRI L.L.I N ;¡ SE FHII c: E 5 I I I I I I I I I I I I I I I I I I I Nikaitchuq 1 - Diary of Events r~;3/'bt\ #1Vì S-/1 15th February 2004 Rig up Nabors 27E rig over well head. !# 3/*' conductor set at 151' MD. 16th February 2004 Pickup 5" drill pipe, make up BHA #1 (NB 1 12 %" MXC1, TFA=.900). Clean out conductor. Well spudded under conductor at 2050 hours on 16th February. Drill to 380' MD. Maximum ROP 327 ft/hr. Mud weight 8.9 ppg. No drill gas was noted. \~ \ (...;.\ 17th February 2004 Drill ahead 12 1 ?4" hole, lost pump pressure, check surface equipment. Pull out of hole and check downhole tools. Pickup and run in hole with new mud motor. Work on top drive. Drill ahead to 1234' Md. Repaired ball mill pump. Drill ahead tp 1501' MD. Average ROP 100-300 ft/hr. Maximum gas 33 units at 1501' MD. First sign of methane gas at 1403' MD. Formation consisted of Clays interbedded with sands and gravel. Mudlogger's top of Permafrost 840' MD, 837' TVD. Mudlogger's Base of Permafrost 1825' MD, 1744' TVD. Mud weight was 9.2 ppg. 18th February 2004 Drill 12 %" hole to 3233' MD.. Perform short trip ( Short trip gas 72 units.). Ball mill repair. Work tight spots ( 1310-1350' MD, 1800-1888' MD, 1911-1925' MD). Drill ahead to 3292' MD. Mud weight 9.3 ppg. Average ROP 227 ft/hr. Maximum gas 281 units at 2040' MD. Formation consisted of interbedded clays and sands with trace to 5 % coal. 19th February 2004 Drill 12 %" hole from 3292 to 5311' MD, sliding as necessary to maintain azimuth and inclination. Mud weight 9.6 ppg. Average ROP for interval 203 ft/hr. Maximum gas 3120 units at 5062' MD from a sand formation 5040 to 5090' MD (See Show Report #2). An additional high gas reading of 1269 units was from interval 4795 to 4890' MD ( See Show Report #1). Formation consisted of clays with interbedded sands and minor coal. 20th February 2004 Drilled to 9 5/8" casing point at 5720' MD. Circulated and pumped sweep and circulated bottoms up. Continued to circulatr until shakers were clean. Perform wiper trip, pump high vis sweep and circulate hole clean. Short trip gas observes was 769 units with a mud weight of 9.6 ppg. Average ROP for interval 5311 to 5720' MD was 107 ft/hr. Maximum gas observed was 248 units at 5522' MD. Bit #1 statistics (#1 and Rerun #!) = 5569 feet, 41.0 hours and 258K revolutions. Tight hole spots encountered at 3104', 1880', 1720' and 1316'MD. Rig up to run wireline logs. Mudlogger's Top of West Sak formation 4368' MD, 3660' TVD. Lithology in interval 5311 to 5720' MD consisted of clay with prograding and interbedded siltstones. 21th February 2004 Run in hole with e-Iogs on wireline. Tool would not go below 1600' MD. Pull out of hole with same and rig down wireline. Pickup 12 %" bit, I I I I I I I I I I I I I I I I I I I BHA and trip in hole. Break circulation at 2986' MD. Continue trip in hole, encountered tight spots at ( 1640-1680' MD, 4480' md and 5160' MD). Circulated bottoms up and until shakers cleaned up. Maximum clean out trip gas 140 units. Trip out of hole and rig up wireline to run e-logs. 22nd February 2004 Run wireline e-logs. E-log tool would not go below 4750' MD. Pull out of the hole with wireline and rig down wireline unit. Pick up 12 1,4" bit and BHA for wiper trip in preparation for running 9 5/8" casing. Perform wiper trip. 23rd February 2004 Rig up to run 9 5/*" casing. Run in hole with 9 5/8" casing to 5720' MD. Circulate bottoms up-maximum gas 76 units. Rig up to cement casing. Cement as per plan. Displace cement with rig pumps, 75 bbls excess to surface and lost returns last 64 bbl pumped. Rig down cement equipment. Rig up and test BOP's. 24th February 2004 Test BOP's. 25th February 2004 Finish testing BOP's, pull test plug and set wear ring. Makeup BHA #2 ( Bit #2 8 ¥2"HCM605 TF A=.6480). Test MWD and orient mud motor. Trip in hole, picking up 144 joints of 5" drill pipe. Tag cement at 5622' MD. Circulate bottoms up and perform casing test. Drill cement to 5692' MD and repair HCR valve. 26th February 2004 Drill cement, float, casing shoe and new formation to 5740' MD. Perform Leak off Test to 13.2 ppg Equivalent mud weight. Drill 8 ¥2" hole to 8003' MD. Average ROP 195 ftlhr. Maximum gas 206 units at 7859' MD. Formation consisted of predominately siltstone with scattered stringers of sandstone. 27th February 2004 Drill 8 ¥2" hole, sliding to maintain azimuth and inclination from 8003 to 8097' Md. Circulated bottoms up. performed a wiper trip to 9 5/8" casing shoe. Resume drilling to 8234' MD. Circulated and raised md weight to 10.4 ppg. Drill to 8851' MD. Average ROP for interval 8003 to 8851' MD was 119 ftlhr. Maximum gas was 484 units at 8698' MD. Formation in this interval consisted of siltstone interbedded with claystones and shales. 28th February 2004 Drill 8 ¥2" hole from 8851 to 9846' MD. At 9096' MD an 8 stand wiper trip was performed. Average ROP for this interval was 73 ftlhr. Maximum gas for interval was 478 units at 8934' MD. Mud weight of 10.55 ppg. Formation consisted of predominately siltstone with some interbedded claystones and shales 29th February 2004 Drilled 8 ¥2" hole from 9846 to 10427' MD. Circulate out high gas (maximum 3561 units). Check flow no flow. Drill to 10450' MD., where a loss of pump pressure was noted ( steady loss since drill pipe connection). Pump carbide pill to determine suspected washout. Trip out of hole to 8525' MD and found washout. Trip in hole to bottom and resume drilling to 10730' MD. Pump pressure I I I I I I I I I I I I I I I I I I I loss again noted. Trip out of hole looking for washout. Bottoms up not circulated. Average ROP for interval 9846 to 10730' MD was 80 ftJhr. Average drilled gas 312 units, with a mud weight of 10.7 ppg. Formation consisted of siltstones with some shales to 10350' MD. Sag River and Shublik formation sands and interbedded limestones with shale from 10350 to 10730' MD. Gas decreased to 750 unit average after maximum at 10427' MD. Gas increased to a high of 1200 units at 10630' MD. Mudlogger's gas chromatograph failed for interval 10530 to 10705' MD. . Total gas equipment worked well. 18t March 2004 Found second washout and replaced bad joint of drill pipe. Slip and cut drilling line at 9 5/8" casing shoe. Trip in hole. Resume drilling. Short trip gas 308 units. Drill 8 ¥2" hole from 10730 to 10918' MD. Circulated bottoms up and increased mud weight to 10.8 ppg. Noted gas peaks of 1190 units at 10865' MD and 1965 units at 10971' MD. (See Show Report #3 (10290-10895' MD and Show Report #4 ( 10935-11000' MD) for details). Drill from 10918' Md to Total Depth of 11010' MD. Perform wiper trip to 10073' MD. Spot Steel seal pill and trip out of the hole. Bit #2 statistics= 5290 feet, 46.6 hours and 403 K revolutions. Formation from 10730 to 11010 was Shublik and Ivishak formations. 2nd March 2004 Finish trip out of hole, Laydown BHA and rig up to wireline e-logs. Begin wireline e-logs. 3rd March 2004 Run wireline e-logs. 4th March 2004 Finish wireline logging. Rig down same. Trip in hole for wiper trip. Wiper trip gas 869 units maximum. 5th March 2004 Rig up and run completion / testing casing string. 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 1 2/16/2004 380' 229' Drilling White/ Lewis spe............v-sun eFt I L..L..I N G 5 Ei Ft V I c: Ei 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 121 ftIhr 327 ftIhr ( 643 ftIhr @ 258' Pump 1 68 spm Flow rate gpm; Gas* 3 units 4 unit¡ ( 6 units @ 246' Pump 2 70 gps Temp Out Deg F ( deg F @ Pump Liner x Stk in. SPP 757 psi Mud Wt In Mud Wt Out 8.90 ppg 8.90 ppg Visc 72 secs API filt 19.0 ml HTHP m Mud Wt at Max Gas PV 15 cp YP 35 Ibs/100ft2 Gels 11 \ 13 \ 14 pH --ª.Lppg 8.9 Sd 0.1 % -- Bit No.: 1 Type: MXC1 Bit Size: 12 1/4 Jets: 3 x 18 \ 3x 14 \ \ TFA: 0.9 in2 - - Wt On Bit: 7.00 RPM: 90 Hrs. On Bit: 0.7 Total Revs on Bit: 7000 Footage for Bit Run 229' 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 y: 60 0/0 Clay 25 % Sand 15 % 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 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Pick up pipe, make up BHA, did clean out run of conductor, and started drilling ahead. Spudded at 20:50 hours and reached 380 feet at 24:00 hours, Presently drilling ahead. Logging Engineer: Doug Wilson 1 Jason Power * 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 2 2/17/2004 1505 1125 Drilling White/ Lewis spef""'lf""'lV- sun (J RILL IN G 5 e FI v I c:: e 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 255 ftIhr 135 ftIhr ( 679 ftIhr @ 747 ) Pump 1 71 spm Flow rate 603 gpm - Gas* 26 units 7 unit¡ ( 33 units @ 1501 ) Pump 2 70 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 758 Mud Wt In Mud Wt Out 9.20 9.20 ppg ppg Visc 68 secs PV 14 cp API filt ~ ml HTHP _ m Mud Wt at Max Gas _ ppg YP 331bs/100ft2 Gels 11 \ 14 \ 16 pH 9.4 Sd 1.5 % - - -- - - Bit No.: 1 RR Type: Wt On Bit: 12.00 RPM: MXC1 80 Bit Size: Hrs. On Bit: 12 1/4 8.3 Jets: 3 x 18 \ 3 x --- Total Revs on Bit: 42 14 \ \ TFA: Footage for Bit Run 0.9 in2 1354 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 - Current Lithology: 35 % Sand 55 % Clay 10 % 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Drill ahead, lost pump pressure, check surface equipment, pull out of hole checked downhole tools P/U new mud motor and TIH, work on top drive, drill ahead, drilled to 1234 ft , repaired ball mill pump, presently drilling ahead at 1505 ft MD. Logging Engineer: Doug Wilson / Jason Power * 10000 units = 100% Gas In Air I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 3 2/18/2004 3292 1787 Drilling White/ Lewis spe....,....,v- sun ORIL...L...INC!i 5ERVIC:E5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 123 ft/hr 227 ft/hr ( 796 ft/hr @ 2000 ) Pump 1 70 spm Flow rate 597 gpm - Gas' 19 units 101 uniÜ ( 282 units @ 2040 ) Pump 2 67 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 1225 I I I I I I I I I I I I I I Mud Wt In 9.60 ppg Visc 61 secs API filt 7.6 ml HTHP m Mud Wt at Max Gas ppg - - Mud Wt Out 9.60 ppg PV 15 cp YP 33 Ibs/100ft2 Gels 12 \ 16 \ 19 pH 9.1 Sd 1.5 % - - - - - - Bit No.: 1 RR Type: MXC1 Bit Size: 12 1/4 Jets: 3 x 18 \ 3x 14 \ \ TFA: 0.9 in2 - -- Wt On Bit: 22.00 RPM: 98 Hrs. On Bit: 18.8 Total Revs on Bit: 143 Footage for Bit Run 3141 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth 3233 ft Short Trip Gas: 72 Mud Cut: ppg Short Trip CI: ppm - Tight Spots: 1310 to 1350 1800 to 1888 1911 tc 1925 Feet of Fill on Bottom: ft - ., . ~ , 40 % Sand 55 % Clay 5 % lignite TR % gravel % y: - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Drill ahead to 3233', do short trip, attempt to repair ball mill, work tight spots, TIH, presently drilling ahead at 3292' Logging Engineer: Doug Wilson I Jason Power . 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 4 2/19/2004 5311 2019 Drilling White/ Lewis sperrv-sun [J FU L.L.I N G !is Ei A V I c: Ei!iS Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 66 ftIhr 203 ftIhr ( 682 ftIhr @ 4828 ) Pump 1 89 spm Flow rate 765 gpm - Gas* 48 units 65 unit~ ( 3140 units @ 5062 ) Pump 2 90 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 2211 Mud Wt In Mud Wt Out 9.60 9.60 ppg ppg Visc 50 secs PV 16 cp API filt 7.2 ml HTHP m Mud Wt at Max Gas - - YP 23 Ibs/100ft2 Gels 8 \ 15 \ 17 pH - ppg 1 % 8.6 Sd - - -- - - Bit No.: 1 RR Type: Wt On Bit: 30.00 RPM: MXC1 87 Bit Size: Hrs. On Bit: 12 1/4 36.2 Jets: 3 x 18 \ 3 x 14 --- Total Revs on Bit: 273k \ \ TF A: -- Footage for Bit Run 0.9 in2 5160 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 tc Feet of Fill on Bottom: ft Liulology: 60 % Clay 35 % Sand 5 % Coal TR % 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Drill ahead at 5311' MD. Rotate and slide as necessary to maintain direction and inclination. Logging Engineer: Doug Wilson / Jason Power * 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 5 2/20/2004 5720 409 Wire Line Whitel Lewis spel"""'l"""'\{- sun I:J RILL I N 13 5 E R V I c: E 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftlhr 107 ftlhr ( 436 ftlhr @ 5361 ) Pump 1 0 spm Flow rate 0 gpm - Gas* 0 units 82 unit~ ( 248 units @ 5522 ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In Mud Wt Out 9.60 9.60 ppg ppg Visc 42 secs PV 19 cP API filt ~ ml HTHP _ m Mud Wt at Max Gas _ ppg YP 19 Ibs/100ft2 Gels 6 \ 12 \ 16 pH 9.0 Sd 0.25 % - - -- - - Bit No.: 1 RR Wt On Bit: 0.00 Type: RPM: MXC1 o Bit Size: Hrs. On Bit: 12 1/4 41.0 Jets: 3 x 18 \ 3 x --- Total Revs on Bit: 258K 14 \ \ TFA: Footage for Bit Run 0.9 in2 5569 Trip Depth: 5720 ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth 5720 ft Short Trip Gas: 769 Mud Cut: ppg Short Trip CI: ppm - Tight Spots: 3104 1 1880 / 1720 1 1316 Feet of Fill on Bottom: ft LllI,vlv::¡y. ûO % Clay 40 % Siltstone TR % Sand % 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Drill ahead to casing point (5,720' MD), circulate and pump sweep, circulate bottoms up and continue circulating until shakers were clean, did wiper trip, TIH, pump high vis sweep and circulate hole clean, Trip out of hole for wire line operations. Logging Engineer: Doug Wilson / Jason Power * 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 6 2/21/2004 5720 o Wire Line Whitel Lewis spe...,...,v-sun I:J R I L..L..I N G 5 E R V I c: E 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ftIhr ftIhr ( ftIhr @ Pump 1 0 spm Flow rate 0 gpm - Gas* units unih ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 9.30 ppg Visc 43 secs API filt 6.0 ml HTHP m Mud Wt at Max Gas ppg - - Mud Wt Out 9.30 ppg PV 12 cp YP 17 Ibs/100ft2 Gels 5 \ 11 \ 14 pH 9.3 Sd 0.1 % - - - - - - Bit No.: 1 RR Type: MXC1 Bit Size: 12 1/4 Jets: 3 x 18 \ 3x 14 \ \ TFA: 0.9 in2 - - - -- Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 41.0 Total Revs on Bit: 258K Footage for Bit Run 5569 Trip Depth: 5720 Short Trip Depth Tight Spots: 1640 to ft Trip Gas: ft Short Trip Gas: 1680 I 4490 140 Mud Cut: _ ppg Trip CI: Mud Cut: _ ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft 1 5160 y: 60 % Clay 40 % Siltstone TR % Sand % 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: RIH with wireline, hit obstruction at 1600', log out, ran in for clean out, pump high vis sweep and circulated to surface, continue to circulate until shakers were clean, pumped dry job and POOH, presently rigging up wireline. Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air I I I I I I I I I I I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: sper'r'v-sun C R I L..L..I N ¡:¡¡¡ 5 E A V It:: E 5 Mudlogger's Morning Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 7 2/22/2004 5720 o Wire Line Whitel Lewis Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( fVhr @ Pump 1 0 spm Flow rate 0 gpm Gas* units unit! ( units @ Pump 2 0 gps Temp Out Deg F ( deg F @ Pump Liner x Stk in. SPP 0 Mud Wt In Mud Wt Out 9.30 ppg 9.30 ppg Bit No.: 1 RR Type: Wt On Bit: 0.00 RPM: Trip Depth: 5720 Short Trip Depth Tight Spots: 1640 to 60 % ft ft ft units units units Depth to to Visc 43 secs PV 12 cP API filt 6.0 ml HTHP m Mud Wt at Max Gas YP 17 Ibs/100ft2 Gels 5 \ 11 \ 14 pH 9.3 Sd ppg 0.1 % MXC1 o Bit Size: Hrs. On Bit: -- 12 1/4 41.0 Jets: 3 x 18 \ 3 x 14 --- Total Revs on Bit: 258K \ \ TFA: -- Footage for Bit Run 0.9 in2 5569 140 Mud Cut: Mud Cut: ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ft Trip Gas: ft Short Trip Gas: 1680 / 4490 1 5160 Clay 40 % Siltstone TR % Sand % Gravel ppg ppg ppg before Drill Rate during Connection Gas and Mud Cut ft units ppg ft units _ ppg ft units _ppg ft ft ft Drilling Breaks after Gas during after before ppm ppm ft % units units units ppg ppg ppg % Lithology Cgl Sst Ls Sh 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: oz. 24 hr Recap: Wireline in progress. Logging Engineer: Doug Wilson I Jason Power NIA * 10000 units = 100% Gas In Air _H~· I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 8 2/23/2004 5720 o Test BOP's White spel"'""l"'""V- sun I:J RILL I N G 5 e R v I c: e 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. fUhr fUhr ( fUhr @ Pump 1 0 spm Flow rate 0 gpm - Gas* units unit¡ ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 I I I I I I I I I I I I I I Mud Wt In Mud Wt Out 9.50 9.50 ppg ppg Vise 46 secs PV 15 cp - API filt 6.8 ml HTHP m Mud Wt at Max Gas - - YP 20 Ibs/100ft2 Gels 6 \ 14 \ 18 pH -ppg 9.0 Sd 0.05 % - -- - - Bit No.: 1 RR Type: MXC1 Bit Size: 12 1/4 Jets: 3 x 18 \ 3x 14 \ \ TFA: 0.9 in2 - - -- Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 41.0 Total Revs on Bit: 258K Footage for Bit Run 5569 Trip Depth: 5720 ft Trip Gas: 76 Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / I / Feet of Fill on Bottom: ft Current Lithology: 60 % Clay 40 % Siltstone TR % Sand % % - - - - 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 - - - - - - - -, - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: RU casing equipment,. PU landing joint and make dummy run with hanger, RIH with 9 5/8 casing string, Circulate casing volume, Cement as per plan, Displace with rig pumps, 75 bbl excess cement to surface, Lost circulation last 64 bbl pumped, blowdown cement lines, RD cement head, flush stack, ND diverter, presently rigging up to test BOP's Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 9 2/24/2004 5720 o Test BOP's White spe....,....,v- sun I:J R I L..L..I N G 5 E R V I c: E 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ftIhr ftIhr ( ftIhr @ Pump 1 0 spm Flow rate 0 gpm - Gas* units unit! ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In Mud Wt Out 9.20 9.20 ppg ppg Visc 45 secs PV 12 cp API filt ~ ml HTHP _ m Mud Wt at Max Gas _ ppg YP 22 Ibs/100ft2 Gels 7 \ 10 \ 13 pH 8.9 Sd 0.1 % - - -- -- Bit No.: 1 RR Wt On Bit: 0.00 Type: RPM: MXC1 o Bit Size: Hrs. On Bit: 12 1/4 41.0 Jets: 3 x 18 \ 3 x --- Total Revs on Bit: 258K 14 \ \ TFA: -- Footage for Bit Run 0.9 in2 5569 Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / / / Feet of Fill on Bottom: ft Current Lithology: % % % % % - - - - Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg - - - - - - ft units ppg ft units ppg ft units ppg - - - - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Continue to nipple up BOP stack and test. Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air I I I I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 10 2/25/2004 5720 o Replace Valve White spel"'""l"'""V- sun I:) R I L..L..I N G 5 E FI V It: E 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. ft/hr ft/hr ( ft/hr @ Pump 1 0 spm Flow rate 0 gpm - Gas* units unit~ ( units @ ) Pump 2 0 gps - Temp Out Oeg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 I I I I I I I I I I I I I I Mud Wt In 9.25 ppg Visc 43 secs API filt 7.4 ml HTHP m Mud Wt at Max Gas ppg - - Mud Wt Out 9.25 ppg PV 12 cp YP 17 Ibs/100ft2 Gels 4 \ 8 \ 12 pH 9.5 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 0.0 Total Revs on Bit: 0 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: 1 I 1 Feet of Fill on Bottom: ft ". y: % % % % % - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. 24 hr Recap: Finish testing BOP's, pulled test plug and lay down, set wear bushing, M/U BHA, LWD and MWD, orient mud motor, and RIH, Pick up 144 joints of pipe, Cant RIH, Tag cement at 5622', circulate BU and did casing test, Drilled cement to 5,692' and presently repairing HCR valve. Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air I I I I I spe...,...,v-sun ORIL-L-ING seRVIc:es Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Morning Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 11 2/26/2004 8003' 2283' Drill Ahead White Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 229 ftIhr 195 ftIhr ( 548 ftIhr @ 6875' Pump 1 71 spm Flow rate 620 gpm - Gas* 89 units 48 unit~ ( 206 units @ 7859' ) Pump 2 73 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 2100 I I I I I I I I I I I I I I Mud Wt In Mud Wt Out Visc PV ppg ppg secs - cp YP - Bit No.: Wt On Bit: 2 Type: 29.00 RPM: HCM605 120 Bit Size: Hrs. On Bit: API filt - Ibs/100ft2 ml HTHP m Mud Wt at Max Gas Gels _\ _\ pH _Sd ppg - - % - - 81/2 11.7 Jets: 5 x 13 \ 3 \ - - Total Revs on Bit: 108K \ \ TFA: 0.65 in2 Footage for Bit Run 2283' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / / / Feet of Fill on Bottom: ft y: 90 % Siltstone 10 % Sand % % % - - - - 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 - - - - - - Depth Drill Rate during before to to Drilling Breaks after Gas during after % Lithology Cgl Sst Ls Sh - - - - - - - - - - - - - - - - before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 24 hr Recap: Logging Engineer: Doug Wilson I Jason Power NIA oz. * 10000 units = 100% Gas In Air I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitehuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 12 2/27/2004 8851' 848' Drill Ahead White I I I I I I I I I I I I I I I I I spe....,....,v- sun OR I L.L.I N G 5 e R v I c: e 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr 119 ftIhr ( 449 ftIhr @ 8103' Pump 1 0 spm Flow rate 0 gpm - Gas* 3 units 82 unit~ ( 484 units @ 8698 ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 10.50 ppg Visc 46 secs API filt 5.0 ml HTHP 9.4 m Mud Wt at Max Gas ppg - - Mud Wt Out 10.50 ppg PV 22 cp YP 24 Ibs/100ft2 Gels 5 \ 19 \ 25 pH 9.0 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - -- Wt On Bit: 20.00 RPM: 30 Hrs. On Bit: 18.8 Total Revs on Bit: 184K Footage for Bit Run 3131' 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: / 1 / Feet of Fill on Bottom: ft Current Lithology: 30 % Siltstone 15 % Clay 55 % Shale % % - - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Rotate and slide to 8097', Cire. BU, Wiper trip to shoe. TIH, drilled to 8234'. Cire. And raised mud wt to 10A.Drilled ahead to 8851' Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air I I I I I I I I I I I spe..........v- sun CAI L...L...I N G SEAVI c: E 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 13 2/28/2004 9846' 995' Drill Ahead White Mudlogger's Morning Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 150 ftIhr 73 ftIhr ( 232 ftIhr @ 9165' Pump 1 72 spm Flow rate 530 gpm Gas* 118 units 82 unit~ ( 478 units @ 8934' Pump 2 73 gps Temp Out Deg F ( deg F @ Pump Liner x Stk in. SPP 3470 Bit No.: Wt On Bit: Mud Wt In Mud Wt Out API filt 5.4 ml HTHP 9.4 m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 27 pH 9.1 Sd ppg 0.2 % 10.55 ppg 10.55 ppg Visc 45 secs PV 17 cp -- 2 Type: 25.00 RPM: Jets: 5 x 13 \ 3 \ --- Total Revs on Bit: 276k \ \ TFA: 0.65 in2 -- Footage for Bit Run 4126' HCM605 78 Bit Size: Hrs. On Bit: 81/2 32.3 Trip Depth: Short Trip Depth Tight Spots: 8994' / Mud Cut: Mud Cut: ppg Trip CI: ppg Short Trip CI: Feet of Filion Bottom: ppm ppm ft ft Trip Gas: ft Short Trip Gas: 8851 ' I Current Lithology: 85 % Siltstone 5 % Shale % % 10 % 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 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Drill to 8851', pump weighted/hi-vis sweep. Drill to 9096', pump sweep, made 8 stand wiper trip. Wash and ream last 150' to bottom. Drill ahead. Logging Engineer: Howard McClellan I Dave Hutchins * 10000 units = 100% Gas In Air I I I I I I I I I spef"""f"""Y- sun I:J A I LL IN C; 5 e A v I c: e 5 Customer: Well: Area: Lease: Rig: Job No.: Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 14 2/29/2004 10730' 884' Wiper trip White Mudlogger's Morning Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr 80 ftIhr ( 221 ftIhr @ 9851' Pump 1 0 spm Flow rate 0 gpm Gas* 3 units 312 unit¡ ( 3561 units @ 10427' Pump 2 0 gps Temp Out Deg F ( deg F @ Pump Liner x Stk in. SPP 0 Bit No.: Wt On Bit: Mud Wt In Mud Wt Out API filt 5.6 ml HTHP 10.4 m Mud Wt at Max Gas YP 16 Ibs/100ft2 Gels 7 \ 23 \ 29 pH 9.1 Sd ppg 0.2 % 10.70 ppg 10.70 ppg Visc 44 secs PV 16 cp -- 2 0.00 81/2 43.3 \ \ TFA: 0.65 in2 -- Footage for Bit Run 5010' Type: RPM: Bit Size: Hrs. On Bit: Jets: 5 x 13 \ 3 \ --- Total Revs on Bit: 359K HCM605 o Trip Depth: Short Trip Depth Tight Spots: ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft ft Trip Gas: ft Short Trip Gas: / I Mud Cut: Mud Cut: . hology: 5 % Siltstone 35 % Sand % 60 % Shale % 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 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Drilled to 10426', no flow, drilled to 10446', Circulated out high gas- 3561 Units - drilled to 10540' lost pump pressure, POOH to 8525' and found wash out. Replaced bad joint, TIH, resumed drilling to 10730'. Lost pressure, curently POOH. Logging Engineer: Howard McClellan 1 Dave Hutchins * 10000 units = 100% Gas In Air I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 15 3/1/2004 11010 280' POOH White I I I I I, I I I I I I I I spe..............v- sun 1:1 R I L..L..I N ¡;¡¡¡ 5 e R v I c: e 5 Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr 84 ftIhr ( 280 ftIhr @ 10751 ' Pump 1 0 spm Flow rate 0 gpm - Gas* 0 units 525 unit! ( 1965 units @ 10971 ' ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 10.80 ppg Visc 48 secs API filt 5.0 ml HTHP 10.4 m Mud Wt at Max Gas ppg - - Mud Wt Out 10.80 ppg PV 17 cp YP 17 Ibs/100ft2 Gels 6 \ 17\ 19 pH 8.9 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 8 1/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 46.6 Total Revs on Bit: 403K Footage for Bit Run 5290' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / / / Feet of Fill on Bottom: ft I ·...~I~, y: 90 % Sand 10 % Claystone % % % - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. I 24 hr Recap: Found second washout, replaced bad joint. RIH, slip and cut at shoe. RIH, resume drilling. I TD at 11010'. Wiper trip to 10073'. Spotted steel pill, POOH. t Logging Engineer: Howard McClellan I Dave Hutchins * 10000 units = 100% Gas In Air 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 16 3/2/2004 11010 spe.....,.....,v- sun OAI L...L...I N G SEAVI c: E 5 Wire line logs White/Fritts Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr ftIhr ( ftIhr @ Pump 1 0 spm Flow rate 0 gpm - Gas' 0 units unit~ ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 10.80 ppg Visc 46 secs API filt 5.0 ml HTHP m Mud Wt at Max Gas ppg - - - Mud Wt Out 10.80 ppg PV 17 cP YP 17 Ibs/100ft2 Gels 6 \ 15 \ 18 pH 9.2 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 46.6 Total Revs on Bit: 403K Footage for Bit Run 5290' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / I / Feet of Fill on Bottom: ft 90 % Sand 10 % Claystone % % % - - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Finish POOH. LD BHA. RU wireline, begin logging. Logging Engineer: Howard McClellan I Dave Hutchins * 10000 units = 100% Gas In Air I I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 17 3/3/2004 11010 I I I I sper'r'v-sun [J R I L...L...I N G 5 e R v I c: e 5 Wire line logs White/Fritts Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ftIhr ftIhr ( ftIhr @ Pump 1 0 spm Flow rate 0 gpm - Gas* 0 units unit¡ ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 I I I I I I I I I I I I I Mud Wt In 10.80 ppg Visc 46 secs API filt 5.2 ml HTHP m Mud Wt at Max Gas ppg - - - Mud Wt Out 10.80 ppg PV 18 cp YP 15 Ibs/100ft2 Gels 6 \ 14 \ 18 pH 9.2 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 46.6 Total Revs on Bit: 403K Footage for Bit Run 5290' Trip Depth: ft Trip Gas: Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / I / Feet of Fill on Bottom: ft vUlI t:" Il L-llIIOlogy: 90 % Sand 10 % Claystone % % % - - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Wireline logging. Logging Engineer: Howard McClellan / Dave Hutchins * 10000 units = 100% Gas In Air I Mudlogger's Morning Report Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 18 3/4/2004 11010 I I I I I I I I I I I I I I I I I sper'1r'1v-sun DR I L...L...I N G seRVI c:e 5 TIH White/Fritts Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 ft/hr ft/hr ( ft/hr @ Pump 1 0 spm Flow rate 0 gpm - Gas* 0 units unit! ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 10.80 ppg Visc 46 secs API filt 5.2 ml HTHP m Mud Wt at Max Gas ppg - - - Mud Wt Out 10.80 ppg PV 18 cp YP 15 Ibs/100ft2 Gels 6 \ 14 \ 18 pH 9.2 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 46.6 Total Revs on Bit: 403K Footage for Bit Run 5290' Trip Depth: ft Trip Gas: 869 Units Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / / / Feet of Fill on Bottom: ft ~~"~, 90 % Sand 10 % Claystone % % % - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: Finish wireline logging. TIH for wiper trip. Logging Engineer: Howard McClellan / Dave Hutchins * 10000 units = 100% Gas In Air I 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 #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Footage Last 24 hrs: Rig Activity: Report For: 19 3/5/2004 11010 spe~~v-sun [J R I ~~ IN G S e R v I c: e s Wiper trip White/Fritts Current 24 hr Avg 24 hr Max Pump and Flow Data R.O.P. 0 fUhr fUhr ( fUhr @ Pump 1 0 spm Flow rate 0 gpm - Gas* 0 units unit! ( units @ ) Pump 2 0 gps - Temp Out Deg F ( deg F @ ) Pump Liner x Stk in. - SPP 0 Mud Wt In 10.80 ppg Visc 46 secs API filt 5.2 ml HTHP m Mud Wt at Max Gas ppg - - - Mud Wt Out 10.80 ppg PV 18 cp YP 15 Ibs/100ft2 Gels 6 \ 14 \ 18 pH 9.2 Sd 0.2 % - - - - - - Bit No.: 2 Type: HCM605 Bit Size: 81/2 Jets: 5 x 13 \ 3 \ \ \ TFA: 0.65 in2 - - - Wt On Bit: 0.00 RPM: 0 Hrs. On Bit: 46.6 Total Revs on Bit: 403K Footage for Bit Run 5290' Trip Depth: ft Trip Gas: 869 Units Mud Cut: ppg Trip CI: ppm - Short Trip Depth ft Short Trip Gas: Mud Cut: ppg Short Trip CI: ppm - Tight Spots: / I / Feet of Fill on Bottom: ft Current Lithology: 90 % Sand 10 % Claystone % % % - - - - 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 - - - - - - - - - - - - 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: NIA oz. 24 hr Recap: TIH for wiper trip. Logging Engineer: Howard McClellan I Dave Hutchins * 10000 units = 100% Gas In Air I I I I I Gas' Temp Out I I Bit No.: 1 RR Type: MXC1 Bit Size: II" Wt On Bit: 15r/30s1 RPM: 90r/0 51 Hrs. On Bit: -I I I I I I I I 24 hr Recap: Drill ahead to 3195' MD. spe....,....,v-sun Customer: Well: Area: Lease: Rig: Job No.: CAI LLI N G 5EAVI C:E 5 Mudlogger's Afternoon Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 R.O.P. Current 190 76 14 hr Avg 14 hr Max ft/hr 170 ft/h r { 430 ft/hr @ 3180 Pump 1 units 90 unit~ { 252 units @ 2055 Pump 2 Deg F { degF@ Pump SPP ml HTHP Gels Mud Wt In Mud Wt Out 9.30 ppg 9.20 ppg Visc secs PV 14 cP API filt YP 33 Ibs/100ft2 -- Trip Depth: Short Trip Depth Tight Spots: ft ft Trip Gas: Short Trip Gas: to y: 35 % Sand 60 121/4 15.7 Jets: 3 x 18 \ 3 x --- Total Revs on Bit: 105k to Mud Cut: Mud Cut: to % Clay % Lignite 5 NA ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units ft units ft units -ppg -ppg -ppg units units units Depth Drill Rate during before to to Drilling Breaks after Gas during before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Mudlogger's Top Permafrost 840' MD, 837' TVD Mudlogger's Base Permafrost 1825' MD, 1744' TVD Logging Engineer: Doug Wilson 1 Jason Power \ Report No.: Date: Depth Ftg last 14h's Rig Activity: Report For: (2PM) 2/18/2004 3195 1690 Drilling White/ Lewis Pump and Flow Data 78 spm Flow rate 79 Liner 1320 x Stk m Mud Wt at Max Gas \ pH 670 gpm gps in. ppg Sd % 14 \ \ TFA: -- Footage for Bit Run ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: % ft ft ft after NIA oz. 0.9 in2 2815 ppm ppm ft % units units units ppg ppg ppg Cgl % Lithology Sst Ls Sh . 10000 units = 100% Gas In Air spe....,....,v-sun CAI L..L..I N G 5 EAVI c:: E 5 Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: Mudlogger's Afternoon Report (2PM) 2/20/2004 5720 409 TOH White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data fVhr 91 fVhr { 246 fVhr @ 5628 Pump 1 85 spm Flow rate 763 gpm units 70 unit~ ( 248 units @ 5521 Pump 2 82 gps Deg F ( degF@ Pump Liner x Stk in. SPP 2350 Mud Wt In 9.60 ppg Vise secs API tilt ml HTHP m Mud Wt at Max Gas ppg Mud Wt Out 9.60 ppg PV cp YP Ibs/1 00ft2 Gels \ \ pH Sd % - - Type: MXC1 Bit Size: 121/4 Jets: 3 x 18 \ 3 x 14 \ \ TFA: 0.9 in2 -- -- 15r/30s1 RPM: 96r/0 51 Hrs. On Bit: 38.2 Total Revs on Bit: 240k Footage for Bit Run 5340 _:-:11!.11!. Trip Depth: Short Trip Depth Tight Spots: 5720 ft ft na Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: Trip Gas: Short Trip Gas: to to % Sand 60 % Clay 40 % Siltstone % ~,~"~~~,...~~.,.=.",~~~,,,,,,~>===~~_~_':~,,i,t__í,::____i:__,:~"~ "'''''n'''"~Jl~&, - .",f:¡¡, NA ft ft ft Connection Gas and Mud Cut ppg ft units ppg ppg ft units ppg ppg ft units _ ppg . .. m .=="--:::·::"~I:II' ¡ TIJI Iii ft ft ft units units units Drilling Breaks Gas during Depth Drill Rate during before after before after to to 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A 14 hr Recap: Drill ahead to 5720' MD, CBU, TOH. Mudlogger's Top West Sak 4368' MD, 3660' TVD ppm ppm ft % units units units ppg ppg ppg % Lithology Cgl Sst Ls Sh oz. * 10000 units = 100% Gas In Air Logging Engineer: Doug Wilson 1 Jason Power I I I I I I I I I I I I I~ I I I I I I spel""".....v-sun CRILLING seRVices Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: (2PM) 2/21/2004 5720 o TIH White/ Lewis Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. fVhr fVhr ( fVhr @ Pump 1 91 spm Flow rate 772 gpm Gas* 30 units 40 unit~ ( 65 units @ CIRC Pump 2 90 gps Temp Out Deg F ( degF@ Pump Liner x Stk in. SPP 1725 Mud Wt In Mud Wt Out 9.10 ppg 9.60 ppg Visc PV secs API filt cp YP Ibs/100ft2 ml HTHP Gels ..-. .M .'::\iJ-.~~~tì1ì::;¡!_ ¡ I Bit No.: 1 RR Wt On Bit: Type: RPM: MXC1 Bit Size: 121/4 Hrs. On Bit: Jets: 3 x 18 \ 3 x -- Total Revs on Bit: Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to 35 % Sand 60 % Current Lithology: .....r--...w I -'__7¡¡-j¡¡¡[j , . Mud Cut: Mud Cut: to .NN·:~ Clay % Lignite 5 ill.. '..' NA ft ft ft ppg ppg ppg Connection Gas and Mud Cut ft units _ppg ft units ppg ft units _ppg units units units ''''''S=l".tn..J'i.!n..~""""",," Depth Drill Rate during before to to Drilling Breaks after Gas during before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: \ m Mud Wt at Max Gas \ pH ppg Sd % ..... 14 \ \ TFA: 0.9 in2 -- Footage for Bit Run II ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ·.-HI IIT¡ % ft ft ft after N/A oz. ppm ppm ft A % units units units ppg ppg ppg % Lithology Cgl Sst Ls Sh 24 hr Recap: RUN E LOGS, E-LOG TOOL WOULD NOT GO BELOW 1600' , PULL OUT WITH E-LOG, RIG DOWN SCHLUMBERGER, WIPER TRIP, PICK UP 12 1/4" BIT, BHA AND TIH, BREAK CIRC AT 2986' , CONTINUE TIH Logging Engineer: Doug Wilson / Jason Power * 10000 units = 100% Gas In Air I I I spe............v-sun [J A I L..L..I N G 5 e A V I c: e 5 Mudlogger's Afternoon Report Current R.O.P. ft/h r NO CIRC units Oeg F I I I Bit No.: I Wt On Bit: I Gas' Temp Out Mud Wt In Mud Wt Out 9.10 ppg 9.20 ppg Type: RPM: Trip Depth: Short Trip Depth Tight Spots: Current Lithology: ]f.J'~1#::,~;;;,~~- JBn'>:>.=21 NA ft ft ft units units units Depth to to 14 hr Avg ft/h r ( unit! ( ( Visc PV Customer: Well: Area: Lease: Rig: Job No.: Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabros 27E AK-AM- 2893103 14 hr Max ft/hr @ units @ degF@ Pump 1 Pump 2 Pump SPP I ~m .. ml HTHP Gels secs API filt cp YP Ibs/100ft2 Bit Size: Hrs. On Bit: ft Trip Gas: ft Short Trip Gas: -- Jets: x \ 3 x -- Total Revs on Bit: to Mud Cut: Mud Cut: to to 35 % Sand before -Hcr-\~^ : I ~-"~ 60 % Clay ".,.. '_,,___,,___""_m"__~~ Logging Engineer: Doug Wilson I Jason Power ppg ppg ppg Drill Rate during 5 % Lignite ~ 1n"',..i"{~ Connection Gas and Mud Cut ft units _ ppg ft units _ ppg ft units _ ppg Drilling Breaks after Gas during before 24 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: (2PM) 2/22/2004 5720 o PREP TIH White/ Lewis Pump and Flow Data spm Flow rate gpm gps in. Liner x Stk \ m Mud Wt at Max Gas \ pH % ppg Sd \ \ TFA: -- Footage for Bit Run ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft ¡:;¡n-' ..=M!U lIT! . % % ft ft ft units units units ppg ppg ppg after % Lithology Cgl Sst Ls Sh NIA oz. 24 hr Recap: RUN E LOGS, E-LOG TOOL WOULD NOT GO BELOW 4750' , PULL OUT WITH E-LOG, RIG DOWN SCHLUMBERGER, FIX RIG BRAKES, PICK UP 12 1/4" BIT, BHA PREPARE TO TIH F/WIPER TRIP FOR 95/8" CASING RUN * 1 0000 units = 1 00% Gas In Air I I I I I I I I I I Ii Mudlogger's Afternoon Report Customer: Well: Area: Lease: Rig: Job No.: 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: (2PM) 2/23/2004 5720 o TIH Whitel Lewis spe....,....,v- sun [J A I L..L..I N Gi 5 E A V I c: E 5 Current R.O.P. Gas' 35 Temp Out fVhr units Deg F 14 hr Avg fVhr( 55 unit! ( ( 14 hr Max fVhr @ units @ degF@ ) CBUlCSG ) ) Pump and Flow Data 51 spm Flow rate 220 gpm gps in. 76 Pump 1 Pump 2 Pump SPP Liner x Stk 300 . ~~::JL:í¡¡j¡Pij~ f! !!!:rl:¡ ~ ::nt.¡! Mud Wt In Mud Wt Out 9.10 ppg 9.20 ppg Visc PV secs API filt cp YP Ibs/100ft2 ml HTHP Gels \ m Mud Wt at Max Gas \ pH ppg Sd % -- -------.~ m"",,,,,,_,,'~.$",,, \ \ TFA: -- Footage for Bit Run 19lir- - Bit No.: Wt On Bit: Type: RPM: Bit Size: Hrs. On Bit: Jets: x \ 3 x -- Total Revs on Bit: Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft % Sand % Clay % Lignite % % X~~~fY~f1'iií1'f;'K~(¡~~~[ ~_c-- J[ 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: N/A oz. 14 hr Recap: RIG UP TO RUN 9 5/8" CASING RUN 9 5/8" CASING TO BOTTOM AT 5720-GOOD, CIRC BOTTOMS UP, MAXIMUM GAS 76 UNITS. RIG UP TO CEMENT 9 5/8" CASING Logging Engineer: Doug Wilson I Jason Power * 10000 units = 100% Gas In Air T I I I I I I I I I I I I I I I I I I I Mudlogger's Afternoon Report Customer: Well: Area: Lease: Rig: Job No.: 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: (2PM) 2/24/2004 5720 o test bop's White/ Lewis ~ ''''',...",., sper'r'v-sun C RILL I N G 5 E R V I c: E 5 ~w '-'-=_.~.~._~--_"I: . 14 hr Max ftIhr @ units @ degF@ _ill nIt:-:.., K.. :~_-m!I\' ,., 11[~= Current ftIh r units Deg F 14 hr Avg ftIh r ( unit! ( ( Pump and Flow Data spm Flow rate gpm gps in. R.O.P. Gas* Temp Out Pump 1 Pump 2 Pump SPP Liner x Stk -- m Mud Wt at Max Gas \ pH ppg Mud Wt In Mud Wt Out 9.10 ppg 9.20 ppg Visc PV secs API filt cp YP Ibs/100ft2 ml HTHP Gels \ Sd % Bit No.: Wt On Bit: Type: RPM: Bit Size: Hrs. On Bit: Jets: x \ 3 x -- Total Revs on Bit: \ \ TFA: -- Footage for Bit Run Trip Depth: Short Trip Depth Tight Spots: ft Trip Gas: ft Short Trip Gas: to to Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft % Sand % Clay % Lignite % % 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: N/A oz. 14 hr Recap: TEST BOPS Logging Engineer: Doug Wilson / Jason Power * 10000 units = 100% Gas In Air _."~."".,,,,,...,,, -~"'~ "" ~¡¡j I Mudlogger's Afternoon Report Customer: Well: Area: Lease: Rig: Job No.: 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: (2PM) 2/25/2004 5720 o P/U DP White/ Lewis I I I I I ~".'I I I I I I I I I spe....,......v-sun [J A I LL IN G 5 e A v I c: e 5 Current Gas* Temp Out fVhr units Deg F 14 hr Avg fVhr ( unit~ ( ( 14 hr Max fVhr @ units @ degF@ Pump and Flow Data spm Flow rate - gpm gps in. R.O.P. ) Pump 1 ) Pump 2 ) Pump SPP - Liner x Stk - ! J'mïC::::.".:_ ¡ rr Jí¡¡~bWr7:",,,,,:"jlïllìlil¡ '" ..",,=,~¡;;~ Mud Wt In Mud Wt Out YP API filt - Ibs/100ft2 ml HTHP Gels - \ m Mud Wt at Max Gas \ pH - ppg 9.10 ppg 9.20 ppg Visc PV secs - cp Sd % - - -- - - IILJlÞì ¡!~llli~~ - Bit No.: Wt On Bit: Type: RPM: Bit Size: Hrs. On Bit: Jets: x --- Total Revs on Bit: \ 3 x \ \ TFA: -- Footage for Bit Run ~ ·'.@..":.VL@.,,,,;;;· - .."""JI Trip Depth: Short Trip Depth Tight Spots: ft ft Trip Gas: Short Trip Gas: - to to Mud Cut: Mud Cut: to - ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft - Current Lithology: % Sand % Clay - - - - % Lignite % % Connection Gas and Mud Cut NA ft units -ppg ft units -ppg ft units ppg - - - - ft units ppg ft units ppg ft units ppg II - - - - - - ft units -ppg ft units -ppg ft units ppg - - - - ,..,._ MNNN._.~.,,·,,_, PI' ! ¡ ! ! I -= Drilling Breaks before Drill Rate during after before Gas during after % Lithology Cgl Sst Ls Sh - - - - - - - - - - - - - - - - Depth to to I I 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: N/A oz. ! ¡ J " ;j 14 hr Recap: Completed testing BOP's as per programme. Picked up BHA with MWD. Started P/U DP Logging Engineer: Howard McClellan / Jason Power * 10000 units = 100% Gas In Air I I I I I I I I I I I I I I I I Mudlogger's Afternoon Report Customer: Well: Area: Lease: Rig: Job No.: 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: (2PM) 2/26/2004 6872 1152 Drilling White/ Lewis spe....,....,v-sun [J RILL I N c¡¡¡ 5 E R V I c: E 5 Current 14 hr Avg 14 hr Max Pump and Flow Data R.O.P. 165 ftIhr ftIhr ( ftIhr @ Pump 1 70 spm Flow rate 610 gpm Gas* 34 units unit~ ( 140 units @ 6042 Pump 2 70 gps Temp Out Deg F ( deg F @ Pump Liner 6 x Stk 12 in. SPP 2100 Mud Wt In Mud Wt Out 9.25 ppg 9.25 ppg Visc PV secs AP I filt cp YP Ibs/100ft2 ml HTHP Gels \ Sd % -- m Mud Wt at Max Gas \ pH ppg Bit No.: Wt On Bit: 2 5-8 klb Type: HCM 605 (PDC) Bit Size: RPM: 75-100 Hrs. On Bit: 81/2 6.2 Jets: x \ 3 x --- Total Revs on Bit: 61 k \ \ TFA: 0.6480 -- Footage for Bit Run 1152 Trip Depth: ft Trip Gas: Short Trip Depth ft Short Trip Gas: Tight Spots: to to y: 10 % Sand 10 % Clay Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft 80 % 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: N/A oz. 14 hr Recap: Completed picking up DP. Drilled cement, float and casing shoe and new formation. Performed LOT to 13.2 ppg emw. Continued drilling 8.5" hole to 6872 ft. by 14:00 hrs I Logging Engineer: Howard McClellan I Jason Power * 10000 units = 100% Gas In Air I I I I I I I I I I I 1:1 '" I I I I I I I, spe.....,....,v-sun CRI L..L..I N G SERVI c: E 5 Mudlogger's Afternoon Report Current 230 44 R.O.P. fVhr units Deg F Gas* Temp Out Mud Wt In Mud Wt Out 10.40 ppg 9.80 ppg Bit No.: Wt On Bit: 14 hr Avg fVhr ( unit~ ( ( Visc PV .~~,~,~ Customer: Well: Area: Lease: Rig: Job No.: 200 secs cp YP 2 5-8 klb Type: HCM 605 (PDC) Bit Size: RPM: 75-100 Hrs. On Bit: _,,,,_:,m~, ~ . ¡ Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 14 hr Max fVhr @ units @ degF@ 7660 Pump 1 Pump 2 Pump SPP AP I filt Ibs/1 00ft2 ml HTHP Gels \ -- I ¡i ] Report No.: Date: Depth Ftg last 14h's Rig Activity: Report For: (2PM) 2/26/2004 9096 (md) Wiper trip White/ Lewis Pump and Flow Data 70 spm Flow rate 70 Liner 6 x Stk 2300 ft ft ft ¡ ¡r;;'1~@8¡~ after N/A oz. __":~:"'ÎÍ" in ;¡~-~;' m Mud Wt at Max Gas \ pH 610 gpm gps in. 12 ¡U 11134 {J % ~ ppg Sd 81/2 6.2 Jets: x \ 3 x --- Total Revs on Bit: 61 k \ \ TFA: 0.6480 -- Footage for Bit Run 1152 Trip Depth: 8089 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 j¡:¡ ,iJ ~r~ [I I II. I II ~~~".."JI.~ Current Lithology: % Sand % Clay 100 % SLTST % % -I NA ft ft ft units units units Depth to to before ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg Drill Rate during ''!: " "._'_'n"_..........-.,~ Drilling Breaks after before 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: Gas during 14 hr Recap: Drilled to 9096 ft with occasional stuck pipe. Made wiper trip to Logging Engineer: Howard McClellan I units units units ppg ppg ppg % Lithology Cgl Sst Ls Sh * 10000 units = 100% Gas In Air I I I I I I I I I I I I 1 1 I I I, spe...,...,v-sun CRILLING SERVICES Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report 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: (2PM) 2/28/2004 9225 373 Drilling White/ Lewis Current R.O.P. 91 fVhr Gas* 130 units Temp Out Deg F 14 hr Avg fVhr ( unit¡ ( ( mil 14 hr Max fVhr @ 479 units @ deg F @ 8934 Pump 1 Pump 2 Pump SPP Pump and Flow Data 63 spm Flow rate 545 63 Liner 6 x Stk 12 2800 Ilil~~-~.._",,~ gpm gps in. ~_~_·...".nn_.__ "-q"" irçl\ì1ìÎ;¡n;íiìi¡~J'¡ ¡; ¡:¡¡·.œìBIR.,·Jj}¡J¡ ppg ",'%.",~~"~"",,,....¡t$>~ ][1 Mud Wt In Mud Wt Out I I' ,%......'11:. ml HTHP Gels \ m Mud Wt at Max Gas \ pH % 10.40 ppg 9.80 ppg Visc PV secs API filt cp YP Ibs/1 00ft2 -- .==._:·:ml!r··::~~~¡ i mil! I ;~'Jlc:~~,,~;;.;.;;~;;iiffiii!\.,~!:., 2 15-20 Type: HCM 605 (PDC) Bit Size: RPM: 110 Hrs. On Bit: Bit No.: Wt On Bit: Sd 81/2 24.8 Jets: x \ 3 x --- Total Revs on Bit: 231 \ \ TFA: 0.6480 -- Footage for Bit Run 3505 Trip Depth: 9096 ft Trip Gas: 360 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: % Sand % Clay % SL TST 100 % % ",,-'" ,.. I! ,~. 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: N/A oz. 14 hr Recap: Drilled to 9096 ft with occasional stuck pipe. Made 10 stand wiper trip then continued drilling. Recorded 360 units trip gas after restart of drilling. II Logging Engineer: Howard McClellan 10000 I * units = 100% Gas In Air I j ~ I I I I I I I I I I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: spe....,....,v-sun [JRI LLI N G 5ERVI C:E 5 Mudlogger's Afternoon Report R.O.P. Current 141 130 Gas* Temp Out Mud Wt In Mud Wt Out Bit No.: Wt On Bit: 2 15-20 Trip Depth: Short Trip Depth Tight Spots: Current Lithology: ""'_~_""V"'~'= NA ft ft ft Depth to to ft/hr units Deg F 14 hr Avg 364 ft/h r ( unit! ( ( 10500 3561 Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 14 hr Max ft/h r @ units @ degF@ 10446 _,_.~::':~-:;:-""':::;':"¿l;æ¡L.! Pump 1 Pump 2 Pump SPP Report No.: Date: Depth Ftg last 14h·s Rig Activity: Report For: (2PM) 2/29/2004 10539 693 Drilling White/ Lewis -- Pump and Flow Data 63 spm Flow rate 63 Liner 6 x Stk 2800 545 gpm gps in. 12 r 10.55 ppg 10.55 ppg Visc 46 secs PV 17 cP API filt 6.0 ml HTHP m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 27 pH % Type: HCM 605 (PDC) Bit Size: RPM: 110 Hrs. On Bit: ft Trip Gas: ft Short Trip Gas: to to 80 % Sand o_~~-'K~ ppg 9.0 Sd 81/2 34.1 Jets: x \ 3 x --- Total Revs on Bit: 335 \ \ TFA: 0.6480 -- Footage for Bit Run 4819 Mud Cut: Mud Cut: to "J.~_"'''''''~ 20 % SLTST % units units units ppg ppg ppg Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg before Drill Rate during Drilling Breaks after before Gas during ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ppm ppm ft 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: % % ft ft ft units units units ppg ppg ppg after % Lithology Cgl Sst Ls Sh Logging Engineer: Howard McClellan 1 Dave Hutchins NIA oz. 14 hr Recap: Drilled from 9846 to 10539 f1. Pumped carbide pill in an attempt to determine suspected washout (standpipe pressure noted to be steadilly decreasing after connection). * 10000 units = 100% Gas In Air I I I I I I I I I I I spe....,....,v- sun CRI L.L.I N G seRVI c: es Customer: Well: Area: Lease: Rig: Job No.: Mudlogger's Afternoon Report Current 141 387 14 hr Avg 105 fVhr ( unit! ( ( R.O.P. fVhr units Deg F 275 1190 Gas* Temp Out ~"""",,, ,[WI ~.I.:-' Mud Wt In Mud Wt Out 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: (2PM) 3/1/2004 10918 188 Drilling White/ Lewis ~I 14 hr Max fVhr @ units @ degF@ Pump and Flow Data 63 spm Flow rate 63 Liner 6 x Stk 2800 Pump 1 Pump 2 Pump SPP 545 gpm gps in. 10865 12 10.70 ppg 10.70 ppg Visc 46 secs PV 17 cp API tilt 6.0 ml HTHP m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 27 pH -- Bit No.: Wt On Bit: 2 Type: HCM 605 (PDC) Bit Size: 15-20 RPM: 110 Hrs. On Bit: ~~:=-"::~^ If '-'-':;;¡;-:jì1II_ r '.." Trip Depth: Short Trip Depth Tight Spots: ft 1 0730 ft to Trip Gas: Short Trip Gas: Current Lithology: 70 % Sand ppg 9.0 Sd % 81/2 44.5 r::. Jets: x \ 3 x --- Total Revs on Bit: 385 \ \ TFA: 0.6480 -- Footage for Bit Run 5198 308 Mud Cut: Mud Cut: to ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: t ppm ppm ft to % 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: NIA oz. 14 hr Recap: Drilled from 10730 ft to 10918 ft and circulated bottoms up. Increased mud wt to 10.8 ppg. Logging Engineer: Howard McClellan 1 Dave Hutchins * 10000 units = 100% Gas In Air I I I I I I I I I I ~tlg~, I I I I I I I I I Customer: Well: Area: Lease: Rig: Job No.: spe...,...,v-sun [J AI LL I N G 5 E A V I c: E 5 Mudlogger's Afternoon Report Current R.O.P. Gas* Temp Out Mud Wt In Mud Wt Out Bit No.: Wt On Bit: 2 15-20 Trip Depth: Short Trip Depth Tight Spots: Current Lithology: NA ft ft ft Depth to to ftIhr units Deg F 10.70 ppg 10.70 ppg 14 hr Avg ftIhr( unit~ ( ( Kerr McGee Nikaitchuq #1 North Slope NW Miline Point Nabors 27E AK-AM- 2893103 14 hr Max Pump 1 Pump 2 Pump SPP Report No.: Date: Depth Ftg last 14h's Rig Activity: Report For: (2PM) 3/2/2004 11010 188 E-Iogging White/ Lewis Pump and Flow Data spm Flow rate Liner 6 x Stk gpm gps in. 12 Visc 46 secs PV 17 cp 6.0 ml HTHP m Mud Wt at Max Gas YP 18 Ibs/100ft2 Gels 6 \ 22 \ 27 pH % Type: HCM 605 (PDC) Bit Size: RPM: 110 Hrs. On Bit: 10730 to units units units ft ft Trip Gas: Short Trip Gas: -- 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 308 to % 30 70 % Sand ¡~\~iIi':::'_;~1 ~~.. % Mud Cut: Mud Cut: to % SLTST ppg ppg ppg 'I:~---- Connection Gas and Mud Cut ft units ppg ft units ppg ft units ppg before Drill Rate during Drilling Breaks after before 14 hour accumulation of Steel Filings from Possum Belly Magnets: Description of fillings: 14 hr Recap: Running E-Iogs Logging Engineer: Howard McClellan I Dave Hutchins Gas during ~~w ppg Trip CI: ppg Short Trip CI: Feet of Fill on Bottom: ft ft ft after N/A oz. ppm ppm ft * 10000 % ...IL....=... units units units ppg ppg ppg Cgl % Lithology Sst Ls Sh units = 100% Gas In Air WELL NAME: OPERATOR: CONTRACTOR: Nikaitchuq 1 Kerr McGee Corp Nabors N27E BIT Bit Bit Bit Footage TFA # Type Size Hrs 1 MXC1 12.25 41.00 5569 0.900 2 HCM605 8.5" 46.60 5290 0.648 LOCATION: Spy Island AREA: North Slope STATE: Alaska ------------------- · Sperry-Sun Casing Record Company: Kerr McGee Corporation Lease Drilling Services Well Nikaitchuq 1 Area North Slope - Alaska 133/8" CSG 200 ft MD Rig Nabors N27E Job No: AK-AM-0002893102 95/8" 5713 ft MD Waterbased Mud Record Mud Co Baroid Spud Date 16 February 2004 7" Liner TD Date: 1 March 2004 Date Depth Wt Vis PV YP Gels Filt R600/R300 Cake Solids Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft-MD ppg sec Ib/1 00 Ib/1 OOft~ m/30m 32nds 0/0 % % ppm(k) CaH 16-Feb 245 8.9 72 15 32 11/13/14 19.0 62/47 1 0.4 95.5 0.1 0.20 8.9 0 0.1/0.3 48.5 80 Repars/drilling 17-Feb 1234 9.2 68 14 33 11/14/16 8.8 61/47 1 2.2 93.3 1.5 0.3 9.4 1.5 0.1/0.4 51.0 60 Drilling 18-Feb 3233 9.6 61 15 33 12/16/19 7.6 63/48 1 5.8 90.2 1.5 0.3 9.1 5 0.1/0.45 50.0 80 Drilling 19-Feb 5100 9.6 50 16 23 8/15/17 7.2 55/39 1 5.6 90.3 1.0 0.3 8.6 8.0 0.1/0.45 51 80 Drilling 20-Feb 5720 9.55 42 14 19 8/12/16 6.2 47/33 1 4.9 91.3 0.25 0.35 9.0 8.0 0.15/0.45 47.5 100 Drilling/CSG pI. 21-Feb 5720 9.3 43 12 17 5/11/14 6.0 41/29 1 3.1 92.8 0.1 0.35 9.3 8.0 0.2/0.45 49.5 120 22-Feb 5720 9.4 44 16 18 5/13/16 6.4 27/18 1 4.0 92.0 0.5 0.30 9.1 8.0 0.15/0.4 49.5 120 23-Feb 5720 9.5 46 15 20 6/14/1 8 6.8 50/35 1 4.9 91.5 0.5 0.3 9.0 9.0 0.05/0.45 46.0 140 24-Feb 5720 9.2 45 12 22 7/10/13 7.2 46/34 1 1.5 93.2 0.1 0.4 8.9 5.0 0.05/0.45 63.0 120 25-Feb 5720 9.25 43 12 17 4/8/12 7.4 41129 1 2.7 93.0 0.2 0.75 9.5 7.0 0.4/1,2 52.0 120 26-Feb 7495 9.35 46 17 17 4/14/19 6.4 51/34 1 3.5 92.2 0.2 0.4 9.3 8.8 0.210.6 53.0 240 Drilling 27-Feb 8660 10.5 46 22 24 5/19/25 5.0 68/46 1 8.8 87.0 0.2 0.35 9.0 8.0 0.25/0.7 54.0 240 28-Feb 9609 10.55 45 17 18 6/22/27 5.4 52/35 1 9.0 86.5 0.2 0.35 9.1 10.0 0.2/0.65 58.0 260 29-Feb 10730 10.7 44 16 16 7/23/29 5.6 48/32 1 10.5 85.0 0.2 0.3 9.1 12.5 0.2/0.7 59.0 280 1-Mar 11010 10.8 48 17 17 6/17/19 5.0 51/34 1 10.8 84.5 0.2 0.2 8.9 8.8 0.15/0.65 61.5 280 Well at TD 2-Mar 11010 10.8 46 17 17 6/15/18 5.0 51/34 1 10.4 85.0 0.2 0.3 9.2 8.8 0.2/0.65 60.0 240 Wiper trip/logs 3-Mar 11010 10.8 46 18 15 6/14/'18 5.2 51/33 2 10.4 85.0 0.2 0.3 9.2 8.8 0.15/0.7 60.0 320 E-Iog/wiper trip 4-Mar 11010 10.8 46 18 15 6/14/18 5.2 51/33 2 10.4 85.0 0.2 0.3 9.2 8.8 0.15/0.7 60.0 320 W-triptrun liner , , - - - - - - - - - - - - - - - - - - - I I I I I ! i, L! ri I sperry..sun DRILLING SERVICES Show Report Well Name: Location: Operator: Report Prepared By: Report Delivered To: Depth (MD) (TVD) Interpretation: High gas corresponds to Clay Matrix Sandstone in West Sak Formation. Sandstone-fine to medium grain in clay matrix, .Ioose good inferred porosity, slight oil odor, medium to dark brown oil droplets, medium brown stain, overall dull yellow tan fluorescence, 30 0 gravity oil from comparison chart, very fast milky streaming cut fluorescence, medium tan white light cut. Gas ratios from chromatograph of ditch mud and gas trap. Drill pipe connection in middle of lagged gas samples-No ratios for high gas peak. I ppm ppm ppm (Steam Still PPM's in 1000's) Depth # C1 C2 C3 C4 C5 I I AnalysIs n\ias rx), Non-t-'roduclDle HydrocarDons 10.0 Gas ~; d i-;i l1 :1 ¡ -J Mud Chlorides (ppm)::: C1 C1 C4 C1 C5 Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 ::: C lIC5 1000.0 x NPH 100.0 Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 Mud Chlorides (ppm)::: I Jj ~~ of! ~ C3 I C4 C5 ppm ppm ppm (Steam Still PPM's in 1000's) .........-----..----.............--..................................-......--...---...---- - -!!:!:- - "" - -.. ~ 1.0 Oil ------------ NPH 0.1 I pq Non-¡.>roducIDle Hydrocarbons ii I I Hydrocarbon Ratios C1 C1 C4 +' i Mud Chlorides (ppm) ::: C1 ~.. C5 ~. Hydrocarbon Ratios C1/C2 ::: C1/C3 C1/C4 C1/C5 1000,0 l , i ,ß, NPH 100.0 _...-""" ,~-~-~~ I [XI Non-¡.>rOClUClble HydrocarDons Gas t f~ ~ , ; iJ f~ i, 1 I ¡:j C1 , ;'1 C2 C3 I f· C4 ..¡.. C5 I I I Mud Chlorides (ppm) ::: Hydrocarbon Ratios C1/C2 C1/C3 ::: C1/C4 C1/C5 10.0 Oil NPH 1.0 uCIOle HydrocarbOns I I t! ¡~ sperry-sun DRilLING SERVICES Show Report I ff' u Well Name; Location; Operator; Report Prepared By: Report Delivered To: I Depth (MD) (TVD) DatelTìme; ~1 1 ¡ ¡ j . 1 FJ I Interpretation: High gas corresponds to Clay Matrix Sandstone in West Sak Formation. Sandstone-fine to medium grain in clay matrix, good inferred porosity,mild oil odor, medium to dark brown oil droplets, medium brown stain, overall dull yellow tan fluorescence,occ bright yellow pinpoint fluorescence,30-35 0 gravity oil from comparison chart, very fast milky streaming cut fluorescence, medium tan/yellow white light cut. Gas ratios from chromatograph of ditch mud and gas trap. I Chlorides (ppm) '" ...--...----.........--...-------.......--..............................;......----....................- C1 I I Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 '" C1/C5 '" 1 000.0 NPH =-;~~ -;;;"<,~~ --- 100.0 I fl NOn-l-'roaUCIOle Hyarocaroons I I Mud Chlorides (ppm) '" Gas 10.0 ---- Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 '" ClIC5 NPH 1.0 I n Non-I-'roauclole Hyòrocaroons C1 Hydrocarbon Ratios C1 C1 C4 I ppm ppm ppm (Steam Still PPM's in 1000's) C1 C2 C3 C4 C5 I I Mud Chlorides (ppm) '" Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 1000.0 NPH 100.0 I fJ,NOn-l-'rOaUClOle Hyarocaroons Gas Mud Chlorides (ppm) '" -...--............--.....................--...............-.........-......----...... I Hydrocarbon Ratios C1/C2 '" C1/C3 C1/C4 '" ClIC5 10.0 Oil 1"\ Non-I-'roauclole Hyarocaroons NPH 1.0 I I. ~J L2J ¡'f LJ " C1 C5 I I I , , ..,,":: ~ I " '. .4 I I ¡ ; ] i] I I I t:l ~ 1 I.j ¡ ~ I I I :'1 j .~ I " I t ¡- } sperry-sun DRIL.L.ING SERVICES Show Report Well Name: Location: Operator: Report Prepared By: Report Delivered To: '. !~. Depth (MD) (TVD) OatelTime: Interpretation: High gas in sands accompanied by fast streaming yellow flourescence. Ratios indicate gasseous lithologies Loose sand is clear with light brown staining. Depth ¡, V'· "''\\I,\II''''1''r'''''';~''iI'''''''''''f'\''''''"W¡'f:1¡¡¡¡Y'~;~~b~;rlfR~~;~I~~I~'!ffl~'''''~"'-~ f ¡ ~ Ci Ci C1 C4 Mud Chlorides (ppm) '" Hydrocarbon Ratios Ci/C2 '" Ci/C3 '" C1/C4 C1/C5 1000.0 ppm ppm ppm (Steam Still PPM's in 1000's) ------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) I NPH nNOn-l-'rOdUCIDle HydrocarDons -"",- Mud Chlorides (ppm) '" Gas Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 '" C1/C5 '" 10.0 Oil NPH 1.0 fl NOn-l-'roduclDle HydrocarDons -------------------------------------- ppm ppm ppm (Steam Still PPM's in 1000's) 0.00 Mud Chlorides (ppm) '" C1 Hydrocarbon Ratios C1 C1 CS Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/CS '" 1000.0 NPH 100.0 n NOn-l-'rOduCIDle HydrocarDons C1 C2 "i C3 I ~: ;: AnalysIS Ii '. I I Mud Chlorides (ppm) '" ----------------------~------------- Gas Hydrocarbon Ratios C1/C2 '" C1/C3 '" C1/C4 C1/CS 10.0 Oil ----"-"- - - - -'- -.... NPH 1,0 I I tj ri f~ ; 1 sperry-sun ~. DRilliNG SERVICES Show Report Well Name: Location: Operator: Report Prepared By: Report Delivered To: I IJ' !.ti , Depth (MD) (TVD) I Interpretation: High gas in sands accompanied by fast streaming yeliow flourescence, Ratios indicate gasseous lithologies Loose sand is clear with light brown staining. Shows in this last part of the well were contaminated by mud products r f ¡::( I Depth .mF[ôwliñë- ppm ppm ppm (Steam Still PPM's in 1000's) I C1 C2 C3 C4 C5 I I AnalYSIS ~i. W~I"~\~·""'""~~HY~ci;~b(;'~{Iõ;~"~""'I'm~· ~! C1 C1 C1 C1 - - C4 C5 d Chlorides (ppm) '" ......--...-......----...-...---.............--.....................-...... Hydrocarbon Ratios C1/C2 '" C1/C3 '" C1/C4 '" C1/C5 1000,0 -1 " ,¡ ~ ;:; NPH ...... ... 100.0 n Non-proauclt)le Hyarocaroons -"""-,¡¡¡¡¡iI<' r .... -=;~ ;;;"~'iiiÞ Mud Chlorides (ppm) '" Gas .............-......-----...................--......---.........................-------......--............. I C1 C2 C3 C4 C5 I I AnalysIS Depth ppm ppm ppm (Steam Still PPM's in 1000's) I I --------- Hydrocarbon Ratios C1/C2 '" C1/C3 C1/C4 C1/C5 10.0 , i ¡ Oil NPH 1.0 .¢, ~ o! ¡ fl Non-produclOle Hydrocaroons Hydrocarbon Ratios C1 C1 C1 C5 Mud Chlorides (ppm) '" Hydrocarbon Ratios C1/C2 '" C1/C3 C1/C4 '" C1/C5 '" 1000.0 NPH I I Depth I ppm ppm ppm (Steam Still PPM's in 1000's) 100.0 ...-- ......- ------~-_...;;.. -;,,;..::,_:::..:!!!::.~:-~-::..:.::...::;;.,::.:..:"._. _~_~!!!!!L.~~ !Xl Non-prOduCIOle Hyarocamons Mud ChlQrides (ppm) '" Gas ...-- r 11-' .......---...........................................--...--...-...-.........---- Hydrocarbon Ratios C1/C2 C1/C3 C1/C4 C1/C5 10.0 Oil NPH 1.0 I I I Halliburton Sperry-Sun Western North Slope, Kerr McGee Spy Island Nikaitchuq #1 Job No. AKZZ2893103, Surveyed: 1 March, 2004 Survey Report 2 April, 2004 Your Ref: API 500292319300 Surface Coordinates: 6054881.08 N, 519518.28 E (70033' 39.9854H N, 149050' 23.5896H W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Global Coordinates: 916.41 S, 150.75 W (Grid) Surface Coordinates relative to SHL of Nikaitchuq #1: 916.01 S, 153.16 W (True) Kelly Bushing Elevation: 35.94ft above Mean Sea Level !51QE!r-ar-aY-!5Uf1 CRILLING seFt.vlc:es A Halliburton Company DEFINITIVE Survey Ref: svy2069 ------------------- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 0.00 0.000 0.000 -35.94 0.00 0.00 N 0.00 E 6054881.08 N 519518.28 E 0.00 MWD Magnetic - IIFR+MS 323.20 1.740 180.940 287.21 323.15 4.91 S 0.08W 6054876.17 N 519518.21 E 0.538 -4.90 416.41 0.560 186.970 380.40 416.34 6.77 S 0.16W 6054874.31 N 519518.14 E 1.271 -6.77 508.16 2.020 6.130 472.13 508.07 5.61 S 0.04W 6054875.47 N 519518.25 E 2.812 -5.61 574.11 3.960 1.530 537.99 573.93 2.18 S 0.14 E 6054878.90 N 519518.43 E 2.962 -2.18 682.76 7.200 1.070 646.11 682.05 8.38 N 0.37 E 6054889.46 N 519518.63 E 2.982 8.37 773.44 9.230 2.010 735.86 771.80 21.33 N 0.73 E 6054902.42 N 519518.96 E 2.243 21.30 864.96 10.720 359.870 825.99 861.93 37.18 N 0.97 E 6054918.26 N 519519.15 E 1.677 37.14 963.03 12.480 356.470 922.06 958.00 56.88 N 0.30 E 6054937.96 N 519518.43 E 1.925 56.85 1056.49 15.030 355.130 1012.83 1048.77 79.04 N 1.35W 6054960.11 N 519516.72 E 2.749 79.04 1150.44 17.550 355.960 1103.00 1138.94 105.31 N 3.39W 6054986.38 N 519514.62 E 2.694 105.36 1246.39 19.640 356.690 1193.94 1229.88 135.84 N 5.34W 6055016.91 N 519512.59 E 2.192 135.94 1340.83 22.540 357.010 1282.04 1317.98 169.77 N 7.20W 6055050.83 N 519510.64 E 3.073 169.90 1436.96 25.570 356.650 1369.81 1405.75 208.89 N 9.37W 6055089.94 N 519508.36 E 3.156 209.Q7 1531.52 26.680 356.000 1454.71 1490.65 250.44 N 12.04 W 6055131.49 N 519505.58 E 1.212 250.68 1625.78 28.550 355.780 1538.23 1574.17 294.02 N 15.18 W 6055175.05 N 519502.33 E 1.987 294.33 1719.65 30.880 356.810 1619.75 1655.69 340.44 N 18.17 W 6055221.48 N 519499.21 E 2.541 340.82 1812.46 33.160 355.350 1698.44 1734.38 389.53 N 21.55 W 6055270.55 N 519495.70 E 2.594 389.98 1906.46 37.830 355.250 1774.95 1810.89 443.91 N 26.03 W 6055324.92 N 519491.08 E 4.968 444.4 7 2000.50 39.430 354.620 1848.41 1884.35 502.39 N 31.22 W 6055383.38 N 519485.74 E 1.752 503.07 2094.32 41.040 354.310 1920.03 1955.97 562.70 N 37.06 W 6055443.68 N 519479.73 E 1.729 563.52 2186.55 41.020 352.810 1989.60 2025.54 622.86 N 43.85 W 6055503.82 N 519472.79 E 1.068 623.85 2283.03 40.390 353.110 2062.74 2098.68 685.31 N 51.57 W 6055566.25 N 519464.91 E 0.684 686.49 2378.91 41.380 352.090 2135.23 2171.17 747.54 N 59.65 W 6055628.46 N 519456.66 E 1.245 748.92 2470.90 42.370 351.990 2203.73 2239.67 808.35 N 68.16 W 6055689.25 N 519447.99 E 1.079 809.95 2565.44 43.980 352.630 2272.67 2308.61 872.45 N 76.81 W 6055753.33 N 519439.17 E 1.765 874.27 2658.08 43.390 351.620 2339.66 2375.60 935.84 N 85.57 W 6055816.69 N 519430.24 E 0.986 937.87 2751.40 42.520 351.350 2407.96 2443.90 998.72 N 94.99 W 6055879.55 N 519420.66 E 0.953 1001.00 2845.18 40.880 354.170 2477.99 2513.93 1060.59 N 102.87 W 6055941 .40 N 519412.61 E 2.657 1063.07 2940.76 40.140 354.270 2550.65 2586.59 1122.36 N 109.12 W 6056003.15 N 519406.20 E 0.777 1124.99 3036.77 40.580 356.980 2623.82 2659.76 1184.35N 113.86W 6056065.12 N 519401.30 E 1.884 1187.08 3129.11 41 .190 358.470 2693.63 2729.57 1244.74 N 116.25 W 6056125.50 N 519398.75 E 1.246 1247.51 3221.22 42.220 0.000 2762.40 2798.34 1306.01 N 117.06 W 6056186.77 N 519397.78 E 1.572 1308.78 3316.34 42.160 359.880 2832.88 2868.82 1369.89 N 117.13 W 6056250.65 N 519397.54 E 0.106 1372.64 3411.00 41.960 359.830 2903.15 2939.09 1433.30 N 117.29 W 6056314.07 N 519397.21 E 0.214 1436.03 2 April, 2004 - 14:02 ----- - - -- Page 2 of 6 DrillQuest 3.03.06.002 ---------- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 3505.13 41 .480 359.530 2973.41 3009.35 1495.94 N 117.64W 6056376.71 N 519396.70 E 0.552 1498.66 3599.33 41.610 0.610 3043.92 3079.86 1558.41 N 117.56 W 6056439.18 N 519396.61 E 0.773 1561.10 3692.98 40.950 1.690 3114.30 3150.24 1620.18 N 116.33 W 6056500.95 N 519397.68 E 1.037 1622.81 3784.99 40.760 1.410 3183.89 3219.83 1680.35 N 114.70 W 6056561.12 N 519399.15 E 0.287 1682.91 3881.71 40.270 1.050 3257.42 3293.36 1743.17 N 113.35 W 6056623.94 N 519400.34 E 0.561 1745.67 3974.96 41.260 1.770 3328.05 3363.99 1804.04 N 111.85 W 6056684.82 N 519401.68 E 1.175 1806.47 4069.86 41.250 2.060 3399.39 3435.33 1866.58 N 109.76 W 6056747.36 N 519403.61 E 0.202 1868.93 4165.07 40.670 1.590 3471.29 3507.23 1928.96 N 107.77 W 6056809.75 N 519405.43 E 0.690 1931.23 4260.03 40.390 1.160 3543.46 3579.40 1990.65 N 106.28 W 6056871.45 N 519406.75 E 0.417 1992.85 4354.65 41.680 0.620 3614.84 3650.78 2052.76 N 105.32 W 6056933.56 N 519407.55 E 1.414 2054.91 4445.75 41.610 0.790 3682.91 3718.85 2113.30 N 104.58 W 6056994.09 N 519408.13 E 0.146 2115.40 4538.76 41.070 0.980 3752.75 3788.69 2174.72 N 103.63 W 6057055.52 N 519408.92 E 0.596 2176.78 4631.46 40.240 0.540 3823.07 3859.01 2235.11 N 102.83 W 6057115.91 N 519409.56 E 0.947 2237.12 4725.51 41 .250 1.280 3894.32 3930.26 2296.49 N 101.85 W 6057177.29 N 519410.38 E 1.190 2298.44 4819.65 41 .440 0.940 3965.00 4000.94 2358.66 N 100.64 W 6057239.47 N 519411.42 E 0.312 2360.56 4912.36 40.760 0.460 4034.86 4070.80 2419.60 N 99.90 W 6057300.41 N 519412.01 E 0.809 2421.46 5006.54 40.110 359.990 4106.55 4142.49 2480.69 N 99.66 W 6057361.50 N 519412.09 E 0.762 2482.51 5099.47 41 .790 0.380 4176.73 4212.67 2541.59 N 99.46 W 6057422.40 N 519412.13 E 1.829 2543.38 5195.09 41.580 0.580 4248.14 4284.08 2605.18 N 98.92 W 6057485.99 N 519412.49 E 0.260 2606.93 5288.44 40.640 359.420 4318.48 4354.42 2666.55 N 98.92 W 6057547.36 N 519412.34 E 1.297 2668.28 5387.90 39.780 359.220 4394.43 4430.37 2730.76 N 99.68 W 6057611.57 N 519411.41 E 0.874 2732.48 5481.84 40.310 358.940 4466.35 4502.29 2791.19 N 100.65 W 6057672.00 N 519410.27 E 0.596 2792.92 5574.13 39.830 359.010 4536.97 4572.91 2850.59 N 101.71 W 6057731.39 N 519409.06 E 0.522 2852.32 5649.25 39.190 357.690 4594.93 4630.87 2898.36 N 103.09 W 6057779.16 N 519407.56 E 1 .406 2900.11 5745.62 38.850 356.600 4669.80 4705.74 2958.96 N 106.11 W 6057839.75 N 519404.38 E 0.795 2960.77 5840.98 38.240 356.940 4744.39 4780.33 3018.28 N 109.45 W 6057899.06 N 519400.87 E 0.677 3020.17 5934.98 38.010 355.960 4818.33 4854.27 3076.20 N 113.05 W 6057956.98 N 519397.13 E 0.689 3078.17 6029.74 37.490 356.090 4893.26 4929.20 3134.08 N 117.07W 6058014.84 N 519392.95 E 0.555 3136.13 6119.44 36.370 2.750 4964.99 5000.93 3187.90 N 117.65W 6058068.66 N 519392.23 E 4.631 3189.95 6218.18 35.440 2.760 5044.97 5080.91 3245.74 N 114.87 W 6058126.50 N 519394.86 E 0.942 3247.68 6310.58 34.740 1.790 5120.57 5156.51 3298.81 N 112.76 W 6058179.58 N 519396.83 E 0.969 3300.68 6404.40 34.280 0.990 5197.88 5233.82 3351.95 N 111.47W 6058232.72 N 519397.98 E 0.688 3353.76 6498.07 33.820 1.080 5275.49 5311.43 3404.39 N 110.52 W 6058285.16 N 519398.79 E 0.494 3406.15 6591.14 33.360 0.960 5353.02 5388.96 3455.87 N 109.60 W 6058336.65 N 519399.57 E 0.499 3457.58 6687.26 35.000 0.160 5432.54 5468.48 3509.86 N 109.08 W 6058390.64 N 519399.95 E 1.769 3511.54 2 April, 2004 - 14:02 ----- - - -- Page 30f6 - - DrillQuest 3.03.06.002 -------- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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) 6782.25 34.700 1.140 5510.49 5546.43 3564.14 N 108.47 W 6058444.92 N 519400.42 E 0.669 3565.78 6874.26 33.650 0.540 5586.61 5622.55 3615.82 N 107.71 W 6058496.60 N 519401.04 E 1.199 3617.41 6971.46 32.920 358.890 5667.87 5703.81 3669.15 N 107.97 W 6058549.94 N 519400.65 E 1.197 3670.74 7064.28 32.370 358.050 5746.03 5781.97 3719.21 N 109.30 W 6058599.98 N 519399.18 E 0.768 3720.81 7157.26 31.010 356.910 5825.14 5861.08 3768.00 N 111.44W 6058648.77 N 519396.91 E 1.598 3769.64 7251.13 30.400 356.190 5905.85 5941.79 3815.84 N 114.32 W 6058696.61 N 519393.91 E 0.759 3817.55 7345.35 31.480 358.290 5986.67 6022.61 3864.22 N 116.64 W 6058744.98 N 519391.46 E 1.621 3865.97 7439.70 30.410 358.950 6067.59 6103.53 3912.72 N 117.81 W 6058793.48 N 519390.16 E 1.190 3914.49 7533.23 32.500 359.270 6147.37 6183.31 3961.52 N 118.56 W 6058842.28 N 519389.28 E 2.242 3963.29 7626.73 35.880 356.020 6224.70 6260.64 4013.99 N 120.79 W 6058894.74 N 519386.92 E 4.108 4015.80 7721.28 38.060 354.500 6300.24 6336.18 4070.65 N 125.50 W 6058951.39 N 519382.05 E 2.500 4072.57 7814.17 36.510 354.620 6374.15 6410.09 4126.67 N 130.84 W 6059007.39 N 519376.57 E 1.670 4128.71 7908.68 34.990 353.630 6450.85 6486.79 4181.59 N 136.48 W 6059062.30 N 519370.78 E 1.721 4183.78 8004.43 33.720 355.480 6529.89 6565.83 4235.37 N 141.62 W 6059116.07 N 519365.50 E 1.717 4237.68 8099.52 32.270 359.900 6609.66 6645.60 4287.08 N 143.75 W 6059167.77 N 519363.23 E 2.954 4289.43 8191.09 31.540 358.130 6687.39 6723.33 4335.46 N 144.57 W 6059216.15 N 519362.28 E 1.296 4337.81 8286.19 33.870 358.080 6767.41 6803.35 4386.82 N 146.27 W 6059267.50 N 519360.45 E 2.450 4389.19 8378.83 33.330 358.420 6844.57 6880.51 4438.06 N 147.84 W 6059318.73 N 519358.75 E 0.617 4440.46 8473.30 32.340 357.820 6923.95 6959.89 4489.25 N 149.52 W 6059369.92 N 519356.93 E 1.103 4491.68 8569.07 31.190 357.530 7005.37 7041.31 4539.63 N 151.56 W 6059420.29 N 519354.76 E 1.211 4542.09 8663.17 31.290 357.470 7085.83 7121.77 4588.38 N 153.69 W 6059469.04 N 519352.50 E 0.111 4590.89 8756.59 32.340 359.730 7165.22 7201.16 4637.61 N 154.88 W 6059518.27 N 519351.18 E 1.700 4640.13 8852.67 31.510 358.890 7246.76 7282.70 4688.41 N 155.48 W 6059569.07 N 519350.44 E 0.980 4690.93 8944.20 30.510 359.350 7325.21 7361.15 4735.56 N 156.21 W 6059616.21 N 519349.59 E 1.123 4738.08 9036.47 29.540 0.660 7405.10 7441.04 4781.73 N 156.21 W 6059662.38 N 519349.47 E 1.269 4784.23 9130.28 28.320 359.640 7487.20 7523.14 4827.10 N 156.09 W 6059707.76 N 519349.47 E 1 .403 4829.58 9224.04 27.350 359.260 7570.11 7606.05 4870.88 N 156.51 W 6059751.53 N 519348.94 E 1.052 4873.36 9316.88 26.660 359.060 7652.83 7688.77 4913.03 N 157.12 W 6059793.68 N 519348.21 E 0.750 4915.51 9411.75 25.590 1.670 7738.01 7773.95 4954.80 N 156.87 W 6059835.44 N 519348.35 E 1.655 4957.25 9508.86 24.810 4.500 7825.88 7861.82 4996.07 N 154.67 W 6059876.73 N 519350.45 E 1.4 78 4998.45 9600.03 23.600 4.250 7909.03 7944.97 5033.34 N 151.81 W 6059914.01 N 519353.20 E 1.332 5035.62 9693.93 21.900 0.800 7995.63 8031.57 5069.60 N 150.17 W 6059950.27 N 519354.75 E 2.301 5071.82 9789.26 20.650 1.930 8084.46 8120.40 5104.18 N 149.36 W 6059984.85 N 519355.47 E 1.380 5106.36 9887.01 18.520 2.680 8176.55 8212.49 5136.92 N 148.05 W 6060017.59 N 519356.69 E 2.194 5139.05 9978.42 17.070 1.420 8263.58 8299.52 5164.83 N 147.04 W 6060045.51 N 519357.63 E 1.641 5166.93 2 April, 2004 - 14:02 ----- Page 4 of6 ------ Dríl1Quest 3.03.06.002 -------- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 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 Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10073.74 15.800 1.180 8355.01 8390.95 5191.79N 146.43 W 6060072.47 N 519358.17 E 1.334 5193.86 10167.90 14.480 358.470 8445.90 8481.84 5216.38 N 146.48 W 6060097.06 N 519358.06 E 1.590 5218.44 10259.96 13.940 357.280 8535.14 8571.08 5238.96 N 147.31 W 6060119.63 N 519357.16 E 0.667 5241.03 10321.38 13.350 357.830 8594.83 8630.77 5253.44 N 147.93 W 6060134.11 N 519356.51 E 0.984 5255.52 10447.82 12.800 355.390 8717.99 8753.93 5281.99 N 149.61 W 6060162.65 N 519354.75 E 0.616 5284.10 10546.34 11.840 356.530 8814.24 8850.18 5302.95 N 151.10 W 6060183.62 N 519353.21 E 1.005 5305.10 10634.44 10.730 355.330 8900.63 8936.57 5320.15 N 152.31 W 6060200.81 N 519351.95 E 1.288 5322.33 10729.67 9.740 354.110 8994.35 9030.29 5337.00 N 153.86 W 6060217.65 N 519350.35 E 1.064 5339.21 10824.42 9.360 352.360 9087.78 9123.72 5352.61 N 155.71 W 6060233.26 N 519348.47 E 0.505 5354.87 10916.31 9.390 351.370 9178.45 9214.39 5367.42 N 157.83 W 6060248.07 N 519346.31 E 0.179 5369.74 11010.00 9.390 351.370 9270.88 9306.82 5382.54 N 160.12W 6060263.18 N 519343.98 E 0.000 5384.91 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 @ 35.94' MSL. Northings and Eastings are relative to 404' FSL, 1336' FWL. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from 404' FSL, 1336' FWL and calculated along an Azimuth of 358.390° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1101 O.OOft., The Bottom Hole Displacement is 5384.92ft., in the Direction of 358.296° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~) ~) Comment 11010.00 9306.82 5382.54 N 160.12 W Projected Survey - 2 April, 2004 - 14:02 - -- - - - - - Page 50f6 - - - - - - - DrillQuest 3.03.06.002 - -- Halliburton Sperry-Sun Survey Report for Spy Island - Nikaitchuq #1 Your Ref: API 500292319300 Job No. AKZZ2893103, Surveyed: 1 March, 2004 Western North Slope, Kerr McGee Survey tool program for Nikaitchuq #1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 11010.00 9306.82 MWD Magnetic - IIFR+MS 2 April, 2004 - 14:02 ----- Page 6 of 6 DrillQuest 3.03.06.002 -------------- 10000.00 11000.00 12000.00 I Tue 17 Wed 18 Thu 19 Fri 20 Sat 21 Sun 22 Man 23 Tue 24 Wed 25 Thu 26 Fri 27 Sat 28 Sun 29 Man 01 Ti me & Date . ---. - - - - - - - - - - - - - - - - - - - 8000.00 -: 4000.00 1000.00 3000.00 -" 2000.00 7000.00 6000.00 - 5000.00 - ~~\~ '\,...... "'* . "':<... , ~ ~ "..,.~ .'"". " :¡ * ¡ ~ 0.00 ft I I I I I I I I I I I I I I I I I I I NIKAITCHUQ #1 ASCII LITHOLOGY DATA Depth % 1 00 1 00 150 100 180 50 180 50 210 40 210 50 210 10 240 40 240 50 240 10 270 30 270 60 270 1 0 300 10 300 50 300 40 w/cly 330 330 330 360 360 360 390 glac 390 30 390 50 420 30 420 45 420 25 450 20 450 65 450 15 480 20 cly, tr glac 480 60 CLAY 480 20 GRAVEL 510 20 SAND 510 55 CLAY 510 25 GRAVEL 570 20 SAND 570 55 CLAY 570 25 GRAVEL 580 20 SAN D 580 55 CLAY 580 25 GRAVEL Med - dk gry, It - dk brn, occ wh, sm- med pea sz, occ Ig pea SZ, sb rnd - sb ang, occ rnd-ang, qtz, cht peb ip, intbd wI cly 630 35 SAN D 630 30 CLAY 630 35 GRAVEL 660 40 SAND clr, gry, varicolor,f-cgr, sbang-sbrnd,msrt, uncons, intbd w. cly 660 10 GRAVEL 660 50 CLAY 20 70 10 25 60 15 20 Lithology o o SAND gry, clr, wh, vf-cgr. sbang, intbd+intmx wI cly CLAY SAND CLAY m gry, amorph, stky, gmmy, sft. GRAVEL SAND CLAY G RAVEL SAND gry, clr, wh, blk, cgr. sbang-rnd, intbd+intmx wI cly CLAY GRAVEL SAND CLAY GRAVEL Description blk, dk gry, clr, wh, med-Ig pea sz, rnd-ang, qtz, cht peb, intbd SAND CLAY m gry, amorph, stky, gmmy, slty, sft. GRAVEL SAND CLAY GRAVEL SAND clrss - clr, gry, wh, It grn, blk, fn - cgr. sbang-rnd, intbd+intmx wI cly, tr CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND It gry - gry, clr, off wh - wh, ace It grn blk, cgr, occ fn, sbang-rnd, intbd wI I I I I I I I I I I I I I I I I I I I 690 720 720 750 750 750 780 intbds 780 65 CLAY 780 10 GRAVEL 810 15 SAND 810 80 CLAY 810 5 GRAVEL 840 10 SAND 840 80 CLAY It gyr-gry, gmmy, stky, intbd+intmx wI sd+gvl ,sft 840 10 GRAVEL 870 15 SAND blk, clr, gry, bf, c-vcgr,sbrnd, msrt, uncons, tr coal frags, incr cly intbds 870 80 CLAY 870 5 GRAVEL 900 35 SAND 900 60 CLAY 900 5 GRAVEL 930 30 SAND 930 65 CLAY 930 5 GRAVEL 960 30 SAN D 960 50 CLAY 960 20 GRAVEL 990 40 SAN D 990 50 CLAY 990 10 GRAVEL 1020 40 SAND 1020 50 CLAY It gyr-gry, amorph, ace It brn, v gmmy, stky, intmx wI sd ,sft 1020 10 GRAVEL 1050 20 SAND 1050 60 CLAY 1050 20 GRAVEL 1080 20 SAND 1080 50 CLAY 1080 30 GRAVEL 1103 20 SAND clrss - clr, blk, It gry - gry, c-vcgr, ace f - v fn, sbrnd - sbang, msrt, p srt ip, uncons, tr coal frags 1103 50 CLAY 1103 30 GRAVEL 1110 25 SAN D 1110 45 CLAY 1110 30 GRAVEL 1140 30 SAND 1140 60 CLAY 1140 10 GRAVEL 1170 35 SAND 1170 50 CLAY 1170 15 GRAVEL 1180 35 SAN D 1180 50 CLAY 1180 15 GRAVEL 100 40 60 35 60 5 25 o SAND CLAY It gyr-gry, gmmy, stky, intbd+intmx wI sd+gvl ,sft SAND CLAY G RAVEL SAND blk, clr, gry, bf, f-mgr,sbang, msrt, uncons, sme f-mgr coal frags, incr cly gry, blk, varic, Ig pea sz, rnd-ang,intbd wI cly, qtz, cht frags I I I I I I I I I I I I I I I I I I I 1200 50 1200 30 1200 20 frags, tr pyr 1230 40 SAND 1230 40 CLAY 1230 20 GRAVEL 1260 35 SAND 1260 50 CLAY It gyr-gry, ace It brn, amarph, v gmmy, stky, intmx wi sd ,sft - v sft 1260 15 GRAVEL 1290 45 SAND 1290 45 CLAY 1290 10 GRAVEL 1320 30 SAND 1320 60 CLAY 1320 10 GRAVEL 1350 25 SAND Clrss - clr, ace blk, occ It grn, occ gry, f -med grn ,sbrnd, occ rnd, msrt, w srt ip, uncons, com coal frags 1350 65 CLAY 1350 10 GRAVEL 1380 25 SAND 1380 60 CLAY 1380 15 GRAVEL 1410 35 SAND 1410 55 CLAY 1410 10 GRAVEL 1470 30 SAND 1470 65 CLAY It gyr-gry, amoprh, v gmmy, stky, com pyr intmx wi sd ,v sft 1470 5 GRAVEL 1500 50 SAND 1500 45 CLAY 1500 5 GRAVEL 1530 35 SAND Clrss - clr, ace blk, f -med grn ,sb ang - sbrnd, occ rnd, sb sph - sph, msrt, p srt ip, uncons, tr caal frags camm pyr 1530 60 CLAY 1530 5 GRAVEL 1560 40 SAND 1560 55 CLAY 1560 5 GRAVEL 1590 30 SAND 1590 65 CLAY 1590 5 GRAVEL 1620 25 SAND 1620 65 CLAY 1620 10 GRAVEL 1650 40 SAND 1650 55 CLAY 1650 5 GRAVEL 1670 40 SAND 1670 55 CLAY 1670 5 GRAVEL med - dk gry, ace It brn, occ blk, varic, sm - med pea sz, occ Ig pea sz, sub ang - sb rnd, intmx wi cly, com nod pyr 1680 35 SAND 1680 50 CLAY 1680 15 GRAVEL 1710 30 SAND SAND CLAY GRAVEL gry, blk, varic, sm - med pea sz, rnd-ang,intbd wi cly, qtz, tr cht 1710 1710 1740 1740 1740 1770 1770 1770 1800 1800 1800 1830 1830 1830 1860 1860 1860 1870 1870 1870 1920 1920 1920 1950 1950 1950 1960 1960 frags 1960 10 GRAVEL 1980 50 SAND 1980 40 CLAY 1980 10 GRAVEL 2010 50 SAND 2010 40 CLAY 2010 10 GRAVEL 2070 50 SAN D 2070 40 CLAY 2070 10 GRAVEL 2100 45 SAND 2100 45 CLAY 2100 10 GRAVEL 2120 45 SAND 2120 45 CLAY 2120 10 GRAVEL 2125 45 SAND Clrss - clr, occ blk, ace gry, f -med grn, occ crse grn ,sbrnd, ace rnd, msrt, uncons, com coal frags 2125 45 CLAY 2125 10 GRAVEL 2160 30 SAND 2160 65 CLAY 2160 5 GRAVEL 2190 30 SAND 2190 60 CLAY 2190 10 GRAVEL 2220 35 SAN D I I I I I I I I I I I I I I I I I I I 60 10 40 55 5 30 65 5 50 45 5 45 45 10 45 50 5 45 50 5 55 40 5 55 35 10 55 35 CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY GRAVEL SAND CLAY It gyr-gry, occ It brn - brn, amorph, v gmmy, stky, intbd+intmx wi sd ,sft GRAVEL SAND CLAY GRAVEL SAND CLAY G RAVEL SAND CLAY G RAVEL SAND CLAY G RAVEL SAND CLAY G RAVEL SAND CLAY It gyr-gry, occ brn, gmmy, stky, intbd+intmx wi sd ,sft, tr coal, tr wood It - med gry, blk, varic, Ig pea SZ, sb rnd-ang,intbd wi cly I I I I I I I I I I I I I I I I I I I 2220 2220 2240 2240 tr coal 2240 5 2250 45 2250 45 2250 10 2280 45 2280 50 2280 5 2310 30 NSOFC 2310 69 CLAY 2310 1 GRAVEL 2340 20 SAN D 2340 79 CLAY It gry-gry, gmmy, stky, intbd+intmx wi sd ,sft 2340 1 G RAVEL 2370 20 SAN D 2370 70 CLAY 2370 10 GRAVEL 2400 20 SAND clr,dk gry, occ blk, f -med grn, tr crse grn ,sbrnd, occ rnd, msrt, uncons, tr coal frags NSOFC 2400 79 CLAY 2400 1 G RAVEL 2430 20 SAN D 2430 79 CLAY 2430 1 G RAVEL 2460 10 SAND 2460 89 CLAY It gry-gry, gmmy, stky,incr slty sme frm,sft 2460 1 GRAVEL 2490 50 SAN D 2490 49 CLAY 2490 1 GRAVEL 2520 40 SAN D 2520 59 CLAY 2520 1 GRAVEL 2550 20 SAN D 2550 55 CLAY 2550 25 0 2580 20 SAN D 2580 70 CLAY 2580 1 0 0 2610 10 SAND 2610 88 CLAY It gry-gry, gmmy, stky,incr slty, gdg to sltst ip, sme frm,sft 2610 2 0 2640 10 SAND 2640 80 CLAY 2640 5 0 blk, dk brn, woody, crumbly 2640 5 GRAVEL 2670 15 SAND 2670 70 CLAY 2670 10 0 2670 5 GRAVEL 2700 15 SAND 60 5 35 60 CLAY GRAVEL SAND CLAY It gyr-gry, brn, amorph, gmmy, stky, intbd+intmx wi sd ,sft, tr wood frag, GRAVEL SAND CLAY G RAVEL SAND CLAY G RAVEL SAND clr,dk gry, occ blk, f -med grn, tr crse grn ,sbrnd, occ rnd, msrt, uncons, blk, dk brn, woody ip, tr pyr, hd I I I I I I I I I I I I I I I I I I I 2700 70 2700 5 2700 10 2730 20 2730 65 2730 10 2730 5 2760 10 2760 84 2760 5 2760 1 2790 5 2790 89 2790 5 2790 1 2820 5 2820 93 2820 1 2820 1 2850 40 2850 55 2850 4 2850 1 2880 45 2880 50 2880 4 2880 1 2910 40 2910 48 2910 2 2910 10 2940 40 2940 40 2940 10 2940 10 2970 10 2970 80 2970 5 2970 5 3000 38 3000 60 3000 1 3000 1 3030 60 3030 38 3030 1 3030 1 3060 60 3060 38 3060 1 3060 1 3090 40 3090 58 3090 1 3090 1 3120 25 CLAY It gry-gry, gmmy, stky,v slty, gdg to sltst ip,sft o GRAVEL SAND CLAY o GRAVEL SAND CLAY It gry-gry, gmmy, stky,v slty, incr hyd,sft o G RAVEL SAND CLAY o GRAVEL SAND CLAY o G RAVEL SAND clr, gry, m-vcgr, ang-sbang, msrt, uncons, qtz, tr pyr, tr lig, NSOFC CLAY o G RAVEL SAND CLAY o GRAVEL SAND CLAY It gry-gry, gmmy, stky,v slty, incr hyd, intbd wi sd,sft o GRAVEL SAND CLAY o blk, dk brn,v woody, grdg to coal, crumbly-hd GRAVEL SAND CLAY o GRAVEL SAND CLAY o GRAVEL SAND clr, gry, blk, m-vcgr, ang-sbang, msrt, uncons, qtz, tr pyr, tr lig, NSOFC CLAY o GRAVEL SAND CLAY o GRAVEL SAND CLAY o G RAVEL SAND 3120 69 3120 5 3120 1 3150 70 frags, NSOFC 3150 28 3150 1 3150 1 3180 60 3180 38 3180 1 3180 1 3210 40 NSOFC 3210 54 CLAY 3210 1 0 3210 5 GRAVEL 3240 35 SAN D 3240 59 CLAY 3240 1 0 3240 5 GRAVEL 3270 50 SAN D 3270 44 CLAY It gry-gry, occ off wh, gmmy, stky,occ v slty, incr hyd, intbd wI sd, v sft 3270 1 0 3270 5 GRAVEL 3300 74 SAND 3300 25 CLAY 3300 1 GRAVEL 3330 60 SAN D 3330 25 CLAY 3330 15 0 3360 50 SAND 3360 40 CLAY 3360 10 0 3370 50 SAN D 3370 40 CLAY 3370 10 0 3390 60 SAN D 3390 35 CLAY 3390 5 0 3420 45 SAN D 3420 45 CLAY 3420 10 0 3450 30 SAND clrss - clr, occ It - med wh gry, blk ip, mad grn, occ vcgr, ang-sbang, occ sb rnd - rnd msrt, uncons, qtz, tr pyr, tr coal frags, tr wood frag, NSOFC 3450 29 CLAY 3450 40 0 3450 1 GRAVEL 3480 45 SAN D 3480 45 CLAY 3480 10 0 3510 30 SAND 3510 60 CLAY 3510 10 0 3540 25 SAN D 3540 65 CLAY I I I I I I I I I I I I I I I I I I I CLAY o GRAVEL SAND clr, gry, blk ip, pred cgr, ang-sbang, msrt, uncons, qtz, tr pyr, tr coal CLAY o G RAVEL SAND CLAY o GRAVEL SAND clr, gry, blk ip, vcgr, ang-sbang, msrt, uncons, qtz, tr pyr, tr coal frags, blk, sb blky - blky, occ sb ang, intmx Iw snd and clay, frm - hd I I I I I I I I I I I I I I I I I I I 3540 10 3570 20 3570 70 3570 10 3600 40 3600 50 3600 10 3630 38 3630 50 3630 2 3630 10 3660 49 3660 49 3660 1 3660 1 3690 49 NSOFC 3690 49 3690 1 3690 1 3720 69 3720 25 3720 1 3720 5 3750 59 wI cly, NSOFC 3750 35 3750 1 3750 5 3780 80 3780 18 3780 1 3780 1 3810 80 NSOFC 3810 18 3810 1 3810 1 3840 70 3840 19 3840 1 3840 10 3870 80 NSOFC 3870 18 3870 1 3870 1 3900 28 3900 70 3900 1 3900 1 3930 49 3930 49 3930 1 3930 1 3960 29 o SAND CLAY o blk, occ dk brn, v woody ip, grdg to coal, fr - hd, crmbly where woody SAND CLAY o SAND clr, gry, blk, c-vcgr, ang-sbang, msrt, uncons, qtz,tr coal frags, NSOFC CLAY o GRAVEL SAND CLAY o GRAVEL SAND clr, gry, blk, c-vcgr, ang-sbang, msrt, uncons, qtz, intbd+intmx wI cly, CLAY o GRAVEL SAND CLAY o GRAVEL SAND clr,transl, gry, blk, c-vcgr, ang-sbang, msrt, uncons, qtz,decr intbd+intmx CLAY o GRAVEL SAND CLAY o GRAVEL SAND clr,transl, gry, blk ip, m-cgr, sbang-sbrnd, wsrt, uncons, qtz,sme cly mtx, CLAY o GRAVEL SAND CLAY o GRAVEL SAND clr,transl, gry, blk ip, m-cgr, sbang-sbrnd, wsrt, uncons, qtz,sme cly mtx, CLAY o GRAVEL SAND CLAY It gry-gry, gmmy, stky, slty, incr hyd, grdg to sltst ip,sft-frm ip o GRAVEL SAND CLAY o GRAVEL SAND I I I I I I I I I I I I I I I I I I I 3960 69 3960 1 3960 1 3990 9 3990 89 3990 1 3990 1 4020 4 4020 94 4020 1 4020 1 4050 24 4050 70 4050 1 4050 5 4080 10 NSOFC 4080 80 4080 1 4080 9 4110 10 4110 87 4110 1 4110 2 4140 1 0 4140 88 4140 1 4140 1 4170 20 4170 78 4170 1 4170 1 4200 20 NSOFC 4200 78 4200 1 4200 1 4230 20 4230 78 4230 1 4230 1 4260 10 4260 80 4260 1 4260 9 4290 15 mtx, NSOFC 4290 75 4290 1 4290 9 4320 1 0 4320 80 4320 1 4320 9 4350 8 4350 90 CLA Y It gry-gry, gmmy,incr slty, incr, grdg to SL TST ip,sft-frm o GRAVEL SAND CLAY o GRA VEL SAND CLAY It gry-gry, gmmy,sli slty, grdg to clyst ip,sft-frm o GRAVEL SAND CLAY o GRAVEL SAND clr, gry, blk ip, vc-cgr,sm mgr, ang-rnd, psrt, uncons, qtz,gvl frags, CLAY o GRAVEL SAND CLAY o G RAVEL SAND CLAY It gry-gry, gmmy,sli slty, grdg to clyst ip,sft-frm o GRAVEL SAND CLAY o GRAVEL SAND clr, gry, blk ip, vcgr, ang-sbang, psrt, uncons, qtz,gvl frags,abnt cly mtx, CLAY o GRAVEL SAND CLAY It gry-gry, gmmy,incr slty,sme brn\blk carb mtl, sft-frm o GRAVEL SAND CLAY o GRAVEL SAND clr, gry, blk ¡p, vcgr, ang-sbang, psrt, uncons, qtz,sme gvl frags,abnt cly CLAY o GRAVEL SAND CLAY o GRAVEL SAND CLAY I I I I I I I I I I I I I I I I I I I 4350 0 4350 GRAVEL 4380 50 SAND blk, gry, brn ip,clr, cgr-xsm pea, ang-sbang, psrt, uncons,cht, qtz,mod amt coal frags,sme sft carb mtl,tr pyr, NSOFC 4380 30 4380 15 4380 5 4410 50 4410 30 4410 15 4410 5 4440 30 NSOFC 4440 60 4440 5 4440 5 4470 20 4470 70 4470 5 4470 5 4500 40 NSOFC 4500 50 4500 5 4500 5 4530 50 4530 40 4530 5 4530 5 4560 20 4560 70 4560 5 4560 5 4590 25 4590 60 4590 1 0 4590 5 4620 20 4620 64 4620 15 4620 1 4650 50 NSOFC 4650 44 4650 5 4650 1 4680 55 4680 39 4680 5 4680 1 4710 45 4710 49 4710 5 4710 1 4740 25 4740 60 CLAY o GRAVEL SAND CLAY o GRAVEL SAND blk, gry, brn ip,clr, cgr-vcgr ang-sbang, psrt, uncons, qtz, in abnt cly mtx, CLAY o G RAVEL SAND CLAY o GRAVEL SAND blk, gry, brn ip,clr, cgr-vcgr ang-sbang, psrt, uncons, qtz, in abnt cly mtx, CLAY o GRAVEL SAND CLAY o GRAVEL SAND CLAY It gry-gry, gmmy,incr stky,tr brn\blk carb mtl,sdy intbds, sft-frm o G RAVEL SAND CLAY o GRAVEL SAND CLAY o GRAVEL SAND blk, gry, brn ip,clr, cgr-vcgr ang-sbang, psrt, uncons, qtz, in abnt cly mtx, CLAY o GRAVEL SAND CLAY o GRAVEL SAND CLAY o GRAVEL SAND CLAY I I I I I I I I I I I I I I I I I I I 4740 10 0 4740 5 GRAVEL 4770 25 SAND 4770 65 CLAY It gry-gry, gmmy,incr stky,tr brn\blk carb mtl,sdy intbds, sft-frm 4770 5 0 4770 5 GRAVEL 4800 35 SAN D 4800 59 CLAY 4800 5 0 4800 1 GRAVEL 4830 40 SAND clr, Itgry, Itbrn ip,f-mgr, ace cgr, ang-sbang, psrt, uncons, qtz,glauc,tr pyr, in abnt cly mtx, slty , Ise, gd infer per, sli 0 od, m-dk brn 0 droplets, mbrn stn, overall dl yel-tn fluor, 30 grav 0, v fst mlky strmg ct fluor, mtn wh It ct 4830 58 CLAY 4830 1 0 4830 1 GRAVEL 4860 45 SAND 4860 49 CLAY 4860 5 0 4860 1 GRAVEL 4920 25 SAND 4920 69 CLAY 4920 5 0 4920 1 GRAVEL 4950 25 SAN D 4950 73 CLAY 4950 1 0 4950 1 GRAVEL 4980 35 SAND 4980 63 CLAY It gry-gry, gmmy, amorph, sl stky,tr brn\blk carb mtl,sdy intbds, slty , v slty ip 4980 1 0 4980 1 GRAVEL 5010 15 SAND 5010 83 CLAY 5010 1 0 5010 1 GRAVEL 5040 40 SAN D 5040 58 CLAY 5040 1 0 5040 1 GRAVEL 5070 30 SAND clr, Itgry, Itbrn ip,f-mgr, ang-sbang, psrt, uncons, qtz,glauc,tr pyr, in abnt cly mtx, slty, mod gd infer por, sli a ad, m-dk brn,occ It brn, 0 droplets, mbrn stn, overall dl yel-tn fluor, occ bright yellow pin point flar, 30 - 35 grav 0, v fst mlky strmg ct fluor, It tn wh It ct 5070 68 CLAY 5070 1 0 5070 1 GRAVEL 5100 30 SAND 5100 68 CLAY 5100 1 0 5100 1 GRAVEL 5130 35 SAND 5130 59 CLAY 5130 5 0 5130 1 GRAVEL 5190 15 SAND I I 5190 79 CLAY I 5190 5 0 5190 1 GRAVEL 5220 10 SAND 5220 89 CLAY It gry-gry, gmmy,incr stky,tr brn\blk carb mtl,sdy intbds, sft-frm I 5220 1 0 5250 10 SAND 5250 60 CLAY I 5250 30 SILTSTONE 5280 5 SAND 5280 60 CLAY 5280 35 SILTSTONE It gry - gry, amorph, ace sub blky, non cal, tr pyr, tr carb spks, I sft, occ frm 5310 5 SAND 5310 55 CLAY I 5310 40 SILTSTONE 5340 5 SAND 5340 50 CLAY 5340 45 SILTSTONE I 5370 5 SAND 5370 45 CLAY It gry-gry, sl gmmy, sl stky,tr brn\blk carb mtl, rr sdy intbds, sft, grdng to sit I 5370 50 SILTSTONE 5400 5 SAND 5400 40 CLAY 5400 55 SILTSTONE I 5430 5 SAND 5430 40 CLAY 5430 55 SILTSTONE 5460 5 SAND I 5460 45 CLAY 5460 50 SILTSTONE It - mad gry, occ vlt brn, amph, occ crmbly, non cal, tr pyr, tr carb mat, sft I 5490 5 SAND 5490 60 CLAY 5490 35 SILTSTONE 5520 1 SAND I 5520 55 CLAY It gry-gry, gmmy,incr stky,tr brn\blk carb mtl,sdy intbds, sft-frm 5520 44 SILTSTONE 5560 1 SAND I 5560 55 CLAY 5560 44 SILTSTONE 5580 1 SAND 5580 55 CLAY I 5580 44 SILTSTONE 5610 5 SAND 5610 60 CLAY I 5610 35 SILTSTONE It -mad grn gry, amph, rr crmbly, non cal , com pyr, com carb mat, v sft 5640 1 SAND 5640 54 CLAY I 5640 45 SILTSTONE 5670 1 SAND 5670 64 CLAY I 5670 35 SILTSTONE 5700 1 SAND I 5700 64 5700 35 5720 1 5720 60 5720 39 5750 40 5750 59 frag, sft - v sft 5750 1 SAND 5780 50 CLAY 5780 49 SILTSTONE 5780 1 SAN D 5810 40 CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr frm 5810 55 SILTSTONE 5810 5 SAND 5840 35 CLAY 5840 64 SILTSTONE 5840 1 SAN D 5870 30 CLAY 5870 60 SILTSTONE 5870 10 SAND 5900 25 CLAY 5900 65 SILTSTONE 5900 10 SAND clrss - clr, acc It gry, v fn, occ med grn, sub ang - sub rnd, occ rnd, mod srt, Ise, intmx wi clay and sit 5930 20 CLAY 5930 70 SILTSTONE 5930 10 SAND 5960 25 CLAY 5960 70 SILTSTONE 5960 5 SAND 5990 25 CLAY 5990 60 SILTSTONE 5990 15 SAND clrss - clr, acc It gry, v fn, acc f grn, sub ang - ang, occ sb rnd, p-mod srt, Ise, intmx wi clay and sit 6020 25 CLAY 6020 60 SILTSTONE 6020 15 SAND clrss - clr, acc It gry, v fn, occ f grn, sub ang - ang, occ sb rnd, p-mod srt, Ise, intmx wi clay and sit 6050 20 CLAY 6050 60 SILTSTONE 6050 20 SAND 6080 20 CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr frm 6080 60 SILTSTONE 6080 20 SAN D 6110 20 CLAY 6110 60 SILTSTONE frag, sft - v sft 6110 20 6140 20 6140 70 6140 10 6170 20 6170 70 6170 10 6200 20 I I I I I I I I I I I I I I I I I I I CLAY SILTSTONE SAND CLAY SILTSTONE CLAY SILTSTONE Lt - med gry, acc It - med brn, amph, non cal, com pyr, tr carb Lt - med gry, acc It - med brn, amph, non cal, com pyr, tr carb SAND CLAY SILTSTONE SAND CLAY SILTSTONE SAND CLAY 6200 70 6200 10 6230 20 6230 70 trag, sft - v sft 6230 10 6260 20 6260 70 6260 10 6290 20 6290 70 6290 1 0 6320 20 6320 70 6320 1 0 6350 20 6350 60 trag, sft - v sft 6350 20 SAN D 6380 20 CLAY 6380 60 SILTSTONE 6380 20 SAN D 6410 15 CLAY 6410 60 SILTSTONE 6410 25 SAND 6440 10 CLAY 6440 80 SILTSTONE 6440 10 SAND clrss - clr, occ It gry, v tn, occ t grn, sub ang - ang, occ sb rnd, p-mod srt, Ise, intmx wI clay and sit 6470 30 CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr trm 6470 60 SILTSTONE 6470 10 SAND 6500 30 CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr trm bee shly i/p 6500 60 trag, sft - v sft 6500 10 6530 30 6530 60 6530 10 6560 30 6560 60 6560 10 6590 30 6590 60 6590 10 6620 30 6620 60 trag, sft - v sft 6620 10 6650 30 6650 60 6650 10 6680 40 i/p 6680 50 I I I I I I I I I I I I I I I I I I I SILTSTONE SAND CLAY SILTSTONE Lt - med gry, occ It - med brn, amph, non cal, com pyr, tr carb SAND CLAY SILTSTONE SAND CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr trm SILTSTONE SAND CLAY SILTSTONE SAND CLAY SILTSTONE Lt - med gry, ace It - med brn, amph, non cal, com pyr, tr carb SILTSTONE Lt - med gry, occ It - med brn, amph, non cal, com pyr, tr carb SAND CLAY SILTSTONE SAND CLAY SILTSTONE SAND CLAY SILTSTONE SAND CLAY SILTSTONE Lt - med gry, occ It - med brn, amph, non cal, com pyr, tr carb SAND CLAY SILTSTONE SAND CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr trm sl shly SILTSTONE I I I I I I I I I I I I I I I I I I I 6680 10 SAND 6710 30 CLAY Lt gry brn - gry brn, gmmy, skly, com carb mat, sndy ip, sft, rr trm sl shly i/p 6710 65 SILTSTONE 6710 5 SAND 6740 30 CLAY 6740 65 SILTSTONE 6740 5 SAND 6770 30 CLAY 6770 65 SILTSTONE Lt - mad gry occ dk gry, occ It - mad brn, amph, non cal, com pyr, tr carb trag, sft - v sft 6770 5 SAN D 6800 30 CLAY 6800 60 SILTSTONE 6800 10 SAND 6830 20 CLAY 6830 80 SILTSTONE 6860 20 CLAY 6860 80 SILTSTONE 6890 20 CLAY 6890 80 SILTSTONE 6920 20 CLAY 6920 80 SILTSTONE Lt - mad gry occ dk gry, occ It - mad brn, amph, non cal, com pyr, tr carb trag, sft - v sft 6950 10 CLAY 6950 90 SILTSTONE 6980 5 CLAY 6980 95 SILTSTONE 7010 100 SILTSTONE 7040 1 00 SILTSTONE : Lt-mad gry, occ dk gry, amorph, non calc, occ tr pyr, rar carb trag, sft-v sft 7070 1 00 SILTSTONE 7100 1 00 SILTSTONE Lt gry, occ mad gry, occ vlt brn, amph, acc cmbly, non cal, tr - com pyr, com carb mat, vsft, occ sft, rr trm 7130 1 00 SILTSTONE 7160 1 00 SILTSTONE Lt gry - mad gry, amorph, occ cmbly, non cal, tr pyr, tr carb mat, sft 7220 1 00 SILTSTONE 7250 1 00 SILTSTONE Lt brn gry - med gry, sb blky - sb ang, occ amph, non cal, tr pyr, com carb mat, trm, occ sft, rr hard 7280 1 00 SILTSTONE 7310 1 00 SILTSTONE 7340 1 00 SILTSTONE 7370 100 SILTSTONE 7400 100 SILTSTONE 7430 100 SILTSTONE Lt- mad gry, sub blky- ang, com carb mat, sft- trm 7460 90 SILTSTONE 7460 10 SAND 7490 85 SILTSTONE 7490 15 SAND 7520 95 SILTSTONE 7520 5 SAN D 7550 95 SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- trm 7550 5 SAN D 7580 90 SILTSTONE 7580 10 SAND I I I I I I I I I I I I I I I I I I I 7610 90 7610 10 7640 95 7640 5 7670 95 7670 5 7700 85 7700 15 7730 80 7730 20 7760 85 7760 15 7790 90 7790 1 0 carb mat 7820 90 7820 1 0 7850 90 hd 7850 10 7880 90 7880 10 7910 95 7910 5 7940 95 7940 5 7970 95 7970 5 8000 95 8000 5 8030 95 8030 5 8060 95 8060 5 8090 95 8090 5 8120 95 8120 5 carb mat 8150 85 8150 5 8150 10 8180 85 8180 5 8180 10 8210 85 8210 5 8210 10 8240 90 8240 10 8270 90 8270 10 8300 90 8300 10 8330 90 8330 10 SILTSTONE SAND SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- frm SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE SAND clrss- clr, occ off wh, vf gr, occ f gr, sub rnd- rnd, occ ang, msrt, Ise, tr SILTSTONE SAND SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- frm, occ SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- frm SAND SILTSTONE SAND SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- frm SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE SAND SILTSTONE SAND clrss- clr, occ off wh, vf gr, occ f gr, sub rnd- rnd, occ ang, msrt, Ise, tr SILTSTONE SAND CLAY SILTSTONE SAND CLAY Lt-med gy, occ dk gry, non calc, sft-occ frm, grds to sltst SILTSTONE SAND CLAY SILTSTONE CLAY SILTSTONE Lt- mad gry, sma blk, sub blky- ang, com carb mat, sft- frm CLAY SILTSTONE CLAY SILTSTONE CLAY I I Lt- med gry, sme blk, sub blky- ang, com carb mat, sft- frm 8360 90 SILTSTONE I 8360 10 CLAY 8390 90 SILTSTONE 8390 10 CLAY 8420 90 SILTSTONE I 8420 5 CLAY 8420 5 SAND 8450 90 SILTSTONE I 8450 5 CLAY 8450 5 SAND 8480 90 SILTSTONE Lt gry- blk, sub blky- ang, com carb mat, sft- frm, hd ip 8480 5 CLAY I 8480 5 SAND 8510 90 SILTSTONE 8510 5 CLAY 8510 5 SAND I 8540 90 SILTSTONE Lt- m gry, blk ip, sub blky- ang, com carb mat, sft- frm, occ hd 8540 10 CLAY 8570 85 SILTSTONE I 8570 15 CLAY 8600 85 SILTSTONE Lt- m gry, blky- ang, com carb mat, sft- frm 8600 15 CLAY 8630 85 SILTSTONE I 8630 10 CLAY 8630 5 SAND 8660 80 SILTSTONE Lt- m gry, blky- ang, com carb mat, sft- frm I 8660 10 CLAY 8660 5 SAND 8660 5 SHALE 8690 65 SILTSTONE I 8690 20 CLAY 8690 15 SHALE 8720 55 SILTSTONE Lt- dk brn, amor- ang, com carb mat, sft- frm, occ hd I 8720 15 CLAY 8720 30 SHALE Dk brn- blk, blky, frm- hd 8750 40 SILTSTONE 8750 15 CLAY I 8750 45 SHALE 8780 30 SILTSTONE 8780 15 CLAY I 8780 55 SHALE Dk brn- blk, blky- ang, non calc, sft- frm 8810 30 SILTSTONE 8810 15 CLAY 8810 45 SHALE I 8810 10 SAND 8840 30 SILTSTONE 8840 15 CLAY I 8840 45 SHALE Dk brn- blk, blky- ang, non calc, sft- frm, hd ip, tr pyr 8840 10 SAND 8870 30 SILTSTONE 8870 15 CLAY I 8870 45 SHALE 8870 10 SAND 8900 30 SILTSTONE I 8900 15 CLAY 8900 40 SHALE Dk brn- blk, blky- ang, tr pyr, frm- hd I I I SAND 8900 15 I 8930 30 SILTSTONE 8930 15 CLAY 8930 40 SHALE 8930 15 SAND I 8960 30 SILTSTONE 8960 15 CLAY 8960 45 SHALE Dk brn- blk, blky- ang, tr pyr, frm- hd Tr pa yal fluor I 8960 10 SAND 8990 90 SILTSTONE 8990 10 CLAY 9020 90 SILTSTONE I 9020 10 CLAY 9050 90 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, com carb mat, pyr, v sft-sft- rr frm. 9050 10 CLAY I 9080 90 SILTSTONE 9080 10 CLAY 9110 90 SILTSTONE I 9110 10 CLAY 9140 90 SILTSTONE 9140 10 CLAY 9170 90 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, com carb mat, pyr, v sft-sft- I rr frm. No shows 9170 10 CLAY 9200 90 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, com carb mat, pyr, v sft-sft- I rr frm. No shows 9200 10 CLAY 9230 90 SILTSTONE 9230 10 CLAY I 9260 90 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, abdt carb mat, pyr, v sft-sft- rr frm. No shows 9260 10 CLAY I 9290 90 SILTSTONE 9290 10 CLAY 9320 95 SILTSTONE 9320 5 CLAY I 9350 75 SILTSTONE Lt- mad gy, It- dk brn, am or- ang, abdt carb mat, pyr, v sft-sft 9350 15 CLAY 9350 10 SHALE I 9380 70 SILTSTONE 9380 15 CLAY 9380 15 SHALE 9410 65 SILTSTONE Lt- dk brn, am or- ang, abdt carb mat, pyr, v sft-sft- rr frm. No I shows 9410 15 CLAY 9410 20 SHALE Dk brn- blk, blky- ang, tr pyr, frm- hd I 9440 60 SILTSTONE 9440 15 CLAY 9440 20 SHALE 9440 5 SAND I 9470 55 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, abdt carb mat, pyr, v sft-sft- rr frm. No shows 9470 10 CLAY I 9470 30 SHALE 9470 5 SAND I I I 9500 55 SILTSTONE I 9500 10 CLAY 9500 30 SHALE 9500 5 SAND 9530 55 SILTSTONE Lt- mad gy, It- dk brn, amor- ang, abdt carb mat, pyr, v sft-sft I 9530 10 CLAY 9530 30 SHALE 9530 5 SAND I 9560 50 SILTSTONE 9560 10 CLAY 9560 30 SHALE 9560 10 SAND I 9590 70 SILTSTONE 9590 10 CLAY 9590 15 SHALE I 9590 5 SAND 9620 80 SILTSTONE Lt- mad gy -occ drk brn, amor- ang, abdt carb mat, v sft-sft 9620 10 CLAY 9620 10 SHALE I 9650 80 SILTSTONE 9650 15 CLAY 9650 5 SHALE 9680 80 SILTSTONE Lt- med gy, amor- ang, abdt carb mat, v sft-sft I 9680 15 CLAY 9680 5 SHALE 9710 80 SILTSTONE I 9710 15 CLAY 9710 5 SHALE 9740 80 SILTSTONE Lt- mad gy, amor- ang, abdt carb mat, v sft-sft 9740 10 CLAY I 9740 10 SHALE 9770 85 SILTSTONE 9770 10 CLAY I 9770 5 SHALE 9800 85 SILTSTONE It gy, m gy ip, occ It brn, amor-blky, sli sdy ip, mod arg, occ carb mat, v sft-sft 9800 15 SHALE I 9830 90 SILTSTONE 9830 10 SHALE 9860 85 SILTSTONE I 9860 15 SHALE 9890 90 SILTSTONE 9890 10 SHALE 9920 90 SILTSTONE Lt- mad gy, amor- ang, abdt carb mat, v sft-sft I 9920 10 SHALE 9950 90 SILTSTONE 9950 10 SHALE I 9980 95 SILTSTONE Lt- mad gy, It brn ip, amor- ang, carb mat, v sft-sft 9980 5 SHALE 10010 95 SILTSTONE 10010 5 SHALE I 1 0040 95 SILTSTONE Lt- mad gy, It brn ip, amor- ang, carb mat, tr pyr, v sft-sft 1 0040 5 SHALE 1 0070 90 SILTSTONE I 1 0070 1 0 SHALE 10100 90 SILTSTONE Lt- mad gy, It brn ip, amor- blky, carb mat, sft- frm I 10100 10 10130 90 10130 10 10160 90 10160 10 10190 90 10190 10 10220 95 10220 5 10250 95 10250 5 10280 80 10280 20 yel/why flour 10310 85 shows 10310 15 SHALE 10340 80 SILTSTONE 1 0340 20 SHALE 10370 70 SILTSTONE 10370 30 SHALE 10400 15 SILTSTONE 10400 40 SHALE 10400 45 SAND Clr, v fn- fn grns, rnd- srt rnd- sang, w It brn stng, tr pyr, tr carb mat, tr glauc (after 10430' MD /8736' TVD) fast pa yel strm cut fluor 10410 10 SILTSTONE 10410 30 SHALE 10410 60 SAND 10430 5 SILTSTONE 1 0430 25 SHALE 1 0430 70 SAN D 10440 5 SILTSTONE 10440 15 SHALE 10440 80 SAN D 10450 15 SILTSTONE 10450 5 SHALE 10450 80 SAN D 10460 5 SILTSTONE 10460 5 SHALE 10460 90 SAN D 10470 5 SILTSTONE 10470 5 SHALE 10470 90 SAND 10480 5 SILTSTONE 10480 5 SHALE 10480 90 SAN D 10490 5 SILTSTONE 10490 5 SHALE 10490 90 SAN D 10500 5 SILTSTONE 1 0500 5 SHALE 1 0500 90 SAN D 10530 5 SILTSTONE 1 0530 5 SHALE 1 0530 90 SAN D 10560 1 0 SILTSTONE I I I I I I I I I I I I I I I I I I I SHALE SILTSTONE SHALE SILTSTONE Lt- med gy, amor- blky, carb mat, sft- frm No shows SHALE SILTSTONE SHALE SILTSTONE SHALE SILTSTONE SHALE SILTSTONE SHALE Med- dk gry, gry/brn- brn, blky, mod hd-hd, sli slty, non calc, tr bri Lt- med gy, amor- blky, carb mat, rr tr pyr, sft- occ frm No shows SILTSTONE Lt- med gy, amor- blky, carb mat, rr tr pyr, sft- occ frm, No 10560 30 SHALE 10560 60 SAN D 10590 10 SILTSTONE 10590 10 SHALE 10590 70 SAND 10590 10 LIMESTONE 10620 10 SILTSTONE 10620 10 SHALE 10620 60 SAND 10620 20 LIMESTONE pa yel strm flour 10650 10 SILTSTONE 10650 10 SHALE 10650 10 SAND 10650 70 LIMESTONE 10680 5 SILTSTONE 1 0680 5 SHALE 10680 10 SAND 10680 80 LIMESTONE 10710 5 SILTSTONE 10710 5 SHALE 10710 10 SAND 10710 80 LIMESTONE 10740 5 SILTSTONE 1 0740 5 SHALE 10740 70 SAND 10740 20 LIMESTONE 10770 100 SAND Clr- It brn, rnd- s rnd, occ sang, qtz, vf - fn gr, mod- w srt, tr chrt, tr py, no shows 1 0800 100 1 0830 100 1 0860 90 1 0860 1 0 1 0890 80 10890 20 10918 70 10918 30 10950 90 10950 1 0 10980 90 10980 1 0 11010 90 11010 10 I I I I I I I I I I I I I I I I I I I Wh, off wh- gry, dk brn, mott, mod hd- hd, micxln, occ sl arg, fair SAND SAND SAND CLAYSTONE SAND CLA YSTON E SAND CLA YSTON E SAND CLAYSTONE SAND Clr- wh/gy, rnd-s rnd, occ sang, vf- fn gr, w srt, tr chrt, tr py, no shows CLA YSTON E SAND CLA YSTON E Lt gy, off wh- wh, v sft- sft, non- calc, grding to sltst ip, no shows · WELL SITE SURVEY SHALLOW DRILLING HAZARDS,EV ALUATION PROPOSED NIKAITCHUQ #1 ALASKA STATE LEASE 388582 (Surface hole location) ALASKA STATE LEASE 388580 (Bottom hole location) SPY ISLAND, ALASKA Summary Pursuant to 20 AAC 25.061 all available CDPgeophysica1, 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 #1 well will be drilled from an ice pad located approximately 4.0 miles north of Oliktok Point on Spy Island. The proposed surface hole location will be 1320' NSL & 1980' EWL of Section 16, Township 14 North by Range 9 East (70.5791976 degrees latitude north by 149.8475566 degrees longitude west). The associated bottom hole location will be 1980' NSL & 330 EWL of section 9, T14N, R9E. 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 from ~ 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 Sak Formation, 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 nearby Milne Point and 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 #1 well location were 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 # 1. 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 #1 location. Illustrated inline 85, crossline 184 (both intersect the Nikaitchuq #1) and reconstruction lines that intersect the MPU F- 33A and NW Milne # 1 well, the BP #1 North Milne and parallel the Nikaitchuq #1 wellbore path are enclosed for your reference. A Nikaitchuq #1 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 # 1 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 unifo:r;m "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 6 miles west of the Nikaitchuq # 1 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 450' and an anticipated permafrost base at the Nikaitchuq #1 location of approximately 435' subsea. Shallow Gas/Oil Accumulations There is no geophysical or geological evidence for any significant accumulation of shallow gas beneath the Nikaitchuq #1 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 Point 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 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 amounts 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 free gas 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 permafrost. Regardless, minor elevated background gas levels within and immediately below the permafrost interval are being planned for in the proposed Nikaitchuq #1 well. The composite Ugnu-West Sak sand 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 from approximately -2300 to -4500' subsea in the Nikaitchuq #1 well. Any sands present will most likely be water-bearing or 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 # 1 well. Summary We have not identified from seismic or offset well data any conditions beneath the Nikaitchuq # 1 location which could pose a prohibitive shallow or intermediate depth drilling hazard to the planned drilling operations. Natural gas hydrates are likely in the sands and gravels of the 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 # 1 well design and operational plan. ~ ~~ MD-f>5 ~CL~ Armstrong Alaska, Inc. ALASI<A NORTI-I SLOPE: Nikaitchuq Prospect Nikaitchuq #1 Shallow Hazards/Abnormal Pressure Location Map MXF/JVS/JAL I o I 1 ~ 2 miles I 3 1/04 Nikaitchuq Prospect Map. CNV . -.- . ,·WellSite SurveyAbnormal FormationPressureÆvaluation State LeaseADL 388580 · WELL SITE SURVEY ABNORMAL FORMATION PRESSURE EVALUATION NIKAITCHUQ #1 LOCATION ALASKA STATE LEASE ADL 388582 (surface hole location) ALASKA STATE LEASE ADL 388580 (bottom hole location) SPY ISLAND, ALASKA Pursuant to 20AAC 25.033 (e) (1) available geophysical data and proximal offset well data to the Nikaitchuq #1 (surface hole is located 1320' NSL & 1980' EWL of Section 16, Township 14 North by Range 9 East and the associated bottom hole location will be 1980' NSL & 330 EWL of section 9, T14N, R9E) have been examined and evaluated for potentially overpressured strata. Examination and interpretation of these data suggest that fonnation pore pressure increases at a nonnal gradient with depth and abnonnal fonnation pressure is not anticipated to the proposed total depth of 9150 ft TVD. · Reference is hereby made to the proposed Nikaitchuq #1 seismic/well base map and several seismic interval velocity exhibits previously submitted to the DNR Oil and Gas Conservation Commission in January, 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 # 1 well location is included for reference. Also included is a pressure versus depth plot generated for the Nikaitchuq #1 from available geologic, petrophysical, engineering and geophysical infonnation. The plot depicts increasing fonnation 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 fonnations 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 Low'er 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 fonnation density, fluid density, velocity, and lithology. Based on our analysis of the fonnations to be penetrated by the Nikaitchuq #1, no overpressure is anticipated above the proposed total depth of 9500 ft. 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 7426 ft to 9189 ft TVD. All six of these wells were drilled with maximun1 mud weights ranging from 9.9 ppg to 10.4 ppg. As it is general practice to drill slightly overbalanced, in situ pore pressures are likely less than there observed mud weights. · 1 . Well Site Survey AbnormaiPormation Pressure Evaluation State Lease ADL388580 · In summary, abnonnal fonnation pressure is not anticipated beneath the proposed Nikaitchuq #1 well location. All operations and engineering personnel have been advised of the anticipated geological drilling conditions. · · 2 ~ c;,l,-z-ul M~6 ({ttCLJuuL Armstrong Alaska, Inc. ALASI<A NORTI-I SLOPE: Nikaitchuq Prospect Nikaitchuq #1 Shallow Hazards/Abnormal Pressure Location Map o MXF/JVS/JAL I 1 I 3 I 2 miles 1/04 Nikaitchuq Prospect Map. CNV - Kcrf' M t. b;~e I /'I ¡/t.a.ifchu f; -f1-~ T~G "[; Dee. t:CL >~ J2.. Î Jle r ;t òi- ð ) ?? ~ 03/14/2004 10:30 0 2.44 22.98 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 103.75 0.00 0.00 0.00 #DIV/O! 03/14/2004 11 :00 0 13.28 151.95 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 207.50 0.00 0.00 0.00 #DIV/O! 03/14/2004 11 :30 0 947.28 128.45 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 311.25 0.00 0.00 0.00 #DIV/O! 03/14/2004 12:00 0 2.44 91.75 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 415.00 0.00 0.00 0.00 #DIV/O! 03/14/2004 12:30 0 5.95 72.45 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 518.75 0.00 0.00 0.00 #DIV/O! 03/1512004 7:30 0 717.48 32.28 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 622.50 0.00 0.00 0.00 #DIV/OI 03/15/2004 8:00 0 8.77 25.08 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 726.25 0.00 0.00 0.00 #DIV/O! 03/15/2004 9:00 0 6.64 23.05 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 4.98 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! 03/15/2004 9:30 0 6.64 21.25 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! 03/15/200410:00 0 16.1 24.93 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! 03/15/2004 10:30 0 6.64 30.18 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/OI .. 03115/200411:00 0 6.64 33.57 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! - 03/15/2004 11 :30 0 8.77 32.28 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! - 03/15/2004 12:00 0 6.64 33.64 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/OI .... . ::0 03/15/200412:30 0 6.64 34.69 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! 52 03/15/200415:00 0 6.64 36.19 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! !:: m 03/16/200414:30 0 1.22 43.4 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/O! 2Ct .~ 03/16/200415:00 0 10.53 37.09 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/I!i> G) (") 03/16/2004 23:00 0 8.77 37.09 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/aD I» 03/16/200423:30 0 8.77 36.95 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/¡£. en C m 03/17/20040:00 0 8.77 36.78 0 0.00% 0.00% 0.00% 0.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/IJI:) C") ~ -. Q - 03/17/20040:30 0 1370.41 31.68 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 0 0.00 0.00 830.00 0.00 0.00 0.00 #DIV/II» ::2 < 03/17/20041:00 12 464.48 64.72 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 1280.26 0.00 1280.26 830.00 26.67 0.00 26.67 #DIVÆi ~ I'V C> 03/17/20041:30 12 417.41 63.52 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 760.15 0.00 760.15 830.00 42.51 0.00 42.51 #DIV/O! C") c:::;) m 03/17/20042:00 12 336.69 63.81 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 720.14 0.00 720.14 830.00 57.51 0.00 57.51 #DIV/O! 0 ..þ. 03/17/20042:30 35 415.5 63.52 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 1800.36 0.00 1800.36 830.00 95.02 0.00 95.02 #OIV/O! 3 0 03/17/2004 3:00 14 241.32 61.56 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 1000.2 0.00 1000.20 830.00 115.86 0.00 115.86 #DIV/OI 3 03/17/20043:30 14 537.5 60.51 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 880.18 0.00 880.18 830.00 134.19 0.00 134.19 #DIV/O! ë;;' 03/17/20044:00 14 545.05 58.64 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 480.1 0.00 480.10 830.00 144.20 0.00 144.20 #DIV/O! CA ëï 03/17/20044:30 12 377.97 60.89 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 880.18 0.00 880.18 830.00 162.53 0.00 162.53 #DIV/O! :::¡ 03/1712004 5:30 14 333.03 64.87 0 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 1040.21 0.00 1040.21 830.00 205.87 0.00 205.87 #DIV/O! 03/17/2004 6:00 14 453.12 60.22 600 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 280.06 0.00 280.06 830.00 211.71 0.00 211.71 #DIV/O! 03/17/2004 6:30 14 355.69 61.49 600 100.00% 0.00% 0.00% 100.00% 0 0 0 0 0 0 0 800.16 0.00 800.16 830.00 228.38 0.00 228.38 #DIV/O! 03/17/2004 7:00 14 370.57 59.84 600 90.00% 0.00% 0.00% 90.00% 0 0 0 0 0 0 0 1120.22 112.02 1008.20 830.00 251.72 2.33 249.38 0.00 03/1712004 7:30 14 396.89 58.19 600 90.00% 0.00% 0.00% 90.00% 0 0 0 0 0 0 0 960.19 96.02 864.17 830.00 271.72 4.33 267.39 0.00 03/17/2004 8:00 14 430.61 58.04 600 85.00% 0.00% 0.00% 85.00% 0 0 0 0 0 0 0 1100.22 165.03 935.19 830.00 294.64 7.77 286.87 0.00 03/17120048:30 20 402.53 59.39 600 80.00% 0.00% 0.00% 80.00% 0 0 0 0 0 0 0 1100.22 220.04 880.18 830.00 317.56 12.36 305.21 0.00 03/17/20049:00 20 466.24 60.29 600 80.00% 0.00% 0.00% 80.00% 0 0 0 0 0 0 0 1340.27 268.05 1072.22 830.00 345.49 17.94 327.54 0.00 03/17/20049:30 20 543.3 59.53 600 80.00% 0.00% 0.00% 80.00% 0 0 0 0 0 0 0 1120.22 224.04 896.18 830.00 368.82 22.61 346.22 0.00 03/17/200410:00 20 608.84 59.09 600 80.00% 0.00% 0.00% 80.00% 0 0 0 0 0 0 0 1200.24 240.05 960.19 830.00 393.83 27.61 366.22 0.00 03/17/200410:30 20 678.19 58.41 600 75.00% 0.00% 0.00% 75.00% 0 0 0 0 0 0 0 1120.22 280.06 840.17 830.00 417.17 33.44 383.72 0.00 03/17/2004 11 :00 20 758.75 56.99 600 75.00% 0.00% 0.00% 75.00% 0 0 0 0 0 0 0 800.16 200.04 600.12 830.00 433.84 37.61 396.23 0.00 03/17/200411:30 20 798.28 56.01 600 60.00% 0.00% 0.00% 60.00% 0 0 0 0 0 0 0 1280.26 512.10 768.16 830.00 460.51 48.28 412.23 0.00 03/17/2004 12:00 20 826.35 55.25 600 60.00% 0.00% 0.00% 60.00% 0 0 0 0 0 0 0 320.06 128.02 192.04 830.00 467.18 50.95 416.23 0.00 03/17/2004 12:30 20 850.77 55.1 600 50.00% 0.00% 0.00% 50.00% 0 0 0 0 0 0 0 960.19 480.10 480.10 830.00 487.18 60.95 426.23 0.00 03/17/2004 13:00 20 877.09 54.81 600 35.00% 0.00% 0.00% 35.00% 0 0 0 0 0 0 0 800.16 520.10 280.06 830.00 503.85 71.79 432.07 0.00 03/17/2004 14:00 20 953.77 54.43 600 36.00% 0.00% 0.00% 36.00% 0 0 0 0 0 0 0 480.1 307.26 172.84 830.00 523.86 84.59 439.27 0.00 03/1712004 14:30 20 970.86 55.71 600 34.00% 0.00% 0.00% 34.00% 0 0 0 0 0 0 0 560.11 369.67 190.44 830.00 535.52 92.29 443.23 0.00 03/17/2004 15:00 20 858.09 53.45 600 42.00% 0.00% 0.00% 42.00% 0 0 0 0 0 0 0 720.14 417.68 302.46 830.00 550.53 100.99 449.54 0.00 03/1712004 15:30 20 824.6 55.1 600 45.00% 0.00% 0.00% 45.00% 0 0 0 36.9 0 0 0 800.16 440.09 360.07 830.00 567.20 110.16 457.04 0.00 03/17/2004 16:00 20 869.54 54.51 600 45.00% 0.00% 0.00% 45.00% 0 0 0 36.9 0 0 0.56 960.19 528.10 432.09 841.67 587.20 121.16 466.04 1060.40 03/17/2004 16:30 20 820.86 54.21 600 45.00% 0.00% 0.00% 45.00% 0 0 0 36.9 0 0 0.54 480.1 264.06 216.05 852.92 597.20 126.66 470.54 2045.03 03/17/2004 17:00 20 816.82 55.1 600 50.00% 0.00% 0.00% 50.00% 0 2.1 0 36.9 8000 0 0.6 1200.24 600.12 600.12 865.42 622.21 139.17 483.04 999.80 03/17/2004 17:30 20 809.49 55.1 600 40.00% 0.00% 0.00% 40.00% 0 2.1 0 36.9 8000 0 0.78 1200.24 720.14 480.10 881.67 647.21 154.17 493.04 1083.12 03117/2004 18:00 20 796.29 55.41 600 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.64 1120.22 672.13 448.09 895.00 670.55 168.17 502.38 952.19 03/17/2004 18:30 20 785.08 55.25 600 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.66 1120.22 672.13 448.09 908.75 693.89 182.17 511.71 981.95 03/17/2004 19:00 20 773.86 55.1 1050 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.65 1120.22 672.13 448.09 922.29 717.23 196.18 521.05 967.07 03/17/2004 19:30 24 644.46 54.89 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.78 1160.23 696.14 464.09 938.54 741.40 210.68 530.72 1120.47 03/17/200420:00 24 638.67 56.31 1150 47.00% 0.00% 0.00% 47.00% 0.77 2.1 0 36.9 8000 0 0.78 1280.26 678.54 601.72 954.79 768.07 224.82 543.25 1149.53 03/1712004 20:30 24 636.91 56.61 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.78 1320.26 792.16 528.10 971.04 795.58 241.32 554.26 984.65 03/1712004 21 :00 24 638.67 56.61 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.79 1280.26 768.16 512.10 987.50 822.25 257.32 564.93 1028.44 (I) ~ 03/17/200421 :30 24 642.71 56.99 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.79 1160.23 696.14 464.09 1003.96 846.42 271.83 574.59 1134.83 03/17/200422:00 24 655.68 57.28 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.8 1240.25 744.15 496.10 1020.63 872.26 287.33 584.93 1075.05 03/17/200422:30 24 657.59 57.28 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.81 1320.26 792.16 528.10 1037.50 899.76 303.83 595.93 1022.53 03117/200423:00 24 655.68 57.51 1080 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.81 1360.27 816.16 544.11 1054.38 928.10 320.83 607.27 992.45 03/17/200423:30 24 683.23 57.58 1300 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.83 1280.26 768.16 512.10 1071.67 954.77 336.84 617.94 1080.51 03/18/20040:00 24 674.45 57.88 1300 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.83 1440.29 864.17 576.12 1088.96 984.78 354.84 629.94 960.45 03/1812004 0:30 24 678.19 58.11 1325 35.00% 0.00% 0.00% 35.00% 0.77 2.1 0 36.9 8000 0 0.84 1280.26 832.17 448.09 1106.46 1011.45 372.18 639.27 1009.41 03/1812004 1 :00 24 685.74 58.19 1325 35.00% 0.00% 0.00% 35.00% 0.77 2.1 0 36.9 8000 0 0.85 1360.27 884.18 476.09 1124.17 1039.79 390.60 649.19 961.35 03/1812004 1 :30 24 693.06 58.41 1325 37.00% 0.00% 0.00% 37.00% 0.77 2.1 0 36.9 8000 0 0.85 1280.26 806.56 473.70 1141.88 1066.46 407.40 659.06 1053.85 03/18/2004 2:00 24 685.74 58.48 1325 37.00% 0.00% 0.00% 37.00% 0.77 2.1 0 36.9 8000 0 0.86 1280.26 806.56 473.70 1159.79 1093.14 424.21 668.93 1066.25 03/18/2004 2:30 24 696.96 58.11 1325 37.00% 0.00% 0.00% 37.00% 0.77 2.1 0 36.9 8000 0 0.83 1280.26 806.56 473.70 1177.08 1119.81 441.01 678.80 1029.06 03/18/20043:00 24 693.06 57.88 1325 40.00% 0.00% 0.00% 40.00% 0.77 2.1 0 36.9 8000 0 0.82 1240.25 744.15 496.10 1194.17 1145.65 456.51 689.13 1101.93 03/18/20043:30 24 721.52 56.31 1450 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 8000 0 0.65 1040.21 603.32 436.89 1207.71 1167.32 469.08 698.24 1077.37 03/1812004 4:00 24 717.48 56.46 1425 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 8000 0 0.78 1160.23 672.93 487.30 1223.96 1191.49 483.10 708.39 1159.10 03/18/2004 4:30 24 704.51 56.83 1420 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 8000 0 0.81 1200.24 696.14 504.10 1240.83 1216.49 497.60 718.89 1163.56 03/18/2004 5:00 24 700.77 57.13 1420 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 8000 0 0.81 1200.24 696.14 504.10 1257.71 1241.50 512.11 729.39 1163.56 03/18/2004 5:30 24 685.74 57.28 1420 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 13000 0 0.85 1280.26 742.55 537.71 1275.42 1268.17 527.58 740.59 1144.70 03/18/2004 6:00 24 693.06 57.28 1470 42.00% 0.00% 0.00% 42.00% 0.77 2.1 0 36.9 13000 0 0.83 1280.26 742.55 537.71 1292.71 1294.84 543.05 751.80 1117.77 03/18/2004 6:30 24 685.74 57.28 1480 25.00% 0.00% 0.00% 25.00% 0.77 2.1 0 34.5 13000 0 0.81 1200.24 900.18 300.06 1309.58 1319.85 561.80 758.05 899.82 03/18/20047:00 24 685.74 57.28 1480 25.00% 0.00% 0.00% 25.00% 0.77 2.1 0 34.5 11000 0 0.81 1120.22 840.17 280.06 1326.46 1343.19 579.30 763.88 964.10 03/18/20047:30 24 678.19 56.75 1485 25.00% 0.00% 0.00% 25.00% 0.77 2.4 0 34.5 11000 0 0.77 1360.27 1020.20 340.07 1342.50 1371.52 600.56 770.97 754.75 03/18/20048:00 24 672.54 56.99 1010 23.00% 0.00% 0.00% 23.00% 0.77 2.4 0 34.5 11000 0 0.8 1280.26 985.80 294.46 1359.17 1398.20 621.10 777.10 811.52 03/18/20048:30 24 670.79 57.13 1020 25.00% 0.00% 0.00% 25.00% 0.77 2.4 0 34.5 11000 0 0.79 960.19 720.14 240.05 1375.63 1418.20 636.10 782.10 1097.01 03/1812004 9:00 28 661.33 57.43 1020 25.00% 0.00% 0.00% 25.00% 0.77 2.4 0 34.5 12500 0 1.02 1160.23 870.17 290.06 1396.88 1442.37 654.23 788.15 1172.18 03/18/2004 9:30 28 620.05 59.31 1065 25.00% 0.00% 0.00% 25.00% 0.77 2.4 0 34.5 12500 0 0.94 1480.3 1110.23 370.08 1416.46 1473.21 677.36 795.86 846.68 03/18/2004 10:00 28 614.4 59.31 1100 25.00% 0.00% 0.00% 25.00% 0.77 2.4 0 34.5 12500 0 1 1520.3 1140.23 380.08 1437.29 1504.88 701.11 803.77 877.02 03/18/2004 10:30 28 595.64 59.53 1125 28.00% 0.00% 0.00% 28.00% 0.77 2.4 0 34.5 12500 0 1.03 1360.27 979.39 380.88 1458.75 1533.22 721.52 811.71 1051.67 03/18/2004 11 :00 28 578.77 60.13 1125 28.00% 0.00% 0.00% 28.00% 0.77 2.4 0 34.5 12500 0 0.99 1440.29 1037.01 403.28 1479.38 1563.23 743.12 820.11 954.67 03/18/200411:30 28 567.56 60.51 1125 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.91 1360.27 993.00 367.27 1498.33 1591.57 763.81 827.76 916.42 03/18/2004 12:00 28 560.01 60.74 1125 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.99 1600.32 1168.23 432.09 1518.96 1624.91 788.15 836.76 847.43 03/18/200412:30 28 550.7 61.19 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.99 1280.26 934.59 345.67 1539.58 1651.58 807.62 843.96 1059.29 03/18/2004 13:00 28 550.7 61.42 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.97 1360.27 993.00 367.27 1559.79 1679.92 828.30 851.62 976.84 03/18/2004 13:30 28 903.41 52.86 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1560.00 1679.92 828.30 851.62 #DIV/O! 03/18/2004 14:00 28 1015.79 47.75 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1560.21 1679.92 828.30 851.62 #DIV/O! 03/18/2004 14:30 28 1075.84 43.62 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1560.42 1679.92 828.30 851.62 #DIV/O! 03/18/2004 15:00 28 1079.65 39.94 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1560.63 1679.92 828.30 851.62 #DIV/O! 03/18/2004 15:30 28 1083.39 37.39 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1560.83 1679.92 828.30 851.62 #DIV/O! 03/18/2004 16:00 28 1079.65 35.59 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1561.04 1679.92 828.30 851.62 #DIV/O! 03/18/2004 16:30 28 1075.84 33.86 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1561.25 1679.92 828.30 851.62 #DIV/O! 03/18/2004 17:00 28 1073.85 32.28 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1561.46 1679.92 828.30 851.62 #DIVlO! 03/18/2004 17:30 28 1068.44 25.98 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.02 0 0.00 0.00 1561.88 1679.92 828.30 851.62 #DIV/O! 03/18/2004 18:30 28 1053.33 25.75 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.02 0 0.00 0.00 1562.71 1679.92 828.30 851.62 #DIV/O! 03/18/200419:30 28 1045.78 23.5 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1563.13 1679.92 828.30 851.62 #DlV/O! 03/18/200420:00 28 1038.38 24.48 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.01 0 0.00 0.00 1563.33 1679.92 828.30 851.62 #DIV/O! 03/18/2004 20:30 28 134.28 24.55 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.02 0 0.00 0.00 1563.75 1679.92 828.30 851.62 #DIV/O! 03/18/200421 :00 28 982.22 30.48 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 0.02 0 0.00 0.00 1564.17 1679.92 828.30 851.62 #DIV/O! 03/18/200421 :30 28 888.3 45.27 1230 27.00% 0.00% 0.00% 27.00% 0.77 2.6 0 34.5 12500 0 1.65 1480.3 1080.62 399.68 1598.54 1710.76 850.82 859.94 1526.90 03/18/2004 22:00 28 706.26 46.17 1230 0.00% 0.00% 0.00% 0.00% 0.75 2.6 0 38.7 12500 0 1.3 1480.3 1480.30 0.00 1625.63 1741.60 881.66 859.94 878.20 03/18/2004 22:30 28 670.79 51.2 260 0.00% 0.00% 0.00% 0.00% 0.75 2.6 0 38.7 12500 0 1.19 1480.3 1480.30 0.00 1650.42 1772.44 912.50 859.94 803.89 03/18/200423:00 32 614.4 51.35 260 35.50% 0.00% 0.00% 35.50% 0.75 2.6 0 38.7 13000 0 1.51 1560.31 1006.40 553.91 1681.88 1804.94 933.46 871.48 1500.40 03/18/200423:30 32 586.33 52.86 400 15.00% 0.00% 0.00% 15.00% 0.75 2.6 0 38.7 13000 0 1.3 1920.38 1632.32 288.06 1708.96 1844.95 967.47 877.48 796.41 03/19/2004 0:30 32 528.04 55.71 400 18.00% 0.00% 0.00% 18.00% 0.76 2.6 0 36 13000 0 1.08 1720.34 1410.68 309.66 1753.96 1916.63 1026.25 890.39 765.59 03/19/2004 1 :00 32 516.98 56.31 850 18.00% 0.00% 0.00% 18.00% 0.76 2.6 0 36 13000 0 1.05 1640.33 1345.07 295.26 1775.83 1950.81 1054.27 896.54 780.63 03/19/2004 1 :30 32 505.76 56.61 850 21.00% 0.00% 0.00% 21.00% 0.76 2.6 0 36 13000 0 1.04 1600.32 1264.25 336.07 1797.50 1984.15 1080.61 903.54 822.62 03/19/2004 2:00 32 496.3 57.13 850 30.00% 0.00% 0.00% 30.00% 0.76 2.6 0 36 13000 0 1.01 1560.31 1092.22 468.09 1818.54 2016.65 1103.36 913.29 924.72 03/19/20042:30 32 490.65 57.43 850 30.00% 0.00% 0.00% 30.00% 0.76 2.6 0 36 13000 0 1.01 1720.34 1204.24 516.10 1839.58 2052.49 1128.45 924.04 838.70 03/19/20043:00 32 483.1 57.81 1040 30.00% 0.00% 0.00% 30.00% 0.76 2.6 0 36 13000 0 1 1440.29 1008.20 432.09 1860.42 2082.50 1149.45 933.05 991.86 03/19/2004 3:30 32 477.45 58.11 1100 35.00% 0.00% 0.00% 35.00% 0.77 2.6 0 36.1 15000 0 0.99 1560.31 1014.20 546.11 1881.04 2115.01 1170.58 944.42 976.14 03/19/2004 4:00 32 469.98 58.48 1100 35.00% 0.00% 0.00% 35.00% 0.77 2.6 0 36.1 15000 0 0.97 1560.31 1014.20 546.11 1901.25 2147.51 1191.71 955.80 956.42 03/19/2004 4:30 32 464.48 58.64 1100 31.00% 0.00% 0.00% 31.00% 0.77 2.6 0 35.6 14500 0 0.97 1440.29 993.80 446.49 1921.46 2177.52 1212.42 965.10 976.05 03/19/2004 5:00 32 460.82 58.71 1100 31.00% 0.00% 0.00% 31.00% 0.77 2.6 0 35.6 14500 0 0.96 1440.29 993.80 446.49 1941.46 2207.53 1233.12 974.40 965.99 03/19/2004 5:30 32 453.12 59.01 1230 30.00% 0.00% 0.00% 30.00% 0.77 2.6 0 35.4 14500 0 0.96 1600.32 1120.22 480.10 1961.46 2240.87 1256.46 984.41 856.97 03/1912004 6:00 32 453.12 59.31 1230 30.00% 0.00% 0.00% 30.00% 0.77 2.6 0 35.1 15000 0 0.95 1440.29 1008.20 432.09 1981.25 2270.87 1277.46 993.41 942.27 03/19/2004 6:30 32 445.56 59.31 1280 25.00% 0.00% 0.00% 25.00% 0.77 2.6 0 35.1 15000 0 1.03 1760.35 1320.26 440.09 2002.71 2307.55 1304.97 1002.58 780.15 (z) 03/19/20047:00 32 441.83 59.16 1310 25.00% 0.00% 0.00% 25.00% 0.77 2.6 0 35.1 15000 0 1.01 1040.21 780.16 260.05 2023.75 2329.22 1321.22 1007.99 1294.61 03/19/20047:30 32 438.16 59.31 1310 25.00% 0.00% 0.00% 25.00% 0.78 2.6 0 36.8 14000 0 0.92 1600.32 1200.24 400.08 2042.92 2362.56 1346.23 1016.33 766.51 03/19/2004 8:00 32 432.36 59.31 1340 30.00% 0.00% 0.00% 30.00% 0.78 2.6 0 36.8 14000 0 1.03 1360.27 952.19 408.08 2064.38 2390.90 1366.06 1024.83 1081.72 03/1912004 8:30 32 430.61 59.53 1350 30.00% 0.00% 0.00% 30.00% 0.77 2.6 0 36.8 14000 0 1 1480.3 1036.21 444.09 2085.21 2421.73 1387.65 1034.08 965.06 03/1912004 9:00 32 426.95 59.69 1360 28.00% 0.00% 0.00% 28.00% 0.78 2.6 0 36.1 14500 0 1 1400.28 1008.20 392.08 2106.04 2450.91 1408.66 1042.25 991.87 03/19/2004 9:30 32 423.21 59.91 1360 28.00% 0.00% 0.00% 28.00% 0.78 2.6 0 36.1 14500 0 0.92 1440.29 1037.01 403.28 2125.21 2480.91 1430.26 1050.65 887.17 03/19/2004 10:00 32 119.33 54.65 1360 25.00% 0.00% 0.00% 25.00% 0.78 2.6 0 36.1 14500 0 0.03 1200.24 900.18 300.06 2125.83 2505.92 1449.01 1056.90 33.33 03/19/200410:30 32 222.4 58.86 1280 30.00% 0.00% 0.00% 30.00% 0.78 2.6 0 36.1 14500 0 0.98 720.14 504.10 216.04 2146.25 2520.92 1459.52 1061.40 1944.07 03/19/200411:00 32 276.8 59.39 1320 20.00% 0.00% 0.00% 20.00% 0.79 2.6 0 36.1 14500 0 0.95 1680.34 1344.27 336.07 2166.04 2555.93 1487.52 1068.41 706.70 03/19/2004 11 :30 32 333.03 59.31 1320 20.00% 0.00% 0.00% 20.00% 0.79 2.6 0 36.1 14500 0 0.8 1360.27 1088.22 272.05 2182.71 2584.27 1510.19 1074.07 735.15 03/19/2004 12:00 32 396.89 58.64 1320 25.00% 0.00% 0.00% 25.00% 0.79 2.6 0 36.1 14500 0 0.84 1040.21 780.16 260.05 2200.21 2605.94 1526.45 1079.49 1076.71 03/19/2004 12:30 32 423.21 59.31 1320 25.00% 0.00% 0.00% 25.00% 0.76 2.6 0 36.1 16000 0 0.77 1520.3 1140.23 380.08 2216.25 2637.61 1550.20 1087.41 675.31 03/19/2004 13:00 32 419.17 60.51 1320 15.00% 0.00% 0.00% 15.00% 0.75 2.6 0 36.1 13500 0 0.84 1280.26 1088.22 192.04 2233.75 2664.28 1572.87 1091.41 771.90 03/19/2004 13:30 32 415.5 60.51 1320 13.00% 0.00% 0.00% 13.00% 0.75 2.6 0 36.1 13500 0 0.88 1360.27 1183.43 176.84 2252.08 2692.62 1597.53 1095.09 743.60 03/19/2004 14:00 32 438.16 62.09 1390 12.00% 0.00% 0.00% 12.00% 0.75 2.6 0 36.1 13500 0 1.25 1600.32 1408.28 192.04 2278.13 2725.96 1626.87 1099.09 887.61 03/19/200414:30 32 400.63 61.42 1390 13.00% 0.00% 0.00% 13.00% 0.75 2.6 0 36.1 13500 0 0.95 1280.26 1113.83 166.43 2297.92 2752.63 1650.07 1102.56 852.92 03/19/200415:00 32 385.67 61.27 1390 12.00% 0.00% 0.00% 12.00% 0.75 2.6 0 36.1 14000 0 0.81 1360.27 1197.04 163.23 2314.79 2780.97 1675.01 1105.96 676.67 03/19/200415:30 32 382.01 61.27 1390 14.00% 0.00% 0.00% 14.00% 0.75 2.6 0 36.1 14000 0 0.81 1440.29 1238.65 201.64 2331.67 2810.98 1700.82 1110.16 653.94 03/19/2004 16:00 32 377.97 61.56 1440 10.00% 0.00% 0.00% 10.00% 0.75 2.6 0 36.1 14000 0 0.87 1280.26 1152.23 128.03 2349.79 2837.65 1724.82 1112.83 755.05 03/19/2004 16:30 32 377.97 61.71 1440 30.00% 0.00% 0.00% 30.00% 0.75 2.6 0 36.3 14000 0 0.87 1400.28 980.20 420.08 2367.92 2866.82 1745.24 1121.58 887.58 03/19/2004 17:00 32 370.57 61.11 1440 27.00% 0.00% 0.00% 27.00% 0.75 2.4 0 36.3 14000 0 0.84 1400.28 1022.20 378.08 2385.42 2896.00 1766.54 1129.46 821.75 03/19/2004 17:30 32 374.23 60.51 1000 27.00% 0.00% 0.00% 27.00% 0.75 2.4 0 36.3 14000 0 0.76 1440.29 1051.41 388.88 2401.25 2926.00 1788.44 1137.56 722.84 03/19/2004 18:00 32 374.23 60.51 1000 27.00% 0.00% 0.00% 27.00% 0.75 2.4 0 36.3 14000 0 0.72 1160.23 846.97 313.26 2416.25 2950.17 1806.09 1144.09 850.09 03/19/2004 18:30 32 374.23 59.98 1000 27.00% 0.00% 0.00% 27.00% 0.75 2.4 0 36.3 14000 0 0.72 1120.22 817.76 302.46 2431.25 2973.51 1823.12 1150.39 880.45 03/19/2004 19:00 32 374.23 59.69 1000 27.00% 0.00% 0.00% 27.00% 0.75 2.4 0 36.3 14000 0 0.69 1320.26 963.79 356.47 2445.63 3001.02 1843.20 1157.82 715.92 03119/2004 19:30 32 377.97 59.69 1020 30.00% 0.00% 0.00% 30.00% 0.75 2.4 0 36.3 13500 0 0.79 1200.24 840.17 360.07 2462.08 3026.02 1860.71 1165.32 940.29 03/19/200420:00 32 370.57 59.98 1020 30.00% 0.00% 0.00% 30.00% 0.77 2.4 0 36.3 13500 0 0.84 1280.26 896.18 384.08 2479.58 3052.69 1879.38 1173.32 937.31 03119/200420:30 32 370.57 60.51 1020 22.00% 0.00% 0.00% 22.00% 0.77 2.4 0 36.3 13500 0 0.86 1440.29 1123.43 316.86 2497.50 3082.70 1902.78 1179.92 765.52 03/19/200421:00 32 368.81 60.81 1020 22.00% 0.00% 0.00% 22.00% 0.77 2.4 0 36.3 13500 0 0.77 1200.24 936.19 264.05 2513.54 3107.71 1922.28 1185.42 822.49 03119/200421:30 32 363.01 61.11 1020 30.00% 0.00% 0.00% 30.00% 0.77 2.4 0 34.9 14000 0 0.77 1200.24 840.17 360.07 2529.58 3132.71 1939.79 1192.92 916.48 03/19/2004 22:00 32 357.44 61.11 1020 30.00% 0.00% 0.00% 30.00% 0.77 2.4 0 34.9 14000 0 0.77 1280.26 896.18 384.08 2545.63 3159.38 1958.46 1200.92 859.20 03/19/200423:00 32 349.89 61.49 1020 30.00% 0.00% 0.00% 30.00% 0.77 2.4 0 34.9 14000 0 0.7 1200.24 840.17 360.Q7 2574.79 3209.39 1993.47 1215.93 833.17 03/19/200423:30 32 349.89 61.49 1020 33.00% 0.00% 0.00% 33.00% 0.76 2.4 0 36.2 14000 0 0.69 1200.24 804.16 396.08 2589.17 3234.40 2010.22 1224.18 858.04 03/2012004 0:00 32 346.15 61.71 1020 33.00% 0.00% 0.00% 33.00% 0.76 2.4 0 36.2 14000 0 0.92 1280.26 857.77 422.49 2608.33 3261.07 2028.09 1232.98 1072.54 03/20/2004 0:30 32 344.4 61.87 1020 25.00% 0.00% 0.00% 25.00% 0.76 2.1 0 36.6 14000 0 0.85 1280.26 960.20 320.07 2626.04 3287.74 2048.09 1239.65 885.24 03/20/2004 1 :00 32 342.49 61.87 1020 25.00% 0.00% 0.00% 25.00% 0.76 2.1 0 36.6 14000 0 0.81 1280.26 960.20 320.07 2642.92 3314.41 2068.10 1246.32 843.58 03/2012004 1 :30 32 340.73 61.78 1020 25.00% 0.00% 0.00% 25.00% 0.76 2.1 0 36 14000 0 0.84 1200.24 900.18 300.06 2660.42 3339.42 2086.85 1252.57 933.15 03/2012004 2:00 32 340.73 61.71 1020 25.00% 0.00% 0.00% 25.00% 0.76 2.1 0 36 14000 0 0.86 1240.25 930.19 310.06 2678.33 3365.26 2106.23 1259.03 924.54 03/2012004 2:30 32 340.73 61.49 1040 27.00% 0.00% 0.00% 27.00% 0.76 2.1 0 35 14000 0 0.8 1200.24 876.18 324.06 2695.00 3390.26 2124.48 1265.78 913.06 03/20/2004 3:00 32 340.73 61.27 1040 27.00% 0.00% 0.00% 27.00% 0.77 2.1 0 36.2 14500 0 0.76 1280.26 934.59 345.67 2710.83 3416.93 2143.95 1272.98 813.19 03/20/2004 3:30 32 342.49 60.89 1040 27.00% 0.00% 0.00% 27.00% 0.77 2.1 0 36.2 14500 0 0.81 1040.21 759.35 28o.B6 2727.71 3438.61 2159.77 1278.83 1066.70 03/2012004 4:00 32 342.49 60.66 1040 27.00% 0.00% 0.00% 27.00% 0.77 2.1 0 36.2 14500 0 0.72 1200.24 876.18 324.06 2742.71 3463.61 2178.03 1285.58 821.75 03/20/2004 4:30 32 342.49 60.51 1040 30.00% 0.00% 0.00% 30.00% 0.77 2.1 0 36.2 15000 0 0.79 1160.23 812.16 348.07 2759.17 3487.78 2194.95 1292.83 972.71 03/20/2004 5:00 32 344.4 60.36 1040 30.00% 0.00% 0.00% 30.00% 0.77 2.1 0 36.2 15000 0 0.82 1360.27 952.19 408.08 2776.25 3516.12 2214.79 1301.34 861.17 03/20/2004 5:30 32 338.63 60.51 1000 30.00% 0.00% 0.00% 30.00% 0.76 2.1 0 36.2 14500 0 0.73 1160.23 812.16 348.07 2791.46 3540.29 2231.71 1308.59 898.84 03/20/2004 6:00 32 342.49 60.66 1000 30.00% 0.00% 0.00% 30.00% 0.76 2.1 0 36.2 14500 0 0.92 1040.21 728.15 312.06 2810.63 3561.96 2246.87 1315.09 1263.48 03/20/2004 6:30 32 338.83 60.81 980 25.00% 0.00% 0.00% 25.00% 0.76 2.1 0 35.9 14500 0 0.76 1280.26 960.20 320.07 2826.46 3588.64 2266.88 1321.76 791.51 03/20/2004 7:00 32 333.03 60.66 980 27.00% 0.00% 0.00% 27.00% 0.76 2.2 0 37.5 14000 0 0.9 1280.26 934.59 345.67 2845.21 3615.31 2286.35 1328.96 962.99 03/2012004 7:30 32 334.94 60.89 980 27.00% 0.00% 0.00% 27.00% 0.76 2.2 0 37.5 14000 0 0.84 1360.27 993.00 367.27 2862.71 3643.65 2307.04 1336.61 845.92 03/20/2004 8:00 32 325.63 60.81 1080 25.00% 0.00% 0.00% 25.00% 0.76 2.2 0 37.2 14000 0 0.95 1040.21 780.16 260.05 2882.50 3665.32 2323.29 1342.03 1217.70 03/2012004 8:30 32 323.87 60.81 980 24.00% 0.00% 0.00% 24.00% 0.76 2.2 0 37.2 14000 0 0.82 1400.28 1064.21 336.07 2899.58 3694.49 2345.46 1349.03 770.52 03/20/2004 9:00 32 327.53 60.89 980 23.00% 0.00% 0.00% 23.00% 0.76 3 0 37.2 14000 0 0.74 1320.26 1016.60 303.66 2915.00 3722.00 2366.64 1355.35 727.92 03/20/2004 9:30 32 325.63 60.89 980 25.00% 0.00% 0.00% 25.00% 0.76 3 0 37.2 14000 0 0.83 1280.26 980.20 320.Q7 2932.29 3748.67 2386.64 1362.02 864.41 03120/2004 10:00 32 321.74 60.81 980 25.00% 0.00% 0.00% 25.00% 0.76 3 0 37.8 14000 0 0.9 1040.21 780.16 260.05 2951.04 3770.34 2402.90 1367.44 1153.61 03/20/2004 10:30 32 325.63 61.11 980 25.00% 0.00% 0.00% 25.00% 0.76 3 0 37.8 14000 0 0.88 1120.22 840.17 280.06 2968.96 3793.68 2420.40 1373.27 1023.61 03/20/2004 11 :00 32 319.83 61.27 980 25.00% 0.00% 0.00% 25.00% 0.76 3 0 37.8 14500 0 0.75 1600.32 1200.24 400.08 2984.58 3827.02 2445.41 1381.61 624.88 03120/2004 11 :30 32 318.07 61.27 960 25.00% 0.00% 0.00% 25.00% 0.76 3 0 38.3 14500 0 0.97 960.19 720.14 240.05 3004.79 3847.02 2460.41 1386.61 1346.96 03/20/2004 12:00 32 318.07 61.42 980 25.00% 0.00% 0.00% 25.00% 0.76 3 0 38.3 15000 0 0.85 880.18 660.14 220.05 3022.50 3865.36 2474.16 1391.20 1287.62 03/20/2004 12:30 32 321.74 61.71 960 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 38.3 15000 0 0.8 1280.26 998.60 281.66 3039.17 3892.03 2494.97 1397.06 801.12 03/20/2004 13:00 32 318.07 61.56 960 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 38.3 15000 0 0.87 1040.21 811.36 228.85 3057.29 3913.70 2511.87 1401.83 1072.27 03/20/2004 13:30 32 310.67 61.42 960 16.00% 0.00% 0.00% 16.00% 0.76 2.4 0 36.1 14500 0 0.76 1040.21 873.78 166.43 3073.13 3935.37 2530.07 1405.30 869.79 03/20/2004 14:00 32 312.43 60.89 960 16.00% 0.00% 0.00% 16.00% 0.76 2.4 0 38.7 14500 0 0.85 1360.27 1142.63 217.64 3090.83 3963.71 2553.88 1409.83 743.90 03/20/2004 14:30 32 308.61 60.51 960 16.00% 0.00% 0.00% 16.00% 0.77 2.4 0 38.7 14000 0 0.83 1120.22 940.98 179.24 3108.13 3987.05 2573.48 1413.57 882.05 03/20/2004 15:00 32 318.07 60.51 960 17.00% 0.00% 0.00% 17.00% 0.77 2.4 0 38.9 14500 0 0.67 980.19 796.96 163.23 3122.08 4007.05 2590.09 1416.97 840.70 (3) 03/20/2004 15:30 32 308.61 60.22 960 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 39.2 14500 0 0.81 1040.21 811.36 228.85 3138.96 4028.72 2606.99 1421.73 998.32 03120/2004 16:00 32 318.07 60.29 965 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 39.2 14500 0 0.87 1120.22 873.77 246.45 3157.08 4052.06 2625.19 1426.87 995.68 03/20/2004 16:30 32 308.61 60.29 965 30.00% 0.00% 0.00% 30.00% 0.76 2.4 0 38.8 16200 0 0.75 1040.21 728.15 312.06 3172.71 4073.73 2640.36 1433.37 1030.01 03/20/2004 17:00 32 310.67 60.51 965 18.00% 0.00% 0.00% 18.00% 0.76 2.4 0 38.8 16200 0 0.63 1360.27 1115.42 244.85 3185.83 4102.07 2663.60 1438.47 564.81 03/20/2004 17:30 32 308.61 60.13 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.79 1320.26 1148.63 171.63 3202.29 4129.58 2687.53 1442.05 687.78 03/20/2004 18:00 32 308.61 60.29 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.63 1080.22 939.79 140.43 3215.42 4152.08 2707.11 1444.97 670.36 03120/2004 18:30 32 306.86 60.13 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.78 960.19 835.37 124.82 3231.67 4172.09 2724.51 1447.57 933.72 03/20/2004 19:00 32 310.67 60.22 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.17 1120.22 974.59 145.63 3247.71 4195.42 2744.82 1450.61 790.07 03/20/2004 19:30 32 308.61 60.29 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.79 1120.22 974.59 145.63 3264.17 4218.76 2765.12 1453.64 810.60 03/20/2004 20:00 32 308.61 60.51 965 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 37.7 15500 0 0.7 1080.22 939.79 140.43 3278.75 4241.27 2784.70 1456.57 744.85 03/20/2004 20:30 32 297.55 60.22 965 28.00% 0.00% 0.00% 28.00% 0.76 2.4 0 34.4 15000 0 0.85 1120.22 806.56 313.66 3296.46 4264.60 2801.50 1463.10 1053.86 03/20/2004 21 :00 32 306.61 60.29 965 28.00% 0.00% 0.00% 28.00% 0.76 2.4 0 34.4 15000 0 0.81 1080.22 177.76 302.46 3313.33 4287.11 2817.71 1469.40 1041.45 03/20/2004 21 :30 32 306.86 60.51 965 23.00% 0.00% 0.00% 23.00% 0.76 2.4 0 33.7 15000 0 0.7 1160.23 893.38 266.85 3327.92 4311.28 2836.32 1474.96 783.54 03120/2004 22:00 32 304.88 60.59 965 23.00% 0.00% 0.00% 23.00% 0.76 2.4 0 33.7 15000 0 0.75 1040.21 800.96 239.25 3343.54 4332.95 2853.00 1479.95 936.37 03/20/2004 22:30 32 310.67 60.51 965 23.00% 0.00% 0.00% 23.00% 0.76 2.4 0 33.7 15000 0 0.72 1080.22 831.77 248.45 3358.54 4355.46 2870.33 1485.12 865.62 03/20/2004 23:00 32 314.41 60.81 965 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 33.7 15500 0 0.58 1040.21 811.36 228.85 3370.63 4317.13 2887.24 1489.89 714.85 03/20/2004 23:30 32 316.07 61.11 940 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 36.9 15500 0 0.64 1120.22 813.17 246.45 3383.96 4400.46 2905.44 1495.02 732.46 03/21/2004 0:00 32 314.41 60.89 940 22.00% 0.00% 0.00% 22.00% 0.76 2.4 0 36.9 15500 0 0.81 1120.22 873.77 246.45 3400.83 4423.80 2923.64 1500.16 927.02 03/21/20041:00 32 303.12 60.89 940 26.00% 0.00% 0.00% 26.00% 0.76 2.4 0 36.2 15500 0 0.74 1080.22 799.36 280.86 3431.67 4468.81 2956.95 1511.86 925.74 03/21/2004 1 :30 32 323.87 61.11 940 26.00% 0.00% 0.00% 26.00% 0.76 2.4 0 36.2 15500 0 0.53 1120.22 828.96 291.26 3442.71 4492.15 2974.22 1517.93 639.35 03/21/2004 2:00 32 306.86 61.11 940 26.00% 0.00% 0.00% 26.00% 0.76 2.4 0 36.2 15500 0 0.83 1000.2 740.15 260.05 3460.00 4512.99 2989.64 1523.35 1121.40 03/21/2004 2:30 32 306.86 61.11 940 26.00% 0.00% 0.00% 26.00% 0.76 2.4 0 36.2 15000 0 0.76 1120.22 828.96 291.26 3475.83 4536.32 3006.91 1529.41 916.81 03/21/2004 3:00 32 303.12 60.96 940 26.00% 0.00% 0.00% 26.00% 0.76 2.4 0 36.2 15000 0 0.55 1120.22 828.96 291.26 3487.29 4559.66 3024.18 1535.48 663.48 03/21/20043:30 32 295.41 60.74 940 20.00% 0.00% 0.00% 20.00% 0.74 1.8 0 36.5 15000 0 0.65 1160.23 928.18 232.05 3500.83 4583.83 3043.52 1540.32 700.29 03/21/2004 4:00 32 295.41 60.81 940 20.00% 0.00% 0.00% 20.00% 0.74 1.8 0 36.5 15000 0 0.77 920.18 736.14 184.04 3516.88 4603.00 3058.85 1544.15 1045.99 03/21/2004 4:30 32 273.14 60.89 940 20.00% 0.00% 0.00% 20.00% 0.74 1.8 0 36.5 15000 0 1.17 1200.24 960.19 240.05 3541.25 4628.01 3078.86 1549.15 1218.51 03/21/2004 5:00 32 295.41 60.51 940 20.00% 0.00% 0.00% 20.00% 0.74 1.8 0 36.5 15000 0 0.66 960.19 768.15 192.04 3555.00 4648.01 3094.86 1553.15 859.20 03/21/2004 5:30 32 291.75 60.51 940 22.00% 0.00% 0.00% 22.00% 0.77 1.8 0 35.9 16500 0 0.49 1040.21 811.36 228.85 3565.21 4669.68 3111.76 1557.92 603.92 03/21/2004 6:00 32 293.66 60.66 940 22.00% 0.00% 0.00% 22.00% 0.77 1.8 0 35.9 16500 0 0.63 1120.22 813.17 246.45 3578.33 4693.02 3129.97 1563.05 721.01 03/21/20046:30 32 295.41 60.89 940 22.00% 0.00% 0.00% 22.00% 0.17 1.8 0 35.9 16500 0 0.76 1160.23 904.98 255.25 3594.17 4717.19 3148.82 1568.37 839.80 03/21/2004 7:00 32 308.61 61.11 940 18.00% 0.00% 0.00% 18.00% 0.75 1.8 0 36.5 15800 0 0.82 1160.23 951.39 208.84 3611.25 4741.37 3168.64 1572.72 861.90 03/21/2004 7:30 32 304.88 61.19 890 17.00% 0.00% 0.00% 17.00% 0.75 1.8 0 36.5 15800 0 0.94 1120.22 929.78 190.44 3630.83 4764.70 3188.01 1576.69 1010.99 03/21/2004 8:00 32 297.55 61.11 890 20.00% 0.00% 0.00% 20.00% 0.75 1.8 0 37.2 16200 0 0.89 1120.22 896.18 224.04 3649.38 4788.04 3206.68 1581.36 993.11 03/21/2004 8:30 32 295.41 61.11 890 20.00% 0.00% 0.00% 20.00% 0.75 1.8 0 37.2 16200 0 0.9 1120.22 896.18 224.04 3668.13 4811.38 3225.35 1586.03 1004.27 03/21/2004 9:00 32 290 60.81 920 19.00% 0.00% 0.00% 19.00% 0.75 1.8 0 37.9 16100 0 0.7 880.18 712.95 167.23 3682.71 4829.72 3240.21 1589.51 981.84 03/21/2004 9:30 32 295.41 61.11 920 20.00% 0.00% 0.00% 20.00% 0.75 1.8 0 37.9 16100 0 0.85 1120.22 896.18 224.04 370Q.42 4853.05 3258.88 1594.18 948.47 03/21/2004 10:00 32 276.8 61.11 920 21.00% 0.00% 0.00% 21.00% 0.75 1.8 0 36.8 16500 0 1.07 1360.27 1074.61 285.66 3722.71 4881.39 3281.26 1600.13 995.71 03/21/2004 10:30 32 295.41 61.42 920 23.00% 0.00% 0.00% 23.00% 0.75 1.8 0 38.1 16500 0 0.63 1040.21 800.96 239.25 3735.83 4903.06 3297.95 1605.11 786.55 03/21/2004 11 :00 32 293.66 61.78 920 20.00% 0.00% 0.00% 20.00% 0.75 1.8 0 38.1 16500 0 0.71 800.16 640.13 160.03 3750.63 4919.73 3311.29 1608.45 1109.15 03/21/200411:30 32 293.66 61.94 920 20.00% 0.00% 0.00% 20.00% 0.75 1.8 0 38.1 16500 0 0.17 920.18 736.14 184.04 3766.67 4938.90 3326.62 1612.28 1045.99 03/21/2004 12:00 32 286.34 61.11 920 18.00% 0.00% 0.00% 18.00% 0.75 1.8 0 38.1 16300 0 0.82 1120.22 918.58 201.64 3783.75 4962.24 3345.76 1616.48 892.68 03/21/2004 12:30 32 274.89 60.89 920 18.00% 0.00% 0.00% 18.00% 0.75 1.8 0 38.1 16300 0 1.19 1320.26 1082.61 237.65 3808.54 4989.75 3368.31 1621.43 1099.19 03/21/2004 13:00 32 329.29 61.87 920 19.00% 0.00% 0.00% 19.00% 0.75 2.4 0 35.1 16200 0 0.53 960.19 177.75 182.44 3819.58 5009.75 3384.52 1625.23 681.45 03/21/2004 13:30 32 382.01 62.31 920 19.00% 0.00% 0.00% 19.00% 0.75 2.4 0 35.1 16200 0 0.85 1200.24 972.19 228.05 3837.29 5034.76 3404.17 1629.98 874.31 03/21/2004 14:00 32 377.97 62.46 920 19.00% 0.00% 0.00% 19.00% 0.75 2.4 0 39 16200 0 0.76 1200.24 972.19 228.05 3853.13 5059.76 3425.03 1634.74 781.74 03/21/2004 14:30 32 400.63 62.99 920 19.00% 0.00% 0.00% 19.00% 0.75 2.4 0 39 16300 0 0.87 880.18 712.95 167.23 3871.25 5078.10 3439.88 1638.22 1220.29 03/21/2004 15:00 32 393.23 63.52 920 25.00% 0.00% 0.00% 25.00% 0.75 2.4 0 39 16300 0 0.87 960.19 720.14 240.05 3889.38 5098.10 3454.88 1643.22 1208.09 03/21/2004 15:30 32 377.97 63.36 920 25.00% 0.00% 0.00% 25.00% 0.75 2.4 0 39 16300 0 0.12 1280.26 960.20 320.07 3891.88 5124.17 3474.89 1649.89 124.97 03/21/2004 16:00 32 415.5 63.96 920 16.00% 0.00% 0.00% 16.00% 0.75 2.4 0 38.9 16800 0 0.86 1120.22 940.98 179.24 3909.79 5148.11 3494.49 1653.62 913.94 03/21/2004 16:30 32 342.49 62.92 920 22.00% 0.00% 0.00% 22.00% 0.75 2.4 0 38.9 16800 0 1.24 1280.26 998.60 281.66 3935.63 5174.78 3515.29 1659.49 1241.73 03/21/2004 17:00 32 299.31 62.31 920 22.00% 0.00% 0.00% 22.00% 0.75 2.4 0 38.9 16300 0 0.71 1240.25 967.40 272.86 395Q.42 5200.62 3535.45 1665.17 733.93 03/21/2004 17:30 32 245.06 60.66 920 22.00% 0.00% 0.00% 22.00% 0.75 2.4 0 38.9 16300 0 0.55 1120.22 873.77 246.45 3961.88 5223.96 3553.65 1670.31 629.46 03/21/2004 18:00 32 241.32 60.22 920 22.00% 0.00% 0.00% 22.00% 0.75 2.4 0 37.6 16300 0 0.59 680.14 530.51 149.63 3974.17 5238.13 3564.70 1673.43 1112.14 03121/2004 18:30 32 258.03 60.43 920 22.00% 0.00% 0.00% 22.00% 0.75 2.4 0 37.6 16300 0 0.65 320.06 249.65 70.41 3987.71 5244.80 3569.91 1674.89 2603.68 03/21/2004 19:00 32 245.06 60.22 920 21.00% 0.00% 0.00% 21.00% 0.75 2.4 0 37.4 16000 0 0.79 960.19 758.55 201.64 4004.17 5264.80 3585.71 1679.09 1041.46 03/21/2004 19:30 32 263.68 60.51 920 21.00% 0.00% 0.00% 21.00% 0.75 2.4 0 37.4 16000 0 0.78 1040.21 821.17 218.44 4020.42 5286.47 3602.83 1683.65 949.18 03/21/200420:00 32 282.6 60.81 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.72 1040.21 894.58 145.63 4035.42 5308.14 3621.47 1686.68 804.85 03/21/200420:30 32 282.6 60.81 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.8 960.19 825.76 134.43 4052.08 5328.15 3638.67 1689.48 968.80 03/21/200421 :00 32 271.23 60.51 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.17 1000.2 860.17 140.03 4068.13 5348.99 3656.59 1692.40 695.17 03/21/200421 :30 32 259.94 60.29 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.95 1040.21 894.58 145.63 4087.92 5370.66 3675.23 1695.43 1061.95 03/21/2004 22:00 32 258.03 59.91 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.83 1160.23 997.80 162.43 4105.21 5394.83 3696.01 1698.81 831.83 03/21/2004 22:30 32 252.38 59.91 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.89 1040.21 894.58 145.63 4123.75 5416.50 3714.65 1701.85 994.88 03/21/2004 23:00 32 201.88 59.46 920 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 37.8 16500 0 0.67 1080.22 928.99 151.23 4137.71 5439.00 3734.00 1705.00 721.21 03/21/200423:30 32 256.28 60.06 900 19.00% 0.00% 0.00% 19.00% 0.17 2.4 0 37 16500 0 0.8 1040.21 842.57 197.64 4154.38 5460.68 3751.56 1709.12 949.48 (0/) 03/2212004 0:00 32 246.81 60.59 900 19.00% 0.00% 0.00% 19.00% 0.77 2.4 0 37 16500 0 0.29 880.18 712.95 167.23 4160.42 5479.01 3766.41 1712.60 406.76 03/22/2004 0:30 32 205.54 60.22 900 19.00% 0.00% 0.00% 19.00% 0.77 2.4 0 37 16500 0 0.57 960.19 777.75 182.44 4172.29 5499.02 3782.61 1716.40 732.88 03/22/2004 1 :00 32 241.32 60.66 900 19.00% 0.00% 0.00% 19.00% 0.77 2.4 0 37 16500 0 0.97 1160.23 939.79 220.44 4192.50 5523.19 3802.19 1720.99 1032.15 03/22/2004 1:30 32 243.15 60.59 900 20.00% 0.00% 0.00% 20.00% 0.76 2.4 0 37.4 16000 0 0.45 560.11 448.09 112.02 4201.88 5534.86 3811.53 1723.33 1004.27 03/22/20042:00 32 301.21 61.11 900 20.00% 0.00% 0.00% 20.00% 0.76 2.4 0 37.4 16000 0 0.51 1000.2 800.16 200.04 4212.50 5555.69 3828.20 1727.50 637.37 03/22/2004 2:30 32 231.86 60.51 900 10.00% 0.00% 0.00% 10.00% 0.77 2.4 0 37.4 16000 0 0.87 1560.31 1404.28 156.03 4226.46 5588.20 3857.45 1730.75 477.11 03/22/2004 3:00 32 259.94 60.68 900 13.00% 0.00% 0.00% 13.00% 0.77 2.4 0 37.1 17000 0 0.91 960.19 835.37 124.82 4245.42 5608.20 3874.86 1733.35 1089.34 03/22/2004 3:30 32 229.95 60.36 900 13.00% 0.00% 0.00% 13.00% 0.77 2.4 0 37.1 17000 0 0.63 1040.21 904.98 135.23 4258.54 5629.88 3893.71 1736.16 696.15 03/22/2004 4:30 32 239.26 60.22 900 13.00% 0.00% 0.00% 13.00% 0.76 1.3 0 37.6 16000 0 0.26 920.18 800.56 119.62 4269.38 5668.22 3927.07 1741.15 324.77 03/22/2004 5:00 32 263.68 59.91 900 13.00% 0.00% 0.00% 13.00% 0.76 1.3 0 37.6 16000 0 0.78 1080.22 939.79 140.43 4285.63 5690.72 3946.65 1744.07 829.97 03/22/2004 5:30 32 209.2 59.6 900 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.3 16700 0 0.58 1040.21 894.58 145.63 4297.71 5712.39 3965.28 1747.11 648.35 03/22/2004 6:00 32 261.92 60.36 900 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.3 16700 0 0.25 1200.24 1032.21 168.03 4302.92 5737.40 3986.79 1750.61 242.20 03/22/2004 6:30 32 220.65 59.53 900 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.3 16700 0 0.57 1280.26 1101.02 179.24 4314.79 5764.07 4009.73 1754.34 517.70 03/22/2004 7:00 32 250.48 59.6 860 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.7 17200 0 0.97 1440.29 1238.65 201.64 4335.00 5794.08 4035.53 1758.54 783.11 03/22/2004 7:30 32 312.43 60.81 860 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.9 17200 0 0.29 720.14 619.32 100.82 4341.04 5809.08 4048.43 1760.64 468.26 03/2212004 8:00 32 261.92 60.59 860 14.00% 0.00% 0.00% 14.00% 0.78 1.3 0 37.9 17200 0 0.84 720.14 619.32 100.82 4358.54 5824.08 4061.34 1762.74 1356.33 03/22/2004 8:30 32 338.83 62.31 860 24.00% 0.00% 0.00% 24.00% 0.78 1.3 0 37.9 17200 0 0.8 1200.24 912.18 288.06 4375.21 5849.09 4080.34 1768.75 877.02 03/22/2004 9:00 32 325.63 62.09 920 16.00% 0.00% 0.00% 16.00% 0.82 2.4 0 37.9 16500 0 0.63 800.16 672.13 128.03 4388.33 5865.76 4094.34 1771.41 937.31 03/22/2004 9:30 32 291.75 60.51 920 16.00% 0.00% 0.00% 16.00% 0.82 2.4 0 37.9 16500 0 1.11 960.19 806.56 153.63 4411.46 5885.76 4111.15 1774.61 1376.22 03/22/2004 10:00 32 175.56 58.71 890 18.00% 0.00% 0.00% 18.00% 0.82 2.4 0 37.9 16800 0 0.15 880.18 721.75 158.43 4414.58 5904.10 4126.18 1777.91 207.83 03/22/2004 10:30 32 310.67 60.51 890 16.00% 0.00% 0.00% 16.00% 0.84 2.4 0 37.8 17200 0 0.47 1200.24 1008.20 192.04 4424.38 5929.10 4147.19 1781.91 466.18 03/22/2004 11 :00 32 168 58.41 890 12.00% 0.00% 0.00% 12.00% 0.84 2.4 0 37.8 17200 0 0.51 960.19 844.97 115.22 4435.00 5949.11 4164.79 1784.32 603.57 03/22/2004 11 :30 32 303.12 60.36 890 15.00% 0.00% 0.00% 15.00% 0.84 2.4 0 38.7 17200 0 0.41 520.1 442.09 78.02 4443.54 5959.94 4174.00 1785.94 927.42 03/22/2004 12:00 32 291.75 60.22 840 15.00% 0.00% 0.00% 15.00% 0.84 2.4 0 38.7 17200 0 0.27 960.19 816.16 144.03 4449.17 5979.95 4191.00 1788.94 330.82 03/22/2004 12:30 32 370.57 61.94 840 6.00% 0.00% 0.00% 6.00% 0.84 2.4 0 38.7 17200 0 0.74 1160.23 1090.62 69.61 4464.58 6004.12 4213.73 1790.39 678.52 03/22/2004 13:00 32 226.06 59.98 840 6.00% 0.00% 0.00% 6.00% 0.73 2.4 0 38.4 17400 0 0.14 880.18 827.37 52.81 4467.50 6022.45 4230.96 1791.49 169.21 03/22/2004 13:30 32 284.35 61.11 840 16.00% 0.00% 0.00% 16.00% 0.73 2.4 0 38.4 17400 0 0.07 1280.26 1075.42 204.84 4468.96 6049.13 4253.37 1795.76 65.09 03/22/2004 14:00 32 333.03 61.87 840 16.00% 0.00% 0.00% 16.00% 0.73 2.4 0 38.4 17400 0 0.48 800.16 672.13 128.03 4478.96 6065.80 4267.37 1798.43 714.14 03122/2004 14:30 32 233.62 59.01 840 8.00% 0.00% 0.00% 8.00% 0.73 2.4 0 38.4 17400 0 0.55 1200.24 1104.22 96.02 4490.42 6090.80 4290.37 1800.43 498.09 03/22/2004 15:00 32 363.01 60.89 840 8.00% 0.00% 0.00% 8.00% 0.73 2.4 0 38.4 17400 0 1.77 1120.22 1030.60 89.62 4527.29 6114.14 4311.85 1802.29 1717.44 03/22/2004 15:30 32 314.41 60.22 840 8.00% 0.00% 0.00% 8.00% 0.73 2.4 0 38.4 17400 0 0.44 800.16 736.15 64.01 4536.46 6130.81 4327.18 1803.63 597.71 03/22/2004 16:00 32 334.94 60.36 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.55 1360.27 1224.24 136.03 4547.92 6159.15 4352.69 1806.46 449.26 03122/2004 16:30 32 385.67 55.41 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.03 0 0.00 0.00 4548.54 6159.15 4352.69 1806.46 #OIV/O! 03122/2004 17:00 32 499.96 50.83 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.02 0 0.00 0.00 4548.96 6159.15 4352.69 1806.46 #DIV/O! 03/22/2004 17:30 32 582.51 47.83 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.02 0 0.00 0.00 4549.38 6159.15 4352.69 1806.46 #DIV/O! 03/22/2004 18:00 32 650.03 45.34 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.02 0 0.00 0.00 4549.79 6159.15 4352.69 1806.46 #OIV/O! 03/22/2004 18:30 32 696.96 43.09 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.01 0 0.00 0.00 4550.00 6159.15 4352.69 1806.46 #DIV/O! 03/22/2004 19:00 32 745.78 41.3 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 0.01 0 0.00 0.00 4550.21 6159.15 4352.69 1806.46 #DIV/O! 03/22/2004 19:30 32 363.01 37.77 840 10.00% 0.00% 0.00% 10.00% 0.75 2.4 0 38.4 16900 0 1.29 0 0.00 0.00 4577.08 6159.15 4352.69 1806.46 #DIV/O! 03/22/200420:00 32 325.63 48.8 840 2.00% 0.00% 0.00% 2.00% 0.75 2.4 0 38.4 16900 0 0.74 1080.22 1058.62 21.60 4592.50 6181.65 4374.74 1806.91 699.03 03/22/2004 20:30 32 366.9 54.51 880 2.00% 0.00% 0.00% 2.00% 0.76 2.4 0 39.4 16900 0 0.81 1320.26 1293.85 26.41 4609.38 6209.16 4401.70 1807.46 626.04 03122/2004 21 :00 32 355.69 53.38 880 2.00% 0.00% 0.00% 2.00% 0.76 2.4 0 39.4 16900 0 0.8 1280.26 1254.65 25.61 4626.04 6235.83 4427.84 1808.00 637.63 03/22/2004 21 :30 32 377.97 53.45 880 2.00% 0.00% 0.00% 2.00% 0.76 2.4 0 39.4 16900 0 0.87 1280.26 1254.65 25.61 4644.17 6262.50 4453.97 1808.53 693.42 03/22/2004 22:00 32 370.57 53.45 880 2.00% 0.00% 0.00% 2.00% 0.76 2.4 0 39.4 16900 0 0.88 1280.26 1254.65 25.61 4662.50 6289.17 4480.11 1809.06 701.39 03/22/2004 22:30 32 363.01 53.45 880 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 391 17000 0 0.88 1240.25 1066.62 173.64 468D.83 6315.01 4502.33 1812.68 825.04 03/22/200423:00 32 323.87 53.45 550 14.00% 0.00% 0.00% 14.00% 0.76 2.4 0 391 17000 0 0.85 1040.21 894.58 145.63 4698.54 6336.68 4520.97 1815.71 950.17 03/22/2004 23:30 32 304.88 54.05 550 18.00% 0.00% 0.00% 18.00% 0.76 2.4 0 38.1 16500 0 0.73 1120.22 918.58 201.64 4713.75 6360.02 4540.11 1819.91 794.70 03/23/2004 0:00 32 209.2 50.6 550 18.00% 0.00% 0.00% 18.00% 0.76 2.4 0 38.1 16500 0 0.54 640.13 524.91 115.22 4725.00 6373.36 4551.04 1822.31 1028.75 03/23/2004 0:30 32 190.59 48.57 550 18.00% 0.00% 0.00% 18.00% 0.76 2.4 0 38.1 16500 0 0.49 800.16 656.13 144.03 4735.21 6390.03 4564.71 1825.32 746.80 03/23/2004 1 :00 32 188.68 47.52 570 14.00% 0.00% 0.00% 14.00% 0.77 2.4 0 39.1 17000 0 0.34 760.15 653.73 106.42 4742.29 6405.86 4578.33 1827.53 520.09 03/23/2004 1 :30 32 186.92 47.37 570 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 38.5 16500 0 0.32 720.14 626.52 93.62 4748.96 6420.87 4591.38 1829.48 510.76 03/23/2004 2:00 32 175.56 47.68 570 13.00% 0.00% 0.00% 13.00% 0.76 2.4 0 38.5 16500 0 0.28 760.15 661.33 98.82 4754.79 6436.70 4605.16 1831.54 423.39 03/23/2004 2:30 32 282.6 50.9 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.67 960.19 825.76 134.43 4768.75 6456.71 4622.37 1834.34 811.37 03/23/2004 3:00 32 306.86 52.4 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.77 1120.22 963.39 156.83 4784.79 6480.05 4642.44 1837.61 799.26 03/23/2004 3:30 32 338.83 53.31 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.82 1640.33 1410.68 229.65 4801.88 6514.22 4671.83 1842.39 581.28 03/23/2004 4:00 32 303.12 52.18 570 14.00% 0.00% 0.00% 14.00% 0.78 24 0 37.9 17000 0 0.69 1040.21 894.58 145.63 4816.25 6535.89 4690.46 1845.43 771.31 03/23/2004 4:30 32 469.98 47.52 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.03 0 0.00 0.00 4816.88 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 5:00 32 593.73 41.3 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.03 0 0.00 0.00 4817.50 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 5:30 32 659.34 36.49 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0.03 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 6:00 32 702.53 31.99 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 6:30 32 725.19 28.53 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 7:00 32 743.8 25.08 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 7:30 32 760.66 22.07 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 8:00 32 773.86 20.05 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! (Ç) 03/23/2004 8:30 32 788.74 18.69 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 9:00 32 798.28 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 9:30 32 813.15 15.92 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 10:00 32 824.6 13.89 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 10:30 32 835.81 12.54 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 11 :00 32 850.77 11.78 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/OI 03/23/2004 11 :30 32 862.13 11.34 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 12:00 32 873.35 11.18 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 12:30 32 882.66 10.89 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 13:00 32 895.7 10.81 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 13:30 32 905.17 10.96 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 14:00 32 914.63 10.81 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 14:30 32 925.69 11.27 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 15:00 32 933.24 11.87 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 15:30 32 942.7 12.46 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIVlO! 03/23/2004 16:00 32 953.77 13.07 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 16:30 32 965.21 13.59 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 17:00 32 972.76 14.27 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 17:30 32 983.98 15.01 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 18:00 32 993.29 15.54 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 18:30 32 1000.84 16.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 19:00 32 1010.3 16.13 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 19:30 32 1017.7 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/200420:00 32 1028.92 16.75 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 20:30 32 1034.56 16.75 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 21 :00 32 1038.38 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 21 :30 32 1045.78 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/23/2004 22:00 32 1045.78 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 22:30 32 1049.44 16.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/23/2004 23:00 32 1055.24 16.45 570 14.00% 0.00% 0.00% 14,00% 0.78 2,4 0, 37,9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845,43 #DIV/O! 03/23/2004 23:30 32 1060.88 16.3 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845,43 #DIV/O! 03/24/2004 0:00 32 1062.64 16.22 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37,9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 0:30 32 1068.44 16.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 1 :00 32 1070.19 15.92 570 14.00% 0,00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818,13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 1 :30 32 1073.85 15.77 570 14,00% 0,00% 0.00% 14.00% 0,78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 2:00 32 1075.84 15.47 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 2:30 32 1079.65 15.47 570 14,00% 0.00% 0.00% 14.00% 0,78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818,13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 3:00 32 1083.39 15.54 570 14,00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818,13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 3:30 32 1087.05 15,77 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 4:00 32 1088.96 15.92 570 14,00% 0.00% 0,00% 14.00% 0,78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 4:30 32 1090,72 15.92 570 14.00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0,00 0.00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 5:00 32 1094.61 15,62 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 5:30 32 1098,27 15,31 570 14.00% 0.00% 0,00% 14,00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 6:00 32 1098.27 15,17 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535,89 4690.46 1845.43 #OIV/O! 03/24/2004 6:30 32 1105.97 15,17 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 7:00 32 1105.97 15.31 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 7:30 32 1107.73 14,19 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0,00 0.00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 8:00 32 1113.38 14,04 570 14.00% 0.00% 0.00% 14,00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 8:30 32 1117.04 14.34 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 9:00 32 1118.79 14.12 570 14.00% 0.00% 0.00% 14,00% 0.78 2,4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 9:30 32 1120.93 14.27 570 14.00% 0.00% 0.00% 14.00% 0.78 2,4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 10:00 32 1122.84 14.27 570 14.00% 0.00% 0.00% 14,00% 0.78 2,4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 10:30 32 1128.33 12.77 570 14.00% 0,00% 0.00% 14,00% 0.78 2.4 0 37,9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690,46 1845.43 #OIV/O! 03/24/2004 11 :00 32 1130.24 10.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 11 :30 32 1139.54 8,26 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03124/2004 12:00 32 1139.54 6,61 570 14.00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0,00 4818.13 6535,89 4690.46 1845.43 #DIV/O! 03/24/2004 12:30 32 1143.36 5.25 570 14.00% 0.00% 0.00% 14,00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 13:00 32 1145.19 4.65 570 14.00% 0,00% 0.00% 14,00% 0.78 2.4 0 37,9 17000 0 0 0 0.00 0.00 4818.13 6535.89 4690,46 1845.43 #OIV/O! 03/24/2004 13:30 32 1147.25 4.06 570 14.00% 0,00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 4920.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 14:00 32 1150.91 3.76 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5021.88 6535.89 4690,46 1845.43 #DIV/O! 03124/2004 14:30 32 1150,91 3.76 570 14.00% 0,00% 0.00% 14.00% 0.78 2.4 0 37,9 17000 0 4.89 0 0.00 0.00 5123.75 6535.89 4690,46 1845.43 #DIV/O! 03/24/2004 15:00 32 1154.65 3.76 570 14.00% 0,00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5225.63 6535.89 4690.46 1845.43 #OIV/O! 03/24/2004 15:30 32 1158.31 3.31 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5327.50 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 16:00 32 1162.2 3.23 570 14,00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5429.38 6535.89 4690.46 1845.43 #DIV/O! (6) 03124/2004 16:30 32 1165.87 3.45 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5531.25 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 17:00 32 1165.87 3.6 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5633.13 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 17:30 32 1165.87 3.76 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 18:00 32 1162.2 3.76 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 18:30 32 1165.87 3.76 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/24/2004 19:00 32 1165.87 3.76 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/24/2004 19:30 32 1165.87 4.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 20:00 32 1165.87 4.51 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 20:30 32 1165.87 5.18 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 21 :00 32 1165.87 5.71 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O' 03/24/2004 21 :30 32 1173.27 6.39 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 22:00 32 1173.27 6.75 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 22:30 32 1173.27 7.66 570 14.00% 0.00% 0.00% 14,00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 23:00 32 1177.08 8.57 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/24/2004 23:30 32 1177.08 9.24 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 0:00 32 1180.97 9.69 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 0:30 32 1180.97 10.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/25/2004 1 :00 32 1180.97 10.36 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 1 :30 32 1182.73 10.81 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 2:00 32 1186.39 11.34 570 14.00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 2:30 32 1186.39 11.63 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/OI 03/25/2004 3:00 32 1188.53 11.87 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/OI 03/25/2004 3:30 32 1188.53 12.39 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 4:00 32 1190.28 12.69 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #OIV/O! 03/25/2004 4:30 32 1193.94 12.84 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 5:00 32 1193.94 13.14 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 5:30 32 1193.94 13.59 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 6:00 32 1199.59 14.12 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 6:30 32 1203.4 14.64 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 7:00 32 1209.05 15.17 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 7:30 32 1210.8 15.54 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 8:00 32 1212.71 16.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/25/2004 8:30 32 1218.36 16.52 570 14.00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/25/2004 9:00 32 1224 17.04 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 9:30 32 1233.46 17.57 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 10:00 32 1242.92 18.16 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIVlO! 03/25/2004 10:30 32 1253.99 18.55 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 11 :00 32 1257.88 19.07 570 14.00% 0.00% 0,00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 11 :30 32 1265.2 19.67 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 12:00 32 1272.76 20.12 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 12:30 32 1284.2 20.65 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 13:00 32 1285.95 21.1 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 13:30 32 1297.02 21.7 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 14:00 32 1306.48 22.37 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 14:30 32 1312.28 22.83 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 15:00 32 1315.94 23.12 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 15:30 32 1319.68 23.43 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 16:00 32 1317.69 23.72 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5735.00 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 16:30 32 1317.69 23.95 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 4.89 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 17:00 32 1315.94 24.33 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 17:30 32 1308.48 24.33 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #OIV/O! 03/25/2004 18:00 32 1310.22 23.5 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 18:30 32 1310.22 22.68 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #OIV/O! 03/25/2004 19:00 32 1312.28 22.07 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 19:30 32 1314.03 21.25 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #OIV/O! 03/25/2004 20:00 32 1312.28 20.05 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 20:30 32 1308.46 18.77 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 21 :00 32 1308.46 17.57 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #OIV/O! 03/25/2004 21 :30 32 1304.72 16.22 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 22:00 32 1301.08 14.87 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 22:30 32 1293.38 13.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/25/2004 23:00 32 1285.95 12.46 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIVlO! 03/25/2004 23:30 32 1282.06 11.34 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 0:00 32 1274.74 10.29 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! r7) 03/26/2004 0:30 32 1271 9.24 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 1:00 32 1263.45 8.26 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIVlO! 03/2612004 1 :30 32 1257.88 7.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 2:00 32 1248.42 8.93 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 2:30 32 1240.86 10.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 3:00 32 1229.8 10.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 3:30 32 1222.25 10.66 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #D!V/O! 03/26/2004 4:00 32 1216.6 10.43 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 4:30 32 1212.71 10.06 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 5:00 32 1209.05 10.13 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 5:30 32 1201.65 10.43 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIVlO! 03/26/2004 6:00 32 1193.94 10.74 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #D!V/O! 03/26/2004 6:30 32 1190.28 10.96 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 7:00 32 1186.39 11.27 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 7:30 32 1180.97 11.63 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 03/26/2004 8:00 32 1177.08 11.87 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIVlO! 03/26/2004 8:30 32 1177.08 12.16 570 14.00% 0.00% 0.00% 14.00% 0.78 2.4 0 37.9 17000 0 0 0 0.00 0.00 5836.88 6535.89 4690.46 1845.43 #DIV/O! 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