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Home My WebLink About201-026 Dear Please well work can also not the same welded attachment listed on the Senior Western North Growth Alaska 265-6402 office 5-91 "There is no such and through -- Darren K Roya! comes ITom within long as a person doesn't admit he is defeated, he is not 3 CRJPG» and Abandon for AOGCC.doc» 3 P & A 003 3 and AOGCCdoc base64 3P&A P&A :3 P & A 006 CRJPG P& 006 of Nanuq #3 P&A Operations Summary ReviSi. . Content-Encoding: base64 RECEIVED APR 1 2 2007 Alaska Oil & Gas Cons. Commission Anchorage 30f3 4/12/2007 10:20 AM . . Nanuq #3 Plug and Abandon Operations Summary 12/28/2006 AOGCC contacted in a.m. - waived witness 12/29/2006 Pull BPV. RIH with tbg gauge and tag cement @ 4701' WLM. 1500 psi MIT on lA and Tbg. Set Baker N-2 CIBP in 3.5" tbg @ 1010'. Perf from 1004 - 1006' Pumped down tbg to verify communication with OA. 12/30/2006 AOGCC notified in a.m. - waived witness. 12/31/2006 Pumped 59 bb1s brine down tbg at 2.5 bpm taking returns up lA. Clean samples obtained. Sl IA and pump 46 bb1s brine at 2.5 bpm down tubing taking returns up OA. Clean sample obtained. Sl OA and open lA. Pumped 35 bbls AS-1 down tbg. Clean cement to surface. Swap to take returns up OA. Pumped 28 bbls down tubing. Bullhead remaining cement down OA. 2/16/2007 Excavate ground around well for P &A. 2/17/2007 Excavate well to P &A. 3/4/2007 Remove wellhead, cut off conductor, casings and tubing to 3' below tundra, dressed stub for cappmg. 3/5/2007 Top off stub wi AS-1 cement -¡,.ÞO"1 3/6/:SOOf ;6Þ..¡ ·1% .07 Welded data on cap. 317/2007 Cover and compact RECEIVED APR 1 2 2007 Alaska Oil & Gas Cons. Comnission Anchorage Totals 89 bb1s Arctic Set 1 slurry 105 bbls Brine 20 bbls Spacer. . . . Tim Crumrine Senior Engineer WNS Development . . ConocJPhillips P. O. Box 100360 Anchorage. AK 99510-0360 Phone: 907-265-6402 March 20, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 JÐ 1- ()J-~ Subject: Submission of Form 10-407 Well Recompletion Report for NANUQ #3 Plug and Abandon (Sundry # 306-378) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Form 10-407 Well Completion or Recompletion Report and Log for the plug and abandonment Alpine CD-4 well Nanuq #3 in accordance with Sundry Number 306-378. The attached report is the final disposition for the well. State witnessing of all operations was waived. Included with Form 10-407 is an operations summary for plug and abandon operations. If you have any questions regarding this matter, please contact me at 265-6402. Sincerely, ~NNED MAY C 3 2D07 ~- .--~.~,_...,..y,' /~ -' "/ !0'Y:Z,1A¿'ä__"'"' ,......, 1": ,.,,--- , --~. . Tim Crumrine, P.E. Senior Engineer CPAI WNS Development RECEIVED . STATE OF ALASKA . ALASKA Oil AND GAS CONSERVATION COMMIS MAR 2 2 2007 WELL COMPLETION OR RECOMPLETION REPORT ANQ Le~M Comrnissil s Gas Gon . 1 a. Well Status: OilU GasU Plugged [] . Abandoned [] . Suspended 0 WAGlJ 1 b. Well Class: Anch~g a 20AAC 25.105 20AAC 25,110 Development 0 Exploratory ./ GINJD WINJD WDSPL 0 No. of Completions 0 Other Service 0 Stratigraphic Test 0 2. Operator Name: 5. Date Comp., Susp., or 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. Aband.: ,- f.,.-ZCD7 201-026 .. 3. Address: 6. Date Spudded: /"f,z,.o'" 13. API Number: P.O. Box 100360, Anchorage, Alaska 99510 3/1/2001 ¿ 4·1 50-103-20365-00 ,/' 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2268' FSL, 574' FEL, Sec. 24, T11N, R4E, UM ,/ 3/14/2001 /' Nanuq #3 Top of Productive Horizon: 8. KB Elevation(ft): 15. Field/Pool(s): 2129' FSL, 703' FWL, Sec. 24, T11N, R4E, UM RKB 28' + Pad 15' Colville River Unit 1 Nanuq-Nanuq Total Depth: 9. Plug Back Depth(MD+TVD): Nanuq-Kuparuk 2151' FSL, 95' FWL, Sec. 24, T11N, R4E, UM surface 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 377669./ y- 5957405 / Zone- 4 , 9112' MD 1 7646' TVD , ADL 380077 / TPI: x- 373664 y- 5957333 Zone- 4 11. Depth Where SSSV Set: 17. Land Use Permit: Total Depth: x- 373056 y- 5957366 Zone- 4 N/A 18. Directional Survey: Yes [] No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost: N/A feet MSL 85' 21. Logs Run: Original Logs GRlNeutlDens/Sonic 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 surface 117' 24" 320 sx AS 1 9.625" 40# L-80 surface 1965' 12.25" 360sx AS Lite 1 350sx Cis G 7" 26# L-80 surface 9092' 8.5" 460sx Cis G 1 200sx Cis G 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 3.5" 2290' N/A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 1006' Tbg x IA 35 bbls AS-1 slurry 1006' Tbg x OA 54 bbls AS-1 slurry 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): PluQQed and Abandoned Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: Test Period -+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ~ 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Submitted 5/10/2001 ;ff-~;""''''''''''.'' ,,;::'Y~Ü}à £ tr.)1"/'; t ,~".;..- ~~\OC-\O~~ ¡¡,o¡;:' ,. i,J...~..~ \7 ~ ~~-rwt"G~-:O ""\ 1 ~"j ven~ ';~'~.... . .-- .- Form 10-407 Revised 12/2003 o RIG I N~ltED ON REVERSE A ¢ 1'2.·c.7 ~/f/Í?Ø? & · NAME GEOlOGIC MARKER MD TVD 29. ORMATION TESTS Include and briefly su ze test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. , None K-3 HRZ K-1 4642' 8152' 8449' 30. List of Attachments: Summary of P&A operations 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: 265-6402 Title: Senior Engineer Printed Name: Tim Crumrine Phone: 265-6402 Date: :J.: INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 ~ . . Nanuq #3 Plug and Abandon Operations Summary 12/28/2006 AOGCC contacted in a.m. - waived witness 12/29/2006 Pull BPV. RIH with tbg gauge and tag cement @ 4701' WLM. 1500 psi MIT on IA and Tbg. Set Baker N-2 CIBP in 3.5" tbg @ 1010'. Perf from 1004 - 1006' Pumped down tbg to verify communication with OA. 12/30/2006 AOGCC notified in a.m. - waived witness. 12/31/2006 Pumped 59 bbls brine down tbg at 2.5 bpm taking returns up IA. Clean samples obtained. Sl IA and pump 46 bbls brine at 2.5 bpm down tubing taking returns up OA. Clean sample obtained. Sl OA and open lA. Pumped 35 bbls AS-1 down tbg. Clean cement to surface. Swap to take returns up OA. Pumped 28 bbls down tubing. Bullhead remaining cement down OA. 4 ;}-~ ~\J\s 2/16/2007 Excavate ground around well for P &A. 2/17/2007 Excavate well to P&A Totals 89 bbls Arctic Set 1 slurry 105 bbls Brine 20 bbls Spacer. ,_.< . ¡ . ,--, SARAH PALIN, GOVERNOR ¡ ALASKA OIL AND GAS CONSERVATION COMMISSION i 333 W. 7" A VENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Tim Crumrine Senior Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Unit, Exploration, Nanuq #3 Sundry Number: 306-378 'r·(I¡¡.~...?,¡,;;:;n : "vd'tt 1\ 3 'b.,t"" "';; ~i ¿jl: ~~~ Dear Mr. Crumrine: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this/Vday of December, 2006 Encl. , . ~i F-I h (fltllv',J,' STATE OF ALASKA .. i,){ f-<t:t:E/VED ALA OIL AND GAS CONSERVATION COM_ION It DEC 0 1 APPLICATION FOR SUNDRY APPROVALSAlaska Oil & Gas C ~ orIn r "'11)(11'$ " ...' , 20 MC 25.280 " ,', u:tJ ¡ '~HJfI 1. Type of Request: Abandon 0 . Suspend 0 Operational shutdown 0 Perforate 0 WaiverLj"U' age Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well ~ ~ 2. Operator Name: 4. Current Well Class: 5. Permit to ~ Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 201-026 . 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20365-00· ./ 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes 0 No 0 NANUQ #3 9. Property Designation: 10. KB Elevation (ft):. 11. Field/Pool(s): ADL 380077 Tract 72 T11 N R4E Section 24 27 CRU / Nanuq-Nanuq & Nanuq Kuparuk 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9112 7645 CMT 5155 ft Casing Length Size MD TVD Burst Collapse Structural Conductor 117' 16" 62.5# 117' 117' Surface 1965' 9-5/8" 40# 1965' 1781' Intermediate Production 9092' 7"26# 9092' 7626' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" 9.3# L-80 2290' Packers and SSSV Type: None Packers and SSSV MD (ft): None 13. Attachments: Description Summary of Proposal 0 14. Well Class after proPþd work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0' ~.It. Development 0 Service 0 15. Estimated Date for 13-Dec-06 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas 0 Plugged 0 Abandoned 0- 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Tim Crumrine @ 265-6402 Printed Name Tim Crumrine Title Senior Engineer . Signature~--=,/? ") :r.=> G:- Phone 265-6402 Date ~ /2- ò/-,?OÒ& ( COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: oOLP - ôr¡ 8 Plug Integrity ~ BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: \..~~\o..c\ r~?~~\~~ ~'()~~\\~"'Ç\ì \a ~\\~S~i V ~'û.\ a tJa<:..~~\¡,,$)(\" ~ ~. 0 \- ú.J\- t).\-\ \^"o r- ~o ~ ~\f'~ \' ~ ~ Subsequent Form Required: '-\$~ ø ~MMISSIONER RBDMS 8Ft DEC 1 3 2006 APPROVED BY Date: I Z. ,../'V" I /; Approved by: THE COMMISSION Form 10-403 Revised 06/2006 eml r']J(IAL .AI! 12..-/1.01- Su5mit i Duplicate ..J1 \J ',;Z.(t?¡ "'~ ~f/t. ~ . . . , Nanuq #3 Plug and Abandon 10-403 Summary 12-1-06 Well History: The Nanuq #3 well was originally drilled in March 2001 as an Alpine Satellite exploration well and suspended with the intention to later sidetrack the well in the 2006 and place the well in service as a producer for the Nanuq development. In August of 2005, diesel was found in the well cellar alerting Alpine operations to a possible leak resulting in a well bore integrity problem. State officials were notified of the contained spill. Down hole diagnostics were performed to pinpoint the location of a possible leak, but numerous tests were inconclusive in determining the origin of the leak. A thorough analysis was performed to understand the risk of proceeding with further diagnostics and attempting to salvage the well for future service versus plugging and abandoning the well. In an effort to protect the surrounding environmentally sensitive areas by preventing any further leakage, it is recommended that the well is plugged and abandoned in accordance to state guidelines. P & A summary 1. Notify AOGCC 48hrs in advance of all pressure testing and suspension operations. " 2. Rig up E-line and Tag cement plug at 5155' (existing cement plug in casing) . Pressure test to 1500 psi for 30min. (put on chart). 3. Set plug at 1000' md in 3 %' tubing with E-line. Perf through 3 %" tubing and 7" casing at 995'. 7" x 9 5/8" annulus is not cemented. 4. Establish circulation from 3 %" tubing to IA and OA to surface. 5. RU cement unit. Circulate cement down tubing taking returns up IA (3 %" x 7") When cement is to surface SI IA valve at surface. Open OA (7" x 9 5/8") and circulate cement to surface. 6. Excavate wellhead and cut all casing strings 3' below original ground level. Add cement as need to bring cement in all strings to surface. Weld on cover plate and backfill. · g;. .t = 43' 9-518" x 7" annulus freeze protected with 55 bbl diesel to approx 1950' MD TOC @ +/- 4300' MD (500' MD above top K2) Top K2 sand at 4830' MD Bottom K2 sand at 5170' MD Stage Tool set @ 5286' MD TOC @ +/- MD (600' MD above 7" RMlS Assy) Top Nanuq Reservoir at 7530' MD Top Kuparuk Reservoir at 8543' MD Well TD at 9112' MD 1 7645' TVD 19 Colville Nanuq #3 No. Schematic 103-20365-00 1-026 to Wellhead 16" Conductor to 117' 9-5/8" 40 ppf L-80 STC Surface Casing @ 1965' MD / 1781' TVD cemented to surface Tubing Supended with diesel to 2290' MD Completion Tubing Hanger plus 3-1/2", 93#/ft, Tubing to 2290' MD Top of cement plug @ ..4--/---~-- 5155' M 0 37.8 bbls of 15,8 PPG. Class G cmt w/additives Assume 50% excess annular volume. 7" RMlS latch Assembly @ 6985' MD 7" RMlS latch Assembly @ 8011' MD 7" 26 ppf L-80 STC Mod Production Casing @ 9092' MD 1 7626' TVD @ 19 deg Re: Nanuq #3 P&A . . Thanks Tim. Having XS is a good plan. I calculate about 60 bbls from 995'. Looks like you should have sufficient volume to do as you plan. Tom Maunder, PE AOGCC Crumrine, Tim William wrote, On 12/6/2006 11:18 AM: Hi Tom, 1) The estimated start date should be in box #15, but if not Dec 13 was expected. That was the original projected commencement. Realistically ~ Dec 15 is the target date now. I am trying to plan it when the cement unit will be up and running. I would like to get this done prior to the rig move to CD3 to prevent having to wait until ice road season and bringing equipment from Kuparuk. The less time for leaks to occur the better. 2)The 9-5/8" casing will not be perforated since there is already cement behind pipe. 3)There is no plan to squeeze any cement below the 995' perforations; however I do expect some cement to fall below 995' 4)Cement volume is approximately 50 bbls + 25 bbls excess. The plan is to pump to surface until we see clean cement, but we plan on at least 50% excess on hand. Tim Crumrine, P.E. Senior Engineer Western North Slope Growth ConocoPhillips Alaska (907) 265-6402 office (713) 515-9190 cell "There is no such thing as defeat except when it comes from within. As long as a person doesn't admit he is defeated, he is not defeated-he's just a little behind and isn't through fighting." -- Darrell K Royal -----Original Message----- From: Thomas Maunder [!~éJ:Ll~?:t;._?¡~_rr:9_.'cl~ª.E."E.~~9:ª<:n::í::r:':..:.§.t:(;lt;.<2' ak. us] Sent: Wednesday, December 06, 2006 9:31 AM To: Crumrine, Tim William Subject: Nanuq #3 P&A Tim, I am looking at your application and have a couple of questions. 1. When is the work planned? That information was not given on the 403. 2. When you perforate at 995', will the 9-5/8" casing also be perforated? 3. Is there any plan to squeeze some cement below the perforations in the 9-5/8" x 7" annulus? lof2 12/6/2006 11 :57 AM e e (~- ~" .""'- .' MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LascrFichc\CvrPgs _ Inserts\Microfilm _ Marker. doc ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 . December 5,2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 . Conoc;pJ,illips RECEIVED DEC 0 7 2005 Alaska Oil & Gas Cons. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of Drilline Waste on well CD4-319 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD4-319 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD4-319 approximately December 13,2005 or as soon as a permit is available. C"··~"",:I\'··· Please find attached form 10-403AD and other pertinent information as follows: 1. Annular Disposal Transmittal Form ;: ~;~:~ec~:~~~l~~~~~~~o~ular Disposal SCANNE[; DEC 1. ~ ,üß5 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. 11. Additional information regarding wells within Y4 mile radius at AOGCC: Nanuq 3, Nanuq 5 12. Copy of previous authorization (CD 1 and CD2) for disposal of new product cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (16.1 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.4 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT /LOT. If you have any questions or require further information, please contact Vem Johnson at 265-6081; Chip Alvord can also be reached by calling 265-6120. ~S' ery, 1 / 10 Ie> 5"""--- ~ c...--- ~ Vem Johnson Drilling Engineer cc: CD4-319 Well File Chip Alvord Anadarko Sharon Allsup-Drake ATO-1700 ATO-1530 ,~Q--^(t~ \."\K~ \CêC.D ~ ~ .~\'" ~~"'\. ~ \"if.O\--O;x,,") f: ~O-~-..)<;. ç- c.. ~Od -G~d') . ~~ ,,\ij"C...\v~~ '" '''0\\ ,,~~\\()~ ~~ \:) (è (t." s<L~.-\- \-'0 -\- ~L S'(~~)\'L ~Cè-\\ ..Ç\, \e:S ORIGINAL /JJ'lJV/I~!,,-OS- . . Casing Detail 95/8" surface casina WELL: DATE: 1 OF 1 NANUQ#3 3/3/2001 PAGES PHILLIPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Doyon 141 RT to LDS = 28.00' TOPS Above Rotary 6.70' 9 5/8" Landing Joint (35.20 total) RKB to LR 28.00 9 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.20 28.00 jts.29-47 95/8",40#, L-80 BTC 780.10 30.20 TPC Tam Port Collar 2.92 810.30 jts 3-28 95/8",40#, L-80 BTC 1067.29 813.22 FC Gemeco Float Collar 1.53 1880.51 jts 1-2 9 5/8", 40#, L-80 BTC 81.20 1882.04 FS Gemeco Float Shoe 1.75 1963.24 BTM OF SHOE @-----»»> 1964.99 TD 12 1/4" Hole 1973' CSQ Hanger goes in the top of Joint # 47 Tam Port Collar Jts # 28 & 29 23 TOTAL, Gemeco Bow Spring Centralizers - 4 Stop Rings 4- Centralizers in center of jts.1 & 2,28 and 29 over stop rings 19 - Centralizers over collars of jts. , 4-12, 15, 18, 21, 24, 32, 35,38,41,44 & 46 ** Fill using "Franks" fill tool - Remove tool 011 Joint before Hanger ** Baker Lok all connections from the Top of FC down ** Monitor returns closely ** Remove air from slips for first 10 jts ## Torque first 10 and average-Torque to AVG - Watch Diamonds Remarks: String Weights with Blocks: 110K Up, 85K On, 54K Blocks. Ran 47 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Best-a-Life 2000 thread compound on all connections. Doyon 141 Drílling Supervisor: Dearl W. Gladden . . ~.. ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. I~ate Rpt No I rig Accept - hIS Days Since AcceptlEst 3.3 1 Rig Relase . hIS: ASD005 03103I2OO1 5 02l28J2OO1 04:00:00 PM Well: NANUQ tI3 Depth (MD/TVD) 197311781 Prev Depth MD: 1973 Progress: 0 Contractor. DOYON Daily Cost $ 281019 Cum Cost $ 869935 Est Cost To Date $ Ria Name: Doyon 141 Last Csg: 9 518" .1965' Next Csg: T' .9278' +1- Shoe Test Operation At 0600: RJU to Test BOPS Upcoming Operations: Test BOPs - PU DP and SIB In derrick· PIU BHA #2 MUD DATA DRILLING DATA BIT DATA EH&S DRILLSIBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL SPUD 1973 1 N TST D2J28J2001 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRIll lAST FIRE DRill 10.1ppg 12.25 0212212001 0212012001 VISCOSITY PUWT MAKE MAKE SPill LAST CONFINED LAST SPILL DRILL 54sqc 110K STC N SPACE 02J23l2OO1 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 27/13 85K FGS+C GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3145 4/61 MG4607 APIWl MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRill WATER USED - 340 5.7 1973 0310312001 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN ... POTABLE WATER 200 mll30 min 117 INJECTION USED· BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.9% 1856 1R-18 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST Atfr/AST SOURCE WELL TEMP 'F -21 150bbl 1330 III 9.1/13.2 1 Nanuq #3 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 6 16.3 11211 5-15 - ph LINER SZ RPM1 RPM1 PRESSURE (PSQ WIND DIRECTION 30' 8.9 6\611 50. . lGS SPM1 TFA TFA INJECTION FLUIDS CHILL FACTOR 'F -31.63 4.7% 6316311 .628 Water Base Muds 1280 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 330 254125411 1211511511511 11111 0 0 DAILY MUD SPS1 BIT COST BIT COST CONTRACTOR 26 $1796.94 III 12137 0 PERSONNEL 0 TOTAL MUD SPP1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 8 $42607.49 III 6181RGIA III 1280 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 18 BAROID III EI31WTITD III 2440 PERSONNEL TOTAL 53 BHA DESCRIPTION I DRILLPIPE DATA BHA NO 00 10 WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHALENGTH 5 4.281 19.5 G105 4-1/2 IF DATE LAST 5 3 50.00 HWDP 4-1/2 IF INSPECTED: HOURS ON JARS: 192.2 TIME I END I HOURS OPS CODE HOLE SECT I PHASE OPS I OPERATIONS FROM ??oo - ??oo 12:00 AM 01:30 AM 1.50 CIRC SURF Other Clrcu & Condition to Run Csg 01:30 AM 04:00 AM 2.50 TRIP_OUT SURF Trip Out ObSerVe well - Pump dry job - TOM 04:00 AM 05:00 AM 1.00 BHA SURF Trip Out UD BHA· UD 3 NM Des & NM stab 05:00 AM 05:30 AM 0.50 SURV SURF Other Down Load MWO Info 05:30 AM 06:30 AM 1.00 BHA SURF Trip Out UD MWO,Motor & Bit 06:30 AM 08:00 AM 1.50 RUN_CSG SURF Casing and RJU to Run 9 5J8" Csg (Doyon Csg Crew) Cementing 08:00 AM 12:00 PM 4.00 RUN_CSG SURF Casing and PJSM - Run 9 518" 40# LBO BTC Csg (36 jts IH end of tour) Cementing 12:00 PM 01:30 PM 1.50 RUN_CSG SURF Casing and Con't Running Csg ( Total ran 47 ts ) Cementing 01:30 PM 02:00 PM 0.50 RUN_CSG SURF Casing and UD Frank's flU Tool 1 MJU CMT Head Cementing 02:00 PM 05:30 PM 3.50 CIRC SURF Casing and Clrcu . SlOWly stage up circulation. Clrcu . 8 BPM & Reclp Cementing Csg . No fluid loss ( Co Man Pre Job Safety Meeting with Crew & Con1ractors while clrcu for CMT procedure) 05:30 PM 06:00 PM 0.50 CMT_CSG SURF Casing and Pressure Test Lines· Repair Leak in CMT manifold Cementing Daily Drilling Report: NANUQ #3 0310312001 Page 1 . . 06:00 PM 07:30 PM 1.50 CMT_CSG SURF Casing and Dowell Retest Lines - Cmt per Well Program. Pllmp 5 bbl Cementing watar-Test Lines 35OOpslo3O bbls CW 100.Drop Bttm PJllg 50 bbls MlldPIIsh e 10.5ppg 0300 bbls Lead CMTe 10.7ppg 72 bbls Tall CMT e 15.8ppg-Drop Top PIIIg .pllmp 10 Water ancl tIIm over to Rig 07:30 PM 08:00 PM 0.50 CMT_CSG SURF Casing and Rig displace WI Rig pllmps . Blimp ptllg w/1319 sUes (CalcII Cementing blimp 1315 sUesH CIP. 8:10 ... Note... Had 10.7ppg Cmt to SIIrface e 509 sUes of displacement (82 bbls total back) 08:00 PM 08:30 PM 0.50 CMT_CSG SURF Casing and Hold 880psi (500psJ over blimp) ff 5 min - Bleed off - FIts Cementing held 08:30 PM 09:00 PM 0.50 CMT_CSG SURF Casing and RID Cmt Heacl-l.anding Jt & All Csg tools - Clean tools from Cementing floor 09:00 PM 12:00 AM 3.00 NU_ND SURF other PJSM - NID Dlvelter System 12:00 AM 24.00 Supervisor. DEARL W. GLADDEN Daily Drilling Report: NANUQ #3 0310312001 Page 2 Well Name: CASING TEST and FORMATION INTEGRITY TEST #3 for Nanuk #3 Supervisor: Dearl W. Gladden NANUQ #3 3/6/2001 Date: o Initial Casing Shoe Test Reason(s) for test: 0 Formation Adequacy for Annular Injection o Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 40# L-80 BTC Casing Setting Depth: Hole Depth: 2,022' TMD 1,819' TVD 1,965' TMD 1,781' TVD Mud Weight: Length of Open Hole Section: 57' 9.5 ppg EMW = Leak-off Press. + Mud Weight 0.052 x TVD = 220 psi + 9.5 ppg 0.052 x 1,819' ::::: 11.8 Pump output = 0.1010 bps 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,100 psi 2,000 psi 1 ,900 psi 1,800 psi W 1.700 psi It: 1 ,600 psi :J 1,500 psi ~ 1 ,400 psi W 1,300 psi It: 1,200 psi D.. 1,100 psi 1,000 psi 900 psi 800 psi 700 psi 600 psi 500 psi 400 psi 300 psi 200 psi 100 psi o psi Fluid Pumped = 4.6 bbl I ..- I--- I I / r ~ I , - _. JI. Iii' I I r ~ LEAK-OFF TEST - I - II" ~CASING TEST ~ i! I······· LOT SHUT IN TIME - I - I ---c"---c CASING TEST SHUT IN TIME - 'Iii' .. 1 '" ~ - ¡;; " ~ tn ~ ~ STROKES '" w " '" " '" w ~ ~ '" ~ ~ '" '" '" '" ~ ~ ~ w w ~ w ~ ~ '" NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA '" ~ MINUTES FOR LOT STROKES PRESSURE r- -- - - - - ----- ---"r- - - - --- ---- - - - - '1- - - - -- - - ---------¡ : : () stks: (} psi : ¡----------------¡---2-štk-š---r--1-.¡Õ-pšT-¡ ¡----------------r---4-šTj{-š---r--i.¡o-pš-¡---1 r----------------¡---S-šik-š---r--1-6Õ-pšT-¡ r----------------r---S-šiks--l----fjõ-pš-f--l r--------------r-.¡O-šTks--r--17Õ-pšT--l ~---------------+---------------+----------------.¡ : : 12 stks : 170 psi : ¡----------------¡---.¡4-šTks--¡----fãõ-pšT--¡ ¡---------------¡---16-ší-ks--r---19õ-psf--l ¡--------------T--.¡s-šTks--T---1-gÕ-pšT-l r----------------¡-2o-š-iks--r--iõõ-pšT-l r--------------T-22-štks--r--2ÕO-pšT--l ~---------------+---------------+----------------.¡ : : 24 stks : 200 psi : ¡---------------¡--26-ší-ks--r--210-pšT--¡ r---------------¡--2s-šTks-¡----2.¡Õ-pšT¡ r---------------¡--30-šTks--T--2.¡O-pš-f--¡ ¡----------------¡--32-šTks--T---2-2õ-pšTl r---------------I--34-šTks--r---2-2Õ-pš-f--l ~---------------+---------------+----------------.¡ : : 36 stks : 190 psi : ¡----------------¡---j8"iiïks--r---1-éõ-psT--¡ r--------------T-4o-siks-I---fšõ-pšT--l r----------------¡--42-šTks-I---14o-pšTl r----------------¡--4~fšTks--T---f4õ-pš-f--l r---------------l.....·46·stks..·..r....."1·4Ö..j)'si"·..··¡ I I . : SHUT IN TIME: SHUT IN PRESSURE ¡~~~~I::~~.~~~:::~.l:ill~ ¡ 3.0min ! ! 110psi ¡ ~~~~~~šEiÿ~~~~~~~~~~~~~~~~~~~~J~~~~}Q~Ë!~r~] : 5.0mm : : 110psl : ~~J~~E~~~~~~~~~~~~~~~~~~~~~~rJ~iQ~Ë!~~~~~~ : 7.0 mm : : 110 pSI : ¡---ã-.õ-ñï¡ïl--r--------------r--1-.¡o-pšT--¡ r---g-·õ-ñ-iTñ---¡---------------r--1-.¡õ-pš"f-l r--1Õ~(fmiñT-------------:----1".¡o-pšT-l ...._____.. ___ __.. ____L_........................ __.J__ ___ ____________-' CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE C~~~~~~~~~~~~~r~~~~~!~~~~~r~~~IË~~~~] ! ! 2 stks ¡ 35 psi ! F~~~~~~~~~~~~~i~~~~~~1~f~t~~~~~~~~~F~~¡ ¡---------------1----ã-stk'š---T--217-jišT--l r----------------I---1-Õ-stk'š-i---472"pŠ-¡--¡ t~~~~~~~~~~~~~J:~I~~!!~~~t~~f~~~ë![. ! ! 14 stks ¡ 994 psi , ¡----------------î---f6"Š-ikš--!--.¡~199-jjsi--¡ ¡----------------rTã-Š-tk'š--r-{40ifpsn ¡----------------1---2õ-Š-ik'š--T--.¡~s6f-psi-l :---------------:---22-Š-ikš--T--.¡~944-psi-l I----------------i---------------+--------------;--I L_______________L~~_~!~!!__.L_~l~~~_.e~U 1~~~~~~~~~~~~~~~~~~~~~~~~=~=~~~t~~~~~~~~~==~~:1 ~--------...-------~---------------+-----------------: I I I I : : , : r----------------1---------------T-----------------: } --- -------------1- -----............ --.. t----.. --...... -~--""-1 I I I I I.._______________.t._______________-'-_________________I 1 I I I t : ~ 1 , , : SHUT IN TIME : SHUT IN PRESSURE r--Õ~Õ-m¡r~i--I---------------r-2-:5-1-Õ-pS¡-! ¡---1-~Õ-mfñ--T-------------r2-,5Õ5psi! t - ----------c----i ----- - - - - - - - - -- y-- - - - - - ----- - -~--I !~~~~~ª~ill[K~~l~~~~~~~~~~~~~~~!~l~~~~~~. ! 4.0 mìn ¡ ! 2,495 psi , ¡---5~Õ--mfñ---î-------"-------r-2~495-ps¡--¡ ¡---6~Õ--mfñ--T------------¡--2~495jjsn ¡---Yõ--mfñ--:---------------r-2~495--psi--¡ r-" ----.................... ~.... ------------- ï -------...... -------, : 8.0 min : : 2,495 psi : I-----------c----i---------------+--------------;-- : 9.0 mm : : 2,495 pSI : ¡--:fÕ~Õ-m¡rï-¡__-------------¡_-2~495-jjsì--! ¡--:¡5~Õ¡n¡ñ-¡---------------¡_-2~49Õ--psn ¡--2õ~õ¡Tï¡ñ-T-------------¡--2~49õ-psì-l ¡--25~Õ-m¡ñ--1--------------1--2~49Õ--psn :-3Õ~Õ-rn¡ñ-T-------------T--2~49Õ--ps¡-: I,.________________.I_______________..L_________________I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY . . Casing Detail 7" casina WELL: DATE: 1 OF 1 NANUQ #3 3/14/2001 PAGES PHILLIPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to Tbg Hgr =25.53 25.53 FMC Fluted Hanger 1.85 25.53 JTS 92-218 7" 26#, L-80 BTC-MOD 5258.95 27.38 7" Weatherford Gemoco Stage Tool 2.34 5286.33 JTS 51-91 7" 26#, L-80 BTC-MOD 1696.19 5288.67 7" Sperry Sun RMLS latch assembly w/8.125" OD & 6.140" ID 2.08 6984.86 JTS 44-50 7" 26#, L-80 BTC-MOD 285.38 6986.94 7" 26#,L-80 BTC-MOD MARKER JT(19.90+20.20') 40.10 7272.32 JTS 27-43 7" 26#, L-80 BTC-MOD 698.93 7312.42 7" Sperry Sun RMLS latch assembly w/8.125" OD & 6.140" ID 2.08 8011.35 JTS 4-26 7" 26#, L-80 BTC-MOD 952.61 8013.43 Weatherford screw in shut-off baffle 8966.04 JTS 3 7" 26#, L-80 BTC-MOD 40.49 8966.04 Gemeco Float Collar 1.42 9006.53 JTS 1 - 2 7" 26#, L-80 BTC-MOD 82.44 9007.95 Gemeco Float Shoe 1.72 9090.39 SHOE Depth 9092.11 TD 8.5" Hole ==> 9112.00 33 TOTAL, Gemeco Bow Spring Centralizers 2, Centralizers in center of jts. 2 and 3 over stop collars 31 ,Centralizers over collars of jts. 4,5,6,7,9,11,13,15,17,19,21,23 29,32,52,55,58,61,64,67,70,73,76,169,171, 173, 175,203,208, 213 & 217 Remarks: String Weights with Blocks: 275k Up, 145k On. Ran 218 joints of casing & 1 marker jt. Drifted casing with 6.151" plastic rabbit. Used Best-o-Life 2000 thread compound on all connections.Bakerlocked btm 3 jts, latch subs & stage collar. Doyon 141 Drilling Supervisor: R. W. SPRINGER . . ~... ~" ARCO Alaska, Inc. Daily Drilling Report AFC No. 1=512001 Rpt No I fig Accept - hrs Days Since Accept1Est 15.3 I Rig Relase - hrs: ASDOOS 17 0212812001 04:00:00 PM Well: NANUQ #3 Depth (MD/TVD) 9112/7645 Prev Depth MD: 9112 Progress: 0 Contractor. DOYON Dailv Cost $ 127512 Cum Cost $ 3400489 Est Cost To Date $ Rig Name: Dovon 141 Last Csg: 9 518" ~ 1965' Next Csg: T' ~ 9278' +I- Shoe Test 11.8 Operation At 0600: WAITING ON CEMENT TO OPEN STAGE CEMENTING TOOL. Upcoming Operations: FINISH CEMENTING CASING, NUIDP, SECURE WELL MUD DATA DRILLING DATA BIT DATA EH&S DRILLSIBOPDATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL LSND 2R2 N TST 0311412001 03111/2001 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8pp!! 8.5 0212212001 0311212001 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 43sqc HYC N SPACE 03104/2001 PVIYP SOWT TYPE TYPE TYPE FUEL & WATER .... 10/15 DS70FNLPV GELS A VG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3996 5/71 200349 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED- 180 3.3 0311512001 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 115 Omll3O min 8569 INJECTION USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 543 CD1·19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADTlAST SOURCE WELL TEMP of ·26 338bbl 2300111 7.751 I Nanuq #3 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 24 12.0 11211 5-15 - ph LINER SZ RPM1 RPM1 PRESSURE (psO WIND DIRECTION SO· 10.1 61611 SO-70 - LGS SPM1 TFA TFA INJECTION FLUIDS CHILL FACTOR of -81.11 SO.05% 60160 II Water Base Muds 220 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 1 500 soo III 12112112112112 11111 0 112 0 DAILY MUD SPS1 BIT COST BIT COST CONTRACTOR 27 $1350 1120140 0 0 PERSONNEL 0 TOTAL MUD SPP1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $194642 11220 1410 III III 220 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbQ SERVICE 12 BAROID 9.8111 III III 8310 PERSONNEL TOTAL 45 BHA DESCRIPTIoN I BIT, NAVlDRILL MACH 1 XL, NM STAB, FRT, FRT, MWD, HANG OFF SUB, XO,3NM DP,XO ,6 HWDP, Jars# 1622-0006,23 HWDP DRILLPIPE DATA BHA NO 5 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHA LENGTH 1129.97 5 4.281 19.5 G105 4-1/2 IF DATE LAST 5 3 SO.OO HWDP 4-1/2 IF INSPECTED: HOURS ON JARS: 275.2 TIME I END HOURS OPS CODE HOLE SECT I PHASE OP$ I OPERATIONS FROM ??oo - ??oo 12:00 AM 03:00 AM 3.00 TRIP_OUT PROD Trip Out FINISH POH, LAY DOWN HWDP. 03:00 AM 06:00 AM 3.00 BHA PROD Trip out REMOVE SOURCES, DOWNLOAD MWD, LAYDOWN MWD & MOTOR. 06:00 AM 06:30 AM O.SO BOPE PROD Other PULL WEAR RING & INSTALL TEST PLUG. 06:30 AM 07:30 AM 1.00 BOPE PROD Other INSTALL T' RAMS IN TOP RAMS. 07:30 AM 08:00 AM O.SO BOPE PROD Evaluation TEST DOOR SEALS TO 3500 PSI. 08:00 AM 09:30 AM 1.50 CASG PROD casing and RIG UP TO RUN 7" CASING. Cementing 09:30 AM 01 :30 PM 4.00 CASG PROD Casing and PJSM, RUN CASING TO SURFACE SHOE. Cementing 01:30 PM 02:00 PM O.SO CASG PROD Other FILL PIPE ~ SHOE. 02:00 PM 08:30 PM 6.SO CASG PROD casIng and CONTINUE RUNNING CASING TO 9092'. Cementing 08:30 PM 09:00 PM O.SO CASG PROD Other RID SPYDERS-FILL UP TOOL-RIU CEMENTING HEAD. 09:00 PM 12:00 AM 3.00 CIRC PROD Other ESTABLISH CIRCULATION CIRCULATE & CONDITION MUD FOR CEMENTING. 12:00 AM 24.00 Daily Drilling Report: NANUQ #3 0311512001 Page 1 . . .... ...." ARCO Alaska, Inc. Daily Drilling Report AFC No. 1~4I2OO1 Rpt No I rg Accept. hrs Days Since AcceptlEst 14.31 Rig Relase - hrs: ASD005 16 0212812001 04:00:00 PM Well: NANUQ tI3 Depth (MDnvD) 8572/7140 Prey Depth MD: 8572 Progress: 0 Contractor. DOYON Daily Cost $ 170083 Cum Cost $ 3272977 Est Cost To Date $ Rig Name: Doyon 141 Last Csg: 9 518" lit 1965' Next Csa: T' lit 9278' +1- Shoe Test 11.8 Operation At 0600: LAYING DOWN BHA, PREPARE TO RUN CASING. Upcoming Operations: RUN CASING, CEMENT, FREEZE PROTECT & MOVE. MUD DATA DRILLING DATA BIT DATA Ðt&S DRILLSIBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spill) LAST BOPIDIVERT LAST BOPIDRILL LSND 7112 2R2 N TST 0311412001 0311112001 WEIGHT ROTWT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8DDg 210 8.5 02/2212001 0311212001 VISCOSfTY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 46sqc 260 HYC N SPACE 0310412001 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 12/16 180 DS70FNLPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 4298 6181 10 200349 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED- 520 3.4 20 0311412001 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 121 Oml130 min 25000 8569 INJECTION . USED - BBLS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & 8.5% 21000 3 CD1 -19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADTIAST ADTIAST SOURCE WELL TEMP of -23 653bbl 2300111 7.751 1 Nanuq tI3 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 14 12.0 11211 5-15 - ph LINER SZ RPM1 RPM1 PRESSURE (PSO WIND DIRECTION SOo 10.0 61611 50-70 - LGS SPM1 TFA TFA INJECTION FLUIDS CHILL FACTOR OF -õ9.93 50.05% 60 160 II Water Base Muds 540 PIT VOL GPM2 JETS JETS ARCO PERSONNEL 2 SOO 500111 12112112112112 1I111 0 112 0 DAILY MUD SPS1 BIT COST BIT COST CONTRACTOR 30 $11733 1120140 0 0 PERSONNEL 0 TOTAL MUD SPP1 DULL DULL TOTAL VOL (bbO MISC PERSONNEL 5 $193293 I 12201410 III III 540 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbl) SERVICE 15 BAROID 9.8111 III III 8090 PERSONNEL TOTAL 52 BHA DESCR1P1lON I BIT, NAVlDRILL MACH 1XL, NM STAB, FRT, FRT, MWD, HANG OFF SUB, XO,3NM DP,XO ,6 HWDP, Jars# 1622..0Q06,23 HWDP r)l'~:;·1 I '.j)': nA ; ^ J BHA NO 5 OD ID ,,~~~~~~,.¡··-I ~~!~!..i)i -, :;:J:;¡õ,;:..~;T)~"'T D ;,~~s;' --r ~·8":G···~": BHALENGTH 1129.97 S 4.281 19.5 G105 4-112 IF DATE LAST 5 3 SO.OO HWDP 4-112 IF INSPECTED: HOURS ON JARS: 275.2 11M!:.· I END HOURS OPS CODE I HOLE SECT I PHASE OPS I OPERA110NS FROM ??oo - ??oo 12:00 AM 01:00 AM 1.00 TRIP_IN PROD Trip In FINISH RIH TO 8465', BREAK CIRCULATION 4t 7630'. 01:00 AM 02:00 AM 1.00 OTHER PROD Evaluation MAD PASS FJ8496.855S'. 02:00 AM 05:30 AM 3.SO REAM PROD other WASH & REAM l1GHT HOLE (SLOUGHING SHALE SECTION) FI8S31-8555'. 05:30 AM 06:00 AM 0.50 OTHER PROD Evaluation MAD PASS FI8555-8572'. 06:00 AM 03:00 PM 9.00 DRIL PROD Making Hole DRLD FI8572-9112', ART 7.75 HR. 03:00 PM 05:30 PM 2.50 CIRC PROD other CIRCULATE BOTTOMS UP, SURVEY, PUMP SWEEP AND OBSERVE WELL 05:30 PM 06:30 PM 1.00 WlPERTRP PROD other SHORT TRIP FROM 9112-8370', NO PROBLEMS WITH HOLE. 06:30 PM 09:30 PM 3.00 CIRC PROD other CIRC BTMS UP, SWEEP, OBSERVE WELL, PUMP SLUG. 09:30 PM 12:00 AM 2.SO TRIP_OUT PROD Trip out POH FI CASING. 12:00 AM 24.00 Supervisor. RoW. SPRINGER Daily Drilling Report:NANUQ #3 0311412001 Page 1 . . .... ~r ARCO Alaska, Inc. Daily Drilling Report AFC No. I~te Rpt No Irg Accept - hIS Days Since AcceptJEst 16.31 Rig Relase - hIS: ASD005 0311612001 18 0212812001 04:00:00 PM lVell: NANUQ 3 Depth (MDlTVD) 911217645 Prey Depth MD: 9112 Progress: 0 Contractor: DOYON Daily Cost $ 292872 Cum Cost $ 3693361 Est Cost To Date $ Rig Name: Doyon 141 Last Csg: 7" e 9092' Next Csg: Shoe Test 11.8 Jperation At 0600: NIPPLlNG UP TREE pcoming Operations: FREEZE PROTECT & PREPARE FOR MOVE TO RENDEZVOUS A MUD DATA DRILLING DATA ..... BIT DATA EH&S DRILLSIBOP DATA MUD TYPE DEPTH BIT NO. BIT NO. ACCIDENT (non-spilO LAST BOPIDIVERT LAST BOPIDRILL LSND 2R2 N TST 0311412001 0311112001 WEIGHT ROT WT SIZE SIZE EMPLOYER LAST H2S DRILL LAST FIRE DRILL 9.8ppg 8.5 0212212001 03112/2001 VISCOSITY PUWT MAKE MAKE SPILL LAST CONFINED LAST SPILL DRILL 45sqc HYC N SPACE 0310412001 PVNP SOWT TYPE TYPE TYPE FUEL & WATER 10/15 DS70FNLPV GELS AVG DRAG SERIAL NO SERIAL NO VOLUME (gallons) FUEL USED 3121 0/01 200349 APIWL MAX DRAG DEPTH OUT DEPTH OUT LAST SAFETY MTG DRILL WATER USED- 660 0311612001 BBLS HTHP WL TRQ BTM DEPTH IN DEPTH IN POTABLE WATER 138 mll30 min 8569 INJECTION USED - BBlS SOLIDS TRQ OFF FOOTAGE FOOTAGE INJECTION WELL WEATHER & % 543 CD1 -19 PERSONNEL DATA HOLE VOLUME PUMP PRES ADT/AST ADTIAST SOURCE WELL TEMP OF -32 331bbl 2300111 7.751 I Nanuq #3 MBT PUMP NO WOB2 WOB2 RATE (bpm) WIND SPEED 10 1\211 5-15 - ph LINER SZ RPM1 RPM1 PRESSURE (PSij WIND DIRECTION 45° 61611 50-70 - LGS SPM1 TFA TFA INJECTION FLUIDS CHILL FACTOR of ~0.25 % 6016011 Water Base Muds 1160 PIT VOL GPM2 JETS JETS Fresh Water ARCO PERSONNEL 1 0 500111 12112112112112 11I11 100 112 0 DAILY MUD SPS1 BIT COST BIT COST CONTRACTOR 29 $500 1120140 0 0 PERSONNEL 0 TOTAL MUD SPP1 DULL DULL TOTAL VOL (bbl) MISC PERSONNEL 5 $195642 I 12201410 III III 1260 COMPANY MUDWT GRADE GRADE TOT FOR WELL (bbQ SERVICE PERSONNEL 13 BAROID 9.8111 III III 9570 TOTAL 48 BHA DESCRIPTION I DRILLPlPE DATA BHA NO 5 OD ID WEIGHT GRADE CONNECTION CLASS 2 LENGTH BHAlENGTH 5 4.281 19.5 G105 4-112 IF DATE LAST 5 3 50.00 HWDP 4-112 IF INSPECTED: HOURS ON JARS: TIME I END I HOURS OPS CODE I HOLE SECT IPHASE OPS I OPERATIONS FROM ??oo ' ??oo 12:00 AM 01:00 AM 1.00 CIRC PROD Casing and CIRCULATE & CONDITION MUD, HOLD PJSM, BATCH UP Cementing CEMENT. 01:00 AM 03:30 AM 2.50 CMT_CSG PROD Casing and TEST LINES, PUMP 20 BBL PREFLUSH, 30 BBL SPACER, Cementing 96 BBL 15.8 PPG GASBLOK CMT, DROP PLUG, DISPLACE WIRIG CALC AMOUNT, CEMENT IN PLACE e 0300 HR.. DID NOT BUMP PLUG, FLOATS HELD, FINAL CIRC PRESSURE 700 PSI e 4BPM. 03:30 AM 07:00 AM 3.50 PRB_WOCM PROD Casing and WAITING ON CEMENT DUE TO PLUGS NOT BUMPING. Cementing 07:00 AM 07:30 AM 0.50 OTHER PROD Casing and SHEAR STAGE TOOL OPEN, PINNED FOR 2600 PSI, TOOK Cementing 3500 PSI TO SHEAR. 07:30 AM 08:30 AM 1.00 CIRC PRoo Casing and CIRCULATE BOTTOMS UP, NO CEMENT IN RETURNS Cementing FROM 1ST STAGE. 08:30 AM 10:00 AM 1.50 CMT_CSG PROD Casing and CEMENT 2ND STAGE- PUMP 20 BBL PREFLUSH, 30 BBL Cementing SPACER, 37.8 BBL 15.8 PPG GASBLOK CEMENT, DROP PLUG,5 BBL CMT ON TOP OF PLUG, DISPLACE WIRIG, Daily Drilling Report: NANUQ #3 03116/2001 Page 1 . . BUMP CLOSING PLUG W11200 PSI OVER ClRC PRESS, HOLD 1500 PSI FOR 5 MINUTES, CHECK FOR FLOW.oK. ClP 10:00 AM 11:30 AM 1.50 OTHER PROD other RIG DOWN CSG EQUIPMENT, CLEAR FLOOR. 11:30 AM 12:00 PM 0.50 OTHER PROD other INSTALL r X 9-ðI8" PACKOFF. 12:00 PM 03:30 PM 3.50 RUN_COMP PROD Completion PJSM RIU & RUN 22IØ' 3-112" TUBING OPEN ENDED STRING WEIGHT 15K. 03:30 PM 05:00 PM 1.50 RUN..COMP PROD Casing and PIU T8G HANGER AND LAND Cementing SET TWO WAY CHECK RID TUBING EQUIPMENT. 05:00 PM 12:00 AM 7.00 OTHER PROD other RIU & LAY DOWN DRILLPIPE FROM DERRICK. 12:00 AM 24.00 Supervisor: R.W. SPRINGER Daily Drilling Report: NANUQ #3 0311612001 Page 2 . . Sh0nnon, of " ne\\t-pròdud:. " lip fluids routine üf tr\ud and cemen ,") t. as rmr'/ll as tbe clean up fluids r€su! from out. the t.a::¡k~} at the mud plant tor usinq oil base murl, The of ffl 1 pad, at CLuBS I 2 to and and eIlvironrn..e:'lti:Ü Ir: the~}e "n':.~ques l: s lhe \.¡as le no di :'f0-tT~l:t than previously 1:- i (~~B this copy of email, Phi your is 1":;0 of' clei'ln up as any :;r. Pe LL'O It~u!U En~Jil~eer hLP 8nv Coord 1t.'¡·o t(3 ~ :> H.::". > Si t>e .. SiL e :i 1:1 1 999 J b¡:l!;;erl and the on-site .' :> :> > 'r'nnks at. the :!'Iud products. >- the mud in and it is a l\nIlular:· d1 Cðse. vlell clast¡ I being the ty to presents n "is ;... )< ~ for faci :~ effl Ué.flt » faci :;.. alternative ir. compromise waste management . . ;?' do at (907) 670-4200 :> ). "> by Brrv on. 0112:50 Pt...¡ :;. :>- " :::- lILt? Ew/ Coord ;::.. » Oßl31/()1 12 :4S PM :> :> ..aJc..us > r:c: > Request l:o (Je t. COffiG!r.t :.:: i nSç¡(::r: at C::>2 > :> {PAl) _ CDl and :> :> ;'<:0. > :> :> ;> > '> > >: '> :> _L [ ',¡,'ou contact at 670-';200. :> ~,"'" > tonLmal)nder.vd e Conoc~illips Alaska e P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 4, 2005 ._~o \ - O,Jp .'¿.....-- Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 5CANNED DEC 1 920D5 Subject: Report of Sundry Operations for well Nanuq 3. Dear Mr. Maunder: Enclosed please find a 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. exploratory well Nanuq 3. The Sundry regards re-entering the suspended well to perform diagnostic work. Please call MJ Loveland or Marie McConnell at 659-7224, or me at 659-7043 if you have any questions. Sincerely, ;;t.. ~C.~ Jerry Dethlefs Problem Well Supervisor Attachments e e R !. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSasb¡ measured 9112' feet true vertical 7646' feet measured 9022 feet true vertical 6276 feet Length Size MD 117' 16" /62.58# 117 1965' 9-5/8" / 40# 1965 9092' 7" / 26# 9092 Repair Well D Pull Tubing D Operat. ShutdownD 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 42' 8. Property Designation: Colville River Unit Nanuq 3 Exploratory 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Production Perforation depth: Measured depth: None true vertical depth: None Tubing (size, grade, and measured depth) 3-1/2",9.3,2290 MD. Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development 0 Stratigraphic D Stimulate D Waiver D Re-enter Suspended Other 5. Permit to Drill Number: Exploratory D Service D 6. API Num6êE 50-103-20365-00 9. Well Name and Number: NANUQ 3 10. Field/Pool(s): #N/A Plugs (measured) Junk (measured) TVD Burst Collapse 117' 1775' 7627' Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development D Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oilD GasD WAG D GINJ D WINJ D WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: 305-31 0 Contact Marie McConnell/MJ Loveland Printed Name Jerry Dethlefs Signature A fl ~ ... L.",r Co. Form 10-404 Revised 04/2004 RBDMS BFt NOV íI g 7DŒj Title Phone Problem Well Supervisor ~_£ 659-7224 Date /~~ ORIGINAL Submit Original Only ~ e e ConocoPhillips Alaska, Inc. Exploratory Well Nanuq 3 (PTD 2010260) REPORT OF SUNDRY OPERATIONS 10-404 November 4, 2005 As per Sundry Approval #305-310, ConocoPhillips Alaska (CPA) re-entered Nanuq 3 to perform diagnostics to determine if the surface casing is the source of a leak. The work was performed during the period October 22 through 24,2005. The AOCC Field Inspector was notified of the upcoming work four days prior to work commencement. The daily field reports are as follows: 10-21-05: Pull BPV, rig up tanks and fluids to wellhead. 10-22-05: Circ well with hot SW to warm for diagnostics. Heat water to 135 deg F. 10-23-04: Circ well with hot SW to warm for diagnostics. 10-24-05: Purged N2 down OA for OA X Atmosphere communication. No leak in SC found. T/I/O=100/100/60. Upon arrival LRS was circulating FW warming up the well. Filled conductor with FW until returns came out downspout. FW temp in conductor = 106 degrees. Initial OA FL @ SF. Purged first bottle ofN2 down OA, OA pressure=380 psi. Shot OA FL @ 90', no fluid returns up conductor and no N2 bubbling in FW in conductor. Monitored for 15 min, OA pressure=280 psi, and shot OA FL @ same location. Purged second bottle ofN2 down OA and shot FL @ 90'. OA pressure=380 psi. Monitored 15 min, OA pressure =320 psi, and FL @ same location. Purged third bottle ofN2 down OA, OA pressure =420 psi, and OA FL @ 90'. 15 min monitor, OA pressure = 350 psi, OA FL @ 90'. Purged fourth bottle ofN2 down OA, OA pressure = 420 psi and OA FL dropped to 120'. 15 min monitor, OA pressure = 360 psi and OA FL @ 120'. Purged fifth bottle ofN2 down OA, OA pressure =430 psi, OA FL @ 120'. During all five bottles ofN2, we did not get any fluid or N2 returns up the conductor. Evacuated fluid out of conductor down to cement top. Bled OA down to 0 psi. Final T/I/O=1 0011 00/0. 10-24-05: BPV installed in well. Well is secured. Summary: The Outer Annulus was blown down with nitrogen to 120' and there was no indication of gas leaks to the surface in the conductor x surface casing annulus. Any further investigation using this method will require a larger source of nitrogen gas supply to reach a deeper depth. The well is secured and is returned to Suspended status. NSK Problem Well Supervisor 11/04/05 ) ') .-p~~ :l ru \'Q);\ .,.",'\ '\ ~,\, u ) i.:.~.:::D 'j[ :....:::::3 Y-"'-." :1 Lr'~" II ., r^1~ 'J FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jeny Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. box 100360 Anchorage, Alaska 99510 \/D~ ~~ Re: Nanuq #3 Sundry Number: 305-310 5(;AN\N\Er'~ NO\N 0 ~ 2005 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field' inspectof'af'(907-) 659---3607, (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fùe with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Su perior Court unles rehearing has been requested. DATED this If day of October, 2005 Encl. ) ) y ConocoPhillips Alaska RECEIVED OCT 11 'l005 . o. G s Cons. CommissIon Maska 01\ OL a AnchMage P~O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 10, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 9950 I Subject: Re-entering suspended exploration well Nanuq 3. Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. exploratory well Nanuq 3. The Sundry regards 20 AAC 25.010, re-entering a suspended well. CP AI intends to perform diagnostic testing work on the well. Please callMJ Loveland or Marie McConnell at 659-7224, or me at 659-7043 if you have any questions. Sincerely, '1 ( '.. ~--'/,--ý./:J .Y;'¿~'L'-I' c c..···/~~ .,~~/~ /7'- "./ ) Jerry Dethlefs Problem Well Supervisor Attachments (}fJt (8 -II-OS- ) (})r;:y"h ß RECEIVE £. STATE OF ALASKA ~ [j\~ ALASKA Oil AND GAS CONSERVATION COMMISSION OCT II Z005 APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Alaska Oil & Gas Cons. Commission Operational Shutdown D Perforate D Waiver An~age Other 0 Plug Perforations D Stimulate D Time Extension D Perforate New Pool D 1. Type of Request: D D D Suspend D D D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 42' Repair well Pull Tubing 8. Property Designation: Colville River Unit Nanuq 3 Exploratory 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9112' 7646' 9022 Casing Length Size Conductor 117 16" /62.58# Surface 1965 9-5/8" / 40# Production 9092 7"/26# Perforation Depth MD (ft): None Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Perforation Depth TVD (ft): None October 20, 2005 Date: 4. Current Well Class: Re-enter Suspended Well o 5. Permit to Drill Number: 201-026 V 6. API Number: -/' 50-103-20365-00 9. Well Name and Number: NANUQ 3 10. Field/Pool(s): #N/A PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6276 MD TVD Burst Development 0 Stratigraphic D Exploratory 0 Service D Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethlefs S· t ¡:.../. . /" C· f') ~~ Igna ure t.-- c¿ ¿zc-'.n. / ...c-. .~~ I /F Commission Use Only 117 1965 9092 117 1775 7627 Tubing Size: 3-1/2" Packers and SSSV MD (ft) no SSSV 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil D Gas D WAG D GINJ 0 Contact: Title: Phone 659-7043 Conditions of approval: Notify Commission so that a representative may witness Collapse Tubing Grade: 9.3 Tubing MD (ft): 2290 D Service D 5 ~S\,~J~:cl \O[ <Ñ...f1t1 Plugged 0 Abandoned D WINJ D WDSPL D Marie McConnell/MJ Loveland Problem Well Supervisor Date / ¿1 F C7 ftr.s- Sundry Number: ~S-~3/C Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance 0 Other: Ì) \c.os ~":,\... L ~ \""....... \. ~ Oti£ \,\u... ~ \ Iè... , \-\1:1.. \."'- \c", \ "- (\O~ <è c..Ù"- \ût.. ~ w ( ri\'>rc ~ \o,c>~ço~~ \. '\ ~C) ~\\-^~~~. Subsequent For q 'red: RBDMS BFL OCT 1 2 2005 cmtr{3tH A L APPROVED BY THE COMMISSION Date: ~¡ oS Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. Exploratory Well Nanuq 3 (PTD 2010260) APPLICATION FOR SUNDRY APPROVALS 10-403 October 10, 2005 Exploratory well Nanuq 3 (PTD 2010260) was spudded on March 1,2001 by ConocoPhillips Alaska, Inc. (CPAI). Drilling Operations were completed on March 17,2001, and CPAI submitted Well Completion Report form 10-407 for the well to remain in a "suspended" classification. As per 20 AAC 25.010, CPAI is providing notice to the AOGCC of intent to re- enter the suspended well. "Re-entry" will include pumping and pressure testing for mechanical integrity; wellbore intervention activities are not anticipated at this tÏ111e. The diagnostic testing work is to determine whether the well could have been the source of a diesel release discovered in 2004. CP AI is moving forward with Drilling plans for CD4. The CD4 gravel pad has been installed and access is available via road from CD 1 and the Alpine production facilities. One option is to use N anuq 3 as a developl11ent well. The value of the well for this purpose depends on whether the surface casing has integrity or whether there is a leak present. The purpose of this work is to determine if a leak in the surface casing is present. Backgro~nd Nanuq 3 has been the site of two diesel releases. The first was observed on May 29,2004, as previously reported. The diesel release was observed after a high water event from river flooding. Extensive diagnostic tests were performed in March 2005 after ice roads provided access to the pad. Mechanical Integrity Tests (MIT), wellhead pack-off tests, and observations over several days showed the well appe~~d~~;:~~g~chanical integrity. The second release was in August 2005, agmn after anijh' wàter event (melt water issues on the pad). Again, there were no obvious indications of the diesel source. The surface casing could be the leak source but additional diagnostics need to be performed to verify. The surface casing does not have a cement shoe and will not support an MIT pressure test. Objective The primary objective is to determine if there may be a leak in the surface casing. Since the well is shut-in, there is potential for ice around the casing in the permafrost zone. The first goal is to wam1 the well by circulating hot water so that ice will not be a factor complicating the diagnostics. The conductor will then be intentionally flooded with water so that nitrogen bubbles can be visible at the surface. Nitrogen will then be pumped down the Outer Annulus (7" x 9-5/8" annulus) to see if a leak point can be reached. Visible bubbles at the surface will be the primary indicator. If any response is observed, a fluid-level survey will indicate the depth. Should a problem be identified the AOGCC will be notified and a plan forward will be proposed. NSK Problem Well Supervisor 10/10/05 ') ) Ceneral Procedure 1. Notify AOGCC of intent to re-enter the suspended well via form 10-403. 2. Verify scaffolding is installed and certified. 3. Install gauges on tubing and annular valves and install valve handles where needed. 4. Install secondary spill containment in cellar bottom. 5. Pull BPV from tubing. 6. Rig up to pump down tubing taking returns out IA through brine choke to tan1e 7. Pump heated fresh water as needed to warm up well; target circulating temperature is approximately 100-120 deg F to ensure wellbore and annuli are entirely ice free. Circulate at rate and temperature to be efficient in heating up wellbore. 8. Install thermometer into conductor annulus as deep as possible. Monitor tenlperature so that ice in the conductor should be thawed. 9. Pill conductor casing with water so that gas bubbles will be visible at the surface. Monitor for signs of diesel that may migrate to the surface. Vacuum off any diesel that is present. 10. Rig up nitrogen tanks and manifold to OA. Discharge N2 into OA at slow, stable rate. Monitor conductor top for gas bubbles. Stop N2 flow if bubbles come to surface and shoot OA fluid level to determine depth. Verify depth with repeat shots. ' 11. Bleed off nitrogen from OA. 12. Freeze protect the tubing and IA with diesel. Bleed off any residual T II/O wellhead pressure. 13. Monitor wellhead for 24-48 hours after diagnostics are completed for signs of external leaks. 14. Install BPV and close SSV. Clean up location. 15. Submit Report of Sundry Operations 10-404 test data to AOGCC. Final Status After the progranl detailed above is complete the well is to return to "Suspended" status. There will be no change from previously submitted documents regarding mechanical barriers, kill weight fluids, or wellbore plugs. NSK Problem Well Supervisor 10/10105 2 ·~ '* ) (' Colville River Field (' Nanuq #3 Operations Shutdown RKB - GL = 43' 9-518- X 7" annulus freeze protected with 55 bbl diesel to approx. 1950' MD TOC @ +/- 4300' MD (500' MD above top K2) Top K2 sand at 4830' MD Bottom K2 sand at 5170' MD Stage Tool set @ 5286' MD TOC @ +/- 6500' MD (600' MD above 7A RMLS Assy) Top Nanuq Reservoir at 7530' MD Top Kuparuk Reservoir at 8543' MD Well TD at 9112' MD /7645' TVD (+1- 19 deg Inc.) Final Schematic 5/4/01 , . ': ,.:'<':,::, ...'..:.: ,"~",', ::"':': ,,::,::: :".;:', '. .;::, '.. '¢====' Wellhead ~ :~;~ ~* :1~r:'" 16" Conductor to 117' 11~::; ; : ~ '~I ~I"'~ ,,~ ,,'j( ~ 19-51811 40 ppf L-BO BTC Surface Casing @ 1965' MD /1781' TVD "~",,' cemented to surface -- .4 Tubing Supended with diesel to 2290' MD "'-. Çompletion Tubing Hanger plus 3-112", 9.3##'/ft, Tubing to 2290' MD ~ JI ~:¡,~ -..::: ~~? :~ ';~ ',!: Top of cement plug @ ~~155'MD .... 37.8 bbls of 15.8 PPG. Class G omt w/additives Assume 50% excess annular volume. ;f'; ~ -.~. !:': ~ ~.,.~I .~. 7" RMLS Latch Assembly @ 6985" MD t;: ~~., ¡::;) ~~ .:r:.: ~~ ~~~ it 7- RMLS Latch Assembly @ 8011' MD .~~ ~~, S :~.r .~.~ ~1 . .~ .. -., .'. ..'. I . , .-:-;::"" ".0". . .J".-- :-:.: "~'. ._ ., .~_ ... .. n. ... i: 7" 26 ppf L-80 BTC Mod Production Casing @ 9092' MD /7626' TVD @ 19 deg Rug 12 2005 12:24PM -I")LRSERJET 3330 r _SP _Discharge PI1Dtecl; 08/12/1005 Page: 1 Phillips Alaska, 10(:, Kuparuk Environmental Interim A¡ency Report ') ~() \-od0~ .....I"IL p.2 LOCATION OF DISCHARGE: ARPA ADDIT[ONAL LOCA nON INFO. Nanuq #3 wc=lllocated on Alpinels CD4- pad. TIME OBSERVED: 3:20:00 AM 08/1112005 REPORTED BY: DON GRAlKA TO: ADEC: verbal Sf11/05 ADN~ verbal 8/] 1/05 Ns.B: written 8/12/05 Other: AOOCC verba] Bl1110S Other: Kuukpjk 8/12/05 !,·cf-'t:ì.~'i'Ì\.)H!.:'''~··- f\ ~)f' <;j fn ?nrl~"' ~;)~~if~tr\'l.~'gß:;;'tl.J Nt 10 <) V,» L~"UJ RESPONSIBLE GROUP: CONQCO PHILLIPS ALASKA TYPE AND AMOUNT: 136.8 Total Ga11on(B) 0.0 Gatlon(s) Unto Tundra; oovering 0.0 area 0.0 Gallon(s) Into Water, covering 0.0 area 136.8 Gallon(s) Inside Secondary Con1ainment 0.0 GaHon(s) Into Building 100 % DIESEL CAt'SE OF DISCHARGE: UNKNOWN 136-sa11ans of diesel fuel was discovered in th~ N anuq #3 wen cellar £rom a preaumed leak in the well annulu~. ENVIRONMENTAL DA..VIAGE; None. CLEANUP ACTIONS: A supersuèkel' was USèd to vac up the dieMl ftom the well cellar. The diesel was sen~ to hydrocarbon recycle. CLEANUP VERJFICATION: VISUAL AMOUNT OF SPILL RECOVERED: 1·00% PREVENTIVE ACTION: To be determined after well diagnostics are performed. DISPOSAlfRBCYCLE tOCA TION: BBNEFICIAL REUSE Other Alpine hydrocarbon recyQ1e COMMENTS: A FINAL SPILL REPORT 'WILL BE SUBMmBD ONCE THE SPEClFIC WELL SOURCE HAS BBEN IDENTIFIBD AND CORRECTBD. Fl E \':~ :E1 \/ E r~~,) ~I.:~~~.ç~ ¡ ~ G~, ,,~~_..:,' ~'~\'~~, -:~~ 1. Operations Performed: Abandon 0 RepairWell 0 Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. ShutdownO 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 42' RECEIVED MAR 0 7 2005 REPORT OF SUNDRY WELL OPERATIONS Stimulate OAIMktt Oil ~\, Cuns.¡9l11l11ission Waiver 0 Time ~~~~~f~~e 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 201-026 6. API Number: 50-103-20365-00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ') Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Exploratory 0 Service 0 9. Well Name and Number: NANUQ 3 8. Property Designation: Colville River Unit Nanuq 3 Exploratory 11. Present Well Condition Summary: 10. Field/Pool(s): N/A Total Depth measured 9112' feet true vertical 7646' feet measured 9022 feet true vertical 6276' feet Length Size MD 117' 16" / 62.58# 117 1965' 9-5/8" / 40# 1965 9092' 7"/26# 9092 Plugs (measured) Junk (measured) Effective Depth Casing Structural Conductor Surface Production TVD Burst Collapse 117' 1775' 7627' Perforation depth: Measured depth: None SCANNED MAR 1 (} 2005 true vertical depth: None Tubing (size, grade, and measured depth) 3-1/2",9.3# , 2290 MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFL MAR 0 7 2005 Treatment descriptions including volumes used and final pressure: 13. Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X I N/A N/A Oil-Bbl Representative Daily Average Production or Injection Data I Gas-Met I Water-Bbl N/A N/A N/A N/A 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilO GasO WAG 0 Casinq Pressure 0 0 Tubinq Pressure 0 0 Service 0 GINJO WINJO WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 305-018 Contact Printed Name Signature Brad Gathman/MJ Loveland @ 659-7224 Jerry Dethlefs ~ .L? Title ~~C'~ Phone Problem Well Supervisor 907-659-7043 Date ø~.š-- nn' '~~Ihl 1\ L ! 11:- 1 -.". :1 ", í " t_)~ . \, <..) j¡:" r'~ . Submit Original Only Form 10-404 Revised 04/2004 ) ConocoPhillips Alaska, Inc. Nanuq 3 Exploratory Well (PTD 2010260) MECHANICAL INTEGRITY TEST Background: ConocoPhillips' exploratory well N anuq 3 was suspected to be the source of a hydrocarbon release based on field observations and SRT response in May 2004. The initial checkout of the well did not find any problems but was limited due to the remote location of the well on the tundra. The regulating agencies and CPA agreed to perform thorough diagnostics during the winter months when road access was available. The diagnostics were completed on March 3, 2005, with the results detailed below. Summary: Operations on the well commenced March 1,2005 and ended on March 3, 2005. The well was warmed up by circulating warm water and a variety of tests were performed to determine if any external leak path was present. All the diae:nostic tests passed" indicatine: the well has e:ood mechanical intee:ritv. A list of the tests performed is provided below. The well was freeze protected and returned to its "suspended" condition. The diagnostic testing was witnessed by an AOGCC Field Inspector (John Crisp). Test Sequence: 1. The back-pressure valve (BPV) in the tubing was removed to provide a circulation path between the tubing and annulus (a 2290' kill string is hung in the well). 2. The diesel freeze protection was displaced from the well and diverted to a holding tank. 3. Heated fresh water was circulated down the annulus (IA) and up the tubing. The wellbore temperature was raised to 110 deg F and the circulation continued for 40 hours to ensure all potential ice plugs were thawed. 4. Packoff tests were performed on both the tubing and casing packoff assemblies. The tubing packoff test passed @ 5000 psi, the casing packoff test passed @ 3000 psi. 5. All lock-down screws on the well were checked for proper torque; all were found to be within normal tolerance. 6. All flange ring-gasket connections were checked and found to be tight. 7. The top of cement in the conductor was tagged at 38" down from the hanger flutes. 8. With the circulation stopped, a "combination MIT" (CMIT T x IA) was performed to test the production casing, cement plug, and wellhead for leaks. The test pressure was 2460 psi and was held for 45 minutes. No significant leak-off was observed. 9. An outer annulus (OA) injectivity test was performed to determine if there was a leak from the OA into the conductor. A total of 60 bbls of diesel was pumped into the annulus at an average pressure of 500 psi at 2.5 bpm. There were no indications of fluid in the conductor or other pressure or rate fluctuations that would indicate a problem is present. 10. The tubing and annulus were freeze protected with 80 bbls diesel. 11. A BPV was set into the tubing and all tree valves cycled closed. NSK Problem Well Supervisor (lCD) March 4, 2005 ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,? '-?)zd!,r P.I. Supervisor 1\e¿(I J( 0) DATE: March 03, 2005 FROM: John Crisp, Petroleum Inspector SUBJECT: Mechanical Integrity Test Suspended Exp. Well Nanuq #3 PTO 201-026 March 03, 2005: I traveled to Conoco/Phillips Suspended Exploratory Well Nanuq #3 to witness diagnostic testing to determine if a May 29, 2004 reported hydrocarbon sheen around the well was caused by mechanical problems. I witnessed the tubing pack off test to 4900 psi. for 30 minutes. I witnessed the production casing pack off test to 3000 psi. for 30 minutes. Nanuq #3 has an open end tubing kill string @ 2290' MD. The production casing has cmt. Plug @ 5155' MD. The CMIT was conducted pumping down the tbg. Thru the tree cap & witnessing pressure readings on the IA. CMIT pre test pressure 0 psi. Initial pressure reading 2460 psi. 15 minute pressure reading 2440 psi. 30 minute pressure reading 2400 psi. 45 minute pressure reading 2390 psi. No leaks to atmosphere from any tree or wellhead components were witnessed. Nanuq #3 was suspended with a freeze protected open OA shoe. I witnessed 60 bbl's of 100 degree diesel pumped down the OA @ 2 Y4 bbl per minute 500 psi. No leaks on wellhead or leaks from Surface casing to Conductor before during or after pumping process were witnessed. Summary: I witnessed a successful CMIT on Nanuq #3. Wellhead & Tree inspections showed no leaks to atmosphere. Attachment: none. CONFIDENTIAL """'Cu~1"'iED"\ 1\ DI) ') \:' 110nh. ;::, ,nnW1I '.'-H ì. ¡,.: ...$ L ...,.J MIT Nanuq #3 03-03-05 JC.doc ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Tes1 Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;andJim_Regg@admin.state.ak.us OPERATOR: FIELD J UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. CRU CD4 Nanuq 3 Exploratory 03/03/05 Jerry Dethlefs John Crisp Pretest Initial 15 Min. 30 Min. 45 Min. Tubing 0 2460 2440 2400 2390 Interval 0 IA 0 2460 2440 2400 2390 P/F P OA 0 10 10 10 10 Notes: Kill string tubing, no packer. Tubing and IA show same pressure throughout. Cement plug in casing @ 5155'. Ran test long to verify minor pressure variation. Test perfonned as per Sundry 305-018. Well Nanuq 3 Type Inj P.T.D.2031220 Type Test NA P Packer Depth T.V.D. 5155 Test psi 1500 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERV AIINTERV AL Codes 1= Initial 1 I = Initial Test 4 = Four 't 4 = Four Year Cycle V = Requil V = Required by Variance Test durin, Test during Workover 0 = Other 0 = Other (describe in notes) M IT Report Form Revised: 05/19/02 MITP CRU Nanuq 3 03-03-05.xls 3/4/2005 ) ) (' Colville River Field ( Nanuq #3 Operations Shutdown RKB - GL=43' &-&'8' x r annulus freeze protøctad with 65 bb( diesel to approx. 1950' MD TOC 0 +/- 4300' Me (500' MD above top K2) Bottom K2 sand at 5170' MD Stage Tool set @ 5286' MD TOC C +I- 6500' MD (600' MD above 7' RMLS Assy) Top Nanuq Reservoir at 7530' MD Top Kuparuk Reservoir at 8543' MD Well TD at 9112' MD /7645' TVD (+/.. 19 deg Inc.) Final Schematic 5/4/01 . '- '. : '. ," ',' . . e. ::,::~'::';.::."<"'~'.\"':': ../:.<.". '. .t.~.~ WoUhead ], t 16' Conductor to 117' 1 I ~. 40 WI L-80 BTC Surface Casing 0 1965' MD /1781'1VD cemented to surface ~ .' ì Tubing 'Supended with - -diesel to 2290' MD ........... Compfetion Tubing Hanger plus 3-1fZ', 9.3I1ft, Tubing to 2290' MD 'L< "~ ">':. -,¡;,.. ,~~ ""'- .¡j,,. t Top of cement plug @ ""'------15155' MD ,..~ 37.8 bbls of 15.8 PPG. Class G emt w/additives Assume 50% excess annular volume. '~~~ .;. ~ .;::< :";'1 -\~ ti I 'iT :+ :CoO' 1.:;- ;-." i ~ )~ .... ]- 7" RMLS Latch Assembly 0 6985' MD 7" RMLS Latch Assembly @ 8011' MD "0'" - . l;..O'"t~ 7' 26 ppf L.80 BTC Mod Production Casing @ 9092' MD /7626' TVD @ 19 009 ) Trl,: 1,', r rITìmJ'. IU. ' ~b I d'~ t ~ w L::J '¡ A.,ASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/J GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 ,,;,Q,/~i";"()' ,,'1.' / " ~~,"""";i~ Re: Nanuq #3 Sundry # 305-018 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may fiie with t.ì.e Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd y following the date of this letter, or the next working day if the 23rd day falls on oliday or weekend. A person may not appeal a Commission deCiSi,onYf;8'U, ~rior 000 unless rehearing has been requested. (, ! lne , I \.. ,) /" DATED tltisJij:'¿y of January, 2005 Enc!. SCANNED FEE 0 2 2DDS ) ) ConocJPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 26, 2005 RE I JAN 2 7 2005 Alaska Oil &. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Subject: Re-entering suspended exploration well Nanuq 3. Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. exploratory well Nanuq 3. The Sundry regards 20 AAC 25.010, re-entering a suspended well. CP AI intends to perform diagnostic testing work on the well during the ice road season. Please call MJ Loveland or Brad Gathman at 659-7224, or me at 659-7043 if you have any questions. Sincerely, ~ cI1?tf Jerry Dethlefs Problem Well Supervisor Attachments OR\G\NAL 1. Type of Request: Abandon ,~~ ) STATE OF ALASKAK.> r.-' ALASKA Oil AND GAS CONSERVATION COMMISSION ~ APPLICATION F?o~A~~.~?RY APPROV ALAlaska " , D Suspend D Operation Shutdown D Perforate D Waiver; "jj ',' ~'Å,~hular Disp. 0 D Repair well D Plug Perforations D Stimulate D Time Extension D Other 0 D Pull Tubing D Perforate New Pool D Re-enter Suspended Well 0 JAN 2 7 2005 & Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Development Stratigraphic D D Exploratory 0 Service D 5. Permit to Drill Number: 201-026 6. API Number: 4. Current Well Class: P. O. Box 100360 7. KB Elevation (ft): RKB 42' 8. Property Designation: Colville River Unit Nanuq 3 Exploratory 50-103-20365-00 9. Well Name and Number: NANUQ 3 10. Field/Pool(s): N/A PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7555 5155 MD TVD 117 117 Burst Collapse 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9112' 7646' 9022 Casing Length Size Conductor 117 16" / 62.58# Surface 1965 9-5/8" / 40# Production 9092 7"/26# 1965 9092 1775 7627 Perforation Depth MD (ft): None Packers and SSSV Type: no packer no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Jerry Dethle~ ~ Signature ;:::t'~ C-. c.----~ Commission Use Only Perforation Depth TVD (ft): None Tubing Size: 3-1/2" Tubing Grade: 9.3# Tubing MD (ft): 2290 Packers and SSSV MD (ft) February 2005 Date: no SSSV 13. Well Class after proposed work: Exploratory 0 Development 15. Well Status after proposed work: Oil D GasD WAG D GINJ D D Service D s'vc~þ(.~~<tJ ~~ Plugged 0 Abandoned 0 WINJ D WDSPL D Contact: Title: Phone 659-7043 Loveland/Gathman 659-7224 Problem Well Supervisor Date ;Øy4..s- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ..5oÇ-.OI ð'" Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: t>\o.~~\'\c- ~ 'ö~ ,~ O-(.~([~~ \<2:- \"\<X\ "'~~ \...\ a~t2 cef\.kc-~ "'-J / r i'-~\eYr> -Ç°mO .~~~\-\-'-\ -\0 ~~\ ~~'>~; RBDMS BFL JAN ~ 1 7005 Subsequent FOlj:~: -\()~ 0 RIG I N A L " ~~ BY ORDER OF , Approved by: ~=o'--- COMMiSSIONER THE COMMISSION Date: ~/~ Form 10-403 R' 12/2003 INSTRUCTIONS ON REVERSE Submit in Duplicate ) ') ConocoPhillips Alaska, Inc. Exploratory Well Nanuq 3 (PTD 2010260) APPLICATION FOR SUNDRY APPROVALS 10-403 January 26, 2005 Exploratory well Nanuq 3 (PTD 2010260) was spudded on March 1,2001 by ConocoPhillips Alaska, Inc. (CPAI). Drilling Operations were completed on March 17,2001, and CPAI submitted Well Completion Report form 10-407 for the well to remain in a "suspended" classification. As per 20 AAC 25.010, CPAI is providing notice to the AOGCC of intent to re- enter the suspended well. "Re-entry" will include pumping and pressure testing for mechanical integrity; wellbore intervention activities are not anticipated at this time. The diagnostic testing work is to determine whether the well could have been the source of a diesel release discovered last summer. Backeround On May 29,2004, a hydrologist observed a sheen near Nanuq Well No.3 while marking the high water points from the Colville River break-up. The sheen was reported to Alpine emergency services the morning of May 30th. The discontinuous sheen was determined to be hydrocarbon based and restricted to the standing water outside of, and immediately adjacent to, the well cellar. The investigation identified layers of ice, clear fluid, red fluid (diesel) and solids (mud) inside the cellar. The total estimated volume release to secondary containment and reported to the agencies was approximately 117 gallons of diesel. On May 30, 2004, a Well Supervisor, AES DHD Technician and FMC Wellhead technician traveled to the site. The Wells personnel performed an investigation of the tree, valves and flanges; no leaks or evidence of leaks were found. The tree and all annuli were monitored and no pressure was found except for approximately 5 psi on the tubing/7 inch annulus. All valves were found closed, except for the Subsurface Safety Valve. The SSV was actuated closed during the site visit. The conductor was found to be frozen approximately 2 inches below the cement circulating ports, and diesel was present on top of the ice. Based on the results of their investigation, Wells personnel determined that further diagnostic work would be required in the winter during ice road season when heavier equipment could be made available at the well location. Since the incident was reported the well has been monitored on a periodic basis by CP AI and contractor personnel. No additional accumulation of hydrocarbons has been noted. Objective The primary goal is to determine ifNanuq 3 has good mechanical integrity or has a problem that could have resulted in a release of diesel from the well. The procedure will include pressure tests of the surface and production casing strings and packoff assemblies. Should no problems be found with the mechanical construction of the well it may be inferred that the release was associated with some other origin; i.e., human intervention, groundwater or permafrost movement, or some other mechanism not identified. Should a problem be identified the AOGCC will be notified and a plan forward will be proposed. NSK Problem Well Supervisor 01/26/05 ') General Procedure 1. Extend ice road or gravel pad to the Nanuq 3 well location. 2. Notify AOGCC of intent to re-enter the suspended well via form 10-403. 3. Notify AOGCC Inspector of intent to perform MIT 24 hours prior to testing. 4. Install gauges on tubing and annular valves and install valve handles where needed. 5. Pull BPV from wellhead. 6. Rig up to pump down tubing taking returns out IA through brine choke to tank. 7. Pump heated fresh water as needed to warm up well; target circulating temperature is approximately 100 deg F to ensure wellbore and annuli are entirely ice free. Circulate at rate and temperature to be efficient in heating up wellbore. 8. Perform packofftests on tubing and casing assemblies to verify integrity. 9. Once target circulating temperature is achieved, shut-down pumping and perform mechanical integrity tests (MIT) on production casing and surface casing. 10. CMIT production casing (T x lA, no packer) @ 2500 psi for 30 minutes. Record initial, 15 and 30 minute T/IIO pressure readings. Inspect wellhead closely during MIT for any indication of external leaks. 11. MIT /liquid leak rate test the surface casing. Annulus has an open shoe and should not hold pressure. Pump 50 bbls diesel down OA at 2-3 bpm, not to exceed 1800 psi. If annulus locks- up, perform MIT @ 1800 psi for 30 minutes. Record initial, 15 and 30 minute T/IIO pressure readings. Inspect wellhead closely during pumping and/or MIT for any indication of external leaks. 12. Should an external leak be suspected, stop pumping and/or bleed down pressure to minimize spill potential. Discuss diagnostic options with PWS and AOGCC prior to commencing operations. 13. Freeze-protect tubing & IA with diesel recovered from wellbore. 14. Monitor wellhead pressures for 24-48 hours after pumping has ceased for signs of external leaks. Bleed off any residual T /110 wellhead pressure. 15. Install BPV, close SSV, and remove tree gauges and valve handles. Clean up location. 16. Submit Report of Sundry Operations 10-404 and MIT test data to AOGCC. Final Status After the program detailed above is complete the well is to return to "Suspended" status. There will be no change from previously submitted documents regarding mechanical barriers, kill weight fluids, or wellbore plugs. NSK Problem Well Supervisor 01/26/05 2 -'r,~ ') ) (' Colville River Field (" Nanuq #3 Operations Shutdown Final Schematic 5/4/01 RKB .. GL = 43' .:'::"":'''''''::''''':''':''''''''':,:::.:...'~ '. ' . ~. .' ~'.' .. "..' : . ::.: .'.:. .' .:' . Wellhead ~ 9-518' x r annulus freeze protected with 55 bbl diesel to approx. 1950' MD . - ~ ............ I~~ :;= to~D K2) T: ~? :n ~~ ~~ .~.-: Top K2 sand at 4830' MD --1 ~.\ :;::, :h~: Bottom K2 sand at ~: ¡.r~.' ~l!~;::::r~ ~;~ 517f1MD -111;~""".~':>;:'_1'.':"i.~::~: .i~ ~ Stage Tool set @ ~ ~ 5286' MD TOC 0 +1- 6500' MD (600' MD above 7' RMLS Assy) ::-:r. .. -:t.. "" Top Nanuq Reservoir at 7530' MD -.. ~;'I ¡ :.~~ Top Kuparuk Reservoir at 8543' MD t ~;. Well TD at 9112' MD /7645' TVD (+I-19 deg Inc.) ,,,..~::.. ::.,..~.;::.~ M~;'. :~ ,~ 16" Conductor to 117' I f~ ~ I.. 9-518' 40 ppf L-BO BTC Surface Casing @ 1965' MD /1781' TVD cemented to surface Tubing Supended with diesel to 2290' MD Completion Tubing Hanger plus 3-112-, 9.3#nt, Tubing to 2290' MD Top of cement plug @ '-----"155' MD 37.8 bbls of 15.8 PPG. Class G cmt w/additives Assume 500/0 excess annular volume. ~1 7" RMLS Latch Assembly 0 6985' MD ~ ;-';" ~::. -f.; '::;) ¥ :~ t' J;'- 7" RMLS Latch Assembly 08011' MD 7. 26 ppf L.80 BTC Mod Production Casing @ 9092' MD 17626' TVD @ 19 deg Jð~lt--( \)~~"" '-~() I. (/ ¿,.(ç; about:blar S0'o~ '. ~\E~ \ \~O- ~~ ~ \.G: \ "-~, On fvtonday 5/31. Chuck gave me a call regarding a report of diesel in the cellar of Nanuq #3 a suspended exploration \vell immediately south of Kuparuk. Chuck was not called with regard to this matter, however he picked it up on the IIgrapevine" whi Ie he \vas doing other duties at Kuparuk. He nlade several attempts to contact various CPAl personnel and tìnally talked with Mike Irwin at Alpine. Apparently a sheen was spotted by a pilot doing a flyover. According to what I have been able to find out, diesel was confirmed in the cellar and it has since been pumped out. After decanting. it appears that about 2 barrels of diesel \vas recovered with sOlne water. All ll1Y infonnation is from conversations with the Problell1 Wells contact at Kuparuk. Neither ll1yself. Chuck or Jinl have received anything written on the incident. I understand it was reported to DEC and they have visited the well site and held meetings \\lith CP AI and possibly BP personnel regarding hydrocarbon in well cellars. Today I received a call from Wendy Mahan inquiring about what report I would like on this subject. She said no report had been sent to the Conmlission since according to the regulations, the AOGCC reporting threshold is 10 bbl of oil and 1 MM scf of gas and this was diesel. She said she thought our thresholds were high~ especially in conlparison to other agencies. I agreed that they were high, hO\\lever since the spill involved a \\lell and was an unusual event, that comnl0n sense l11ight prompt one to notify the AOGCC. Wendy asked l11e to send a message indicating the infonnation I would like and she would attenlpt to get it and then notify her colleagues that in the future when such an incident happens that they should notify the Comnlission. I have not sent anything to Wendy on this matter. I have sent a note to Jim and Winton on this nlatter and have recoll1Jnended that the thresholds in our regulation regarding uncontrolled releases be lowered and a phrase such as "any leak IT0111 a well" be included. On this nlatter, with your approval I would like to send a note to Wendy stating that if there is a spill [cnlde, diesel or water] ITom a well (OA, IA. hlbing or flowline) it should be reported to the AOGCC. The threshold reporting quantity \vould be the same as required by DEC. Having this reporting requirement in place should not inundate us with paperwork and on the Operator's side it should only require the sending of an additional copy of a report that is already prepared. We may want to adjust the reporting threshold as experience is gained. Further to this issue, Wendy nlentioned that a DEC person from Fairbanks had been on the slope and visited the Nanuq location. I believe that she was satisfied with the \vork done so tàr. \Vhile on the slope she made a request to CAPI for a list of all wells they had that have Ilcasing leaks". DEC has apparently requested such a list before. but CPAI had not given it to them. She was given such a list this time. I have discussed tllis with .1illl and he reconmlend that I advise you of the situation \\lith IllY reconl111endation. Ç\EQ"';.Ç \~ I,^,< ~~'-C)'--.) ''fO..:) \ rÆ~~"'~~"::; ~Ç( . Lì '-C ~'(~ I of I 6/17/20042:50 P DATA SUBMITTAL COMPLIANCE REPORT Permit to Drill 2010260 Well Name/No. NANUQ 3 311012003 Operator CONOCOPHILLIPS ALASKA INC MD 9112 TVD 7646 Completion Dat 3/17/2001 Completion Statu SUSP Current Status SUSP APl No. 50-103-20365-00-00 UIC N REQUIRED INFORMATION Mud Log No Sample N_..~o Directional Survey N.._~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Name ~~Analysis Report R R L L L L L L L L L L R R C C R R L L L L R R L L ED D Cn See Notes Rpt Cn See Notes (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Scale Media No Start Stop CH Received Number Comments FINAL 8/8/2001 Core Analysis Report ~ual GPJRes 2/5 ~{~'~al GI~ BAT 2/5 ~Dual (~R/NEU/ 2/5 DEN ~ial ,GR/NEU/ 215 ~ Dual GR/BAT 2/5 Directional Survey ~Core photos ~ Log 2 ¢~ROPIDual GP,/Res 2/5 8522 8569 Open FINAL 140 9112 oh FINAL 140 9112 OH FINAL 140 9112 OH FINAL 140 9112 OH FINAL 140 9112 oh FINAL CH FINAL 8522 8569 oh FINAL oh FINAL 8521 8568 oh FINAL 0 9112 ch FINAL ch FINAL 140 9112 oh I 8532 8542 Open I 8532 8542 Open 5/2/2001 ~113"092 8522-8569 5/10/2001 140-9112 BL, Sepia 5/10/2001 140-9112 BL, Sepia 5/10/2001 140-9112 BL, Sepia 5/10/2001 140-9112 BL, Sepia 5/10/2001 140-9112 BL, Sepia 5/10/2001 Directional Survey 5/10/2001 ff00~ 8522-8569 Digital Data 5/10/2001 Core Lab Core photos 5/10/2001 8521-8568 Oaks Core GR Log 5/25/2001 0-9112 Sepia 5/25/2001 Final Well Report 5/10/2001 140-9112 BL, Sepia 1/30/2003 1/30/2003 Well Cores/Samples Information: Name Interval Start Stop Sent Received Cuttings Core Chips 147 9112/../~" Dataset Number Comments Permit to Drill 2010260 DATA SUBMITTAL COMPLIANCE REPORT 3110~2003 Well Name/No. NANUQ 3 Operator CONOCOPHILLIPS ALASKA INC MD 9112 TVD 7646 ADDITIONAL INFORMATION Well Cored? (~ N Chips Received? (~/N Analysis ,.~ / N Received? Completion Dat 3/17/2001 Completion Statu SUSP Daily History Received? Formation Tops Current Status SUSP APl No. 50-103-20365-00-00 UIC N Comments: Compliance Reviewed By: Date: ConocoPhillips TRANSMITTAL ¢ONF.rDENTXAL DA TA FROM: Sandra D. Lemke, ATO1486 TO: ConocoPhillips Alaska, [nc., ATO1486 P.O. Box 100360 Anchorage AK 99510-0360 Lisa Weepie State of Alaska-AOGCC 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 RE: Nanuq 3 DATE: 01/2712003 Transmitted herewith is the following: Nanuq 3 REV~core. Report& 3.5 "disk Labs- Core Analysis Results, Nanuq 3, Revised 1/13/2003 CL File 57111-01076; see cover not related to specifics of revision. Replaces previously delivered Core Labs Analysis for Nanuq 3. P/ease check off each item as received~ siXTh and return one o£ the two transmittals enclosed to address be/ow. Receipt:C_._~ J~Ca~ ~ Date: Return receipt to: ConocoPhillips Naska,Inc. ATI'N: S. Lemke, ATO-1486 700 G. Street Prepared by: Sandra D. Lemke Anchorage, AK 99501 CPAT-GIS 1'1' TDM Group ..' RECEtVED JAN :50 200 , RESERVOIR OF11HIZATIOJl Janua~ 14,2003 Mr. Dave Bannan ConocoPhillips 700 G Street, Room ANO-388 Anchorage, AK 99510-0360 c:::q o I-.-- Petroleum Services 3430 Unicorn Road Bakersfield, California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www. corelab.com -~t?Subject: T/'ansmittal of Revised Core Analysis Report'~ Nanuq 3 Well Colville Delta Field Alaska CL File #57111-01076 Dear Mr. Bannan: Initially, ten horizontally and ten vertically oriented plugs were submitted for analysis. Six additional .horizontal samples that had been partially extracted in Bartlesville were received at a later date. The horizontal and vertical permeability values in the original report for this well were called into question and Core Laboratories was requested to retest the questionable samples. The previously analyzed sample plugs that had been shipped to ConocoPhillips were returned and retested along with the plugs that had remained in our storage. The re-measurements showed that the original measurements on the initial horizontal and vertical plugs had in fact been in error. From all indications the source of the error was a file with corrupted orifice values (correct orifice flow-rates are essential in the permeability calculations). The previously reported permeability values for the six partially extracted horizontal samples proved to have been correct. Accompanying this letter, please find the reissued report with the corrected values. The erroneous values along with the results of the remeasurements are also included for comparison. I sincerely apologize for any and all inconvenience caused by the erroneous results. Please rest assured that we are putting a system in place that should prevent any chance of a reoccurrence. Should you have any questions, or if we may be of further assistance, please contact us. Very~rulyj . yours, ~- ~sor - Rock Properties JLS: nw 1 original reports, 4cc report, 1 diskette; addressee 1 original report, 1 diskette; Jim Hedges, ConocoPhillips, 130 GeoScience Bldg, Bartlesville, OK 74004 CLB RESERVOIR OI~I'II~IZATION EDC Duplicate Petroleum Services 3430 Unicorn Road Bakersfield, California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www. corelab.com CORE ANALYSIS RESULTS PHILLIPS ALASKA, INC. 'RNanuq" #3 COLVILLE DELTA FIELD UMIAT MERIDIAN, ALASKA CL FILE #57111-01076 Performed by: Core Laboratories 3430 Unicom Road Bakemfield, CA 93308 (661) 392-8600 CONFII)ENTII.!!i L. CLB TABLE OF CONTENTS SECTION DESCRIPTION OF SERVICES CORE ANALYSIS RESULTS HYDRAULIC UNIT ANALYSIS RESULTS INITIAL AND REVISED PERMEABILITY RESULTS CORE INVENTORY 5 INTRODUCTION Core Laboratories was selected by ConocoPhillips inc. to perform a core analysis study upon samples recovered from the Coleville River - SW Field, Umiat Meridian, Alaska. Conventional aluminum inner barrel cores were submitted. Presented herein are the results of analysis. This report is divided into five sections. The first section provides a description of services. The second section contains tabulated results of standard PKS analysis. Hydraulic unit classifications in tabular presentation are included in the third section. The fourth section contains the results of the original permeability measurements (performed in 2001) and the results of the permeability remeasurements performed in 2002. An inventory of the recovered core comprises the final section. Core Processing Cores were handled in the field and processed in the Anchorage Lab by Core Laboratories personnel. Core Gamma Surface Log Each core was scanned for natural gamma radiation utilizing Core Lab's gamma spectrometer. Total gamma radiation was reported in APl units. Core Sampling and Slabbing After the gamma measurement, a sample segment approximately three tenths of a foot long was taken from each foot of core for horizontal and vertical plug sampling. The remaining core from each foot was slabbed parallel to the core axis utilizing a one/third - two/thirds cut. Liquid nitrogen was used as the blade coolant. For photography, viewing, description and additional sample selection by ConocoPhillips' representatives the one-third sections were placed into slab boxes with Styrofoam inserts. Each of the approximately seven tenths of a foot segments of the two-third bulk core (left after the material for the plug samples had been removed) were preserved by wrapping with six layers of Saran wrap, three layers of aluminum foil, and then dipping in Core Seal. Sample Preparation Both horizontally and vertically oriented one-inch diameter plugs were drilled from each of the three-tenth foot core sections reserved for sampling. Isopar mineral oil was used as the bit coolant for sample drilling. Plugs were labeled, weighed, wrapped with Saran and aluminum foil, and then sealed in sample jars as each was drilled. Upon completion of all sampling, plugs were packaged and shipped to our Bakersfield California facility or to ConocoPhillips in Bartlesville Oklahoma for analysis. Analysis Techniques Fluid Extraction Samples taken with horizontal orientations were weighed and placed into tared extraction thimbles. Water and the oil were extracted from the samples by Dean Stark methods with toluene as the solvent. Samples were held in the Dean Stark extractors for a minimum of sixteen hours after which the receiving tubes were periodically checked to determine when water ceased to be produced. The plugs were removed from the Dean-Stark extractors after stable water readings were obtained. Complete hydrocarbon extraction was conducted using soxhlet extractors with methylene chloride as the solvent. Cleaned samples were removed from the soxhlets and dried in a convection oven at 230°F for a minimum of forty-eight hours and were removed once their weights had stabilized. The dried samples were cooled to laboratory temperature in a desiccator prior to analysis. Samples designated for vertical permeability determinations were "batch" cleaned in large Dean Stark extractors with toluene to remove water and then transferred to soxhlet extractors for batch cleaning with methylene chloride. Drying was performed as for the horizontal plugs prior to permeability measurements. Grain Density Determinations Grain volumes were determined using a Boyle's Law extended range helium porosimeter. Metal jacket and end-screen weight and volume corrections were applied to any jacketed samples, Grain densities were calculated using Equation 1. 8ma : M~, (1) VVhere; (~ma = Mg = Vg = Matrix / grain density (g/cc) Grain mass (g) Grain volume (cc) i' Confining Pressure for Porosity and Permeability Measurements Following grain volume determinations, the plug samples were placed into a Hassler-type holder and a confining pressure of 400 psig was applied. Measurements made with a confining pressure of 400 psig are considered to be essentially "ambient" condition measurements. The minimal pressure acts to prevent gas by-pass during measurements but does not compress the samples. Porosity Determination Direct pore volume measurements were made upon confined samples utilizing Boyle's Law double-cell methods. Porosity values were calculated using Equation 2. Where: ~) = Porosity (%) Vp = Pore volume (cc) Vg = Grain volume (cc) Fluid Saturation Calculations Oil and water saturation results were calculated using Equations 3 and 4. So = SW = (3) (4) Where: S0 = Sw = Mf = Md = Mw = Vw = (~o = Vp = Oil saturation (%) Water saturation (%) Fresh sample mass (g) Extracted and dried sample mass (g) Extracted water mass (g) Extracted water volume (cc) Density of oil Pore volume (cc) Permeability to Air Permeability determinations were made following the pore volume determinations again using Hassler-type core holders. The permeability values were calculated utilizing Darcy's Equation for compressible fluids, Equation 5. Ka = (5) Where: Ka = Permeability to air (md) Pa = Atmospheric pressure vg = Gas viscosity (cp) &P = Differential pressure ~P = Mean pressure Qa = Flow rate (cc/sec) L = Length (cra) Vb = Bulk volume (cc) Hydraulic Unit Analysis After rock property measurements had been completed, a hydraulic unit analysis was performed. Reservoir quality index (average pore throat size) and pore ratio values were calculated for each of the horizontal samples using Equations 6 and 7. RQI = 0.0314 · (6) (I) PR = (7) Where: RQI = Reservoir quality index Ka = Permeability to air (md) (D = Fractional porosity PR = Pore ratio RQI and PR values were used to group the samples into hydraulic units. Each hydraulic unit represents a unique pore geometry relationship and provides the foundation for the integration of core and electric log data. The results are presented sorted by sample depth, and by hydraulic unit; to facilitate selection of representative samples for any additional testing. Sample Disposition The bulk core sections were retained in Anchorage and returned to ConocoPhillips. The sample plugs that had been forwarded to Bakersfield were initially returned to ConocoPhillips upon the completion of testing. Due to the concerns regarding the initial permeability results, the plugs were again forwarded to Bakersfield for retesting. All plugs will be shipped to ConocoPhillips in Bartlesville Oklahoma following the issuance of this revised report. 1ConocoPhillips Nanuq #3 . Colvill® Delta File No. : 57111-0t076 Loc.: Sec.24-T11N/R4E APl No. : 50-103-20365 CORE ANALYSIS RESULTS Sample Depth . Permeability (Ka~)'.:":'-."po'rosjty. ._-'-'. '.. :-': :sa.m, rati~$::"::.~:~!.':./:':.i~i ..-': .-::Grain..- Description comments No. Horiz.... · , , .Ift, md.. .md...'.......' ":. ~-"--' ' ::::"-'~':" :I ' "-% '-:'"!"'--:'-~'. "- I-:':'~"' ,.': ~/~:',"', ..... 8522.0 - 8567.3 Core # 1 Cut 45' Recovered 45.3' 1 8532.2 0.03 0.044 11.2 30.4 52.7 83.1 0.58 2.74 2 8533.2 6.3 0.86 5.0 33.1 31.0 64.1 1.07 3. t5 11 8534.3 50. 22.3 2.93 3 8534.9 11.6 148.2 18.4 59.7 11.6 71.3 5.15 2.89 4 8535.1 132. 318. 21.1 55.9 14.5 70,4 3.86 2.86 12 8535.7 73. 22.7 2.88 5 8536.3 359. 265. 25.2 62.3 12.0 74.3 5.19 2.79 13 8537.5 0.058 14.4 3.00 6 8538.1 165. 184. 23.4 61.9 10.9 72.8 5.68 2.79 t4 8539.0 171. 23.3 2.84 7 8539.8 415. 236. 24.0 62.6 11.0 73.6 5.69 2.73 8 8540.2 525. 587. 24.0 65.5 8.2 73.7 7.99 2.68 15 8540.7 572. 24.2 2.70 9 8541.2 945. 724. 23.9 46.8 26.9 73.7 1.74 2.65 16 8541.6 179. 21.8 2.71 10 8542.9 0.003 0.017 2.5 0.0 97.3 97.3 0.00 3.34 Sst gry-lt tan vfgrlgmn vslty It sp stn gld flu Sst bm vfgr vslty pyr m stn dgld flu 8st gry-tn vf-fgr slty pyr It stn or flu Sst bm vf-fgr slty dk stn dgld flu Sst bm vf-fgr si slty dk stn dgld flu Sst g~/-tn vf-fgr slty pyr It stn or flu Sst bm vf-fgr slty dk stn dgld flu Sst gry-tn vfgr vslty pyr tt stn or flu Sst bm vf-fgr slty dk stn dgld flu Sst g~,-tn vf-fgr sity pyr It stn or flu Sst bm vf-fgr slty sh incl dk stn dgld flu 8st bm vf-fgr si slty dk stn dgld flu Sst gry-tn vf-fgr si slty It stn or flu Sst bm vf-fgr stty sh dk stn dgld flu Sst gry-tn vf-fgr sity It stn or flu $1tst gry si calc pyr no stn no flu Bartlesville~ Bartlesville~ Bartlesville~ Bartlesville~ Bartlesville~ Bartlesville~ Permeability and porosity were determined at 400 psig confining pressure ~ - Samples were partially extracted by ConocoPhillips, fluid satumtione not determined Permeability to air and pore volume determined using 400 psig confining pressure Conventional Analysis Results ConocoPhillips Nanuq fi3 Colville Delta HYDRAULIC UNITS SORTED BYSAMPLEDEPTH ' . Depth ' " F!°w.' '~ Reservoir-.' '-~'~-HYdraUlic. Zone . '.Quality - ... ' -Unit.'.- (ft) indi,cator..' Index..-. , , , 8532.2 0. t288 0.016 7 8533.2 6.6846 0.352 14 8534.3 1.6441 0.472 12 8534.9 1.1074 0.250 11 8535.1 2.9400 0.786 13 8535.7 1.9127 0.562 12 8536.3 3.5165 1.185 13 8537.5 0.1185 0.020 6 8538.'t 2.7264 0.833 13 8539.0 2.7989 0.850 13 8539.8 4.1370 1.306 13 8540.2 4.6489 1.468 14 8540.7 4.7811 1.526 14 8541.2 6.2877 1.975 14 8541.6 3.2313 0.901 13 8542.9 0.4242 0.01 t 9 File No. : 571114)1076 Loc.: Sec.24-T11NIR4E APINo. : 50-103-20365 -"" ' ~ SORTED BY HYD, UNIT ' ' ' ~th " Fi~,,~' Reservoir Hydraulic' ~' .-Zone Quality Unit (ft)... indica.to.r .Index ,, . 8537.5 0.1185 0.020 6 8532.2 0.1288 0.016 7 8542.9 0.4242 0.011 9 8534.9 1.1074 0.250 11 8534.3 1.6441 0.472 12 8535.7 1.9127 0.562 12 8535.1 2.9400 0.786 13 8536.3 3.5165 t. 185 13 8538.1 2.7264 0.833 13 8539.0 2.7989 0.850 13 8539.8 4.1370 1.306 13 8541.6 3.2313 0.901 13 8533.2 6.6846 0.352 14 8540.2 4.6489 1.468 14 8540.7 4.7811 1.526 14 8541.2 6.2877 1.975 14 ConocoPhillipa Nanuq #3 Coiviile Delta Initial and Remeasured Permeability Values (Horizontal) File No,: 57111-01076 Loc,: Sec,24-Tll NIR4E APl No. : 50-103-20365 -: ;.;::.:"':.'- .::'-" .':? !.:-:::;'!'"'---::"::'-::-'-i~"!::~ili:"':~:;: :'-:";ii~t;i::/::~!; '-i '-":" '" ;' :"-" "'""": .... ...RemhS~:i:. '.-: "-...-" ;... - .:. :.-..-.Initial-'.."- Rerun Change ' .... '::.:'.'-:|'.'.:' ' ':'"':" .-.. ...:. ::.' :.: ..:'..-: :..'--..:'--:..i."...-':~.'-.:i:.;~!:~.::.:-.:.~!i .. . .. .-_...-. :~r :..-. -: :.; :.:,: :..-Kair...- .! : ;Kalr '.,'--j. ::. :Klink . . :¥....'." :.Am. - cm c.m , I 8532.2 0.130 0.030 ~ht fight 3.86 3.86 0.00 2 8533.2 6.73 6.28 3,99 3.49 3.63 3.63 0.00 3 8534.9 2.15 11.6 9.88 8.77 4.00 3.88 -0.t2 4 8535,1 230. 132. 124, 118. 3.96 3.73 -0.23 5 8536,3 56.9 359. 316. 308. 3.41 3.t0 -0.31 6 8538.1 189, 165, t58. 152. 3.98 3.98 0.00 7 8539.8 84,0 415, 402. 398. 3.99 2.53 -i,46 8 8540.2 113. 525. 503. 499. 3.85 3.85 0.00 9 8541.2 170. 945. 920. 901. 3.80 3.56 -0.24 10 8542.9 0,010 0,003 tight l~ght 3.93 3.93 0.00 11 8534.3 48.4 50.4 47.8 44,3 3.95 3.95 0.00 12 8535.7 80,4 72,6 8,5.1 80.6 4.00 4.00 0,00 13 8537.5 0.092 0.058 0.035 0.018 3.06 3,06 0.00 14 8539.0 163, 171. 170, 165, 4,09 4.09 0.00 15 8540.7 534. 572. 565. 560, 4.05 4.05 0.00 16 8541.6 177. ~79, 175. 170, 4.19 4.19 0.00 Steady-state permeabilifies were determined at 400 psig confining pressure. CMS permeabilitiss were determined at 800 psig net stress. Permeability to air and pore volume determined using 400 psig confining pressure Conventional Analysis Results .~.. ConocoPhillips File No. : 57111-01076 Nanuq #3 Loc.: Sec.?.4-T11NIR4E Colville Delta APl No. : 50-103-20365 Initial and Remeasured Permeability Values (Vertical) I 8532.2 0.051 0.051 0.044 1.96 1.96 0.00 2 8533.2 0,872 0.891 0,86t 3.96 3.96 0.00 3 8534.9 1~9t t90. 148, 4.00 4.00 0.00 4 8535.1 ~,~ 319. 318. 2.76 2.76 0.00 5 8536.3 47,8 254, 265. 4.08 4.08 0,00 6 8538.1 172, 189. 184, 4.00 4.00 0,00 7 8539.8 43.3 230. 236. 2.84 2.84 0.00 8 8540.2 ~SA 603. 587, 4.02 4.02 0.00 9 8541.2 140. 748. 724. 3.94 3.94 0.00 10 8542.9 0.099 0.099. 0.017 3.96 3.96 0.00 Permeabilities were determined at 400 psig confining pressure. Values were recalculated using original data but with proper odfiee values. Permeability to air and pore volume determined using 400 psig confining pressure Conventional Analysis Results MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Cammy O.Taylor, ~ DATE: Chair Tom Maunder, P.I. Supervisor August 12, 2001 Lou Grimaldi, Petroleum Inspector SUBJECT: Location Inspection Nanuq #3 Sunday. Aueust 12. 2001: I made a Location Inspection on Phillip's Suspended well "Nanug #3". This exploratory location was clean with no evidence of drilling activity other than the Suspended tree and four large posts around it. There was a slight sheen inside of the culvert surrounding the well'head. The sheen was very transparent. The well sign hung on the tree was of a somewhat poor design, made of plywood and hung with wire on the tree this well sign will most likely end up on the Tundra. I requested that plans be made to secure this sign in a more secure manner. Rick Overstreet (P.P.Co. rep) will take care of this SUMMARY: I made a Location Inspection on. Phillip's suspended Exploratory well "Nanuq #3'. Attachments: Nanuq 3 tree 8-12-01 LG.jpg Nanuq 3 Airshot 8-12-01 LG.jpg cc.' Overstreet/Mordson (Phillip's Alaska Inc.) NON-CONFIDENTIAL Location Inspection Nanuq 3 8-12-01 LG.doc TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, ATO1486 Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Nanuq 3 DATE: 08/07/2001. TO: Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Nanuq 3 501032036500 Report/Analysis v/ Core Labs, Core Analysis report, CL file 57111-01076; 6/11/01; P/ease check off each item as received, sign and return one copy of the transmittal to address be/ow. The other copy is for )/our §les. All data to be held confidential until State of Alaska designated release date (AOGCC) Approx 4/2003 CC: Dave Bannan, PAl Geologist Approved for transmittal by: D. Bannan Receipt: ~ Return receipt to: Phillips Alaska, ]:nc. A'R'N: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: Prepared by: Sandra D. Lemke Phillips Alaska rT Technical Databases RECEIVED 2001 ~ 0ii & Gas Cons. Commilmion TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, AT01486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Nanuq 3 DATI[: 05/2fd2001 Lisa Weepie State of Alaska - AOGCC 333 W. 7~h Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following; Nanuq 3 (501032036500) c~o~- c~ Report / Epoch - Final Well Report, Nanuq 3, 3/15/2001, Well resume, drilling and geologic discussion, lithology,, summary, rig activities, mud record~ directional survey, bit record, drilling progress, dg time, final logs Dafa (film reproducible) / Epoch Formation Log, Nanuq 3; 2"= 100'; 0'-9112'md Please check off each item as received, sign and return transmittal to address below All data to be held confidential until State of Alaska designated release date (AOGCC) Approx 4/2003 CC: Rick I.~vin~n< PAl Geologist Return receipt to: Phillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: Prepared by: Sandra D. Lemke Phillips Alaska 1-r Technical Databases PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 May 11, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Nanuq #3 (201-026 / 301-059) Completion Report Dear Mr. Commissioner: Phillips Alaska, Inc., as operator of the Nanuq #3 exploration well, submits the attached "Well Completion Report" (AOGCC form 10-407). Other attachments to the completion report include the directional survey, report of daily well operations, core description, a memo of abnormal pressure, an as-built, and a final schematic. We will send under separate cover the logs, the mud logs, and other well data and reports. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 265-6120 or Scott Reynolds at 265-6253. Sincerely, G. C. Alvord Alpine Drilling Team Leader .. PA1 Drilling GCA/skad WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas E] Suspended r~ Abandoned E] Service 2. Name of Operator u,,,'~l~ i' 7. Permit Number Phillips Alaska, Inc. VEi~,~I. 201-026 /301-059 3. Address ~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 / 50-103-20365-00 4. Location of well at surface ......... ~---- 9. Unit or Lease Name 2268' FSL, 574' FEL, Sec.24, T11N, R4E, UM (ASP: 377669, 5957405) '~"!" Colville River Unit At Top Producing Interval 10. Well Number 2129' FSL, 703' FWL, Sec. 24, T11N, R4E, UM (ASP: 373664, 5957333) ! -'~-'~ '/~"~"~(' ' Nanuq #3 2151' FSL, 95' FWL, Sec. 24, T11N, R4E, UM (ASP: 373056, 5957366) ..-- 2 ,:~':.-~ Colville River Unit 5. Elevation in feet (Indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 28 & Pad 15'I ADL 380077 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 1, 2001 March 14, 2001 3/17/2001 suspended I N/A . feet USE 0 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey 120. Depth where SSSV set 21. Thickness of Permafrost 9112' MD / 7646' TVD 5155' MD / 4225' TVD YES r~ No DI N/A feet MD 875' 22. Type Electric or Other Logs Run GR/Res/Neut/Dens/Sonic 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.58# H-40 Surface 117' 24' 320 sx AS I 9.625" 40# L-80 Surface 1965' 12.25" 1360 sx AS Lite & 350 sx Class G 7" 26# L-80 Surface 9092' 8.5" 460 sx Class G & 200 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD Interval, size and number) SIZE DEPTH SET.(MD) PACKER SET (MD) 3.5" 2290' N/A None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED None 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Suspended Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press, psi 24-Hour Rate > 28. CORE DATA Brief description of Iithology, poro~ty, fractures, apparent dips and prosssnco of o11, gas or water. Submit core chips. RECEIVED See Attachments MAY 1,4 ZOO1 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit In duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. K-3 464Z HRZ 8152' K-1 8449' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, Memo of Abnormal Pressure, As-Built, Core description, Final Schematic 32. I hereby certify that the following Is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed .~1.~ & (~ Title AIl~lne Drllllnq Team Leader Date ~'(~[0( VG. C. Alvord ~ ' Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED item 28: If no cores taken, indicate "none'. Fo.. MAT ORIGINAL Alaska 0il & Gas Cons. Commission Anchorage Rpt Date 02/27/01 12:00 AM ' Nanuq #3 Operations Summary Comments Move 4 power pak modules from Atlas to Nanuq #3- Return Sows back to Atlas pad 02/28/01 12:00 AM 03/01/01 12:00 AM 03/02/01 12:00 AM 03/03/01 12:00 AM Stack and Secure Counter weights on 2 Peak Sows (Will be used to pull Sub Base) Move Sub from Atlas location to Nanuq #3 location Spot Sub over well - Spot Power Pak Modules & Pipe Sheds M/U Interconnects - Spot Rock Washer Prep Pits - Assm Pumps -Conn M/U Interconnects - Set Spools N/U Diverter- Rig Accepted @ 4:00 PM 2/28/01 Receive 580 bbls Spud Mud into pits - Load all BHA #1 into shed to warm up Fuction Test Diverter & Gas Alarm System - AOGCC Rep John H. Crisp witnessed Test - All "OK" Pre Sub Meeting with all Crew & all Contractors -Co Rep Reviewed well plan & Hazards Load & Strap DP & HWDP in pipe shed - Con't R/U Pre Spud Meeting with Co Man,Tour Pusher & Rig Crew Review Well Plan & Well Hazard P/U 5" DP'& S/B in derrick ( 66 jts) Repair Hose on IR Con't P/U 5" DP & S/B in derrick (48 stds total) - P/U HWDP & S/B in derrick P/U BHA Safety Meeting w/Doyon Managment Con't to P/U BHA- Had to put steam on tools Program MWD Flood Conductor and Circulating System - Ck complete system for leaks - All "OK" Dir Drlg 12.25" hole 140' to 260' S/B 2 stds HWDP - P/U 3 NM DCs & Stab Dir Drlg 12.25" hole 260' to 724' MD (722' TVD) ART 2.6 Dir Drlg 12.25" hole 724' to 1655' MD( 1542' TVD) ART 2.5 hrs, AST 6.2 hrs Dir Drlg 12.25" hole 1655' to 1973' MD ( 1781' TVD) ART 4.0 hrs, AST 1.5 hrs Circu hole clean Wiper Trip to 160' +/No tight hole - Wash 60' to Bttm - No Fill Circu & Condition - Pump wt, Hi Vis Sweep - Circu hole clean Circu & Condition to Run Csg Observe well - Pump dry job - TOH L/D BHA - L/D 3 NM DCs & NM Stab Down Load MWD info L/D MWD,Motor & Bit R/U to Run 9 5/8" Csg (Doyon Csg Crew) PJSM - Run 9 5/8" 40# L80 BTC Csg (36 jts IH end of tour) Con't Running Csg ( Total ran 47 jts ) L/D Frank's fill Tool/M/U CMT Head ,, Nanuq #3 Operations Summary 03/04/01 12:00 AM Circu - Slowly stage up circulation - Circu @ 8 BPM & Recip Csg - No fluid loss ( Co Man Pre Job Safety Meeting with Crew & Contractors while circu for CMT procedure) Pressure Test Lines - Repair Leak in CMT manifold Dowell Retest Lines - (::;mt per Well Program - Pump 5 bbl water-Test Lines 3500psi -30 bbls CW 100-Drop Bttm Plug 50 bbls MudPush @ 10.5 ppg - 300 bbls Lead CMT @ 10.7 ppg 72 bbls Tail CMT @ 15.8 ppg - drop top plug - pump 10 water and turn over to rig Rig displace w/Rig pumps - Bump plug w/1319 stks (Calcu bump 1315 stks)-( ClP @ 8:10 *** Note *** Had 10.7ppg Cmt to Surface @ 509 stks of displacement (82 bbls total back) Hold 880psi (500psi over bump) f/5 min - Bleed off - Fits held R/D Cmt Head-Landing Jt & All Csg tools - Clean tools from floor PJSM - N/D Diverter System PJSM - Clean Cellar- Install Csg Head -Test metal seal 1000psi N/U BOPs Test BOPs & Choke Manif to 250psi/5000psi - Test Annular 250psi/3500psi - No Failures - AOGCC Rep John H. Crisp witnessed Test Install Bowl Protector P/U DP TIH - TOH S/B in derrick Create Simulated Spill (ACS) Preform full blown spill drill - All personell responed per prrocedure Con't P/U 3700' DP and S/B in derrick- SLM P/U & M/U BHA #2 - Program FRTs & Load Scorces TIH to 1222' 03/05/01 12:00 AM Preform Stripping Drill w/L. Clarks Crew - Shut In well - Held PJSM - Stripped DP in hole holding 220 psi w/Annular- Bleed thru choke every 200psi increase - Let each crew member work with choke under T.P. instruction PJSM - Simulate well control problem - Pre Form Stripping Drill w/G. Burley Crew - Did stripping drill letting each crew menber have a turn running the choke on bleed- offs until he felt like he understood the process. Test Ann to 2500psi after Drill - Hold 5 min - Held TIH to tag CMT - Tag @ 1872' Circu air out of system - Circu slowly & recip pipe to minimize csg damage Test Csg to 2500psi - Chart 30 min for AOGCC - (loss of 20 psi over 30 min) Drlg FC, CMT ,FS & 1973' to 1993' MD 1797' TVD (20' new holel Circu & Condition - C/0 to new 9.55ppg LSND mud system- TOH to Shoe Preform FIT - Will test to 16.0 EMW - 598psi @ surface w/9.55ppg mud @ 1797'TVD - Formation broke down @ 595psi back to 200psi formation taking fluid .Pumped 2.8 bbl away @ 4 spm - Shut in f/10 min -psi fell to 130psi(This would be 11.6 EMW) After confer Drlg 1993' to 2013' MD (1813' TVD) - Circu Hole Clean - TOH to Shoe Preform #2 FIT - PSI to 170psi - Formation taking fluid @ 4 spm- pumped 2.2 bbls - Shut in psi fell to 150psi & held constant ( After talking to Well engineer & Team Leader it was decided to lay a plug on Bttm and do a well head squeeze. Nanuq #3 Operations Summary 03/06/01 12:00 AM 03/07/01 12:00 AM 03/08/01 12:00 AM 03/09/01 12:00 AM TOH to Sperry Tools - ( While in the Hole we could NEVER get a signal from Sperry MWD- It appeared to startup and then stop for some unknown reason) Remove RA scorces - Trouble shoot MWD problem L/D BHA #2 R/U Tbg tools - P/U CMT Stinger 259' X 2 7/8" w/Mule Shoe TIH w/Stinger on 5" DP - Space out to 2010' Circu & Condition - R/U Dowell - PJSM w/crew -contractors Lay Plug - Dowell Pump 10 water - Pressure Test Lines 2000psi- Pump 20.8 bbls 15.8ppg Slurry -2 bbk water turn over to Rig Rig Displace w/268 stks (this leaves 5+ bbls CMT in Csg) Cai TOC @ 18988' +/- TOH slowly to 1617' - R/U to Circu lines Pump 100 stks to clear Tbg - Shut in well w/Annular - Preform Well Head Squeeze - Apply 300 psi dn Tbg - Were able to squeeze away 18 stks total (1.8 bbls) - Held 300 psi SICP Con't WOC - Pressure on Squeeze 110 psi Bleed off Ann. - Open & Monitor well - Blow dn TD & Choke manifold TOH - L/D 2 7/8" Tbg stinger P/U BHA #3 - Orient Tools - Program MWD & FRTs TIH to 1782' tag CMT Stringers Drlg Stringers & CMT (Stringers 1782' to 1860') (Solid CMT 1860' to 2013') - Drlg new formation 2013' to 2022' MD 1819 TVD) Circu Hole Clean - S/B std DP - @ Shoe Attempt #2 LOT to 12.0 EMW - Formation broke @ 220 psi on 34 stks shut in after 46 stks @ 110 psi for 10 min = EMW 11.8 Dir Drlg 2022' to 2950' MD (2532' TVD) ART hrs Dir Drlg 2950' 3047' MD(2608'TVD)ART .75 hrs ,AST 0.0hrs Circu weighted hi vis Sweep to surface to improve ECDs ECDs running 10.8pp Dir Drlg 3047' to 3605' MD(3037' TVD)ART 6.25 hrs, AST.5 hrs Dir Drlg 3605' to 4005' MD ( 3450 TVD) CBU - Pump Sweep & Circu Hole Clean Wiper Trip to Shoe @ 1965' - Monitor for flow @ 5,10 stds & Shoe - No Swab - No Excess Drag(Max pulling speed 60 fpm) Service TD - Do Haz Ass. on TD -" Washer" found on floor Loose bolt found on TD TIH to 3900' -Max running speed 80 fpm - No hole problems Wash & Ream 100' to Bttm - No Fill - CBU to lower ECDs - Max Gas units @ BU = 300 units Dir Drlg 4005' to 4150' MD ( 3450' TVD) Total ART 5.5 hrs Dir Drlg 4150' to 4890' MD (4020 TVD)' ART 7.0 hrs, AST .7 hrs Dir Drlg 4890' to 5890' MD (4791' TVD) ART 8.5 hrs, AST .5 hrs Dir Drlg 5890' to 6233' MD (5057' TVD) ART 3.1 hrs, AST .3 hrs Pump Hi Vis/Weighted Sweep - CHC -Monitor Well static TOH-Wiper Trip tp 4005' -(Max pulling speed 60 fph) No Drag - No Swab Service Wash Pipe - Grease Swivel Nanuq #3 {'" Operations Summary 03/10/01 12:00 AM 03/11/01 12:00 AM TIH to 6140' - Wash & Ream to Bttm Service TD - Service Rig CBU to manage ECDs -10.8 down to 10.4+ Dir Drlg 6233' to 6278' MD (5092' TVD) ART .3 hrs AST 0.0 hrs Dir Drlg 6278' to 7178' MD (5863' TVD) ART 6.7 hrs AST 2.0 hrs Dir Dig 7178' to 7255' MD (5933' TVD) ART .8 hrs AST 0.0 L/D 1 Jt DP - Blow dn TD - R/U Circu Head CBU Circu w/Head pin - C/O Swivel Packing - Close IBOP TD & Pressure Test to 3000 psi "OK" P/U Jt DP - Wash & Ream to Bttm Dir Drlg 7255' to 7680' MD(6323 TVD) ART 9.2hrs, AST 0.0 hrs Dir Drlg 7680' to 8360' MD (6943' TVD) ART 9.2, AST 0.0 Dir Drlg 8360' to 8522' MD (7093' TVD) ART 2.2 hrs, AST 0.0 hrs CBU - Survey - Monitor Well - Blow dn TD 03/12/01 12:00 AM Wiper Trip 15 stds (to 7165') Max pulling rate 60 fpm - No excess drag - No Swab Circu & Pump Hi Vis Weighted Sweep - Circu & Condition for coring per Bariod rep (Don Urbatsch) Monitor Well - Pump dry job - Blow dn TD TOH - Max pulling speed 60 fpm to minimize Swab- Monitor well for flow per PAl policy (Held Kick Drill) Con't TOH - Monitor for flow per PAl policy Remove RA Scources - Dn Load Tools - L/D Tools & Motor Clean all Tools off floor & Wash up P/U Stack Washing tool (Clay balled up in Staack) - Wash stack w/TD on Wash tool Test BOPs - Test BOPS 250psi Io & 5000psi Hi - Test Ann 250psi Io & 3500 psi hi- No failures - All test held 5 min & on chart - 24 hr notice was given - AOGCC rep Lou Grimaldi wavied witness test. Con't BOP Test Pull test plug - Install Wear Ring - Blow Dn Choke & TD PJSM w/Co Man, BHI Core Driller & Crew on Picking up Core Assy - Discussed all related hazards P/U Core Assy #1 (60' of barrel) TIH to 1900' - (Max running speed 60 fpm) Fill Pipe - Break circu - Pump 1.5 times pipe volume 03/13/01 12:00 AM TIH- Fill pipe every 2000' - TIH to 8411' - M/U TD (Max running speed 60 fpm CBU - Circ & condition per BHI core rep - (Max gas @ BU 418 units) Drop Ball - Circu to Bttm (@ Bttm 12:34) ~ ~ ~.,~ ,r" ..-e..-. Cut #1 Core from 8522' to 8572' MD (7140' TVD) CBU -Observe well (static) Pump dry job - Blow dn TD TOH Slowly using tripping schedule in well plan POH W/CORE ASSY. PJSM, LAY DOWN CORE & CORING ASSY. CLEAR FLOOR, L/D MOUSEHOLE & CORE BBL HANDLING TOOLS. BHA, P/U MOTOR & BIT, STABILIZERS, MWD & LWD, INITIALIZE MWD & INSTALL SOURCES, P/U STAND OF D.CLRS. RIH TO 1965', FILL DRILLPIPE. CUT DRILLING LINE. Nanuq #3 Operations Summary SERVICE TOP DRIVE. 03/14/01 12:00 AM RIG DOWN TIME!, THAW KELLY HOSE, DISCONNECT KELLY HOSE, THAW BOTH STAND PIPE, GOOSENECK & KELLY HOSE, REASSEMBLE BOTH. SHALLOW TEST MWD/LWD. RIH F/CSG SHOE, fill pipe every 30 stds. FINISH RIH TO 8465', BREAK CIRCULATION @ 7630'. MAD PASS F/8496-8555'. WASH & REAM TIGHT HOLE (SLOUGHING SHALE SECTION) F/8531-8555'. MAD PASS F/8555-8572'. DRLD F/8572-9112', ART 7.75 HR. 03/15/01 12:00 AM CIRCULATE BOTTOMS UP, SURVEY, PUMP SWEEP AND OBSERVE WELL. SHORT TRIP FROM 9112-8370', NO PROBLEMS WITH HOLE. ClRC BTMS UP, SWEEP, OBSERVE WELL, PUMP SLUG. POH F/CASING. FINISH POH, LAY DOWN HWDP. REMOVE SOURCES, DOWNLOAD MWD, LAYDOWN MWD & MOTOR. PULL WEAR RING & INSTALL TEST PLUG. INSTALL 7" RAMS IN TOP RAMS. TEST DOOR SEALS TO 3500 PSI. RIG UP TO RUN 7" CASING. PJSM, RUN CASING TO SURFACE SHOE. FILL PIPE @ SHOE. CONTINUE RUNNING CASING TO 9092'. R/D SPYDERS-FILL UP TOOL-R/U CEMENTING HEAD. 03/16/01 12:00 AM ESTABLISH CIRCULATION, circulate and condition mud for cementing. CIRCULATE & CONDITION MUD, HOLD PJSM, BATCH UP CEMENT. TEST LINES, PUMP 20 BBL PREFLUSH, 30 BBL SPACER, 96 BBL 15.8 PPG GASBLOK CMT, DROP PLUG, DISPLACE W/RIG CALC AMOUNT, CEMENT IN PLACE @ 0300 HR.. DID NOT BUMP PLUG, FLOATS HELD, FINAL ClRC PRESSURE 700 PSI @ 4BPM. WAITING ON CEMENT DUE TO PLUGS NOT BUMPING. SHEAR STAGE TOOL OPEN, PINNED FOR 2600 PSI, TOOK 3500 PSI TO SHEAR. CIRCULATE BOTTOMS UP, NO CEMENT IN RETURNS FROM 1ST STAGE. CEMENT 2ND STAGE- PUMP 20 BBL PREFLUSH, 30 BBL SPACER, 37.8 BBL 15.8 PPG GASBLOK CEMENT, DROP PLUG, 5 BBL CMT ON TOP OF PLUG, DISPLACE W/RIG, BUMP CLOSING PLUG W/1200 PSI OVER ClRC PRESS, HOLD 1500 PSI FOR 5 MINUTES, CHECK FOR FLOW-OK. ClP RIG DOWN CSG EQUIPMENT, CLEAR FLOOR. INSTALL 7" X 9-5/8" PACKOFF. PJSM R/U & RUN 2290' 3-1/2" TUBING OPEN ENDED STRING WEIGHT 15K. P/U TBG HANGER AND LAND SET TWO WAY CHECK R/D TUBING EQUIPMENT. 03/17/01 12:00 AM Nanuq #3 Operations Summary R/U & LAY DOWN DRILLPIPE FROM DERRICK. LAY DOWN DP FROM DERRICK. CHANGE TOP RAMS TO 3-1/2 X 6 VBR'S, BTM RAMS TO 3-1/2". NIPPLE DOWN STACK. N/U TREE, TEST TBG HANGER TO 5000 PSI/10 MIN. TEST TREE TO 5000# W/HOT OIL TRUCK. ATTEMPT TO PERFORM LEAK-OFF TEST ON OUTER ANNULUS W/HOT OIL SERVICES, TRANSFER CASE ON TRUCK WENT OUT, SENT FOR NEW HOT OIL TRUCK. RIG UP HOT OIL TRUCK, PERFORM L.O.T. ON 7" X 9-5/8" ANNULUS, BULLHEAD 250 BBL FRESH H20 DOWN ANNULUS FOLLOWED BY 55 BBL DIESEL TO FREEZE PROTECT, R/D & R/U ON 3-1/2 X 7" ANNULUS TAKING RETURNS F/TUBING, FREEZE PROTECT TO 2290' MD W/80 BBL DIESEL, TEST CSG MOVING RIG TO RENDEZVOUS A. INTER-OFFICE CORRESPONDENCE ANCHORAGE, ALASKA Date: 4/25/01 Subject: Abnormal Pressure in Nanuq #3 From/Location: T.J. Brassfield Telephone: 265-6377 To/Location: Sharon Alisup-Drake As requested from the DNR for data submittal on the Nanuq #3 wellbore , we are required to advise the agency of any abnormally pressured zones encountered while drilling these wells. Please find attached the mud weight graph plotted by depth for Nanuq #3. There were no abnormally pressured zones encountered while drilling this well. Any questions, please call me at 265-6377 or Paul Mazzolini at 263-4603. Cc: Nanuq #3 Well File 116" set @ 117'I DRILLING TIME AND MUD WEIGHT CURVE .-e-Depth Nanuq #3 ~Mud Weight 0 .... I ; ' ' , _~ ............ 11 -- -- -- ~.. _ _1- J.- _ _ _ ....[ ........... -I ....I .....l- ....... I.- .-I ' -,- r ; -I--- { ~ ,' T , "Ho , , ~ . -- .....,L _ _ _ _1 .... I. I I I I I I I i I I I I I lOOO -- - - 10 8 .... . _,_ . ~ ...... ~ .... , .... . _-___.___- ...... L ..... , .... ~___~ .... I j / I ! I I I I I I [ I I I I I I I I F "i .... i I ~ ~ r i ~' I ....i f i '~ ~ f r i - .... '~ ..... {- ~ --~- ........ ' ....4- -1 -~- ~ '~ ....~- ............. ~- ........ ' ....... '+ ....' ....... ~- '~ .... t [ I I _i_ t / I I ] I I I I i / I ___/ --L ...... --I .... ~- J-- .L .L ........ 1- -- -- -- ..[ .... -- F- -F --t .... -F ....I ........... · ----I .... 4- I--------+------~ .......... I I I i I I I I I 3000 . , .... , .... , , 10.4 I I I I I I f I I I I I I I I I I i I [ I T i I [ i '1 [ i i - I11 .... -4- .... , ....{-------4------ --t .... , ....4- -~-- ...... , ....!-- - - -+ .... I ........ ~ .... , ....4----4 .... I / I I I I I ! I I I I I ~ 4000 ' ' ' ' ' L___] 10.2 I-- '~ F I [ I I-- - - - T - - -- -'l , .... I-- - L 'l' .... I -f I r -I ~i~ ~ ' - -'- ' 6' -i/2 : : 5000 ~ ~ rill "Mol 10 a I ', f---i-- ~ ~ ....' I ' f 1--- I I ] i I i I I III ------~ ....! ........ l-------q--- T -I t~I -- -- -- -I-: .... l I .... I{- .... 1-------I I .............. ! 1. lb------ 4---------I I I .... I I I ::~ T , I [ i l' T ~ , i i u) 6000 9.8 i~ ___J. ' L .L___J t I .... .J. _ _ _ _.! .... L _I_ I / .... I .... /___J .... I I I I 1 I I I ! I I I I I I I III ---~ .... i .... r ..... r---~. .... I ..... r---T---a .... r -~ .... r ......... 3 ~ r -- - ~ .... -- -- -- -!-I J,- 4- .... I--------4-------~ .... I I I I I I I I I I I I I I I 7000 i , , , ~ 9.6 ' _' ! .... --' .... ' ....... t .L___J .... L ....... ! ....L -I ....I ....L J T I ~ I I I I I ! I I I I I I I I -------r .... I ....T .... T-------I I .... [ ....T--------I .... r---- , r----r .... -f i r----I .... -- -- -- -J. .... I---- .L -- -- -- --I .... I .....1- --4.------4-1 .... I-- I I- .L I -1 ....I ....L------ I ] I I I / I I I I I I I I I I i 'l T i I i i ~' 'l i' [ I T i i ' 0.4 8000 I I I I I I I J____/_ I ! ! I I I I I I i i ? i , I , ; , ; i - - - -~ ..... , .... r - - - ~ , - - - '~ .... r - TD/Flun 7"/Operational Shuldown - - - ~ , 1- - - - ~ .... ____1______ J.- ---- -- ~ .... I ....4. ....... ~- .... -J- .... I-- ' -[ .... I I I I I / I I I I I I I I i '~ T i I 9000 9.2 I I I I I I i I I I I I I i ', [ [ i , T -r -- -- - -- I- '1 -! , r T -- -- -- --J-- i 'l -r I -t .... I .... 3" -------L .... I-- L-------I ...., ....J. L---- --.L-- -- ---.f .... I I I / / I I I I | I I I I I / / I I ~ , ~ , , , T ; ~ ; r ', i T ' F , ', T 9 1 oooo o 5 1 o 15 20 25 Spud Well @ 1300 hrs 3/1/01 TIME TO DRILL (DAYS) ~ ~-~ ~ Release Rig @ 1700 hrs 3/17/01 prepared by TJB 4/25/01 Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Nanuq #3 1I Location: Date Colville Delta Unit 13-Mar-01 Core #: Recovered: Core #1 described bv D. Bannan Cut 47 recovered 45.3 Depth Rec Description Oil Oil Fluor. Cut Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum Shale, black carbonaceous, w/abundant pyrite scattered throughout. Firm, no obvious bedding. 8522 Slightly calcareous None none - - none none Shale, black carbonaceous, w/abundant pyrite scattered throughout. Faint discontinous parallel lamintation. Occasional flattened ovals (buurows?) 8525 Non calcareous None None - - - None None Shale, black carbonaceous, w/less pyrite scattered throughout. Faint very discontinous 8528 lamintation. Possible slickensides. Non calcareous none none - - - none none Interbedded meal greyshale and It grey sandy shale. Scattered quartz and glauconite grains, scattered pyrite throughout. Sand sub rounded. 8531 Possible burrow cutting the interbeds. Non calc. none strong - - - none none Sandstone, light brown, fine-medium with some coarse. Subrounded, quartz and glauconite. Patchy siderite cement, overall non calcareous. Moderately consoldated. Good visual porosity & instant 8534 perm It. Brwn strong 90 bright yellow amber bright white excellent Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Nanucl #3 1 I Location: Date Colville Delta Unit 13-Mar-01 Core #: Recovered: Core #1 described by D. Bannan Cut 47 recovered 45.3 Depth Rec Description Oil Oil Fluor. Cut Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum Sandstone, light brown, fine-medium with some coarse. Subrounded, quartz and glauconite (10%). Patchy siderite cement, overall non calcareous, instant 8535.2 Mod. Consoldated Good visual porosity & perm dk. Brown strong 95 bright yellow amber bright white excellent Sandstone, light brown, tine-medium with some coarse. Consoldated. Subrounded, quartz and glauconite (10%). Increase in the amount of siderite cement, overall non calcareous. Fair instant 8536.5 visual porosity & perm dk. Brown strong 75 bright yellow It. amber bright white good Sandstone, light brown, mostly Uvf w/some Lm. Subrounded, quartz and glauconite (10%). No obivious siderite cement, mod. calcareous. Good instant 8537 visual porosity & perm. Mod consolidated dk brown strong 100 bright yellow It. Amber bright white excellent Sandstone, light brown, Uvf w/some Lm. Subrounded, quartz and glauconite (5-10%). 'Conslodated extensive siderite cement, non - slightly calcareous. Good visual porosity & perm. instant 8540 Mod consolidated dk brwn strong 40 bright yellow amber bright white good Shale, brown, slightly silty, hard. Scattered pyrite 8543 slightly calcareous none none - - - none none Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of I Nanuq #3 1 I Location: Date Colville Delta Unit 13-Mar-01 Core #: Recovered: Core #1 described by D. Bannan Cut 47 recovered 45.3 Depth Rec Description Oil Oil Fluor. Cut Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum Shale, brown, slightly silty, hard. Scattered pyrite, 8546 slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. Less scattered 8549 slight pyrite, slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. Elongate blebs o~ 8552 pyrite, slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. Scattered pyrite, 8555 slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. Diminishing 8558 amounts of pyrite, slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. minor pyrite, 8561 slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. trace pyrite, 8564~ slightly calcareous none none - - - none none Shale, brown, slightly silty, hard. trace pyrite, 8565 slightly calcareous none none - - - none none Phillips Alaska, Inc. Core Chip Description Operator and Well Name: Section of Nanuq #3 II Location: Date Colville Delta Unit 13-Mar-01 Corn #: Recovered: Core #1 described by D. Bannan Cut 47 recovered 45.3 Depth Rec Description Oil Oil Fluor, Cut Cut Show ft. in. Stain Odor % Int Color Color Fluor color Sum Shale, brown, slightly silty, hard. trace pyrite, 8567.3 mottled texture, slightly calcareous none none - - - none none 03-,07-01 15:16 From-KUP DRILLING TOOL HS U~'q,I~'UI 1~:~4 ri~uul nl, i tsp. Per K01001AC~ +907-666-7691 T-366 P.02/05 F-646 ~OTES: 1. I~ASIS OF' HORIZONTAL ANO ~..RTICAL LOCATION I$ AlP'IN[ CD2 MONUMENTS PER LCIdF. 2, COORDINAI~-S SHOWN ARE ALASKA STATE PLANE ZONE ~, NAD 27, 3. GEOGRAPHIC COOROiNA'fES ARE: NAD 2'/. ~. ELEVATIONS SHOWN ARE BRrflSH PE'TROLF. UM MEAN SEA lEVEL DATUM. 5. AU. t:XSTN,iCE5. ~ TRUE. 6. ICE PAD I$ ROTATED 70' EAST FROM NORTH. 7. DATE OF' ~URVEY: 2/26,/20ol. NANuQ ~ -- I LOCAI~D WITHIN PROTRAC'rEO SEC. 24, T11N. &R 4E, ' UMIAT MERIDIAN. LAT - 70'17,31.692' LONG = 150'5g'25.44 .5;957.404.8t ' I I, , · '.' 2266, F.S.I... 574 F.£.L_.i:~.,.. '.~ GROUND £LEVATION = 1 RIG, PAD 'FJ. EV. = 14.6' i,sCALE-- ~- -20o' IANUQ 3 · , PHIt. LIPS Alaaks, In , A SuDa;dior¥ ¢)f pHII. UPS P£TROI.EUM cOMPANY NO, ' ., J VICINITY .MAP - . SCAI~,: .1'"" = 2 Miles .. LOuNs'm R¥, NANUQ3 EXPLORATORY WEU. CONDUCTOR ASBUILT' II II . m, Depth Depth Section (feet) (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/lOOf) 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 TIE-IN 140.00 0.00 0.00 140.00 0.00 N 0.00 E 0.00 0.00 205.47 0.09 40.64 205.47 0.04 N 0,03 E -0.04 0,14 290.88 0,09 212,00 290,88 0.04 N 0.04 E -0.05 0,21 386.20 1.42 266.06 386.19 0,11 S 1,17 W 1,18 1,44 478,07 568.53 658.84 750,56 842,73 3,05 267,39 477.99 0.30 S 5.59 265,75 568,18 0.73S 7.89 267,33 657,86 1,35 S 10.15 272,15 748,44 1,33S 13,14 271,61 838~71 0.73 S 4,76W 4.76 ' 1.78 11,56W 11.58 2,81 22.14W 22.17 2,55 36,50W 36,52 2,59 55,09W 55.07 3.25 932,33 17,78 271.94 1026,05 22.92 272,39 1117;72 26,17 270,53 1210,39 31,36 268,99 1303.16 34,55 270,18 1396.33 1488.83 1581.43 1675.14 1767.33 37,18 269.14 38,38 267,51 37,99 267,74 38,37 265.75 39,60 263,32 925.04 0.02 N 78.95W 78.89 1012.88 1.27 N 111.51W 111.37 1096.26 2.20 N 149.56W 149.36 1177.47 1.96 N 194.14W 193.91 1255.30 1.61N 244.60W 244.34 .. 1330,80 1403,91 1476,70 1550.37 1622,03 1,27 N 0,39 S 2,77 S 6.06 S ' 11,60 S 299.18W ,298.89 355.81 W 355.55 413.01W 412.79 470.83W 470.70 528.55W 528.59 5,18 5,49 3,64 5,67 3.51 '2,89 1,69 0,45 1.37 . 2.13 ' 1859,84 1908,1'1 1976,16 2068,90 2161.11 2254.10 2347.22 2439.89 2532.26 2625.98 39,33 39,26 38,78 38,91 39,74 40,53 39,93 39,45 39,09 39.74 264.77 ,264.79 263.68 262.12 264.27 266,28 269.85 271,64 271,58 270,89 1693,45 1730,81 1783.68 1855,91 1927,24 1998,34 2069,44 ' 2140.76 2212,27 2284,67 17,71 20,49 24.79 31,98 38.90 '43,82 45.87 45.11 43,46 42,18 587,03W 587.27 617,47W 617.80 660.10W 660,56 717,81W 718,52 775,83W 776,76 .835.56'W ,895.64W 954.82W 1013.26W 1072.75W 838.64 896.78 955.85 1014.19 1073.58 ,1.04 0,15 1..24 1,06 1,73 1,63 ' 2.56 1,34 0,39 0,84 2718,02 2811,16 2902,17 2995,79 .3089,67 39,87 40,13 39,73 39,36 39,45 270,06 268,89 . 268.04 266,59 267,98 2355,38 2426,73 2496,52 2568.72 2641,26 41,70 S 42,25. S 43,82 S 46,60 S 49,42 S 1131,67 1191,54 1249.93 1309.46 1368,99 W. W W W W 1132,43 1192,28 1250,68. 1310,28 1369,87 0,59 .0,85 0.75 1.06 0.94 3182,93 39,22 267,07.' 3276,08 40.10 266.51 3368,94 40,00 266,73 346i ,38 39,84 267,64 3555,05 40,38. 267:51 2713,39' 2785.10 2856.18 2927.07 2998.71 51,97 S 55.30 S 58,82 S 61,74 S 64,29. S .1428,05 1487.40 1547,05 1.606,30 1666.59 W W W W W 1428,98 1488,43 1548.17 1607.49 · 1667.83 0.66 1.02 ' 0,18 0,65 0,59 · Job'No.: AKMM-10074 Well No.: Nanuq #3 End of Well Report , Page 8 II II II Section Depth (feet) 3847,48 3739.57 3832.76 3924,28 4018,~3 4111,52 4200,65 4298,84 4390.90 4484 31 4574.76 4~7,53 478t,17 4854.10 4947.38 5039,,90' .5132,62 5225.82 53'17,42 5409.94 5802,64 5596,03 5888.59 5781,11 5874,42 5987,12 808O1O 6151,17 6246,21 6339.24 ~432,43 6525,38 ~818,43 671Z00 6803,84 889~.51 70~2,07 7175;15 72~671 Depth (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/lOOf) 40.50 267.49 3069.06 66.91 S 1726.49 W 1727.79 0.13 40.50 267.82 3139.09 69.35 S 1786.25 W 1787.60 0.23 40,54 267.56 3209.93 71.79 S 1846.75 W 1848.14 0.19 40.55 267.22 3279.47 74.51 S 1906.18 W 1907.64 0.24 40,98 267.17 3350.93 77.52 S 1967.71 W 1969.24 0.45 40,95 266.10 3421.07 81,10 S 2028.50 W 2030.12 0.76 39,78 266.98 3488.99 84.59 S 2086.12 W 2087.83 1.45 39,46 267.33 3562.93 87,62 S 2147.26 W 2149.04 0.41 39.16 266,45 .3635.86 90.86 S 2206.88 W 2208.75 0.68 39.46 267.11 3708.14 94.19 S 2265.96 W 2267.91 0.55 39.06 266.14 39,72 268.08 39,73 268.09 39,86 268.°4 39,74 267,64 39,82 39,48 39.57 39,59 39,55 39.62 39,71 39,,73 39.71 39,72 39,31 39,01 38,76 38,65 37,26 36.09 34.95 33.69 31.57 29.21 266.48 267.71 267.47 266.69 266.21 267.43 267,14 267.'74 267.72 267.53 269.88 269.54' 269,62 269.27 269.57. 269.83 269.36 269.10 268.07 268.93 27.11 269.99 25,45 270.19 24.53 270.74 ' 24.06 271.79 23,60 272;34 3778.,17 3849.87 3921.89 3993.40 4065.15 4136.27 4207,66 4279.55 4350,15 4421.47 4492.92 4564.81 4636.00 4707.17 4778,94 .. 4850.46 4922.56 .4993.45 5067.62 5140.97 5215.71 5291.36 5368.21 5447.01 5526.22 5607.92 5691.39 5775.20 5860.03 5945.62 97.56 $ 2323.10W 2325.14 0.80 i00,52 S 2381.89W 2384,00 1.51 102.51S 2441.70W 2443.85 0.01 104:52 S 2501.02W 2503.20 0.08 106,77 S 2560.55W 2562.77 0.29 109.81 S 112.81 S' .115.30 S ' 118.27 S 121.92 S 125.19 S 128.02 S' 130.66 S 133.00 S 135.47 S 136.81 S 137.10 $ 137.52 S 138.09 $. 138.67 $ '138.97 $ 139.35S 140.05 S 141.29 S 142.52 S 2619,68W 2621.98 2678.77W 2681.13 2738.03W 2740,44 2796.31W 2798.80 2855.14W 2857.72 29'14.11W 2916.78 2973.68W 2976.39 3032.74W .3035.54 3091.82W 3094.66 3151.39W 3154.28 '321.0.35'W .3213.25 3269.06W 327i.92 3326.23W 3329.08 3385.65W 3388.46 3442.87W. 3445.66 3498.53W' 3501.29 3552.53W '3555.26 3604.98W 3607.70' 3655.42W 3658.15 3701.87W 3704.81 142.94 S 3745:59W 3748.32 142.88S 3786.81W 3789.50 142.56 S 3825.87W 3828.51 141.72 S 3864.15W 3866.73 140.36, S 3901.92W 3904.42 '0.81 0193 0.19 0.55 0.33 0.84 0.22 0.41 .0.02 0.13 1.68 0,40 0.28 0.25 1.51 1':27 1.27 1.36 2.33 . ' 2.61' 2.34 1.78 '1.03 0.68 0.55 Job No,: AK-MM-10074 End of Well Report. Page 9 Well No.: Nanuq ., , Section ! ! ii ! ! ! ! ! ! Depth (feet) 7361.09 7454.51 7544.26 7640.25 7732.85 7825.10 7918.51 8011.52 8103.29 8196.48 8289.60 8382,32 8439,78 8565,79 8660,52 8753.48 8844,90 8938,48 9027,51 91'12.00 Depth (degrees) (degrees) (feet) (feet) (feet) (feet) (deg/lOOf) 22.97 271.56 6030,48' 139.11 S 3938.42W 3940.84 0.76 23.22 271,52 6116.41 138,13 S 3975.05W 3977,40 0,28 23.69 272,54 6198.74 136.86 S 4010,75W 4013.03 0,69 24.84 272,44 6286.25 135,15 S 4050.17W 4052,35 1,20 24.97 273,01 6370,24 133,29 S 4089.12W 4091,19 0,29 24,53, 272.57 6454,01 131,41S 4127.69W 4129,66 0,52 24,30 272.92 6539.07 129,56 S 4168,25W 4168.12 0,29 24,07 272,68 6623.92 127,70 S 4204,31 W 4206,08 0.27' 23.73 272,29 6707,82 126,09 S 4241.46W 4243,13 0,41 23,58 272,00 6793.18 124.69 S 4278.82W 4280,41 0,20 23,27 271,43 22,76 271,79 22,27 271,82 22,18 271,55 21.58 271,01 20.53 19.90 19.81 19.34 19.34' 272,09 272,35 271.88 272,16 272.16 6878.62 123.58 $ 4315.83W 6963.96 122.56 S 4352.07W '701'7.04 121.87 $ 4374.07W .7133.68 120.46 S 4421.72W 7221.59 119.67 $ 4457.01W 7308,34. 7394,13 7482,15 7566,03 7645.75 118.78 S 117,56 S 116,38 S .115,33 S' 114,28 S 4490.39W 4521,96W 4553,73W 4583,54W 4611,51W 4317.35 0,41 4353,52 O,57 ' 4375,47. 0,85 4423,03 O, 11 4458,26 0,67 4491.58 4523.08 4554.77 4584.52 4612.43 1'.20 0.69 0,20 0.54 0,01 . Job No.: AK.MM-10074 Well No.: Nanuq #3 End of'Well Report Page 10 Kuparuk River Unit North Slope, Alaska EXPLORA TION_NON-PAD, Slot Nanuq # 3 Nanuq # 3 Job No. AKMM10074, Surveyed: 14 March, 2001 SURVEY REPORT 9 April, 2001 Your Ref: 5010320365 Surface Coordinates: 5957404.81 N, 377669.05 E (70° 17' 31.5748" N, 150° 59' 25.4572" W) Kelly Bushing: 42.0Oft above Mean Sea Level DRILLING SERVICES Survey Ref: svy9410 A Halliburton Company Sperry-Sun Drilling. Services Survey Report for Nanuq # 3 Your Ref: 5010320365 Job No. AKMM10074, Surveyed: 14 March, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) ' 0.00 0.000 0.000 -42.00 140.00 0.000 0.000 98.00 205.47 0.090 40.640 163.47 290.88 0.090 212.000 248.88 386.20 1.420 266.060 344.19 478.07 3.050 267.390 568.53 5.590 265.750 658.84 7.890 267.330 750.56 10.150 272.150 842.73 13.140 271.610 435.99 526.18 615.86 706.44 796.71 Vertical Depth (ft) 0.00 140.00 205.47 290.88 386.19 477.99 568.18 657.86 748.44 838.71 932.33 17.780 271.940 883.04 925.04 1026.05 22.920 272.390 970.88 1012.88 1117.72 26.170 270.530 1054.26 1096.26 1210.39 31.360 268.990 1135.47 1177.47 1303.16 34.550 270.180 1213.30 1255.30 1396.33 37.180 269.140 1288.80 1330.80 1488.83 38.380 267.510 1361.91 1403.91 1581.43 37.990 267.740 1434.69 1476.69 1675.14 38.370 265.750 1508.36 1550.36 1767.33 39.600 263.320 1580.02 1622.02 1859.84 39.330 264.770 1651.44 1693.44 1908.11 39.260 264.790 1688.80 1730.80 1976.16 38.780 263.680 1741.67 1783.67 2068.90 38.910 262.120 1813.90 .1855.90 2161.11 39.740 264.270 1885.23 1927.23 2254.10 40.530 266.280 1956.33 1998.33 2347.22 39.930 269.850 2027.43 2069.43 2439.89 39.450 271.640 2098.75 2140.75 2532.26 39.090 271.580 2170.26 2212.26 2625.98 39.740 270.890 2242.66 2284.66 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5957404.81N 377669.05 E 0.00 N 0.00 E 5957404.81 N 377669.05 E 0.04 N 0.03 E 5957404.85 N 377669.08 E 0.03 N 0.04 E 5957404.84 N 377669.09 E 0.11 S 1.18W 5957404.72 N 377667.87 E 0.30 S 4.75W 5957404.59 N 377664.29 E 0.74S -11.55W 5957404.26 N 377657.49 E 1.35 S 22.13W 5957403.82 N 377646.90 E 1.34 $ 36.50W 5957404.06 N 377632.53 E 0.74 $ 55.09W 5957404.96 N 377613.95 E 0.01N 78.96W ' 5957406.10 N 377590.10 E 1.25 N 111.51W 5957407.88 N 377557.57 E 2.18 N 149.57W 5957409.43 N 377519.53 E 1.95 N 194.15W 5957409.92 N 377474.96 E 1.61 N 244.60W 5957410.40 N 377424.51 E 1.27 N 299.18W 5957410.94 N. 377369.93-E 0.40 S 355.82W 5957410.20 N 377313.27 E 2.77 S 413.02W 5957408.76 N 377256.04 E 6.07 S 470.84W 5957406.41 N 377198.17 E 11.61 $ 528.56W 5957401.81 N 377140.37 E 17.71 S 587.04W 5957396.66 N 377081.80 E 20.49 S 617.49W 5957394.37 N 377051.31E 24.79 S 660.11W 5957390.76 N 377008.62 E 31.98 S 717.83W 5957384.51 N 376950.79 E 38.89 S 775.85W 5957378.55 N .376892.67 E 43.82 S 835.58W 5957374.59 N 376832.87 E 45.86 S 895.66W 5957373.53 N 376772.76 E 45.10 S 954.84W 5957375.25 N 376713.61E 43.46 S 1013.28W 5957377.85 N 376655.20 E 42.18 S 1072.77W 5957380.10 N 376595.73 E Dogleg Rate (°/100fi) 0.00 0.14 0.21 1.44 1.78 2.81 2.55 2.60 3.25 5.18 5.49 3.64 5.66 3.51 2.90 1.69 0.45 1.37 2.13 1.04 0.15 . 1.25 1.06 1.73 1.63 -2.56 1.34 0.39 0.84 North Slope, Alaska EXPLORATION_NON-PAD Vertical Section Comment 0.00 0.00 -0.04 · -0.04 1.18 4.76 11.57 22.17 36.52 55.08 78.90 111.38 149.37 193.92 244.35 298.90 355.56 412.80 470.71 528.61 587.28 617.81 660.58 718.53 776.78 836.66 896.78 - 955.87 1014.21 1073.60 MWD Magnetic 9 April, 2001 - 15:39 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for Nanuq # 3 Your Reh 5010320365 Job No. AKMM10074, - Surveyed: 14 March, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2718.02 39.870 270.060 2313.37 2355.37 2811.16 40.130 268.890 2384.72 2426.72 2902.17 39.730 268.040 2454.51 2496.51 2995.79 39.360 266.590 2526.70 2568.70 3089.67 39.450 267.980 2599.24 2641.24 3182.93 39.220 267.070 2671.38 2713.38 3276.08 40.100 266.510 2743.09 2785.09 3368.94 40.000 266.730 2814.17 2856.17 3461.38 39.840 267.640 2885.07 2927.07 3555.05 40.380 267.510 2956.71 2998.71 3647.48 40.500 267.490 3027.05 3069.05 3739.57 40.500 267.820 3097.08 3139.08 3832.76 40.540 267.560 3167.92 3209.92 3924.28 40.550 267.220 3237.47 3279.47 4018.63 40.980 267.170 3308.93 3350.93 4111.52 40.950 266.100 3379.07 3421.07 4200.65 39.780 266.980 3446.98 3488.98 4296.64 39.460 267.330 3520.92 3562.92 4390.90 39.160 266.450 3593.85 3635.85 4484.31 39.460 267.110 3666.13 3708.13 4574.76 39.060 266.140 3736.16 3778.16 4667.53 39.720 268.080 3807.86 3849.86 4761.17 39.730 268.090 3879.88 3921.88 4854.10 39.660 268.040 3951.38 3993.38 4947.36 39.740 267.640 4023.14 4065.14 5039.90 39.820 266.480 4094.26 4136.26 5132.62 39.480 267.710 4165.65 4207.65 5225.82 39.570 267.470 4237.54 4279.54 5317.42 39.590 266.690 4308.14 4350.14 5409.94 39.550 266.210 4379.46 4421.46 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 41.69 S 1131.69W 5957381.54 N 376536.83 E 42.24S 1191;55W 5957381.97 N 376476.97 E 43.80 S 1249.95W 5957381.35 N 376418.56 E 46.59 $ 1309.48W 5957379.53 N 376358.98 E 49.41S 1369.01W 5957377.68 N 376299.42 E 51.96 S 1428.07W 5957376.09 N 376240.33 E 55.30 S 1487.42W 5957373.73 N 376180.92 E 58.82 S 1547.07W 5957371.17 N 376121.23 E - 61.73 $ 1606.32W 5957369.22 N 376061.94 E 64.29 $ 1666.61W 5957367.65 N 376001.61 E 66.90 S 1726.51W 5957366.01N 375941.68 E 69.35 S 1786.27W 595736'4.54 N 375881.89 E 71.79 S '1846.76W 5957363.08 N 375821.36 E 74.50 $ 1906.'19W 5957361.34 N 375761.90 E 77.51S 1967.73W 5957359.33 N 375700.32 E 81.09 S 2028.52W 5957356.74 N 375639.48 E 84.58 S 2086.13W 5957354.19 N 375581.82 E 87.62 S 2147.27W 5957352.15 N 375520.64 E 90.85 S 2206.90W 5957349.88 N 375460.97 E 94.18 S 2265.98W 5957347.52 N 375401.84 E 97.54 S 2323.12W - 5957345.08 N 375344.65 E 100.51 S 2381.91W 5957343.08 N 375285.82 E 102.51 S 244!.72W 5957342.05 N 375225.98 E 104.51 $ 2501.04W 5957341.01N 375166.64 E' 106.75 S 2560.57W 5957339.74 N 375107.08 E 109.79 S 26i9.70W 5957337.66 N 375047.91E 112.79 S 2678.79W 5957335.62 N 374988.78 E 115.29 S 2738.05W 5957334.09 N 374929.49 E 118.26 S 2796.34W 5957332.07 N 374871.16 E 121.91S 2855.16W 5957329.38 N 374812.28 E Dogleg Rate (°/lOOfl) 0.59 0.85 0.74 1.06 0.94 0.67 1.02 0.19 0.65 0.58 0.13 0.23 0.19 0.24 0.46 0.76 1.46 -0.41 0.67 0.55 0.81 1.51 0.01 0.08 0.29 0.81 0.92 0.19 0.54 0.33 North Slope, Alaska EXPLORATION_NON-PAD Vertical Section Comment 1132.45 1192.29 1250.70 1310.30- 1369.89 1429.00 1488.45 1548.19 1607.50 1667.85 1727.80 1787.61 1848.16 1907.65 1969.25 2030.14 2087.85 2149.06 2208.76 2267.93 2325.16 2384.02 2443.87 2503.22 2562.79 2621.99 2681.15 2740.47 2798.82 .2857.75 9 April, 2001 - 15:39 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for Nanuq # 3 Your Reft 5010320365 Job No. AKMM10074,' Surveyed: 14 March, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Local Coordinates Depth Northings Eastings Northings (ft) (ft) (ft) (ft) 5502,64 39,620 267,430 4450,90 4492,90 5596,03 39,710 267,140 4522,79 4564,79 5688,59 39,730 267,740 4593,99 4635,99 5781,11 39,710 267,720 4665,15 4707,15 5874,42 39,720 267,530 4736,93 4778,93 5967,12 39,310 269,880 4808,45 4850,45 6060,10 39,010 269,540 4880,54 4922,54 6151,17 38,760 269,620 4951,43 4993,43 6246,21 38,650 269,270 5025,60 5067,60 6339,24 37,260 269,570 5098,95 5140,95 6432.43 36.090 269.830 5173.69 5215.69 6525.38 34.950 269.360 5249.34 5291.34 6618.43 33.690 269.100 5326.19 5368.19 6712.00 31.570 268.070 5404.99 5446.99 6803.84 29.210 268.930 5484.21 5526.21 6896,51 27,110 269,990 5565,90 5607,90 6989,61 25,450 270,190 5649,38 5691,38 7082,07 24,530 270,740 5733,18 5775,18 7175,15 24,060 271,790 5818,02 5860,02 7268,71 23,600 272,340 5903,60 5945,60 7361,09 22,970 271,560 5988,46 6030,46 7454,51 23,220 271,520 6074,39 6116,39 7544,26 23,690 272,540 6156,72 6198,72 7640,25 24,840 272,440 6244,23 6286,23 7732,85 24,970 273,010 6328,22 6370,22 7825,10 24,530 272,570 6412,00 6454,00 7918,51 24,300 272,920 6497,05 6539,05 8011,52 24,070 272,680 6581,90 6623,90 8103,29 23,730 272,290 6665,80 6707,80 8196,48 23,580 272,000 6751,16 6793,16 Global Coordinates Eastings (ft) 125.19 S 2914.14W 5957327.06 N 374753.26 E 128.01S 2973.68W 5957325.21 N 374693.68 E 130.65 S 3032.77W 5957323.53 N 374634.56 E 132.99 S 3091.85W 5957322.15 N 374575.45 E 135.46 S 3151.42W 5957320.65 N 374515.84 E 136.80 S 3210.38W 5957320.27 N 374456.87 E 137.10 S 3269.09W 5957320.93 N 374398.16 E 137.52 S 3326.26W 5957321.44 N 374340.99 E 138.09 $ 3385.69W 5957321.83 N 374281.56 E 138.67 S 3442.90W 5957322.18 N 374224.35 E 138,97 S 139,35 S 140,05 S 141,28 S 142,51S 142,94 S 142,87 S 142,56 S 141,72 S 140,36 S 139.11S 138.13 S - 136.86 S 135.15 S 133.29 S 131,41S 129,56 S 127,70 S 126,09 S 124,69 S. 3498.56W 5957322.79 N 374168.69 E 3552.56W 5957323.29 N 374114.69 E 3605.01W 5957323.44 N 374062.23 E 3655.45W 5957323.03 N 374011.79 E 3701.89W 5957322.56 N 373965.33 E . 3745.62W 5957322.84 N 373921.60 E 3786.84W 5957323.58 N 373880.39 E 3825.90W 5957324.53 N 373841.34 E 3864.18W 5957325.99 N 373803.07 E 3901.96W 5957327.97 N 373765.33 E 3938.45W 5957329.81N 373728.86 E 3975.08W 5957331.39 N 373692.25 E 4010.78W 5957333.24 N 373656.57 E 4050.19W 5957335.59 N 373617.19 E 4089.14W 5957338.08 N 373578.28 E 4127.72W 5957340.59 N 373539.74 E 4166.28W 5957343.06 N 373501.21E 4204.34W 5957345.54 N 373463.19 E 4241.49W 5957347.76 N 373426.07 E 4278.85W 5957349.77 N 373388.74 E Dogleg Rate (°/lOOfl) 0.84 0.22 0.41 0.03 0.13 1.67 0.40 0.28 0.26 1.51 1.27 1.26 1.36 2.34 2.61 2.33 1.79 1.03 0.69 0.55 0.76 0.27 0.69 1.20 0.29 0,52 0,29 0,27 0,41 0,20 North Slope, Alaska EXPLORATION_NON-PAD . . Vertical Section Comment 2916.81 2976.42 3035.56 3094.69 3154.31 3213.27 3271.96 3329.10 3388.50 3445.69 3501.32 3555.29 3607.73 3658.18- 3704.63 3748.34 3789.53 3828.54 3866.76 39O4.46 3940.87 3977.44 4013.06 4052.37 '4091.22 4129,69 4168,15 - 4206,11 4243,16 4280;44 9 April, 2001 - 15:39 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for Nanuq # 3 - Your Reh 5010320365 Job No. AKMM10074, Surveyed: 14 March, 2001 ..0 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates ' Global Coordinates Northings Eastings North!ngs Eastings (ft) (ft) (ft) (ft) 8289.60 23.270 271.430 6836.61 6878.61 123.58 S 4315.85 W 5957351.48 N 373351.76 E 8382.32 22.760 271.790 6921.94 6963.94 122.56 S 4352:09 W 5957353.09 N 373315.54 E 8439.78 22.270 271.820 6975.03 7017.03 121.87 $ 4374.08 W 5957354.14 N 373293.56 E 8565.79 22.180 271.550 7091.67 7133.67 120.47 S 4421.73 W 5957356.31 N 373245.95 E 8660.52 21.580 271.010 7179.58 7221.58 119.68 S 4457.02 W 5957357.68 N 373210.67 E 8753.48 20.530 272.090 7266.33 7308.33 .118.78 S 4490.40W -5957359.12 N 373177.31E 8844.90 19.900 272.350 7352.12 7394.12 117.56 S 4521.97W 5957360.85 N 373145.77 E 8938.48 19.810 271.880 7440.14 7482.14 116.38 S 4553.73W 5957362.54 N 373114.03 E 9027.51 19.340 272.160 7524.02 7566.02 115.33 S 4583.54W 5957364.08 N 373084.24 E 9112.00 19.340 272.160 7603.74 7645.74 114.28 $ 4611.50W 5957365.59 N 373056.30 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.429° (28-Feb-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 267.7~40° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9112.00ft., The Bottom Hole Displacement is 4612.92ft., in the Direction of 268.580° (True). Dogleg Rate (°/lOOft) 0.41 0.57 0.85 0.11 0.67 1.20 0.70 0.20 0.54 0.00 North Slope, Alaska EXPLORATION_NON-PAD Vertical Section -Comment 4317.37 4353.54 4375.49 4423.04 4458.27 4491.59 4523.09 4554.78 4584.52 4612.42 Projected Survey 9 April, 2001 - 15:39 Page 5 of 6 DrillQUest 2.00.08.005 Sperry-Sun Drilling. Services Survey Report for Nanuq # 3 Your Reft 5010320365 Job No. AKMM10074,' Surveyed: 14 March, 2001 Kuparuk River Unit North Slope, Alaska EXPLORATION_NON-PAD Comments Measured Depth (ft) 9112.00 Station Coordinates TVD Northings Eastings (~t) (~t) (~t) 7645.74 114.28 S 4611.50 W Comment Projected Survey Survey tool program for Nanuq # 3 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 9112.00 Vertical Depth (ft) 7645.74 Survey Tool Description MWD Magnetic 9 April, 2001 - 15:39 Page 6 of 6 DrillQuest 2.00.08.005 TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO1486 TO: Phillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Nanuq 3 DATE: 05/02/2001 Lisa Weepie AOGCC 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Transmitted herewith is the following: Nanuq 3 501032036500 2ol- o Z~ CD ROM D/g/tal dat~, , ' Core Labs Color core photos; slabbed core-natural and U.V. light 8522-8569'md Log Pdn~ (2 blueline$ and I .~e~ia each) v/'Sperry Sun BAT/GR;'M~ and 'I'VD 2"&5"= 100' · v/Sperry Sun EWR/DGR; ~D and 'r~D 2"&5"=10ft v/Sperry Sun DGR/CNP/SLD; IVl/D and 'r~'D 2"& 5"=100' Report and illustraEon$ "ore Labs Color core photos ".__~perry Sun directional 'survey printout v III Oaks core gamma ray log' *CDROM digital Version forthcoming. Problem with Iithology text descriptions on test CD Please check off each item as received, sign and return transmittal to address 'below All data'to be held confidential until State of Alaska designated release date (AOGCC) Approx 4/2003 cC: Dave Bannan, PA1 Geologist Approved for transmittal by: D, Bannan. Receipt: '~ {._,_ ,.._',,,2 Return receipt to: Phillips Alaska, Inc. AI'FN-, S. Lemke, ATO-1486 700 G. Street Anchorage, AK 9950! RECEIVED' HAY 10 2001 AlmlaOil& Gas Coas.~ Prepared by: Sandra .D, Lemke Phillips Alaska 1-r Technical Databases PHILLIPS PETROLEUM NANUQ NO. 3 PHILLIPS PETROLEUM WELL: NANUQ # 3 PHILLIPS PETROLEUM WELL: NANUC, LLiPS PETROLEUM WELL: NANUQ :/ Colville River Field Nanuq #3 Operations Shutdown Final Schematic 5/4/01 RKB - GL = 43' Wellhead 16" Conductor to 117' 9-5/8" x 7" annulus freeze protected with 55 bbl diesel to appmx, 1950' MD TOC @ +/-4300' MD (500' MD above top K2) 9-5/8" 40 ppf L-80 BTC Surface Casing @ 1965' MD / 1781' TVD cemented to surface Completion Tubing Supended with diesel to 2290' MD Tubing Hanger plus 3-1/2", 9.3#/ft, Tubing to 2290' MD Top K2 sand at 4830' MD Bottom K2 sand at 5170' MD Stage Tool set @ 5286' MD Top of cement plug @ ..--~~5155' MD 37.8 bbls of 15.8 PPG. Class G cmt w/additives Assume 50% excess annular volume. TOC @ +/-6500' MD (600' MD above 7' RMLS Assy) Top Nanuq Reservoir at 7530' MD Top Kuparuk Reservoir at 8543' MD 7" RMLS Latch Assembly @ 6985' MD 7" RMLS Latch Assembly @ 8011' MD Well TD at 9112' MD 17645' TVD (+/- 19 deg inc.) 7" 26 ppf L-80 BTC Mod Production Casing @ 9092' MD / 7626' TVD @ 19 deg PETROLEUlq SERVICES Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 907-349-3541 Date: Well Name: Number of Samples: Contact: Description of Material: Depths: 3/29/01 Phillips Alaska Inc. Nanuq # 3 Dave Barman Phillips Petroleum Core Chip Samples 8522-8569 Alaska Oil & Gas Conservation Commission 333 W. 7th #100 Anchorage, Alaska 99501 907-279-1433 Sent By: Received By: Tim Lawlor Core Laboratories RECEIVED MAR 2 9 Alaska Oil & Gas Cons. Commission Anchorage RECEIVED Alaska Oil & Gas Cons. Commission Anchorage TRANSMITTAL TO: AOGCC 3001 Porcupine Dr. Anchorage, AK 99501 OPERATOR: PA[ SAMPLE TYPE: DRIES SAMPLES SENT: DATE: 20 MARCH 01 AIRBILL: N/A ABV#: ABV 01-03-20-06 CHARGE CODE#: ASD005 WELL: NANUQ #3 NUMBER OF BOXES: 1 Bundle (7boxes) NANUQ #3 147-9112 SENT BY: Mike McCracken UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: RECEIVED BY: Phillips Alaska, Inc. 619 E. Ship Creek Ave Anchorage, AK. 99510 Attn: Dan Przywojski DATE: PHILLI 'S Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Tom Brassfleld Phone (907) 265-6377 Fax: (907) 265-6224 Email: tbrassi}ppco.com March 15, 2001 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Sundry Application for Nanuq #3 Operations Shutdown Surface Location: Target Location: BHL: 2268' FSL, 574' FEL, Sec. 24, T11N, R4E, UM or ASP4, NAD 27 coordinates of X=377,669 & Y=5,957,405 2154' FSL, 288' FWL, Sec. 24, T11N, 'R4E, UM 2149' FSL, 5' FEL, Sec. 23, T11N, R4E, UM CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby submits the attached sundry for an Operations Shutdown of the Nanuq #3 well which is located approximately 4 miles to the south of the Alpine facilities. This action has been discussed with AOGCC personnel and should be completed by 3/17/01. The wellbore is being evaluated for future development in the Alpine area and the final disposition will be discussed with the AOGCC. If you have any questions or require any further information, please contact me at 265-6120 or Tom Brassfield at 265-6377. Sincerely, Chip Alvord Alpine DrillingTeam Leader ORIGINAL RECEIVED MAR 1 $ ZOO1 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS CONFIDENTIAL 1. Type of Request: Abandon __ Suspend _ Alter casing _ Repair well _ Change approved program __ Operation Shutdown X Re-enter suspended well _ Plugging__ Time extension _ Stimulate_ Pull tubing_ Variance__ Perforate__ Other 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory X Stratigraphic __ Service 4. Location of well at surface: ASP NAD27 Coordinates X=377,669 & Y=5,957,405 2268' FSL, 574' FEL, Sec. 24, T11 N, R4E, UM At top of productive interval 2154' FSL, 288' FWL, Sec. 24, T11N, R4E, UM At effective depth At total depth 2149' FSL, 5' FEL, Sec. 23, T11N, R4E, UM 6. Datum elevation (DF or KB) 28' RKB, Pad 15' Unit or Property name Colville River Unit 8. Well number Nanuq #3 9. Permit number 201-026 10. APl number 50-103-20365-00 11. Field/Pool N/A feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 113' Surface 1937' Intermediate na Production 9084'approx 9112 feet 7645 feet 9022 est. PBTD feet 7555 est. PBTD feet Size Cemented Measured depth True vertical depth 320 sx AS1 141' 141' 360 sx AS Lite & 1965' 1781' 350 sx Class G 460 sx Class G + 9112'approx 7645'approx 200 sx Class G .... 16" 9.625" Perforation depth: NONE Tubing (size, grade, and measured depth) Tubing tail to be left at 2200' MD with BPV in Tree Packers and SSSV (type and measured depth) 13. Attachments Description summary of proposal X Detailed operation program __ BOP sketch _ Contact Chip Alvord at 265-6120 with any questions. LOT test, surface cement details and casing detail sheets _ 14. Estimated date for commencing operation 3/15/01 16. If proposal was verbally approved Name of approver Tom Maunder Date approved 3/15/01 15. Status of well classification as: Oil Gas__ Suspended X Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,,~~,_ ~. ~ Title Alpinr Drilling Team Leader Chip Alvord at 265-6120 Date FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clea. r.anc,..~__~ Mechanical Integrity Test Subsequertt f. o0zi .r.e.q.uire ..10~ -- (JHIL~INAL SJGI\~' '," Approved by the order of the Commission D Taylor See,rno~,,('~, Form 10-403 Rev 06/15/88 .,~ C _.ca, mjb_' _ioner IApPm.~aLN, o.,, SUBMIT ~ ~RI(=LIC~ATE MAR i $ 2:001 Alaska Oil & Gas Cons. Commission Anchoraae Nanuq #3 Operations ShutdownS' CONFIDENTIAL Revised 3/15/01 PURPOSE: Phillips Alaska, Inc. has decided to request an Operations Shutdown to secure the Nanuq #3 wellbore for future Alpine development consideration. The proposed program is as follows: Notify AOGCC 24 hours in advance of all pressure testing and well suspension operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. . Run and cement 7" casing to TD at 9112' MD. The first stage job will have a calculated top of cement at 6500' MD or approx. 1030' above the top of the Nanuq interval at 7530' MD. A second stage cement job will be performed thru a DV Stage tool at 5400' to cover the K-2 interval from 5170' to 4830'. Calculated top of cement will be approx. 4300' MD. See attached schematic. 2. RIH with 3-1/2" tubing to 2200' and land in the wellhead. Pressure test casing to 1500 psi. 3. Freeze protect tubing and 3-1/2" x 7" annulus with diesel. Kill weight mud (9.8 ppg) will be left in the casing above and below the DV stage tool. 4. Install BPV. Nipple down stack, nipple-up tree. Pull BPV. Install test plug. Test tree to 250 and 5000 psi. Pull test plug. 5. RU to 9-5/8" x 7" annulus and bullhead approx. 55 bbls diesel to 1965'. . Set BPV in tree. Close all valves and remove handles. Install flanges with ~" plugs screwed into the flanges on all outer valves and a bull plug with ½" plug in the annulus valve on the wellhead. Release rig. · Risks: A spill could result if vandalism occurred during the Operations Shutdown. · Level: Low · Mitigation: All flanges will be blanked with plugs. 7. Clean-up cellar and location to prepare for inspections and Summer Operations Shutdown. 8. Hang sign on tree with the following information: Phillips ALASKA, INC Nanuq #3 PTD # 201-026 APl # 50-103-20365-00 SHL: 2268' FSL, 574' FEL, Sec. 24, T11N, R4E, UM TJB 3/15/01 FILE: Nanuq #3 TJB 3/15/01 RECEIVED MAR 1 6 2001 Alaska Oil & Gas Cons. Commissior~ Anchorage Colville River Field Nanuq #3 Operations Shutdown Updated 03/15/01 RKB - GL = 43' Wellhead 16" Conductor to 117' TOC @ +/-4300' MD (500' MD above top K2) 9-5/8" 40 ppf L-80 BTC Surface Casing @ 1965' MD / 1781' TVD cemented to surface Completion Tubinc~ Su~)ended with diesel to 2200' MD Tubing Hanger plus 3-1/2", 9.3#/ft, Tubing to 2200' MD Top K2 sand at 4830' MD Bottom K2 sand at 517O' MD Stage Tool set @ 5400' MD Top of cement plug @ .~--~ 5269' MD 43 bbls of 15.8 PPG. Class G cmt w/additives Assume 50% excess annular volume. TOC @ +/-6500' MD (600' MD above 7" RMLS Assy) Top Nanuq Reservoir at 7530' MD Top Kuparuk Reservoir at 8543' MD Well TD at 9112' MD /7645' TVD (+/- 19 deg inc.) 7" RMLS Latch Assembly @ 7100' MD 7" RMLS Latch Assembly @ 8100' MD RECEIVED MAR 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage 7" 26 ppf L-80 BTC Mod Production Casing @ 9112' MD / 7645' TVD @ 19 deg ORIGINAL Nanuk #3 Well Lon~ ;ng Cement loads and CemCADE* ~- Use 50% excess. Drilled with 8 1/2" bit. 7", 26 #casing TMD 9278'. 2 Stage Design, Stage Collar @ 5400' MD Base of permafrost at 767' TVD. nmary. S~__.~gg~l: TOC@ 6500' MD (600' over the RMLS Latch Assy @ 7100' MD) Volume Calcs: Pump 20 bbls CW100 Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 9278' MD to 6500' with Class G + adds @ 15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, DS00, D047, D065, per lab testing Thickening Time 4 hfs at BHCT. 7", 26g x 8 1/2" OH: (9278'-6500') x 0.1268 ft3/ft x 1.50 (50% excess) = 528.4 ft3 Shoe Joint: (80') x 0.2148 ft3/ft = 17.2 ft3 Total Volume = 545.6 ft3. 545.6 ft3 / 1.2 ft3/sk = 455 sks - Round up to 460 sks BHST = 176 deg F CemCADE* Summary,: Fluid sequence: Establish circulation using FW, 20 bbl CW100 Preflush, Drop Bottom Plug. Pump 30 bbls 12.0 ppg MudPUSH XL Spacer, 450 sks Class G + adds (98 bbls). Drop Top Plug. Displacement is approximately 352 bbls. Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formations. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Sta~e 2: TOC@ 4300' MD (500' above K.2 Fm.). Stage Collar @ 5400' MD. Leave 5 BBL cement on top of closing plug. Volume Calcs: Pump 20 bbls CW100 Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 4300' MD to 5400' with Class G + adds @ 15.8 ppg. Leave 5 BBL cement on top of closing Plug. Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, DS00, D047, D065, per lab testing Thickening Time 4 b. rs at BHCT. 7", 20g x 8 1/2" OH: (5400'-4300') x 0.1268 ft3/ft x 1.50 (50% excess) = 209.2 ft3 5 BBL on top of Plug = 28.1 ft3 Total Volume = 237.3 ft3. 237.3 ft3 / 1.2 ft3/sk = 197.8 sks - Round up to 200 sim BHST = 103 deg F .CemCADE* Summary,: Fluid sequence: Establish circulation using FW, 20 bbl CW100 Preflush. Pump 30 bbls 12.0 ppg MudPUSH XL Spacer, 140 sics Class G + adds (43 bbls). Drop Top Plug. Pump 5 BBL Cement on top of plug followed by at least 5 BBL water Spacer Displace and close stage tool. Centralizers: Recommend using at least 1 per joint across the zones of interest and also 500' ablRE E VED the zones of interest to maximize primary success. Recommended Conditioned Mud Properties~: 10.4 ppg, Pv = 15 or under, Ty = 15 or under. MAR 1 6 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Nanuq #3 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 117/117 12.9 54 66 9 5/8 1978 / 1792 12.9 830 1023 8-1/2 hole 9278 / 7792 16.6 3607 2828 · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATFD SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP-(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(12.9 x 0.052) -0.1] x 117 = 66 psi OR ASP = FPP - (0.1 x D) = 830 - (0.1 x 1792') = 651 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1) D = [(12.9 x 0.052) - 0.1] x 1792 = 1023 psi OR ASP = FPP - (0.1 x D) = 3607- (0.1 x 7792) = 2828 psi ALASKA OIL AND GAS CONSERVATION COH~IlSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Exploration/Cook Inlet Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Colville River Unit Nanuq #3 Exploratory Phillips Alaska, Inc. Permit No: 201-026 Sur. Loc. 2268'FSL, 574'FEL, Sec. 24, T11N, R4E, UM Btmhole Loc. 2149'FSL, 5' FEL, Sec. 23, T11N, R4E, UM Dear Mr. Mazzolini: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in surface-hole location. The provisions of the original approved permit dated February 13, 2001, are in effect for this revision. tDaniel T. seamount, .Ir. Commissioner BY ORDER OF THE COMMISSION DATED this 2 '7 'Y-< day of February, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o enel'. Department of Environmental Conservation w/o encl. FW: [Fwd: Nanuq #3 Location Change] Subject: FW: [Fwd: Nanuq #3 Location Change] Date: Fri, 23 Feb 2001 11:05:58 -0900 From: "Steve Schmitz" <ss~dnr. state.ak.us> Reply-To: <Steve_Schmitz~dnr. state.ak.us> To: "Steve Davies" <Steve_Davies~admin.state.ak.us> Steve FYI, PAI has changed the surface location of the NANUQ $ 3 well. Steve S ..... Original Message ..... From: Jackie Timothy [mailto:Jackie Timothy@gov.state.ak.us] Sent: Tuesday, February 20, 2001 12:23 PM To: Kirsten K Ballard; Brian T Renninger; Jack F Winters JR; Kellie M Westphal; Steve Schmitz; Matthew W Rader; Robert P Crandall; James R Baumgartner Cc: Glenn T Gray; Jackie L Timothy; Mark Major; Lisa Pekich Subject: [Fwd: Nanuq #3 Location Change] Hi Reviewers (and PAI) - Do any of you have any objection to this move (Nanuq 93 Oil and Gas Exploration Wells, STATE I.D. NO. AK 0011-05OG)? As far as I can tell, it does not conflict with the project description as written in the final CD (except for possibly ice road length). However, I cannot open two of the documents to check maps (.tif extension). Please check and make a determination if uses and resources will be further impacted by the movement of the Nanuq 93 site (e.g. waterbodies affected, water use changed, extra stream crossings, ice road length changed, exclusion zone impacted, response capabilities reduced, etc.). Also - Mark, will you send me the maps in a different format or tell me how to open them. If anyone else is having a problem opening the documents, please let me know. Thanks. . .Jackie Original Message Subject: Nanuq 93 Location Change Date: Mon, 19 Feb 2001 13:56:57 -1000 From: "Mark A Major" <mmajor@ppco.com> To: Jackie_Timothy@gov.state..ak.us CC: JBaumgar@envircon.state.ak.us, kirsten ballard@envircon.state.ak.us,hbcf@micronet.net, Lchinn@aol.com, "Donnelly&Manson" <nl508@ppco.com>,"NSK Expl Env" <n1662@ppco.com>, jeanne.hanson@noaa.gov, chrism@dnr.state.ak.us, isaacnukapigak@aol.com, logar@envircon.state.ak.us, mwr@dnr.state.ak.us,rockwell.theodore@epamail.epa.gov, ss@dnr.state.ak.us,RWatkins@envircon.state.ak.us, kelliew@dnr.state.ak.us,AOtt@fishgame.state.ak.us, jack winters@fishgame.state.ak.us Hi Jackie, Attached FYI are electronic copies of what is being mailed out to you and others tomorrow. The attacments are self explanatory. Bottom Line: Nanuq 93 is being moved about 500 feet due to construction difficulties at the original site. If you have any ???, please advise. Thanks! Mark Major 265-6136 1 of 2 2/23/01 5:24 PM FW: [Fwd: Nanuq #3 Location Change] (See attached file: 2-19-01 DGC-Nanuq %3 Location Change.doc)(See attached file: 2-19-01 Nan3AS.tif)(See attached file: 2-19-01 Nan3area.tif) ~_~2-19-01 DGC-Nanuq.d~t t Ty~: unspecified type (application/octet-stream)t 1Encoding' base64 [-.~2-19-01 Nan3AS.tif Name: 2-19-01 Nan3AS.tif Type: TIFF Image (image/tiff) Encoding: base64 i Name: 2-19-01 Nan3area.tif [-.~2-19-01 Nan3area.tif] Type: TIFF Image (image/tiff) Encoding' base64 2 of 2 2/23/01 5:24 PM Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 PI- _LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY February 21, 2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: RECEIVED FEB 2 2 2001 Alaska 0il & Gas Cons. Commission Anchorage Application for Permit to Drill Phillips Alaska, Inc. - Nanuq #3 Surface Location: 2268' FSL, 574' FEL, SEC 24, T11N, R4E Target Location: 2145' FSL, 288' FWL, SEC 24, T11N, R4E Bottom Hole Location: 2149' FSL, 5' FEL, SEC 23, T11N, R4E CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine satellite delineation well; the Nanuq #3 (Revised Surface Hole Location), with spud scheduled for February 27tr~ 2001. Nanuq #3 will be drilled from a 500' x 500' ice pad located approximately 3.8 miles South by Southwest of Alpine. The well is designed to penetrate through the Nanuq, Kuparuk, and Alpine sandstone horizons. At the conclusion of drilling and evaluation operations, Nanuq #3 will either be temporarily suspended or plugged and abandoned (P&A'd). The temporarily suspended Nanuq #3 will await the possible development of an Alpine satellite pad at its location. Before suspension operations commence, an Application for Sundry Approvals (Form 10-403) will be submitted in accordance with 20 AAC 25.110 (b). Nanuq #3 will be P&A'd at the conclusion of drilling operations or at a future date if development of this pad does not go forward. Before P&A operations commence an Application for Sundry Approvals (Form 10-403) will be submitted in accordance with 20 AAC 25.105(e). There will be a temporary storage area for drill cuttings on the ice pad. All cuttings will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Waste drilling mud will be hauled to an Alpine Class II disposal well or to a KRU Class II disposal well. There are no shallow hazards expected at Nanuq #3. For the Shallow Hazards Analysis, the local compaction trend and the translation trend model were applied to velocities from 3D seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well locations.. See discussion under "Drilling Area Risks" and the attached Shallow Hazards Analysis. Please note that Phillips does not anticipate the Presence of H2S in the formations to be encountered in this well; however, there will be H2S monitoring equipment operating, as is the usual practice while drilling wells in the Colville River Unit. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following · . . 5. 6. 7. . 9. 10. 11. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Well schematic depicting the well suspension plan. Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Pressure information as required by 20 ACC 25.035 (d)(2). Prediction of overpressured strata as required by 20 ACC 25.033 (e). Seismic refraction and reflection analysis as required by 20 ACC 25.061 (a) Nanuq #3 Drilling Hazards Summary for Posting in Doghouse Information pertinent to this application that is presently on file at the AOGCC is: . . Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). A description of the drilling fluids handling system. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. SiDc-,e,rely, ~ Scott D. Reynolds Drilling Engineer Attachments CC: Nanuq #3 Well File / Sharon AIIsup Drake Chip Alvord Eric Reinbold ATe 1530 ATe 868 ATe 856 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb. Type of Well . Exploratory X Stratigraphic Test Development Oil Re-Entry Deepen! Service Development Gas Single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool PHILLIPS Alaska, Inc. DF 50.6' feet 3. Address 6. Property Designation N/A P. O. Box 100360, Anchora~le, AK 99510-0360 ADL 380077 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2268' FSL, 574' FEL, SEC 24, T11 N, R4E Colville River Unit Statewide At target (=KUP LCU ) 8. Well number Number 2154' FSL, 288' FWL, Sec. 24, T11N, R4E NanucI #3 59-52-180 At total depth (7" casing point) 9. Approximate spud date Amount 2149' FSL, 5' FEL, SEC 23, T11N, R4E 2/27/00 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'R/D) Property line 2154 ' 2149 9278' MD 7792' TVD from ADL384209 Nanuq #2 is 4000' feet Feet feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.0&5(e)(2)) Kickoff depth 300' feet Maximum hole angle 39.87° Ma~mum surface 2828 pslg At total depth (3VD) 3607 18. Casing program Settin g Depth size specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~e data) 20" 16" 62.5# H-40 Weld 80' 37' 37' 117' 117' +/- 200cf 12.25" 9,625" 40# L-80 BTC 1941' 37' 37' 1978' 1792' 417 Sx Arcticset III L & 274 Sx Class G 8.5" 7" 26# L-80 BTC-M 9241' 37' 37' 9278' 7792' 366 Sx Class G N/A 3.5' 9.3# L-80 8rd-Mod 2454' 32' 32' 2486' 2182' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size REC f D Measured depth True Vertical depth Conductor Surface Intermediate ProductionF E B 2 2 ? 0 01 Liner Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~' ~ Title Drillin,~ Team Leader Date ,~ Commission Use Only Permit Number _ I Approval date ,e .... I See cover letter for z - o z I _ 0 $ I ,"J- I ;-'l ' O! I Other requirements Conditions of approval Samples required No I~t~d Icg r~:luired /~ No ~ Directional survey required ' ~ No Hydrogen sulfide measures Yes Required working pressure for BOPEI,,,,/2M 3M 10M 15M Other: -~ -- ~/~~ by erder of~[ ~,~ / Approved ..... Commissioner , the commission Date O __, _.~ ~, Form 10-401 R~ Submit in triplicate Nanuq #3 Summary Drillinq Procedure , . , . . o . o . 10. 11. 12. 13. 14. 15. Install diverter on pre-installed 16" conductor. Move in and rig up Doyon 141. Function test diverter. Spud and directionally drill 12 1/4 inch hole to the 9-5/8" surface casing point (1978' MD / 1792' TVD) per the directional plan. Run MWD/LWD logging tools as required for directional monitoring and for gathering formation data. Run and cement 9 5/8", 40#, L-80, BTC casing string to surface. Install and test BOPE to.,380'~ psi. '~'~ Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe pr 20 ACC 25.030 (0.5 ppg less than the FIT or LOT EMW) Drill 8-1/2" hole to Coring point above the Kuparuk sands (8530' MD / 7105' TVD). POOH and PU coring BHA. RIH to coring point and core 60' of hole through the Kuparuk sands to (8590' MD / 7160' TVD). POOH and LD cores and coring BHA. PU drilling BHA and RIH to 8530' MD. Ream hole to 8590' MD. Continue to directionally drill 8-1/2" hole to TD @ 9278' MD / 7792' TVD per the directional plan. Run and cement 7 inch casing as per program. Displace with kill weight Brine. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing x casing annulus. Run +/- 2500' of 3-1/2" tubing. Land in hanger and test seals to 5,000 psi. Freeze protect tubing and annulus to +/-2,500' MD. Install 2-way check, nipple up tree and secure wellhead. Rig down and move off Doyon 141. Well Proximity Risks: There are no well proximity risks associated with Nanuq #3. Drillinq Area Risks: With the close proximity of Alpine to Nanuq #3 (approximately 3.4 miles to the northwest), and with the conclusion of development drilling on Alpine's CD1 pad, A wealth of knowledge in local formation properties has been gained. No shallow hazards were evident during the development drilling on CD1 Pad at Alpine. The mud weights outlined in the "Drilling Fluid Program" for Nanuq #3 will be consistent with the mud weights used to drill the Pilot Hole on well CD1-NQ1 where no pressure anomalies or lost circulation was encountered. The pilot hole on CD1-NQ1 targeted the same Nanuq, Kuparuk, and Alpine horizons as the Nanuq #3 well plan targets. Examination of the drilling and testing data from offset wells Nanuq #1 and #2 suggest no shallow hazards are present. Pressure data from the RFT's indicates a formation pressure gradient of approximately 0.444 psi/ft. A 9.2 ppg mud is sufficient to provide a 232 psi overbalance margin for the Nanuq formation and a 150 psi overbalance for the Alpine formation. The planned mud weight of 9.8 ppg is more than adequate for drilling the reservoir sections; however, it is required for shale stabilization of the HRZ. The surface locations of Nanuq #1 and #2 are within 5,000' of the surface location of Nanuq #3. The seismic shallow hazards analysis indicates no abnormal pressures or weak formations; particularly at shallow depths. See the attached "Shallow Hazards Analysis". Nanuq ~3 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" 9-5/8"surface casing casing point - 8 ~" point- 12 ¼" Density 8.8 - 9.6 ppg 9.8 - 10.5 ppg PV 16 - 26 10 - 25 YP 20 - 60 15 - 25 Funnel Viscosity 80 - 300 30 - 40 Initial Gels 40 - 90 4 - 8 10 minute gels 90 - 115 <18 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) PH 8.5 - 9.0 9 - 10 % Solids _+ 10% 4 - 7% Surface Hole: RECEIVED 2001 Alaska Oil 8, Gas Cons. Commission Anchorage A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep .flowli.n. e viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.8 ppg. If connection gas is encountered weight up mud one to two tenths of a pound per gallon. Be prepared to add loss circulation material if loss zones are encountered. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. CASING PROPERTIES. Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3090 psi 2.626 osi 5,750 psi 4.887 ~3si 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 ;)si 7,240 psi 6.154 Wt Connection TENSILE STRENGTH OD ,(ppf)Grade Range Type JOINT BODY 9-5/8"40 L-80 3 BTC 727k lbs. 916k lbs 7" 26 L-80 3 BTC-Mod 364k lbs 415k lbs Casing Setting Depth Rational 16" - 117' RKB 9-5/8"- 1792 TVD' RKB 7"- 7792 TVD' RKB Conductor Casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to the next casing setting point. Production Casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if there is not an upside potential indicating a well test should be carried out. Colville River Field Nanuq Suspension Completion Plan( Updated 02/22/01 Wellhead 16" Conductor to 117' 9-5/8" 40 ppf L-80 BTC Surface Casing 1978' MD / 1792' TVD cemented to surface Tubin(] Suoended with diesel to 2200' TVD TOC {} +/-4454' M D (500' MD above top K2) Com.DletjQn MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing WEG (+/- 62 deg) 2486 2182' Top K2 sand at 4954' MD / 4076' TVD Bottom K2 sand at 5063' MD / 4176' Stage Tool set {~ 5163' MD / 4268' TVD Top of cement plug .~.-------"'- 5032' MD 31 bbls of 15.8 PPG. Class G cmt w/additives Assume 88% excess annular volume, TOC ¢~ +/- 7005' M D (500' MD above top Nanuk) Top Nanuq Reservoir at 7505 MD / 6164' TVD 7" RMLS Latch Assembly {} 7300' MD Top Kuparuk Reservoir at 8540' MD / 7114' TVD Well TD at 9278' MD / 7792' TVD (+1- 23.37 deg inc.) 7" 26 ppf L-80 BTC Mod Production Casing 0 9278' MD / 7792' TVD 0 23.37 deg NANUQ #3 Well Cementinq Requirements 9 5/8" Surface Casing run to 1978 MD / 1792' TVD. Cement from 1978' MD to 1478' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2329' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: 1478' X 0.3132 ft3/ft X 4 (300% excess) = 1851.6 ft3 above permafrost Total volume = 1851.6 ft~ => 417 Sx @ 4.44 ft3/sk System: 417 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant Tail slurry: (1978-1542) X~.3132 fts/ft X 1.5 (50% excess) = 204.8 fts below permafrost 64' X 0.3132 ft~/ft X 4 (300% excess) = 80.2 ft~ above permafrost 80' X 0.4341 fts/ft = 34.7 ft~ shoe joint volume Total volume = 204.8 ft3 + 80.2 ft3 + 34.7 fta = 319.7 ft~ => 274 Sx @ 1.17 ft~/sk System: 274 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft~/sk 7" Intermediate Casing run to 9278 MD/7792' TVD Cement from 9278' MD to +/- 7005' MD (minimum 500' MD above top of Nanuq formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9278'- 7005') X 0.1268 fta/ft X 1.4 (40% excess) = 403.5 fta annular volume 80' X 0.2148 ft3/ft = 17.2 ft~ shoe joint volume Total volume = 403.5 ft~ + 17.2 ftc= 420.7 ft~ => 366 Sx @ 1.15 ft~/sk System: 366 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft~/sk RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage ~ By Weight Of mix Water, all other additives are BWOCement Phillips Alaska, Inc. Structure: Nanuk #3 Field: Alpine Field Well: Nan$ Location: North Slope, Alaska Point KOP Permafrost EOC Base West Sak 9 5/8 Casing Pt K-10/C-40 K-5/C-30 K-3 K-2 Begin Drop/Turn Albian-97 / EOC Tgt- Nanuk Top HRZ Tgt- Kuparuk Tgt Horizon - Alpine 'Nuiqsut TD - Csq Pt PROFILE COMMENT DATA MD Inc Dir TVD North 300.00 0.00 267.74 300.00 0.00 766.63 14.00 267.74 762.00 -2.24 1629.15 59.87 267.74 1524.42 - 17.54 1652.05 59.87 267.74 1542.00 - 18.12 1977.80 59.87 267.74 1792.00 -26.36 2485.98 39.87 267.74 2182.00 -39.23 2759.61 39.87 267.74 2392.00 -46.16 4608.59 39.87 267.74 3811.00 -92.97 4953.88 39.87 267.74 4076.00 -101.71 6256.94 59.87 267.74 5076.03 - 154.70 7088.78 23.57 271.86 5782.00 -139.89 7504.90 23.37 271.86 6165.98 -134.55 8025.64 23.57 271.86 6642.00 - 127.81 8539.81 25.57 271.86 7115.99 -121.17 8892.78 25.57 271.86 7438.00 -116.62 9084.51 23.37 271.86 7614.00 -114.15 9278.41 23.37 271.86 7792.00 -111.64 East 0.00 -56.68 -443.79 -458.46 -667.14 -992.68 -1167.97 -2552.44 -2573.64 -3408.38 -3842.78 -4007.75 -4214.2O -4418.05 -4557.98 -4633.99 -4710.87 V. Sect 0.00 56.72 444.13 458.82 667.66 993.45 1168.88 2354.27 2575.64 3411.04 3845.30 4009.93 4215.96 4419.,58 4559.03 4634.89 4711.61 DegfllO0 0.00 5.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 55O 700 1050 1400 1750 2100 2450 ~ 280O ~.~ 3150 ~850 4200 I V 4900 525O 56OO 595O 630O 665O 7000 7~50 770O 8O5O f Phillips Alaska, Inc. R Structure : Nanuk #5 Well : Nan5 KB ELEVATION: 42' Field : Alpine Field Location : North Slope, Alaska ~'.oo 2~O?nn Tm. Ve~Eol De~hl om mfem~ R~ (~n 141). ss.oo 59.00 EOC Bese We~ S.k ....... g 5/8 C=slng ~ n-~o/c-4o g07.74 Azimuth ***~lone of ~roposol*** Albion-97 / EOC ~ 25.12 Renuq5 Tg~=nuk R~d 27-D~-00 ~ Top HRZ Tgi Horizon - ~pined Nenuk5 Tg~lpine ~sd 20-Mor-01 Nu~qeut ~ - Csg Pt i I i ....i t t t t i t t i i ! i t i I i J" 5100 i i i i i i i i 0 350 700 1050 1400 1750 2100 24-50 2800 3150 3 3850 4200 4550 4900 Vertical Section (feet) -) Azimuth 267.74 with reference 0.00 N, 0.00 E from slot #1 Data i~eltad: 21-Feb-2001 Caorolna~ am in f~t refermme clot ~1. rrue Varl~al D'Pflm are ~1~ (DoYon 141). 5250 5000 4750 4500 4250 4000 ~750 Phillips Alaska, Inc. Structure: Nanuk #5 Field: Alpine Field Well: Nan5 Location: North Slope, Alaska <- West (feet) ;~5O0 5250 3000 2750 2500 2250 2000 1750 1500 1250 1000 750 500 250 0 250 1250 1000 750 5OO 25O 0 25O 500 750 IOO0 1250 KUPAEUK LOCATION: 2145' FSL, 288' FWL SEC. 24, T11N, R4E ALPINE LOCATION: 2149' FSL, 148' FWL s~c. 2,~, T~N, ~-~{~ 271.86 Az NANUQ LOCATION: 2152' FSL, 699' FWL SEC. 24, T11N, R4E TD LOCATION: 2149' FSL, 5' FEL SEC. 23, T11N, E4E Estimated SURFACE LOCATION: 2268' FSL, 574' FEL SEC. 24, T11N, R4E 267.74 Az 267.74 Azimuth 471~' (TO TD) ***Plane of Proposal*** 5250 5000 4750 4500 4-250 4000 3750 3500 3250 3000 2750 2500 2250 2000 1750 1500 1250 1000 750 500 250 <- West (feet) 25O 1250 !000 750 5OO 7 0 250 -~ I V 750 1000 1250 5OO Phillips Alaska, Inc. Nanuk #3 Nan3 slot %1 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref : Nanuq %3 Version %10 Our ref : prop4062 License : Date printed : 21-Feb-2001 Date created : 18-Sep-2000 Last revised : 20-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 378205.97~,5955128.07~,999.00000,N Slot location is nT0 17 31.690,w150 59 25.~40 Slot Grid coordinates are N 5957404.593, E 377669.076 Slot local coordinates are 2267.71 N 573.75 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Nanuk #3,Nan3 Alplne Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : Nanuq #3 Version #10 Last revised : 20-Feb-2001 Measured inclin Azimuth True Vert R E C T A N G U L A R G R i D C O O R D S G E O G R A P H i C Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 0.00N 100.00 0.00 267.74 100.00 0.00N 200.00 0.00 267.74 200.00 0.00N 300.00 0.00 267.74 300.00 0.00N 400.00 3.00 267.74 399.95 0.10S 500.00 6.00 267.74 499.63 0.41S 600.00 9.00 267.74 598.77 0.93S 700.00 12.00 267.74 697.08 1.65S 766.63 14.00 267.74 762.00 2.24S 800.00 15.00 267.74 794.31 2.57S 900.00 18.00 267.74 890.18 3.69S 1000.00 21.00 267.74 984.43 5.01S 1100.00 24.00 267.74 1076.81 6.52S 1200.00 27.00 267.74 1167.06 8.22S 1300.00 30.00 267.74 1254.93 10.10S 1400.00 33.00 267.74 1340.18 12.17S 1500.00 36.00 267.74 1422.59 14.40S 1600.00 39.00 267.74 1501.91 16.81S 1629.15 39.87 267.74 1524.42 17.54S 1652.05 39.87 267.74 1542.00 18.12S 1977.80 39.87 267.74 1792.00 26.36S 2000.00 39.87 267.74 1809.04 26.93S 2485.98 39.87 267.74 2182.00 39.23S 2500.00 39.87 267.74 2192.76 39.58~ 2759.61 39.87 267.74 2392.00 46.16S 3000.00 39.87 267.74 2576.49 52.24S 3500.00 39.87 267.74 2960.21 64.90S 4000.00 39.87 267.74 3343.94 77.56S 4500.00 39.87 267.74 3727.67 90.22S 4608.59 39.87 267.74 3811.00 92.97S 4953.88 39.87 267.74 4076.00 101.71S 5000.00 39.87 267.74 4111.39 102.87S 5500.00 39.87 267.74 4495.12 115.53S 6000.00 39.87 267.74 4878.84 128.19S 6256.94 39.87 267.74 5076.03 134.70S 6300.00 39.02 267.87 5109.28 135.74S 6400.00 37.03 268.21 5188.06 137.85S 6500.00 35.04 268.58 5268.92 139.508 6600.00 33.05 268.99 5351.77 140.70S 6700.00 31.07 269.44 5436.52 141.43S 6800.00 29.08 269.95 5523.05 141.70S 6900.00 27.10 270.53 5611.26 141.51S 7000.00 25.12 271.19 5701.05 140.86S 7088.78 23.37 271.86 5782.00 139.89S 7500.00 23.37 271.86 6159.48 134.59S 7504.90 23.37 271.86 6163.98 134.53S 7504.92 23.37 271.86 6164.00 134.53S 8000.00 23.37 271.86 6618.46 128.14S 8025.64 23.37 271.86 6642.00 127.81S 8500.00 23.37 271.86 7077.44 121.69S C O O R D I N A T E S Easting Northing C O O R D I N A T E S 0.00E 377669.08 5957404.59 nT0 17 31.69 w150 59 25.44 0.00E 377669.08 5957404.59 n70 17 31.69 w150 59 25.44 0.00E 377669.08 5957404.59 n70 17 31.69 w150 59 25.44 0.00E 377669.08 5957404.59 n70 17 31.69 w150 59 25.44 2.62W 377666.46 5957404.53 n70 17 31.69 w150 59 25.52 10.45W 377658.62 5957404.35 n70 17 31.69 w150 59 25.74 23.50W 377645.57 5957404.05 n70 17 31.68 w150 59 26.12 41.70W 377627.36 5957403.62 n70 17 31.67 w150 59 26.66 56.68W 377612.37 5957403.27 nT0 17 31.67 w150 59 27.09 65.03W 377604.02 5957403.08 n70 17 31.66 w150 59 27.33 93.40W 377575.63 5957402.42 n70 17 31.65 w150 59 28.16 126.75W 377542.27 5957401.64 n70 17 31.64 w150 59 29.13 164.99W 377504.02 5957400.75 n70 17 31.63 w150 59 30.25 208.00W 377460.99 5957399.74 nT0 17 31.61 w150 59 31.50 255.67W 377413.29 5957398.63 n70 17 31.59 w150 59 32.89 307.88W 377361.07 5957397.42 nT0 17 31.57 w150 59 34.41 364.47W 377304.45 5957396.10 nT0 17 31.55 w150 59 36.06 425.29W 377243.61 5957394.68 n70 17 31.52 w150 59 37.83 443.79W 377225.10 5957394.25 n70 17 31.52 w150 59 38.37 458.46W 377210.42 5957393.90 n70 17 31.51 w150 59 38.80 667.14W 377001.65 5957389.04 nT0 17 31.43 w150 59 44.88 681.36W 376987.43 5957388.71 nT0 17 31.42 w150 59 45.30 992.68W 376675.97 5957381.45 nT0 17 31.30 w150 59 54.37 1001.66W 376666.99 5957381.24 n70 17 31.30 w150 59 54.63 1167.97W 376500.61 5957377.36 n70 17 31.23 w150 59 59.48 1321.97W 376346.55 5957373.77 n70 17 31.17 w151 0 03.96 1642.27W 376026.11 5957366.30 n70 17 31.05 w151 0 13.30 1962.57W 375705.67 5957358.83 nT0 17 30.92 w151 0 22.63 2282.88W 375385.23 5957351.37 n70 17 30.80 w151 0 31.97 2352.44W 375315.64 5957349.74 nT0 17 30.77 w151 0 33.99 2573.64W 375094.34 5957344.59 nT0 17 30.68 w151 0 40.44 2603.18W 375064.79 5957343.90 n70 17 30.67 w151 0 41.30 2923.48W 374744.35 5957336.43 n70 17 30.55 w151 0 50.63 3243.78W 374423.91 5957328.96 n70 17 30.42 w151 0 59.97 3408.38W 374259.24 5957325.12 nT0 17 30.36 w151 I 04.76 3435.72W 374231.89 5957324.52 nT0 17 30.34 w151 i 05.56 3497.28W 374170.32 5957323.41 n70 17 30.32 w151 I 07.35 3556.08W 374111.50 5957322.71 n70 17 30.31 w151 I 09.07 3612.05W 374055.52 5957322.42 nT0 17 30.29 w151 I 10.70 3665.12W 374002.45 5957322.55 n70 17 30.29 w151 i 12.25 3715.23W 373952.34 5957323.09 nT0 17 30.28 w151 I 13.71 3762.32W 373905.27 5957324.04 n70 17 30.29 w151 i 15.08 3806.33W 373861.28 5957325.41 n70 17 30.29 w151 i 16.36 3842.78W 373824.86 5957326.96 n70 17 30.30 w151 i 17.42 4005.81W 373661.95 5957334.90 n70 17 30.35 w151 i 22.17 4007.75W 373660.01 5957335.00 nT0 17 30.35 w151 i 22.23 4007.76W 373660.00 5957335.00 n70 17 30.35 w151 i 22.23 4204.03W 373463.87 5957344.56 nT0 17 30.42 w151 I 27.95 4214.20W 373453.71 5957345.06 n70 17 30.42 w151 I 28.25 4402.26W 373265.79 5957354.22 nT0 17 30.48 w151 i 33.73 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Doyon 141) (42.00 Ft above mean sea level). Bottom hole distance is 4712.19 on azimuth 268.64 degrees from wellhead. Total Dogleg for wellDath is 56.51 degrees. Vertical section is from wellhead on azimuth 267.74 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phi11ips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope0 Alaska Measured Inclln Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 8539.81 23.37 271.86 7113.99 121.17S 4418.05W 8539.82 23.37 271.86 7114.00 121.17S 4418.05W 8892.78 23.37 271.86 7438.00 116.62S 4557.98W 9000.00 23.37 271.86 7536.43 115.24S 4600.49W 9084.51 23.37 271.86 7614.00 114.15S 4633.99W 9278.41 23.37 271.86 7792.00 111.64S 4710.87W PROPOSAL LISTING Page 2 Your ref .- Nanuq #3 version #10 Last revised : 20-Feb-2001 GRID C OORDS GEOGRAPHIC Easting Northing C O 0 R D I N A T E S 373250.01 5957354.99 n70 17 30.48 w151 I 34.19 373250.01 5957354.99 n70 17 30.48 w151 i 34.19 373110.18 5957361.81 n70 17 30.53 w151 i 38.27 373067.70 5957363.89 n70 17 30.54 w151 i 39.50 373034.23 5957365.52 nT0 17 30.55 w151 I 40.48 372957.41 5957369.26 nT0 17 30.57 w151 I 42.72 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Doyon 141) (42.00 Ft above mean sea level). Bottom hole distance is 4712.19 on azimuth 268.64 degrees from wellhead. Total Dogleg for wellpath is 56.51 degrees. Vertical section is from wellhead on azimuth 267.74 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #30Nan3 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : Nanuq #3 Version #10 Last revised : 20-Feb-2001 Comments in we11path ==================== MD TVD Rectangular Coords. Coment 300.00 300.00 0.00N 0.00E KOP 766.63 762.00 2.24S 56.68W Perraafrost 1629.15 1524.42 17.54S 443.79W EOC 1652.05 1542.00 18.12S 458.46W Base West Sak 1977.80 1792.00 26.36S 667.14W 9 5/8" Casing Pt 2485.98 2182.00 39.23S 992.68W K-10/C-40 2759.61 2392.00 46.16S 1167.97W K-5/C-30 4608.59 3811.00 92.97S 2352.44W K-3 4953.88 4076.00 101.71S 2573.64W K-2 6256.94 5076.03 134.70S 3408.38W Begin Drop/Turn 7088.78 5782.00 139.89S 3842.78W A1bian-97 / EOC 7504.90 6163.98 134.53S 4007.75W Tgt- Nanuk 8025.64 6642.00 127.81S 4214.20W Top HRZ 8539.81 7113.99 121.17S 4418.05W Tgt- Kuparuk 8892.78 7438.00 116.62S 4557.98W Tgt Horizon - Alpine 9084.51 7614.00 114.15S 4633.99W Nuiqsut 9278.41 7792.00 111.64S 4710.87W TD - Csg Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 1977.80 1792.00 26.36S 667.14W 9 5/8' Casing 0.00 0.00 0.00N 0.00E 9278.41 7792.00 111.64S 4710.87W 7' Casing Targets associated with this we11pa~h ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuk3 TgtA1pine Rvs 373116.000,5957362.000,0.0000 7438.00 116.34S 4552.17W Nanuq3 TgtNanuk Rvsd 373660.000,5957335.000,0.0000 6164.00 135.48S 4006.85W 18-Sep-2000 Nanuk3 TgtKup Rvsd 2 373250.000,5957355.000,0.0000 7114.00 121.17S 4418.06W 18-Se~-2000 Phillips Alaska, Inc. Nanuk $3 Nan3 slot 91 Alpine Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : Nanuq 93 Version 910 Our ref : prop4062 License : Date printed : 21-Feb-2001 Date created : 18-Sep-2000 Last revised : 20-Feb-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 378205.974,5955128.074,999.00000,N Slot location is n70 17 31.690,w150 59 25.440 Slot Grid coordinates are N 5957404.593, E 377669.076 Slot local coordinates are 2267.71 N 573.75 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 100.00 0.00 267.74 100.00 0.00 N 200.00 0.00 267.74 200.00 0.00 N 300.00 0.00 267.74 300.00 0.00 N 400.00 3.00 267.74 399.95 0.10 S PROPOSAL LISTING Page 1 Your ref : Nanuq #3 Version #10 Last revised : 20-Feb-2001 500.00 6.00 267.74 499.63 0.41 S 600.00 9.00 267.74 598.77 0.93 S 700.00 12.00 267.74 697.08 1.65 S 766.63 14.00 267.74 762.00 2.24 S 800.00 15.00 267.74 794.31 2.57 S 900.00 18.00 267.74 890.18 3.69 S 1000.00 21.00 267.74 984.43 5.01 S 1100.00 24.00 267.74 1076.81 6.52 S 1200.00 27.00 267.74 1167.06 8.22 S 1300.00 30.00 267.74 1254.93 10.10 S 1400.00 33.00 267.74 1340.18 12.17 S 1500.00 36.00 267.74 1422.59 14.40 S 1600.00 39.00 267.74 1501.91 16.81 S 1629.15 39.87 267.74 1524.42 17.54 S 1652.05 39.87 267.74 1542.00 18.12 S 1977.80 39.87 267.74 1792.00 26.36 S 2000.00 39.87 267.74 1809.04 26.93 S 2485.98 39.87 267.74 2182.00 39.23 S 2500.00 39.87 267.74 2192.76 39.58 S 2759.61 39.87 267.74 2392.00 46.16 S 3000.00 39.87 267.74 2576.49 52.24 S 3500.00 39.87 267.74 2960.21 64.90 S 4000.00 39.87 267.74 3343.94 77.56 S 4500.00 39.87 267.74 3727.67 90.22 S 4608.59 39.87 267.74 3811.00 92.97 S 4953.88 39.87 267.74 4076.00 101.71 S 5000.00 39.87 267.74 4111.39 102.87 S 5500.00 39.87 267.74 4495.12 115.53 S 6000.00 39.87 267.74 4878.84 128.19 S 6256.94 39.87 267.74 5076.03 134.70 S 6300.00 39.02 267.87 5109.28 135.74 S 6400.00 37.03 268.21 5188.06 137.85 S 6500.00 35.04 268.58 5268.92 139.50 S 6600.00 33.05 268.99 5351.77 140.70 S 6700.00 31.07 269.44 5436.52 141.43 S 6800.00 29.08 269.95 5523.05 141.70 S 6900.00 27.10 270.53 5611.26 141.51 S 7000.00 25.12 271.19 5701.05 140.86 S 7088.78 23.37 271.86 5782.00 139.89 S 7500.00 23.37 271.86 6159.48 134.59 S 7504.90 23.37 271.86 6163.98 134.53 S 7504.92 23.37 271.86 6164.00 134.53 S 8000.00 23.37 271.86 6618.46 128.14 S 8025.64 23.37 271.86 6642.00 127.81 S 8500.00 23.37 271.86 7077.44 121.69 S Dogleg Vert Deg/100ft Sect 0.00 E 0.00 0.00 0.00 B 0.00 0.00 0.00 E 0.00 0.00 0.00 E 0.00 0.00 KOP 2.62 W 3.00 2.62 10.45 W 3.00 10.46 23.50 W 3.00 23.51 41.70 W 3.00 41.74 56.68 W 3.00 56.72 Permafrost 65.03 W 3.00 65.08 93.40 W 3.00 93.48 126.75 W 3.00 126.85 164.99 W 3.00 165.12 208.00 W 3.00 208.16 255.67 W 3.00 255.87 307.88 W 3.00 308.12 364.47 W 3.00 364.75 425.29 W 3.00 425.62 443.79 W 3.00 444.13 EOC 458.46 W 0.00 458.82 Base West Sak 667.14 W 0.00 667.66 9 5/8" Casing Pt 681.36 W 0.00 681.89 992.68 W 0.00 993.45 K-10/C-40 1001.66 W 0.00 1002.44 1167.97 W 0.00 1168.88 K-5/C-30 1321.97 W 0.00 1323.00 1642.27 W 0.00 1643.55 1962.57 W 0.00 1964.10 2282.88 W 0.00 2284.66 2352.44 W 0.00 2354.27 K-3 2573.64 W 0.00 2575.64 K-2 2603.18 W 0.00 2605.21 2923.48 W 0.00 2925.76 3243.78 W 0.00 3246.32 3408.38 W 0.00 3411.04 Begin Drop/Turn 3435.72 W 2.00 3438.40 3497.28 W 2.00 3499.99 3556.08 W 2.00 3558.81 3612.05 W 2.00 3614.79 3665.12 W 2.00 3667.85 3715.23 W 2.00 3717.93 3762.32 W 2.00 3764.98 3806.33 W 2.00 3808.92 3842.78 W 2.00 3845.30 Albian-97 / EOC 4005.81 W 0.00 4008.00 4007.75 W 0.00 4009.93 Tgt- Nanuk 4007.76 W 0.00 4009.94 4204.03 W 0.00 4205.82 4214.20 W 0.00 4215.96 Top HRZ 4402.26 W 0.00 4403.63 Ail data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from RKB (Doyon 141) (42.00 Ft above mean sea level). Bottom hole distance is 4712.19 on azimuth 268.64 degrees from wellhead. Total Dogleg for wellpath is 56.51 degrees. RECE~VSD Vertical section is from wellhead on azimuth 267.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ FEB 7001 Alaska Oil & Gas Cons. Commission Anchorage (iIl Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : Nanuq #3 Version #10 Last revised : 20-Feb-2001 Dogleg Deg/100ft 8539.81 23.37 271.86 7113.99 121.17 S 4418.05 W 0.00 8539.82 23.37 271.86 7114.00 121.17 S 4418.05 W 0.00 8892.78 23.37 271.86 7438.00 116.62 S 4557.98 W 0.00 9000.00 23.37 271.86 7536.43 115.24 S 4600.49 W 0.00 9084.51 23.37 271.86 7614.00 114.15 S 4633.99 W 0.00 9278.41 23.37 271.86 7792.00 111.64 S 4710.87 W 0.00 Vert Sect 4419.38 Tgt- Kuparuk 4419.39 4559.03 Tgt Horizon - Alpine 4601.45 4634.89 Nuiqsut 4711.61 TD - Csg Pt Ail data is in feet unless otherwise stated. Coordinates from slot %1 and TVD from RKB (Doyon 141) (42.00 Ft above mean sea level). Bottom hole distance is 4712.19 on azimuth 268.64 degrees from wellhead. Total Dogleg for wellpath is 56.51 degrees. Vertical section is from wellhead on azimuth 267.74 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : Nanuq #3 Version #10 Last revised : 20-Feb-2001 Comments in wellpath MD TVD Rectangular Coords. Conunent 300.00 300.00 0 00 N 0.00 E KOP - 766.63 762.00 2 24 S 56 68 W Permafrost 1629.15 1524.42 17 1652.05 1542.00 18 1977.80 1792.00 26 2485.98 2182.00 39 2759.61 2392.00 46 4608.59 3811.00 92 4953.88 4076.00 101 6256.94 5076.03 134 7088.78 5782.00 139 7504.90 6163.98 134 8025.64 6642.00 127 8539.81 7113.99 121 8892.78 7438.00 116 9084.51 7614.00 114 9278.41 7792.00 111 54 S 12 S 36 S 23 S 16 S 97 S 71 S 70 S 89 S 53 S 81 S 17 S 62 S 15 S 64 S 443 79 W 458 46 W 667 14 W 992 68 W 1167 97 W 2352 44 W 2573 64 W 3408 38 W 3842 78 W 4007 75 W 4214 20 W 4418.05 W 4557.98 W 4633.99 W 4710.87 W EOC Base West Sak 9 5/8" Casing Pt K-10/C-40 K-5/C-30 K-3 K-2 Begin Drop/Turn Albian-97 /. EOC Tgt- Nanuk Top HRZ Tgt- Kuparuk Tgt Horizon - Alpine Nuiqsut TD - Csg Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 1977.80 1792.00 26.36S 667.14W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9278.41 7792.00 111.64S 4710.87W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuk3 TgtAlpine Rvs 373116.000,5957362.000,0.0000 7438.00 116.34S 4552.17W 4-Apr-2000 Nanuq3 TgtNanuk Rvsd 373660.000,5957335.000,0.0000 6164.00 135.48S 4006.85W 18-Sep-2000 Nanuk3 TgtKup Rvsd 2 373250.000,5957355.000,0.0000 7114.00 121.17S 4418.06W 18-Sep-2000 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 PHIL(,..IPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY February 8, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Phillips Alaska, Inc. - Nanuq #3 Surface Location: 2385' FSL, 102' FEL, SEC 24, T11N, R4E Target Location: 2145' FSL, 288' FWL, SEC 24, T11N, R4E Bottom Hole Location: 2154' FSL, 5' FEL, SEC 23, T11N, R4E CONFIDENTIAL Dear Mr. Maunder: Per our conversation concerning the isolation of the K2 interval and the suspension of Nanuq #3, I have added a cementing stage tool to isolate the K2 interval. After the K2 interval has been cemented and the stage tool closed, a cement plug will be left in place on top of the stage tool to provide isolation in the wellbore for suspension of the well per 20 AAC 25.110 (d)(2). Before suspension Operations commence, an Application for Sundry Approvals (Form 10-403) will be submitted in accordance with 20 AAC 25.110 (b). Attached is an updated Wellbore diagram depicting the planned completion of Nanuq #3. If you have anY questions or require further information, please contact Scott Reynolds at 265-6253 or ChiP Alvord at 265-6120. Sincerely, Scoff D. Reynolds Drilling Engineer I olville River Field Nanuq #3 Suspension Completion Plan Updated 02/07/01 Wellhead 16" Conductor to 117' Tubin.q Supended with diesel to 2200' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing 2005' MD / 1800' TVD cemented to surface Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing WEG (+/- 62 deg) MD TVD 32' 32' 2540' 2190' TOC, ~ +/- 4643' MD (500'. MD above top K2) Top K2 sand at 5143' MD / 4084' TVD Bottom K2 sand at 5281' MD / 4184' Stage Tool set @ 5381' MD / 4257' TVD 31 bbls of 15.8 PPG. Class G cmt w/additives behind pipe. Assume 88% excess annular volume. TOC Plug ~ +1- 5250' MD 5 bbls of cmt left on top of stage tool to provide for 130' of isolation in the wellbore. TOC ~ +/- 7000' MD (500' MD above top Kuparuk) Top Nanuq Reservoir at 7817 MD / 5988' TVD 7" RMLS Latch Assembly @ 7300' MD Top Kuparuk Reservoir at 8852' MD / 7122' TVD Well TD at 9590' MD / 7800' TVD (+1- 23.37 deg inc.) 7" 26 ppf L-80 BTC Mod Production Casing @ 9580' MD / 7791' TVD @ 23.37 deg DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS roar r o ,gs, $601 C STREET, SUITE 1580 ANCHORAGE, ALASKA 99505-5~18 PHONE: (907) 269-8800 FAX: (907) 562-3852 January 31, 2001 RECEIVED Phillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Attention: James R. Winegarner Subject: Alaska OJl & Gas Cons. Commission Anchorage District Landman Request to Drill an~t~est Nanuq #3, and~ Commingle Nanuq #3'~os~..Fluids~.witl~ ~her Colville River Unit or Kuparuk River Unit Production Dear Mr. Winegarner: By letter, dated January 22, 2001, Phillips Alaska, Inc. (Phillips) applied for approval to drill and test the Nauuq #3 well. Phillips also applied to commingle test production generated from Nanuq #3 with production from either the'Alpine Participating Area (APA) in the Colville River Unit (CRU) or the Kuparuk Participating Area (KPA) in the Kuparuk River Unit (KRU). Nanuq #3 will be a deviated horizontal wellbore with a beginning horizontal bottomhole location in CRU Tract 72 (ADL 380077) and an ending horizontal bottomhole location in CRU Tract 73 (ADL 380077. I approve the drilling and testing of Nanuq #3 and the commingling of the Nanuq #3 test fluids with either APA or KPA production. Since the well is being drilled and tested from an ice pad, this approval is only until June 15, 2001 or the conclusion of Tundra Travel, whichever is later. A status report of the testing operations must be provided to the Division of Oil and Gas on or before August 15, 2001 unless the Division grants an extension. The status report should., list, the sp_ud date.of, the well, the start and stop dates of each testing period, the volume and final disposition of any test fluids and state whether the well is capable of producing or contributing to production of hydrocarbons in paying quantifies. All test production from the Nanuq and Kuparuk objectives of the well should be allocated to CRU Tract 72 (Section 24, T11N, R4E, U.M.), ADL 380077. The test production from the Alpine objective of the well should be allocated to CRU Tract 73 (Section 23, T11N, R4E, U.M.), ADL 380077. The lessees of ADL 380077, Phillips, Phillips Alpine Alaska, and Anadarko Petroleum, shall individually, and separately account for the production allocated to each CRU Tract within ADL 380077 and commingled with either APA or KPA production on their monthly royalty reports. The royalty accounting code for the Nanuq and Kuparuk production allocated to CRU Tract 72 will be CR04. The royalty accounting code for the Alpine production alloeated to CRU Tract 73 will be "Develop, Conserve, and Enhance Natural Resources for Present and Future Alaskans." Mr. James R. Winegarner January 31, 2001 Page 2 CR05. The monthly CRU or KRU Operator's Report provided to the Division, depending on where the test fluids are sent, should individually and separately account for the commingled Nanuq #3 test production gifted to the respective facility. Finally, this approval is only for the general plan of exploration and testing of Nanuq #3. Specific on- site operations will require additional approvals. Sincerely, Mark D. Myers Director cc: Teresa Imm - ASRC (Fax # 344-5642) AOGCC CRU-Nanuq3-Ops.doc PHILLIPS PETROLEUM COMPANY To: Jeff Zawila Dave Bannan Scott Reynolds ATO-1464 ATO-866 ATO-838 From: Kathy Heinlein ATO-1346 Subject: Pre-Drill Seismic Pore Pressure Prediction for Nanuq #3 Date: January 21,2000 Summary Seismic velocity data was used to predict pore pressures likely to be encountered in the proposed Nanuq #3'well location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from surrounding area wells (Nanuk #1, Nanuk #2). The local compaction trend and the translation trend model were applied to velocities from 3D seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well locations. Seismic Processing The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used for pressure prediction were generated using Phillips' AVEL software, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 CDPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in CDP fold. Pressure Prediction Procedure Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. The Nanuk #1 and Nanuk #2 offset wells were used to establish both a local normal compaction trend line and local velocity vs. pressure translation trend model. The model is similar to models used for previous pressure prediction in this area (Wydrinski 1999) but has been updated based upon recent drilling results. The model is similar to the models used for pressure prediction projects at Alpine, NPRA, and Tarn. The proposed Nanuq #3 surface location is located within 1000 ft of the surface location of the Nanuk #1 well, which encountered no shallow hazards or zones of increased pressure. Procedure 1 .) A Normal Compaction Trend Line (NCTL) was determined for a series of seismic lines from the Colville 3D seismic dataset. The seismic-derived NCTLs matched the NCTL slope calculated at Nanuk #1 (-5e-5). The intercept varied slightly from the intercept found at the well (175 seismic vs 165 well). 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (AT) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences,/tAT. 3.) A translation trend model was established by comparing transit time differences (/tAT) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C2*/t/tT**2 + O1 */tAT + CO Where C2 = 8.01e-5, C1 = .0019, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). Seismic Pore Pressure Prediction Pressure gradients were predicted for the Nanuq #3 proposed well location using 3D seismic data. Pressure gradient prediction displays are provided for the following 3D inlines and xlines, both in time and in depth. Predicted Pore Pressure Gradient Displays in Depth: Figure # Seismic Line Proposed Well Location 1 XL 1154 Nanuq #3 (surface) 3 XL 1162 Nanuq #3 (td) Predicted Pore Pressure Gradient Displays in Time with Migrated Time Overlay: Figure # Seismic Line Proposed Well Location 2 XL 1154 Nanuq #3 (surface) 4 XL 1162 Nanuq #3 (td) Warmer colors indicate higher predicted mud weights (pore pressure gradients). No apparent shallow hazards are observed in the 3D seismic pressure analysis. It should be noted that the 3D seismic data used here has a Iow effective fold in the shallow section (above 3000 ft), therefore reducing the reliability of the shallow seismic velocity calculation. It is general practice to run shallow hazards analysis on 2D seismic where 2D data is available with a higher effective shallow fold. 2D seismic data was not available in this area at the time of this report; the 2D analysis will be run when the data becomes available. Pore Pressure Gradient Prediction at Proposed Well Locations Figure # Seismic Line Well Location 5 IL 5563, XL 1154 Nanuq #3 (surface) 6 IL 5508, XL 1162 Nanuq #3 (td) Conclusions 1 .) There are no apparent shallow hazards at the proposed Nanuq #3 well location observed on the Colville 3D seismic dataset. 2.) Overpressure has not been encountered in wells drilled previously in this area (Nanuk #1 and Nanuk #2), The surface location of the proposed Nanuq #3 well is approximately 1000 ft offset from the surface location of the Nanuk #1 well. 3.) The normal compaction trend observed in the Nanuk #1 and Nanuk #2 wells matches compaction trends observed in other area wells (Alpine and NPRA) and matches trends observed in the Colville 3D seismic dataset. 4.) A 2D seismic line will be reviewed when available to verify shallow observations (above 3000 ft). Kathy Heinlein PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Cross Section: XL1154 Method: Trend Curve NCTL: 175-5.5 Model: OST/NS Seismic Line XL1154 (depth) 1000,0. 2000,0. 3000,0, D E P T 4000,0, H 6000~, 6000,0 8.00 8.50 9,00 9,50 10,00 10,50 11,00 11,50 12,00 12.50 13,00 13,50 14,00 14,50 15,00 15,50 16.00 ~16,50 17.00 17,50 18,00 18,50 19,00 ..,~, 7000,0 8000.0 9000,0 CDPInterval=82_~ft Figure 1 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Cross Section: XL1154 Method: Trend Curve NCTL: 175-5.5 Model: OST/NS Seismic LineXL 1154 (time) 17S-S.-SOST..PPS_T NANUQ._O $~imic:~G~_HIaR ~ 0.0, 100.0, 200.0', 300,,0 400.0 5OO,,O 600.0 T 606.0i I M 900,0 imst 1000.0 1100,0 0 O 0 0 0 0 0 1300~ 1400~ 15009 #! 8.00 8.50 9.00 9,60 10.00 10,50 11,00 11.50 12.00 12,50 18.00 13.50 14.00 14,50 15,00 15.50 16.00 16.50 17,00 17,50 18,00 18,50 19,00 17009 1800~' 1900~ :2000~' CDP Interval = 82~ ft Figure 2 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/14/01 K. Heinlein Project: Nanuq Cross Section: XL1162 Method: Trend Curve NCTL: 175-5's Model: OST/NS Seismic Line XL 1162 (depth) 17',',S-S-SOST_PPG NANUQ $ 8 0 2 ~ $ 8 0 2 4 $ 8 O 2 4 6 8 0 2 4 $ 8 02 4 S 8 2 4 $ 8 0 2 ~ $ 8 0 2 4 G 8 0 2 MSL 0,0, 1000~. 2000~, 3000~, D E P T 4000~, H 5000~; 6500~ FPII 8.00 ..~"'~ 8.50 9.00 9.50 10.00 10,50 11,50 11,50 12,00 12,50 13,00 13,50 14,50 14.50 15,50 -- 16,00 -- 16,50 17.50 17.60 18,00 18.68 T000~ 9000~ 90009, CDP Interval = 825 ft Figure 3 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. H®inlein Project: Nanuq Cross Section: XLl162 Method: Trend Curve NCTL: 175-5'5 Model: OST/NS Seismic Line XL 1162 (time) NANUO 3 ~S-S-$OST_PP~_T ~ - SebmJc:AGC_ldlOB SW NE 0 PP! 100,0 200,0 400,0, 600,0~ ?00,0: T 800,0: I M 900,0, ! Insl 1200,0 1500,0 1400,0. 1500.0. 8.OO 8,50 9,00 9,50 1030 10.56 11,00 11,58 12,00 12,~0 13,00 '13.50 14.00 14.50 15,00 15,50 --1630 ~ 16,50 17.00 17,50 18,00 18,50 -- 19,00 1700,0 1800,0 1900,0 CDP Interval = 82.5 ft Figure 4 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Well: Nanuq 3 NCTL: 175-5'$ Nanuq 3: Velocity from IL5563 at XL1154 BL~TI! (Dalum sett~ MSL) MSL 1000 2OOO 300 6000 6000 7000 8000 8600 40 60 80 100 120 140 NCTLIntereept~GL=lTS LogaribmieSleFe= -it-Ii 180 FEET .... : ................ ~ ............ ~ ......... , , :':..'.'.'b:. ::".'..'.'.~::: .':".'::.'.',.~...:'::: .::~;.':....:.._:.:..'. ::':.':~.....:"...'. , ............ t ............. ~ ............. ,, ........ ": ,'.'~:,' ........... ! ....... !,", ".:,,'7.:,".~': 7 7,,',,:'i~:'.Z'":',7 ?,,", .... ~,~ ........... ~ ......... :. ...................... ~ ......... ~ .......... ~ ..... ' .. 1000 ,.,~ ........... t. .......... ~ ....... ~ .......... I .... t. ........... '~ ........... ~ .......... ~- ........ f ........ t ....... '.- .. "~ :"~;-" ........ ~ ........... '- ................ ! ........... i .............. ~ ...... '"' ............................ ~ ........................................ ~ .......... '~ ........... ...... ,-,I ............ ; ............. ; ....... I ................... ] ..... . , .... ~ ........... ...."! ..........., +:'. ........... [ ........ , ................... ~ ......... :....!..: ....... ~..........: ..... ,. ~.'"; ........ i':'".:'."! ...... i'". ..... "" , . - .......... ; ............ .~ ........... ~. ....... ,' ...... .~ :'.'.7 ';"; .'" ;"X.:"';';.}..: Z' ...7.".'. Z." 20OO .: ..,,. ........... ~. ~ ............. !. , r .............. :. .......................... : ......... ; ........ ....................... ,, ................ ~ .................!:: ........... : ............. :. .......... :; .... :...:.: ....... ' 'i .......... '.,z:;....:.,.'..i,,,.,.:' ....... '~ ', ........ ~,,.,.,.: ....... ~.,....Y ........ ' '" ~. . ; .:. .................... .'","'.',','.,:'.c:,,':,'":::I.".::.::::::,",",:':::,:¥':::,': '.",:c:: ...........................'~"' ...... ............ :':: '"'::':':::':,::'::":""'!'"':::"::'i:i:'::i,::,i'i;ii:','.i'.".";.: "i ........ ::::: ::':'-..':,!:,',':::.-,.' ;', ,.'-: :'.':',,':-,"-,. ................... I ........ ~. ............ ~, ............ ,~ ........... ..... "- ..................... ~ ................... ,.' ..... ~ ......... ? .......... ~. ......... i ........ ...' . : ~ , . .... . .......... ..~ ....... ! ........... ~ ........... ;:~. ".:'..'.7;',;.'" : . ........ · " ....... i ............ ~ ........... ' ................... ........... ': ........ ~ ............. i ............ ; ........... 3OOO 4OOO 5000 6 ? 8 9 10 11 12 13 --~- 1TS-~-~OST PPG 0 1T$-S-SOST~G 6OOO r. 85OO 14. 15 16 17 18 19 20 Figure 5 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Well: Nanuq 3 NCTL: 175-5-5 Nanuq 3: Velocity from IL5508 at XL1162 DEPTH (D~um setlo blSL) MSL ~"~-'- 4000 ~~ ~ ' -~ ., ~ 40 60 80 100 lffi 140 180 N~L I~ree~ ~ OL = 6 7 8 9 o I?E-E-~OST PPG 10 11 12 18 14 PPG 15 18 17 18 16 20 FEET MSL 1000 2000 3000 4000 5000 6000 7000 8000 8500 Figure 6 IJJ !11 IJ. IJJ DRILLING TIME AND MUD WEIGHT CURVE --e--Depth Nanuk #1 ~'--Mud Weight 0 10.8 ~' ' 116" set @107' · · ............. [ .................. ~ ..... - ..... ; ......; ............ ; ......; ..... - ..... - ..... ........... I ..... ,~ ..... i ........... ~ ..... ~. ..... i ...... i ............ i ...... i ..... j ..... ~. ..... 2000 ..... ! ...... i ..... _1 ..... ._ _~[[1_. N~k_[ I ! I I I I I '' ' ' '~" -I ..... "'1 ..... ;' ..... l ...... , ........... , ...... , ..... "1 ..... ;' ..... :il:::: :!::::: i::::: : I ! i i i ! i i ! i ~ i , 10 ............ i ..... 'f ..... i ........... '3 ..... /' ..... i ...... ! ........... i ...... ! ..... "l ..... ,' i - q ..... i .......... ..i ..... t.. ..... i ...... i ..... ~ ..... ; ...... i ..... .q ..... p ..... ............ i ..... d ..... i .............. = ...... i ..... i ..... i ...... ~ ..... d ..... i. ..... ............ Il ..... '~1 ..... Il .......... Il ............ : ............................. -... 918 4000 ............. , ..... , ..... ,. , ....... 9.6 5000 ..... : ...... : ..... ", ..... : ........... ','' - Log Hole, cut SWC's, take RI'Ps ..... ', ...... : ..... ',' ..... :' ..... ..... , ...... , ..... ; ..... , ........... -, ....... , ...... , ..... -, ..... ;. ..... 6000 9.2 : ---,.- ..... , .......... , ......i_-:::_---.-:_--~--_---, ...... , .......... . ....... ..... , ..... .- ..... 7000 i ',~ 9 .... i ...... i ..... j ..... i ........... .., ..... t. .... i ...... = .......... i ...... ! ..... ., ..... t. ..... ....:::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 8000 ...... ' ..... ; ..... ' ........... " ..... r ..... , ......, .......... , ......, ..... ', ..... r ..... .... ' '- .... ' .......... ' ..... ' ' ' lTD O 7630' MDI ' ' ........................................................................................... '-- 8.6 .... , ...... i ..... .., ..... I ........... .4 ..... k ..... ! ...... i ............ i ...... , ..... .4 ..... k ..... ..... i ...... i ..... j ..... l ........... .., ..... ;.. ..... i ...... [ ............ i ...... i . i I .... 9000 , , ....... . , . , , , , [ Finish P&A 0/23/1090 ] -- 8.4 ..... , ...... , ..... , ..... , ........... J ..... '. ..... , ...... , ............ , ...... , ..... .' ..... '. ..... ..... ,, ...... ,, ..... ; ..... ,, ........... .: ..... ,~ ..... ,, ...... ,, ............ ,, ...... ,, ..... _,' ..... ,; ..... ..... [ ...... [ ..... 'i ..... ,t ........... "~ ..... i' ..... if ...... ~ ........... ~ ...... ~ ..... '~ ..... ,' ..... 10000 8.2 0 5 10 15 Spud 1500 hrs 3/12/96 TIME TO DRILL (DAYS) Rig Release 1200 hfs 3/24/96 prepared by TJB 5/10/00 Ull IJ. tiJ 1000 2ooo 3000 4ooo 5000 6000 7OOO 8OO0 9000 10000 0 16' set @ 108' I DRILLING TIME AND MUD WEIGHT CURVE Nanuk Drill 12-1/4' Hole ................................ ! ! i ! .... ", ' ' ' ! ................................... - - -t- - - i ...... i- - - '1 ......... 9-5/8' set @ 2219' ~ ............................. I -- I ~ . ll i i I ~ I 1 _t_ . o,_ _ o _, i --e--Depth ~Mud Weight Drill 8-1/2' Hole ........ ! ! ' ' -~- ' - *- ' ' ', - ' -i ...... !- - - - - -m- - - ff - - ..[ - - -m ...... l- - One 120' core _ o _1_ _ . ~ - . ..; - . _! ...... ~. - - - . _1. . -[_ o . j. . -, ......... m. . . _, . . .,... ,... j...t ......... ,....,. - - -. ...... .- - - I_o~ Hole, Run 7', & Complete ...... MD: TD @ 9112 ...... Spud 0230 hrs 3/24/00 Well test conducted in Nanuk & Kuparuk fm 4/17 thru 5/2 ..... ! m m [ ! i , ! ! , , ! ! [ m m ! ! ! ! m i m ~ - . -, - . . ! ....... r - - -;- - - , ...... . . . m. _ . _1 _ . _ Finish P&A 5/6 ! ! ! m m m m ! m t ! i i i i i i i i ! i i i i ! i , i , 5 10 15 20 TIME TO DRILL (DAYS) 10.8 10.6 10.4 10.2 10 9.8 9.6 __. 9.4 "' 9.2 9 8.6 8.4 8.2 25 Rig Release 1900 hrs 4/11/00 prepared by TJB 5/10/00 Nanuq #3 Drillin Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps, run gravel isolation string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2400' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole / 7" Casing Interval Event Risk Level Mitigation Strategy Abnormal Pressure in Low BOPE drills, Keep mud weight above 9.8 Surface Formations ppg. Check for flow during connections and >2400' TVD if needed, increase mud weight Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Nanuq #3 Drilling Hazards Summary. doc prepared by Scott D Reynolds 01/22/2001 Page 1 of I ALASI OIL AND GAS CONSERVATION COMPllSSION Chip Alvord Drilling Team Leader Phillips Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (9O7) 276- 7542 Re:. Colville River Unit Nanuq #3 Phillips Alaska Inc. Permit No: 201-026 Sur. Loc. 2385'FSL, 102'FEL, Sec. 24, TllN, R4E, UM Btmhole Loc.' 2154'FSL, $'FEL, Sec. 23, T1 IN, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above, referenced well. The permit to drill does not exempt you from obtaining .additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. 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. Annular disposal of drilling, wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC' 25.080 are met. Annular disposal of drilling waste will be · . contingent on obtaining a well cemented surface casing conf'umed by a valid.Formation Integrity Test (FIT). Cementing records, FIT data, subsequent LOT' data following setting production casing, and anY CQLs must be submitted to the Commission on .form 10-403 prior to the approval of disposal operations. 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient' notice (approximately 24 hours) Of the diverter function test and initial BOPE test must be .given prior to commencing drilling operations so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petrolenm field inspector on the North Slope pager'at 659- 3607.' Daniel T. Seamount, Jr. Commissioner By oRDER OF THE COMMISSION DATED this / -~4 , ' daY of dlf/Enclosures CC: Deparunent ofFish & Game, Habitat Section w/o encl'. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~ lb. Type of Well Exploratory X Stratigraphic Test Development Oil Re-Entry Deepen! Service Development Gas Single Zone Multiple Zone X 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool PHILLIPS Alaska~ Inc. DF 50.6' feet 3. Address 6. Property Designation N/A P. O. Box 100360~ Anchorage~ AK 99510-0360 ADL 380077 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2385' FSL, 102' FEL, SEC 24, T11N, R4E, UM Colville River Unit Statewide At targ.e.t (=KUP LCU ) 8. Well number Number ~FSL, 288' FWL, Sec. 24, T11N, R4E, UM Nanuq #3 59-52-180 .At total depth (7" casing point) 9. Approximate spud date Amount · .154' 5' FEL~ SEC 23~ T11N~ R4E 2/12/00 $200~000 12.. Distan~.e to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and 'IVD) Property line 2154 ' .P..560' ~/¥q .~j> 9590' MD 7800' TVD from ADL384209 Nanuq #2 is 4000' feet Feet ~ ~ ~ ~ ~'t~,~, feet 16. To be completed for deviated wells~4/~" ~3 17. Anticipated pressure (see 20 AAC'2~.035(e)(L))) Kickoff depth ~ ~" feet ,,~bMaximum hole angle j~ Maximum surface ~ pslg At total depth ('I'VD) 361 1 palg 18. Casing progra~ · Setting Depth size Specifications Top Bottom Quanti ,fy of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" 62.5# H-40 Weld 80' 37' 37' 117' 117' +/- 200cf 12.25" 9.625" 40# L-80 BTC 1763' 37' 37' , L~005' 1800' 425 Sx Arcticset III L & 260 Sx Class G 8.5" 7" 26# L-80 BTC-M 9553' 37' 37' {)590' 7800' 414 Sx Class G N/A 3.5" 9.3# L-80 8rd-Mod 2509' 32' 32' 2541' 2190' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length RE~EIVED Cemented Meesureddepth TrueVerticaldepth Conductor Surface Intermediate ORIGINAL Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchoraq~ 20. Attachments Filing fee X Property plat BOP Sketch Diverter Sketch Drilling program X Drilling fluid program X Time ye depth plot Refraction analysis Seabed report 20 AAC 25.0.50 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge /~.,-d, Title Drilling Team Leader Date //z'~[OI ~ Commission Use Only Signed Permit Number APl number /,-,,/,,. I Approval date .~ I ~J /3 ~ I See cover letter for so-/c:> .-~ -- 2..C,~ ~ 5'--,-.,._., I ~ '", o~ - ~.' ~ I Other requirements Conditions of approval Samples required ~ No Mud Icg required /~fe~ No Hydrogen sulfide measures Yes ~~ Directional survey required {~ ~-'"~o Required working pressure for BOPE 2M 3M ~'M~ 10M 15M V Other: by order of Approved by I'"~ "[avlO~' SeamoLlrlt commissioner the commission Date ~ ""/C~ --Lq/ Form 10-401 Rev. 7-24-89 Submit in triplicate Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 A Subsidiary of PHILLIPS PETROLEUM ~;OMPANY February 8, 2001 Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Phillips Alaska, Inc. - Nanuq #3 Surface Location: 2385' FSL, 102' FEL, SEC 24, T11N, R4E Target Location: 2145' FSL, 288' FWL, SEC 24, T11 N, R4E Bottom Hole Location: 2154' FSL, 5' FEL, SEC 23, TllN, R4E CONFIDENTIAL Dear Mr. Maunder: Per our conversation concerning the isolation of the K2 interval and the suspension of Nanuq #3, I have added a cementing stage tool to isolate the K2 interval. After the K2 interval has been cemented and the stage tool closed, a cement plug will be left in place on top of the stage tool to provide isolation in the wellbore for suspension of the well per 20 AAC 25.110 (d)(2). Before suspension operations commence, an Application for Sundry Approvals (Form 10-403) will be submitted in accordance with 20 AAC 25.110 (b). Attached is an updated wellbore diagram depicting the planned completion of Nanuq #3. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Sincerely, Scott D. Reynolds Drilling Engineer Nanuq #3 Suspension Completion Plan Updated 02/07/01 Wellhead 16" Conductor to 117' Tubing Supended with diesel to 2200' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing 2005' MD / 1800' TVD cemented to surface TOC ~) +/- 4643' MD (500' MD above top K2) Top K2 sand at 5143' MD / 4084' TVD Bottom K2 sand at 5281' MD / 4184' TVD Stage Tool set @ 5381' MD / 4257' TVD TOC ~ +/- 7000' MD (500' MD above top Kuparuk) Top Nanuq Reservoir at 7817 MD / 5988' TVD Top Kuparuk Reservoir at 8852' MD / 7122' TVD Well TD at 9590' MD i 7800' TVD Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing WEG (+/- 62 deg) MD TVD 32' 32' 2540' 2190' 31 bbls of 15.8 PPG. Class G cmt w/additives behind pipe. Assume 88% excess annular volume. TOC Plug ~) +/- 5250' MD 5 bbls of cmt left on top of stage tool to provide for 130' of isolation in the wellbore. 7" RMLS Latch Assembly ~ 7300' MD 7" 26 ppf L-80 BTC Mod Production Casing ~. 9580' MD / 7791' TVD ~ 23.37 deg Nanuq #3 Summaw Drilling Procedure . . . . . o . , . 10. 11. 12. 13. 14. 15. Install diverter on pre-installed 16" conductor. Move in and rig up Doyon 19. Function test diverter. Spud and directionally drill 12 1/4 inch hole to the 9-5/8" surface casing point (2005' MD / 1800' TVD) per the directional plan. Run MWD/LWD logging tools as required for directional monitoring and for gathering formation data. Run and cement 9 5/8", 40#, L-80, BTC casing string to surface. Install and test BOPE to.3S00-psi. ~-~~[~_ Pressure tea casing to 2500 psi. Drill out 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe pr 20 ACC 25.030 '(0.5 ppg less than the FIT or LOT EMW) Drill 8-1/2" hole to Coring point above the Kuparuk sands (8829' MD/7100' TVD). POOH and PU coring BHA. RIH to coring point and core 60' of hole through the Kuparuk sands to (8889' MD / 7156' TVD). POOH and LD cores and coring BHA. PU drilling BHA and RIH to 8820' MD. Ream hole to 8889' MD. Continue to directionally drill 8-1/2" hole to TD @ 9590' MD / 7800' TVD per the directional plan. Run and cement 7 inch casing as per program. Displace with kill weight Brine. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing x casing annulus, x,,e..~ -Nc~-~.N-- ~'~ c..~.\ ~.,~ Run +/- 2500' of 3-1/2" tubing. Land in hanger and test seals to 5,000 psi. Freeze protect tubing and annulus to +/-2,500' MD. Install 2-way check, nipple up tree and secure wellhead. Rig down and move off Doyon 19. RECEIVED JAN ?. ~ ?..qnl Alaska Oil & Gas Cons. Commission Anchorage Well Proximity Risks: There are no well proximity risks associated with Nanuq #3. Drillinq Area Risks: With the close proximity of Alpine to Nanuq #3 (approximately 3.4 miles to the north~'t~,'~nd with the conclusion of development drilling on Alpine's CD1 pad, A wealth of knowledge in local formation properties has been gained. No shallow hazards were evident during the development drilling on CD1 Pad at Alpine. The mud weights outlined in the "Drilling Fluid Program" for Nanuq #3 will be consistent with the mud weights used to drill the Pilot Hole on well CD1-NQ1 where no pressure anomalies or lost circulation was encountered. The pilot hole on CD1-NQ1 targeted the same Nanuq, Kuparuk, and Alpine horizons as the Nanuq #3 well plan targets. Examination of the drilling and testing data from offset wells Nanuq #1 and #2 suggest no shallow hazards are present. Pressure data from the RFT's indicates a formation pressure gradient of approximately 0.444 psi/ft. A 9.2 ppg mud is sufficient to provide a 232 psi overbalance margin for the Nanuq formation and a 150 psi overbalance for the Alpine formation. The planned mud weight of 9.8 ppg is more than adequate for drilling the reservoir sections; however, it is required for shale stabilization of the HRZ. The surface locations of Nanuq #1 and #2 are within 5,000' of the surface location of Nanuq #3. The seismic shallow hazards analysis indicates no abnormal pressures or weak formations; particularly at shallow depths. See the attached "Shallow Hazards Analysis". Nanuq #3 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" 9-5/8"surface casing casing point - 8 Y2" point- 12 ¼" Density 8.8 - 9.6 ppg 9.8 - 10.5 ppg PV 16 - 26 10 - 25 YP 20 - 60 15 - 25 Funnel .Viscosity 80 - 300 30 - 40 Initial Gels 40 - 90 4 - 8 10 minute gels 90- 115 <18 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) PH 8.5 - 9.0 9 - 10 % Solids +_ 10% 4 - 7% Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at + 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. ,Intermediate Hole Section: Fresh water gel / polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. Maintain mud weight at or below 9.8 ppg. If connection gas is encountered weight up mud one to two tenths of a pound per gallon. Be prepared to add loss circulation material if loss zones are encountered. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all R~~t~i~.j~i~ning wellbore stability. J/iN Alaska Oil & Gas Cons. Commiss~e~ Anchorage Nanuq #3 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 117 / 117 12.9 54 66 9 5/8 2005 / 1800 12.9 834 ~ ,~5-'5 8-1/2 hole 9590 / 7800 16.6 .3611 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 5000 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point . ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1) D = [(12.9 x 0.052) - 0.1] x 117 = 66 psi OR ASP = FPP - (0.1 x D) = 834 - (0.1 x 1800') = 653 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052)-0.1) D = [(12.9 x 0.052) -0.1] x 1800 = 1027 psi OR ASP = FPP -(0.1 x D) ~ = 3611 - (0.1 x 7800)(-' 2831 psi ) CASING PROPERTIES. Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 40 L-80 3 BTC 3090 psi 2,626 psi 5,750 psi 4,887 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 ;)si 7,240 psi 6,154 psi Wt Connection TENSILE STRENGTH OD (ppf) Grade Range Type JOINT BODY 9-5/8" 40 L-80 3 BTC 727k lbs. 916k lbs 7" 26 L-80 3 BTC-Mod 364k lbs 415k lbs Casing Setting Depth Rational 16" - 117' RKB 9-5/8"- 1800 TVD' RKB 7"- 7800 TVD' RKB Conductor Casing to provide sufficient anchor and fracture gradient for diverter system. Surface casing to provide good anchor for BOPE and sufficient fracture gradient and well control while drilling to the next casing setting point. Production Casing to cover all open hole and all previously set casing to allow comprehensive testing of the well. This casing will not be set if there is not an upside potential indicating a well test should be carried out. ("- Colville River Field (' Nanuq #3 Suspension Completion Plan Updated 01/22/01 RKB - GL = 37' , Wellhead 18" Conductor to 117' T~¢~ +/- 7000' M O /($00' MD above top Kuparuk) /Top Nanuq Reservoir at 7817 MD / 5988' TVD Top KuParuk Reservoir at 8852' MD / 7122' TVD 9-5/8" 36 ppf Surface Ca g 2829' MD TVD cement to surface Tubing Supended with diesel to 2200' TVD Completion Tubing Hanger 4-1/2", 12.6#/ft, IBT-Mod Tubing WEG (+/- 62 deg) MD TVD 32' 32' 2190' 2540' Well TD at 9590' MD 1 7800' TVD (+1- 23.37 deg inc.) 7" RMLS Latch Assembly {} 7300' MD 7" 26 ppf L-80 BTC Mod Production Casing @ 9580' MD / 7791' TVD @ 23.37 deg NANUQ #3 Well Cementincj Requirements 9 518" Surface Casing run to 2005 MD 11800' TVD. Cement from 2829' MD to 2329' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2329' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: 1505' X 0.3132 ft3/ft X 4 (300% excess) = 1885.5 ft3 above permafrost Total volume = 1885.5 ft= => 425 Sx @ 4.44 ft3/sk System: Tail slurry: 425 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant (2005-1550) X~0.3132 ft3/ft X 1.5 (50% exce _ss~ = 213.8 ft~ below permafrost 45' X 0.3132 ft~/ft X 4 (300% excess) = 56.4 ft" above permafrost 80' X 0.4341 ft3/ft = 34.7 ft3 shoe ioint volumeft~ Total volume = 234.9 ft3 + 56.4 ft3 + 34.7 fta = 304.8 => 260 Sx @ 1.17 fta/sk System: 260 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 9580 MD ! 7791' TVD Cement from 9580' MD to +/- 7000' MD (minimum 817' MD above top of Nanuq formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (9590'- 7000'!3X 0.1268 ft~/ft X 1.4 (40% excess) = 460 fts annular volume 80' X 0.2148 ft/ft = 17.2 ft~ shoe joint volume 3 Total volume = 458 + 17.2 = 475.2 ft => 414 Sx @ 1.15 ft3/sk System: o o o 414 Sx Class G + 0.2 Yo D046 antifoamer, 0.25 Yo D065 dispersant, 0.25 Yo D800 retarder o 3 and 0.18Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk ~ By Weight Of mix Water, all other additives are BWOCement Nanuq #3 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-114" Hole ! 9-518" Casinq Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision None N/A Gas Hydrates Low Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, Iow mud temperatures Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted sweeps, run gravel isolation string. Abnormal Pressure in Low Diverter drills, increased mud weight Surface Formations >2400' TVD Lost Circulation Low Reduced pump rates, mud rheology, lost circulation material, use of Iow density cement slurries 8-1/2" Hole i 7" Casing Interval Event Risk Level Hiti~lation Strategy Abnormal Pressure in Low BOPE drills, Keep mud weight above 9.8 Surface Formations ppg. Check for flow during connections and >2400' TVD if needed, increase mud weight Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Abnormal Reservoir Low Well control drills, increased mud weight, Pressure contingencies for top set casing string. Hydrogen Sulfide gas Low H2S drills, detection systems, alarms, standard well control practices, mud scavengers Nanuq #3 Drilling Hazards Summary. doc prepared by Scott D Reynolds 01/22/2001 Page I of I Phillips Alaska, Inc. Struc'i'ure: Nanuk .~.,'.T Well: Nons Field: Alpine Field Location: North Slope, Alaska 1000 1500 2000 250O 4O00 45OO I v ~ 7OOO 75OO 500 Est;meted RKB Elevation: 50' KOP 3.00 9.00 15 (F~rmofmst · DLS: 3.00 deg per 100 ft 21.00 27.00 33.00 39.0OBese West Ssk EOC g 5/8 Cosing Pt K-~O/C-*O K-5/C-30 266.43 AZIMUTH 5187' (TO TD) ,,.**Plane of Proposal..** TANGENT ANGLE 43.31 DEG K-3 K-2 Begin Drop/Turn 41.51 DLS: 2.00 deg per 100 ft Albian-97 Tgt- Nanuk _.~__ End Drop/Turn TARGET DEG~~' 23.37 ANGLE ~ ,o.,.z Tgt - Kul~rUk ~ Tgt Horizon - Nplne ~ ~, Nulqsut i i i i i i i i i i i i i i i ! I i I i i i i i i 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 5000 YeHic~l Section (feel) -> Azlmufh 266.45 wifh reference 0.00 N, 0.00 E from slot ~1 I 6500 Phillips Alaska, Inc. Stm~ure: N,,nuk t~5 Well: bi-nS . Field Alpine field Location: Norfh Slope, Alaska <- West (feet) 6000 5700 5400 5100 4800 4500 4200 3900 3600 3300 3000 2700 2400 2100 1800 1500 1200 900 600 300 0 300 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I : t ; : ~ ~ ; ~ ~ ~ ~ I 266.43 AZIMUTH (?o ***Plane of Proposal*** I ALPINE TARGEI' KUPARUK TARG----~ I NANUQ TARG-----~ LOCATION: LOCATION: I LOCATION: TRUE 2149' FSI_, 148' FWL 2145' FSI., 288' FWL 2132' FSI_, 699' FWL SEC. 24, T11 N, R4E SEC. 24, T11 N, R4E SEC. 24, T11 N, R4E 2154' FSL, 5' FEL SEC. 23, T11N, R4E AS-SlAKED SURFACE LOCATION: 2385' FSL, 102' FEL SEC. 24, T11N, R4E ~.66.4~ I~ 't'/"" ~/' ~ %,`"' ,e'- ..,.,~ KOP ,,,,<~ ~' _ ,.6¢,d 1800 1500 1200 goo A I Z 6o0 I goo V 12oo 15oo 18oo Phillips Alaska, Inc. Sfru,=fure: Nanuk #3 Well: Nan3 Irleld: Alpine Field Location: North Slope, Alaska Point KOP Permafrost Base West Sak EOC 9 5/8 Casing Pt K-10/C-40 K-5/C- O K-3 K-2 Begin Drop/Turn Albian-97 End Drop/Turn Tgt- Nanuk Top HRZ Tgt- Kuparuk Tcjt Horizon - Alpine :Nuiqsut iTD - Csg Pt PROFILE COMMENT DATA MD Inc Dir TVD North East 300.00 0.00 266.43 300.00 0.00 0.00 774.88 14.25 266.43 770.00 -3.66 -58.62 1662.72 40.88 266.45 1550.00 -28.99 -464.98 1743.52 43.31 266.43 1609.96 -32.36 -519.04 2004.68 43.31 266.43 1800.00 -43.51 -697.82 2540.61 43,51 266.45 2190.00 -66.59 - 1064.69 2829.19 45.51 266.43 2400.00 -78.71 -1262.24 4779.16 '45.51 266.43 5819.00 -161.94 -2597.12 5143.32 45.51 266.43 4084.00 -177.48 -2846.41 6609.83 43.51 266.43 5151,18 -240.08 -5850.32 7596.88 27,70 270.08 5790.00 -256.73 -4305.52 7616.82 25,57 271.86 5988,41 -255.24 -4400.29 7816,80 23.37 271,86 6171.98 -252.66 -4479.57 8537.53 23.37 271.86 6650.00 -245.95 -4686,02 8851.70 25.57 271.86 7121.98 -239.33 -4889.87 9204.67 25.37 271.86 7446.00 -254.78 -5029.81 9396.40 23.37 271.86 7622.00 -232.31 -5105,83 9590.31 23.37 271.86 7800.00 -229.81 -5182.70 V. Sect 0.00 58.73 465.88 520.05 699.17 1066.76 1264.70 2602.16 2851.95 5857.80 4313.15 4407.64 4-486,61 4692,25 4895.29 5034-.67 5110.59 5186,96 Deg/1 O0 0.00 3 O0 3 O0 3 O0 0 O0 0 O0 0 O0 0 O0 0.00 0.00 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 Nanuq #3 Subject: Nanuq #3 Date: Sat, 03 Feb 2001 09:05:13 -0900 From: Tom Maunder <tom_maunder{~admin.state.ak.us> To: Scoff Reynolds <sreynold2~ppco.com> Scott, I was look at Nanuq #3 and comparing with #1 and #2. Based on the information in those files, you may need to bring your 7" cement higher. Please give me a call on Monday. I am also looking at the suspend portion. You may need to make that request with a 403, but I will check that out for you. Tom Tom Maunder <tom maunder~.admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 2/3/01 9:08 AM ~blR{'l' BY: Al{CO ALASKA ; 3- 1-9~ ; 1~:00 ; KPS/'WELL$/CNST/PROJ-, I,Jl- ~:it341P lION :VISED I OC,~,TIOM Y4 92-8~ 90'7 26,5 6224;# 4/ 4 RE~/ISE:D LOCA'nON 93-50 93-22 .BO :.:,:.:.:92..-78: ~,~ 92. 10. NANIJK 93-11 15 A, 93-41 LOCATED WITHIN PROTR SEC, 19, TWP. 11 N,, RGE 5 E. UMIAT MERIDIAN LAT. '= 70' 17' .35" X -- 579,117 , 869' F,W.L., 2,627' F.S.L, .$4 .~ ~ Iq 3 2 ARCO Alaska, Inc. Subsidiory of Atlantic Richfield Company CADD FILE NO. DRAMNG NO: LK601183 ' N'A N~ .92-73A:':': ~2-73B.':::,~,,:. 22 28 Mill. 32 ' ' ' LOUNSBURY & ASSOCIATES, INc. ~,~N~EI{~ PLANNERS NANUK ~1 ~ EXPLORATORY WELL' PERMIT EXHIBIT 6.01 d185 SHEET: 2 OF2' REV; UTP 15~ AHC. 11.35" .'.'-~A~/73. t.rrP .%5~ / · .":,HC./'I 1.35~ ./' / · '~"'\'NANUK #1 SURFACE LOCATION' · _ , NANUK #1 BHL (+~o,35o) AN 60.308= "~,-, AI~""'I 1.35x... · ALK~-4.8~" ¥ .~__ ,,. ADL. ;4.47'1 '" ! 4.538= 34.,23= u'rP 19.692= HUNT ~ RE~ 3.7~ RW RES 372105 AAI ~2.5~, UTP]/7.5~ ALK4715 ADL 25538 UTP 372107 ~DL 25558 AAI '72.5 ~'UTP '"APC. 20.0~ 1-3,1-75 (COND) ALK471~' ADL 3-31-96 ADL 25557 AAI' UTP 16.1x AP'C 20.0~ ALK'4551 ' '~DL 372095 AAI 63.9= UTP 16.1= APC 20x ADL , 372096 // HUNT 3.36~ 3-31-98 ALK4557 ADL 372106 AN 83.9= UTP 16,1x , ,,i ,ALK4559' . :! NiL 372108 UTF 11- 6 UTP, ,4.6 !5579 AN 58.75s BPX 53.33= 6UTP 7.917x --11-02 [601 .5596 !.75~: 33.33= 7.917x Phillips Alaska, Inc. Nanuk #3 Nan3 slot %1 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref = Nanuq %3 Version Our ref = prop4062 License : Date printed : 12-Jan-2001 Date created : 18-Sep-2000 Last revised = 12-Jan-2001 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on 377892.500,5957572.200,999.00000,N Slot location is nT0 17 32.850,w150 59 11.690 Slot Grid coordinates are N 5957514.852, E 378142.717 Slot local coordinates are 53.28 S 251.14 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 266.43 100.00 200.00 0.00 266.43 200.00 300.00 0.00 266.43 300.00 400.00 3.00 266.43 399.95 500.00 6.00 266.43 499.63 600.00 9.00 266.43 598.77 700.00 12.00 266.43 697.08 774.88 14.25 266.43 770.00 800.00 15.00 266.43 794.31 900.00 18.00 266.43 890.18 1000.00 21.00 266.43 984.43 1100.00 24.00 266.43 1076.81 1200.00 27.00 266.43 1167.06 1300.00 30.00 266.43 1254.93 1400.00 33.00 266.43 1340.18 1500.00 36.00 266.43 1422.59 1600.00 39.00 266.43 1501.91 1662.72 40.88 266.43 1550.00 1700.00 42.00 266.43 1577.95 1743.52 43.31 266.43 1609.96 2000.00 43.31 266.43 1796.59 2004.68 43.31 266.43 1800.00 2500.00 43.31 266.43 2160.45 2540.61 43.31 266.43 2190.00 2829.19 43.31 266.43 2400.00 3000.00 43.31 266.43 2524.30 3500.00 43.31 266.43 2888.15 4000.00 43.31 266.43 3252.00 4500.00 43.31 266.43 3615.85 4779.16 43.31 266.43 3819.00 5000.00 43.31 266.43 3979.71 5143.32 43.31 266.43 4084.00 5500.00 43.31 266.43 4343.56 6000.00 43.31 266.43 4707.41 6500.00 43.31 266.43 5071.26 6609.83 43.31 266.43 5151.18 6700.00 41.51 266.73 5217.76 6800.00 39.53 267.08 5293.77 6900.00 37.54 267.47 5372.00 7000.00 35.56 267.89 5452.33 7100.00 33.57 268.36 5534.67 7200.00 31.59 268.87 5618.93 7300.00 29.62 269.45 5704.99 7396.88 27.70 270.08 5790.00 7400.00 27.64 270.10 5792.76 7500.00 25.67 270.85 5882.13 7600.00 23.70 271.70 5972.99 7616.82 23.37 271.86 5988.41 7816.80 23.37 271.86 6171.98 RECTANGULAR COORDINATES 0.00N 0.00E 0.00N 0.00E 0.00N 0.00E 0.00N 0.00E 0.16S 2.61W 0.65S 10.44W 1.46S 23.47W 2.60S 41.65W 3.66S 58.62W 4.05S 64.95W 5.82S 93.29W 7.89S 126.61W 10.28S 164.80W 12.95S 207.76W 15.92S 255 . 38W 19.18S 307.52W 22.70S 364.04W 26.49S 424.79W 28.99S 464.98W 30.53S 489.61W 32.36S 519.04W 43.31S 694.61W 43.51S 697.82W 64.65S 1036.89W 66.39S 1064.69W 78.71S 1262.24W 86.00S 1379.17W 107.34S 1721.45W 128.68S 2063.74W 150.02S 2406.02W 161.94S 2597.12W 171.37S 2748.30W 177.48S 2846.41W 192.71S 3090.58W 214.05S 3432.86W 235.39S 3775.14W 240.0SS 3850.32W 243 . 71S 3911.03W 247.22S 3975.90W 250.19S 4038.12W 252.61S 4097.62W 254.47S 4154.32W 255.78S 4208.16W 256.53S 4259.06W 256.73S 4305.52W 256.73S 4306.97W 256.37S 4351.82W 255.45S 4393.57W 255.24S 4400.29W 252 . 66S 4479.57W PROPOSAL LISTING Page 1 Your ref : Nanuq #3 Version #9 Last revised : 12-Jan-2001 GRID COORDS GEOGRAPHIC Easting Northing C O O R D I N A T E S 378142.72 5957514.85 n70 378142.72 5957514.85 n70 378142.72 5957514.85 n70 378142.72 5957514.85 n70 378140.10 5957514.73 n70 17 32.85 w150 59 11.69 17 32.85 w150 59 11.69 17 32.85 w150 59 11.69 17 32.85 w150 59 11.69 17 32.85 w150 59 11.77 378132.27 5957514.37 n70 378119.23 5957513.77 nT0 378101.03 5957512.93 nT0 378084.05 5957512.15 n70 378077.71 5957511.86 nT0 17 32.84 w150 59 11.99 17 32.84 w150 59 12.37 17 32.82 w150 59 12.90 17 32.81 w150 59 13.40 17 32.81 w150 59 13.58 378049.35 5957510.55 n70 378016.01 5957509.02 n70 377977.79 5957507.26 n70 377934.79 5957505.28 n70 377887.14 5957503.08 n70 17 32.79 w150 59 14.41 17 32.77 w150 59 15.38 17 32.75 w150 59 16.49 17 32.72 w150 59 17.74 17 32.69 w150 59 19.13 377834.95 5957500.68 n70 377778.38 5957498.07 n70 377717.58 5957495.27 n70 377677.36 5957493.42 n70 377652.72 5957492.28 nT0 17 32.66 w150 59 20.65 17 32.63 w150 59 22.30 17 32.59 w150 59 24.07 17 32.56 w150 59 25.24 17 32.55 w150 59 25.96 377623.26 5957490.93 nT0 377447.55 5957482.83 n70 377444.34 5957482.68 nT0 377105.00 5957467.05 nT0 377077.17 5957465.77 nT0 17 32.53 w150 59 26.82 17 32.42 w150 59 31.93 17 32.42 w150 59 32.03 17 32.21 w150 59 41.91 17 32.20 w150 59 42.72 376879.47 5957456.66 nT0 376762.44 5957451.27 n70 376419.89 5957435.50 n70 376077.34 5957419.72 nT0 375734.78 5957403.94 n70 17 32.08 w150 59 48.47 17 32.00 w150 59 51.88 17 31.79 w151 0 01.86 17 31.58 w151 0 11.83 17 31.37 w151 0 21.81 375543.53 5957395.13 nT0 375392.23 5957388.16 n70 375294.04 5957383.64 nT0 375049.67 5957372.38 n70 374707.12 5957356.60 n70 17 31.25 w151 0 27.37 17 31.16 w151 0 31.78 17 31.10 w151 0 34.64 17 30.95 w151 0 41.75 17 30.74 w151 0 51.73 374364.57 5957340.82 nT0 374289.32 5957337.36 nT0 374228.57 5957334.71 n70 374163.66 5957332.26 nT0 374101.40 5957330.30 nT0 17 30.53 w151 I 01.70 17 30.48 w151 I 03.89 17 30.44 w151 I 05.66 17 30.41 w151 I 07.55 17 30.38 w151 I 09.37 374041.87 5957328.86 nT0 373985.15 5957327.91 n70 373931.31 5957327.48 nT0 373880.41 5957327.55 nT0 373833.95 5957328.11 n70 17 30.36 w151 I 11.10 17 30.34 w151 I 12.75 17 30.32 w151 I 14.32 17 30.32 w151 I 15.80 17 30.31 w151 I 17.16 373832.50 5957328.13 nT0 373787.66 5957329.22 nT0 373745.94 5957330.82 n70 373739.23 5957331.14 nT0 373660.01 5957335.00 nT0 17 30.31 w151 I 17.20 17 30.32 wlS1 i 18.51 17 30.33 w151 i 19.72 17 30.33 w151 i 19.92 17 30.35 w151 I 22.23 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Doyon 19) (50.00 Ft above mean sea level). Bottom hole distance is 5187.79 on azimuth 267.46 degrees from wellhead. Total Dogleg for wellpath is 63.45 degrees. Vertical section is from wellhead on azimuth 266.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field0North Slope° Alaska Measured Inclin Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 7816.82 23.37 271.86 6172.00 252.665 4479.58W 8000.00 23.37 271.86 6340.16 250.305 4552.20W 8337.53 23.37 271.86 6650.00 245.955 4686.02W 8500.00 23.37 271.86 6799.14 243.865 4750.44W 8851.70 23.37 271.86 7121.98 239.335 4889.87W 8851.72 23.37 271.86 7122.00 239.335 4889.88W 9000.00 23.37 271.86 7258.12 237.415 4948.67W 9204.67 23.37 271.86 7446.00 234.785 5029.81W 9396.40 23.37 271.86 7622.00 232.315 5105.83W 9500.00 23.37 271.86 7717.10 230.975 5146.90W 9590.31 23.37 271.86 7800.00 229.815 5182.70W PROPOSAL LISTING Page 2 Your ref : Nanu~ #3 Version #9 Last revised = 12-Jan-2001 GRID C OORDS GEOGRA P}{ I C Easting Northing C O O R D I N A T E S 373660.00 5957335.00 n70 17 30.35 w151 I 22.23 373587.43 5957338.54 n70 17 30.38 w151 I 24.35 373453.71 5957345.06 n70 17 30.42 w151 I 28.25 373389.34 5957348.20 n70 17 30.44 w151 I 30.12 373250.01 5957355.00 n70 17 30.48 w151 I 34.19 373250.00 5957355.00 n70 17 30.48 w151 I 34.19 373191.26 5957357.87 n70 17 30.50 w151 I 35.90 373110.17 5957361.82 n70 17 30.53 w151 I 38.27 373034.22 5957365.53 n70 17 30.55 w151 I 40.48 372993.17 5957367.53 n70 17 30.56 w151 I 41.68 372957.40 5957369.27 n70 17 30.57 w151 I 42.72 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #1 and TVD from RKB (Doyon 19) (50.00 Ft above mean sea level). Bottom hole distance is 5187.79 on azimuth 267.46 degrees from wellhead. Total Dogleg for wellpath is 63.45 degrees. Vertical section is from wellhead on azimuth 266.43 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope, Alaska PROPOSAL hISTING Page 3 Your ref= Nanuq #3 Version #9 Last revised = 12-Jan-2001 Convnents in wellpath ==================== MD TVD Rectangular Coords. Comment 300 00 774 88 1662 72 1743 52 2004 68 2540 61 2829 19 4779 16 5143 32 6609 83 7396.88 7616.82 7816.80 7816.82 8337.53 8851.70 8851.72 9204.67 9396.40 9590.31 300.00 0.00N 0.00E KOP 770.00 3.66S 58.62W Permafrost 1550.00 28.99S 464.98W Base West Sak 1609.96 32.36S 519.04W EOC 1800.00 43.51S 697.82W 9 5/8" Casing Pt 2190.00 66.39S 1064.69W K-10/C-40 2400.00 78.71S 1262.24W K-5/C-30 3819.00 161.94S 2597.12W K-3 4084.00 177.48S 2846.41W K-2 5151.18 240.08S 3850.32W Begin Drop/Turn 5790.00 256.73S 4305.52W A1bian-97 5988.41 255.24S 4400.29W End Drop/Turn 6171.98 252.66S 4479.57W Tgi - Nanuk 6172.00 252.66S 4479.58W Nanuq3 TgtNanuk Rvsd 27-Dec-00 6650.00 245.95S 4686.02W Top HRZ 7121.98 239.33S 4889.87W Tgt- Kuparuk 7122.00 239.33S 4889.88W Nanuk3 TgtKup Rvsd 27-Dec-00 7446.00 234.78S 5029.81W Tgt Horizon - A19ine 7622.00 232.31S 5105.83W Nuiqsut 7800.00 229.81S 5182.70W TD - Csg Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2004.68 1800.00 43.51S 697.82W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9590.31 7800.00 229.81S 5182.70W 7" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuq3 TgtNanuk Rvsd 373660.000,5957335.000,0.0000 6172.00 252.66S 4479.58W 18-Sep-2000 Nanuk3 TgtKup Rvsd 2 373250.000,5957355.000,0.0000 7122.00 239.33S 4889.88W 18-Sep-2000 Nanuk3 Tg~Alpine Rvs 373116.000,5957362.000,0.0000 7446.00 234.50S 5023.99W 18-Sep-2000 Phillips Alaska, Inc. Nanuk #3 Nan3 slot #1 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes iNTEQ Your ref : Nanuq 93 Version #9 Our ref : prop4062 License : Date printed : 12-Jan-2001 Date created : 18-Sep-2000 Last revised : 12-Jan-2001 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 377892.500,5957572.200,999.00000,N Slot location is n70 17 32.850,w150 59 11.690 Slot Grid coordinates are N 5957514.852, E 378142.717 Slot local coordinates are 53.28 S 251.14 E Projection tYPe: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,Nor=h Slope0 Alaska PROPOSAL LISTING Page 1 Your ref : Nanuq #3 Version #9 Last revised : 12-Jan-2001 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 266.43 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 266.43 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 266.43 300.00 0.00 N 0.00 E 0.00 0.00 KOP 400.00 3.00 266.43 399.95 0.16 S 2.61 W 3.00 2.62 500.00 6.00 266.43 499.63 0.65 S 10.44 W 3.00 10.46 600.00 9.00 266.43 598.77 1.46 S 23.47 W 3.00 23.51 700.00 12.00 266.43 697.08 2.60 S 41.65 W 3.00 41.74 774.88 14.25 266.43 770.00 3.66 S 58.62 W 3.00 58.73 Permafrost 800.00 15.00 266.43 794.31 4.05 S 64.95 W 3.00 65.08 900.00 18.00 266.43 890.18 5.82 S 93.29 W 3.00 93.48 1000.00 21.00 266.43 984.43 7.89 S 126.61 W 3.00 126.85 1100.00 24.00 266.43 1076.81 10.28 S 164.80 W 3.00 165.12 1200.00 27.00 266.43 1167.06 12.95 S 207.76 W 3.00 208.16 1300.00 30.00 266.43 1254.93 15.92 S 255.38 W 3.00 255.87 1400.00 33.00 266.43 1340.18 19.18 S 307.52 W 3.00 308.12 1500.00 36.00 266.43 1422.59 22.70 S 364.04 W 3.00 364.75 1600.00 39.00 266.43 1501.91 26.49 S 424.79 W 3.00 425.62 1662.72 40.88 266.43 1550.00 28.99 S 464.98 W 3.00 465.88 Base West Sak 1700.00 42.00 266.43 1577.95 30.53 S 489.61 W 3.00 490.56 1743.52 43.31 266.43 1609.96 32.36 S 519.04 W 3.00 520.05 EOC 2000.00 43.31 266.43 1796.59 43.31 S 694.61 W 0.00 695.96 2004.68 43.31 266.43 1800.00 43.51 S 697.82 W 0.00 699.17 9 5/8" Casing Pt 2500.00 43.31 266.43 2160.45 64.65 S 1036.89 W 0.00 1038.91 2540.61 43.31 266.43 2190.00 66.39 S 1064.69 W 0.00 1066.76 K-10/C-40 2829.19 43.31 266.43 2400.00 78.71 S 1262.24 W 0.00 1264.70 K-5/C-30 3000.00 43.31 266.43 2524.30 86.00 S 1379.17 W 0.00 1381.85 3500.00 43.31 266.43 2888.15 107.34 S 1721.45 W 0.00 1724.80 4000.00 43.31 266.43 3252.00 128.68 S 2063.74 W 0.00 2067.74 4500.00 43.31 266.43 3615.85 150.02 S 2406.02 W 0.00 2410.69 4779.16 43.31 266.43 3819.00 161.94 S 2597.12 W 0.00 2602.16 K-3 5000.00 43.31 266.43 3979.71 171.37 S 2748.30 W 0.00 2753.63 5143.32 43.31 266.43 4084.00 177.48 S 2846.41 W 0.00 2851.93 K-2 5500.00 43.31 266.43 4343.56 192.71 S 3090.58 W 0.00 3096.58 6000.00 43.31 266.43 4707.41 214.05 S 3432.86 W 0.00 3439.53 6500.00 43.31 266.43 5071.26 235.39 S 3775.14 W 0.00 3782.47 6609.83 43.31 266.43 5151.18 240.08 S 3850.32 W 0.00 3857.80 Begin Drop/Turn 6700.00 41.51 266.73 5217.76 243.71 S 3911.03 W 2.00 3918.61 6800.00 39.53 267.08 5293.77 247.22 S 3975.90 W 2.00 3983.58 6900.00 37.54 267.47 5372.00 250.19 S 4038.12 W 2.00 4045.87 7000.00 35.56 267.89 5452.33 252.61 S 4097.62 W 2.00 4105.40 7100.00 33.57 268.36 5534.67 254.47 S 4154.32 W 2.00 4162.11 7200.00 31.59 268.87 5618.93 255.78 S 4208.16 W 2.00 4215.92 7300.00 29.62 269.45 5704.99 256.53 S 4259.06 W 2.00 4266.77 7396.88 27.70 270.08 5790.00 256.73 S 4305.52 W 2.00 4313.15 Albian-97 7400.00 27.64 270.10 5792.76 256.73 S 4306.97 W 2.00 4314.60 7500.00 25.67 270.85 5882.13 256.37 S 4351.82 W 2.00 4359.34 7600.00 23.70 271.70 5972.99 255.45 S 4393.57 W 2.00 4400.95 7616.82 23.37 271.86 5988.41 255.24 S 4400.29 W 2.00 4407.64 End Drop/Turn 7816.80 23.37 271.86 6171.98 252.66 S 4479.57 W 0.00 4486.61 Tgt- Nanuk All data is in feet unless otherwise stated. Coordinates from slot %1 and TVD from RKB (Doyon 19) (50.00 Ft above mean sea level). Bottom hole distance is 5187.79 on azimuth 267.46 degrees from wellhead. Total Dogleg for we11Dath is 63.45 degrees. Vertical section is from wellhead on azimuth 266.43 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #3,Nan3 Alpine Field,North Slope0 Alaska PROPOSAL LISTING Page 2 Your ref : Nanuq #3 Version Last revised : 12-Jan-2001 Measured Inclln. Azimuth True Vert R E C T A N G U L A R Dogleg Vert Depth Degrees Degrees Depth C O 0 R D I N A T B S Deg/100ft Sect 7816.82 23.37 271.86 6172.00 252.66 S 4479.58 W 0.00 4486.62 Nanuq3 TgtNanuk Rvsd 27-Dec-00 8000.00 23.37 271.86 6340.16 250.30 S 4552.20 W 0.00 4558.96 8337.53 23.37 271.86 6650.00 245.95 S 4686.02 W 0.00 4692.25 Top HRZ 8500.00 23.37 271.86 6799.14 243.86 S 4750.44 W 0.00 4756.40 8851.70 23.37 271.86 7121.98 239.33 S 4889.87 W 0.00 4895.29 Tgt- Kuparuk 8851.72 23.37 271.86 7122.00 239.33 S 4889.88 W 0.00 4895.30 Nanuk3 TgtKup Rvsd 27-Dec-00 9000.00 23.37 271.86 7258.12 237.41 S 4948.67 W 0.00 4953.85 9204.67 23.37 271.86 7446.00 234.78 S 5029.81 W 0.00 5034.67 Tgt Horizon - Alpine 9396.40 23.37 271.86 7622.00 232.31 S 5105.83 W 0.00 5110.39 Nuiqsut 9500.00 23.37 271.86 7717.10 230.97 S 5146.90 W 0.00 5151.30 9590.31 23.37 271.86 7800.00 229.81 S 5182.70 W 0.00 5186.96 TD - Csg Pt All data is in feet unless otherwise stated. Coordinates from slot #1 and TVD from RKB (Doyon 19) (50.00 Ft above mean sea level). Bo=tom hole distance is 5187.79 on azimuth 267.46 degrees from wellhead. Total Dogleg for wellpath is 63.45 degrees. Vertical section is from wellhead on azimuth 266.43 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Nanuk #30Nan3 Alpine Field,North Slope, Alaska MD TVD Rectangular Coords. PROPOSAL LISTING Page 3 Your ref : Nanuq #3 Version #9 Last revised : 12-Jan-2001 Convnents in wellpath ==================== Comment 300.00 300.00 774.88 770.00 1662.72 1550.00 174352 1609.96 200468 1800.00 254061 2190.00 282919 2400.00 477916 3819.00 514332 4084.00 660983 5151.18 7396.88 5790.00 7616.82 5988.41 7816.80 6171.98 7816.82 6172.00 8337.53 6650.00 8851.70 7121.98 8851.72 7122.00 9204.67 7446.00 9396.40 7622.00 9590.31 7800.00 0.00 N 3.66 S 28.99 S 32.36 S 43.51 S 66.39 S 78.71 S 161.94 S 177.48 S 240.08 S 256.73 S 255.24 S 252.66 S 252.66 S 245.95 S 239.33 S 239.33 S 234.78 S 232.31 S 229.81 S 0.00 58 62 464 98 519 04 697 82 1064 69 1262 24 2597 12 2846.41 3850.32 4305.52 4400.29 4479.57 4479.58 4686.02 4889.87 4889.88 5029.81 5105.83 5182.70 E KOP W Permafrost W Base West Sak W EOC W 9 5/8' Casing Pt W K-10/C-40 w K-5/C-30 w K-3 W K-2 W Begin Drop/Turn W A1bian-97 W End Drop/Turn W Tgt- Nanuk W Nanuq3 TgtNanuk Rvsd 27-Dec-00 W Top HRZ W Tgt- Kuparuk W Nanuk3 TgtKup Rvsd 27-Dec-00 W Tgt Horizon - Alpine W Nuiqsut W TD - Csg Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2004.68 1800.00 43.51S 697.82W 9 5/8" Casing 0.00 0.00 0.00N 0.00B 9590.31 7800.00 229.81S 5182.70W 7# Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised Nanuq3 TgtNanuk Rvsd 373660.000,5957335.000,0.0000 6172.00 252.66S 4479.58W 18-Sep-2000 Nenuk3 TgtKup Rvsd 2 373250.000,5957355.000,0.0000 7122.00 239.33S 4889.88W 18-Sep-2000 Nanuk3 TgtAlpine Rvs 373116.000,5957362.000,0.0000 7446.00 234.50S 5023.99W 18-Sep-2000 PHILLIPS PETROLEUM COMPANY To: Jeff Zawila Dave Bannan Scott Reynolds ATO-1464 ATO-866 ATO-838 From: Kathy Heinlein ATO-1346 Subject: Date: Pre-Drill Seismic Pore Pressure Prediction for Nanuq #3 January 21, 2000 Summary Seismic velocity data was used to predict pore pressures likely to be encountered in the proposed Nanuq #3 well .location. A local compaction trend and a local velocity to pressure gradient translation trend model were established using control from surrounding area wells (Nanuk #1, Nanuk #2). The local compaction trend and the translation trend model were applied to velocities from 3D seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the .proposed well locations. Seismic Processina The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used for pressure prediction were generated using Phillips' AVEL software, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 CDPs to minimize instabilities in .the velocity field that might result from noise, lack of signal or variations in CDP fold. Pressure Prediction Procedure Phillip's PPFG software (developed by ARCO Exploration and Production Technology) was used to calculate the predicted pore pressures. The Nanuk #1 and Nanuk #2 offset wells were used to establish both a local normal compaction trend line and local velocity vs. pressure translation trend model. The model is similar to models used for previous pressure prediction in this area (Wydrinski 1999) but has been updated based upon recent drilling results. The model is similar to the models used for pressure prediction projects at Alpine, NPRA, and Tarn. The proposed Nanuq #3 surface location is located within 1000 ft of the surface location of the Nanuk #1 well, which encountered no shallow hazards or zones of increased pressure. Procedure 1 .) A Normal Compaction Trend Line (NCTL) was determined for a series of seismic lines from the Colville 3D seismic dataset. The seismic-derived NCTLs matched the NCTL slope calculated at Nanuk #1 (-5e-5). The intercept varied slightly from the intercept found at the well (175 seismic vs 165 well). 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (&T) in the existing wells or by seismic velocities in the proposed wells, and the Interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, 3.) A translation trend model was established by comparing transit time differences (z~&T) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C2%&T**2 + Cl*&&T + CO Where C2 = 8.01e-5, C1 = .0019, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). Seismic Pore Pressure Prediction Pressure gradients were predicted for the Nanuq #3 proposed well location using 3D seismic data. Pressure gradient prediction displays are provided for the following 3D inlines and xlines, both in time and in depth. Predicted Pore Pressure Gradient Displays in Depth: Figure # Seismic Line Proposed Well Location 1 XL 1154 Nanuq #3 (surface) 3 XL 1162 Nanuq #3 (td) Predicted Pore Pressure Gradient Displays in Time with Miqrated Time Overlay: Fi_~ure # Seismic Line Proposed Well Location 2 XL 1154 Nanuq #3 (surface) 4 XL 1162 Nanuq #3 (td) Warmer colors indicate higher predicted mud weights (pore pressure gradients). No apparent shallow hazards are observed in the 3D seismic pressure analysis. It should be noted that the 3D seismic data used here has a Iow effective fold in the shallow section (above 3000 ft), therefore reducing the reliability of the shallow seismic velocity calculation. It is general practice to run shallow hazards analysis on 2D seismic where 2D data is available with a higher effective shallow fold. 2D seismic data was not available in this area at the time of this report; the 2D analysis will be run when the data becomes available. Pore Pressure Gradient Prediction at Proposed Well Locations Figure # Seismic Line Well Location 5 IL 5563, XL 1154 Nanuq #3 (surface) 6 IL 5508, XL 1162 Nanuq #3 (td) Conclusions 1 .) There are no apparent shallow hazards at the proposed Nanuq #3 well location observed on the Colville 3D seismic dataset. 2,) Overpressure has not been encountered in wells drilled previously in this area (Nanuk #1 and Nanuk #2). The surface location of the proposed Nanuq #3 well is approximately 1000 ft offset from the surface location of the Nanuk #1 well. 3.) The normal compaction trend observed in the Nanuk #1 and Nanuk #2 wells matches compaction trends observed in other area wells (Alpine and NPRA) and matches trends observed in the Colville 3D seismic dataset. 4,) A 2D seismic line will be reviewed when available to verify shallow observations (above 3000 ft). Kathy Heinlein PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Cross Section: XL1154 Method: Trend Curve NCTL: 175-5'$ Model: OST/NS Seismic Line XL1154 (depth) 'I/'$-S-,SO:ST_PPIB NAHUQ_8 0 2 4 6 0 0 2 4 6 9 0 2 4 6 8 0 2 4 6 0 0 2 4 6 0 2 4 6 0 0 2 4 6 0 0 2 4 6 8 0 2 MSLO,o,O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I~P! 1000.0, 2000,0, 3000,0. D P T 4000.0. H $000~. 6000~. 8.00 8.50 9,00 9,50 10,00 10.50 11,00 11,50 12,00 12.50 13,00 13,50 14,00 14.50 15,00 i15.50 16,00 16.50 17.00 17,50 18,00 18,50 19.00 7000~. 0000~. 9000,0 (~DP Interval = 82~ ~ Figure 1 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Cross Section: XL1154 Method: Trend Curve NCTL: 175-5.5 Model: OST/NS Seismic LineXL 1154 (time) 11S-$.-SOST_PPIi_T NANUQ._O sw NE 0.0. 0 0 0 0 0 3 0 0 0 0 100.0. 200,0". 300,0 400,0 $00,0 600,0 ?00,0 T 800,0 I M 1500~ 1400~ 1500~ PPi 8,00 8,$0 9.00 9.50 10,00 10,50 11,00 11,50 12.00 12,~ 13.00 13,50 14.50 14.E,0 15,00 15.50 16.00 16.50 17.00 17.50 18.00 18.50 19,00 1700~ 1800~' 1900~ 2000ff CDP Interval = 82.5 ft Figure 2 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/14/01 K. Heinlein Project: Nanuq Cross Section: XL1162 Method: Trend Curve NCTL: 175-5'5 Model: OST/NS Seismic Line XL 1162 (depth) I~-Ii-IBII.,.PPl NANUQ._8 8 0 2 ¢ $ 8 0 2 4 $ 8 0 2 4 16 8 0 2 ¢ $ 8 02 4. $ 8 0 2 4 $ 8 0 2 4. $ 8 0 2 4 6 8 0 2 MSL 0 ~ lO00J} 2000J) 8OOOJ~ B E P T 4000~ H $000~} 6000~ BP! ~ .~0 9,00 9,$0 10,00 10,~ 11,58 11,58 12,88 12.58 13.58 13.58 14,58 14,58 15,58 15,58 1 16,~ -- 16,58 17.58 17.58 18.00 18.58 I 19,00 ?000~ 8000~, 9000~, CDP Interval = 825 fl: Figure 3 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Cross Section: XL1162 Method: Trend Curve NCTL: 175-5.5 Model: OST/NS Seismic Line XL 1162 (time) 13~$_$_SOST_PPe_T NANUO_3 8 0 2 4 6 8 6 2 4 6 8 0 2 4 6 8 O 2 ¢ 6 8 02 4 6 8 O 2 4 6 8 O 2 4 6 8 0 2 4 6 8 0 2 0 0 0 6 O 0 0 0 0 0.0 100.0 268.0 400,0 $00.0 600,0~ 700.0 T 800.0 I M 900,0, E 1400.0, 1500,0, 1600 17oo.o 1800,0 1800,0, 8,00 8.50 9,00 9,50 10.00 10.50 11,68 11,68 12,00 12.68 15,00 13.50 14.00 14,68 15,00 15,68 16,00 16,68 17.00 17,68 18,00 18,68 19,00 CDP Interval = 82.$ R Figure 4 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Well: Nanuq 3 NCTL: 175-5.5 ~PTII (Dam ~tt0 MSL) MSL Nanuq 3: Velocity from IL5563 at XL1154 FlIT M~ 1000 2000 i000 8OOO 8OOO 4000 4000 5000 5000 6000 6000 ?000 7000 8000 8500 40 K 80 100 120 140 NCTL Intercept at QL = I?S Logmri~mie Sbpe -- -Se-IS 180 6 ? 8 9 10 11 12 13 PPG o 1;S-S-SOgT PPG o 1TK-S-SOST-I:G 14 16 16 17 18 19 20 Figure 5 PHILLIPS PETROLEUM COMPANY Pore Pressure and Fracture Gradient System 1/19/01 K. Heinlein Project: Nanuq Well: Nanuq 3 NCTL: 175-5-$ Nanuq 3: Velocity from IL5508 at XL1162 nEPTH (Deium set'lo I~k) MSL 1000 '2000 ooO0 FEET MSL 1000 2000 3000 40OO 5000 6OOO ?000 40 60 00 100 120 140 HCTL llroept at GL = Legm'ilhmM ~Olm = ~e-lS 180 6 7 8 9 10 11 o I?!i-B-SOST PPG · = _ 12 18 PPG 14 15 16 17 18 4000 5000 6O00 7000 8000 'i ....... ~8500 19 20 Figure 6 lOOO 2000 3000 4000 5000 6ooo 7000 8000 9000 10000 o 6" set @ 108'I DRILLING TIME AND MUD WEIGHT CURVE Nanuk ~2 Drill 12-1/4" Hole i i i i i i i _ . -! .................. - - -i ...... I- * - r- - - ........ 9-5/8" set @ 2219' · .......... o1_ - - I.... - i i i i i i --e--Depth ~--Mud Weight . . _1. = . i .... i . . i i i - ' '1 '-- t' - ' '! - ' ' ' '1 ''' (' ' ' -i - - - i' ' - Drill 8-1/2" Hole ....... One 120' core i _ _ _ i ...... I_ _ _ .t ' ' - i- - ' .-i - - -]- - - 1. - - i i i i i i ! i i i l - - - l- - - "t - - -I- - - 't . _ . i... j . . .i. _ . .t i i , i i i l i" - - -i - - - i- - - -i ,. _ . .i . . . l....i . . . i i i i i i ' 'l ' ' ' '1 ' ' ' i l I I i i i i i i i i I i i l i- - - -I ............ i'' - -i - - - - - -i - - - Well test conducted in Nanuk & Kuparuk from 4/17 thru 5/2 ...... .' _' -,-"' _' -.' ~- _' _' .-" - _' -," ..... ...... ,- - - Log Hole, Run 7", & Complete :~ - - . --:::::: ~ ~-,; :,,:;i:,;--,,,~[: :::::::::::::::::::::: i-: :~: :,:::-i': :,:::-',,':: :~:: 5 10 15 20 Spud 0230 hrs 3/24/00 TIME TO DRILL (DAYS) 10.8 10.6 10.4 10.2 10 9.8 9.6 t~ 9.4 ~ 9.2 8.8 8.6 8.4 8.2 25 Rig Release 1900 hrs 4/11/00 prepared by TJB 5/10/00 IJJ IJi uJ 1000 2000 3000 4000 5000 6OOO 7000 8000 9000 10000 DRILLING TIME AND MUD WEIGHT CURVE -e--Depth Nanuk #1 ~Mud Weight ' ' ' .' . ......... ' ..... ' ' ' lTD @ 7630' MD I_. ' ' I ~ni~p~3/23/1006 J 0 5 10 15 Spud 1500 hrs 3/12/96 10.8 10.6 10.4 10.2 10 9.8 9.6 9.4 9.2 8.8 8.6 8.4 8.2 TIME TO DRILL (DAYS) Rig Release 1200 hrs 3/24/96 prepared by TJB 5/10/00 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-267-1215 PHIS'LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY January 22, 2001 Daniel J. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th , Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill Phillips Alaska, Inc.- Nanuq #3 Surface Location: 2385' FSL, 102' FEL, SEC 24, T11 N, R4E Target Location: 2145' FSL, 288' FWL, SEC 24, T11N, R4E Bottom 'Hole Location: 2154' FSL, 5' FEL, SEC 23, T11 N, R4E CONFIDENTIAL Dear Commissioner Seamount: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore Alpine satellite delineation well; the Nanuq #3, with spud scheduled for February 12th 2001. Nanuq #3 will be drilled from a 500' x 500' ice pad located approximately 3.8 miles South by Southwest of Alpine. The well is designed to penetrate through the Nanuq, Kuparuk, and Alpine sandstone horizons. At the conclusion of drilling and evaluation operations, Nanuq #3 will be temporarily suspended with a kill string of tubing to 2500' MD. The temporarily suspended Nanuq #3 will await the possible development of an Alpine satellite pad at its location. Nanuq #3 will be permanently abandoned if development of this pad does not go forward. There will be a temporary storage area for drill cuttings on the ice pad. All cuttings will be hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. Waste drilling mud will be hauled to an Alpine Class II disposal well or to a KRU Class II disposal well. There are no shallow hazards expected at Nanuq #3. For the Shallow Hazards Analysis, the local compaction trend and the translation trend model were applied to velocities from 3D seismic data to predict pore pressures. The predictions show no apparent shallow hazards or large pressure anomalies at the proposed well locations.. See discussion under "Drilling Area Risks" and the attached Shallow Hazards Analysis. Please note that Phillips does not anticipate the presence of H2S in the formations to be encountered in this well; however, there will be H2S monitoring equipment operating, as is the usual practice while drilling wells in the Colville River Unit. RECEIVED Alaska Oil & Gas Cons. Commission .~ge Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: . . . 10. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). A proposed drilling program, including a request for approval of annular pumping operations. A drilling fluids program summary. Proposed cementing program and calculations. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). Pressure information as required by 20 ACC 25.035 (d)(2). Prediction of overpressured strata as required by 20 ACC 25.033 (e). Seismic refraction and reflection analysis as required by 20 ACC 25.061 (a) Nanuq #3 Drilling Hazards Summary for Posting in Doghouse Information pertinent to this application that is presently on file at the AOGCC is: . Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). A description of the drilling fluids handling system. If you have any questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Si~/re,~ ~.) Scott D. Reynolds Drilling Engineer Attachments CC: Nanuq #3 Well File / Sharon AIIsup Drake Chip Alvord Eric Reinbold ATO 1530 ANO 868 ANO 856 ~s~,~ Oi~ & GaS Co~s. Comm'~ss'~o~ American Express' ... CaSh Advance Draft 115 . . ""TOT., .~f~'l~ -~4,.4"-'.~,~.~'' ';~' ' ' ~: ' ' / '. ' I _ ~w~, ~ - NOT ~AUD FOA A~OUNT OVEA, ~ -- - ~--/~o~ ~ ~ No~ ~k ~ G~d juan. D~, N~ . History - Eft. 9/22/96, Register 139; am 11/7/99, Register 152 Authority - AS 31.05.030 ARTICLE 02 ABANDONMENT AND PLUGGING Section 105. 107. 110. 112. 11'5. 120. 140. 170. 172. Abandonment of wells Plugging well branches Suspended wells Well plugging requirements Shut-in wells Well abandonmem marker Water wells Onshore location clearance Offshore location clearance 20 AAC 25.105 ABANDONMENT OF WELLS. (a) All wells that have been permitted on a property under 20 AAC 25.005 must be. abandoned before expiration of the owner's rights in that property or if, after notice and hearing, the commission orders abandonmem for safety reasons or because the operator has effectively abandoned operations prior to the expiration of the lease. If the owner is the landowner, all wells that have been permitted on a property by 20 AAC 25.005 must be abandoned within one year following permanent cessation of the operator's oil and gas activity within the field where the wells are located or according to an abandonment schedule apProved by the commission,, unless the wells are earlier abandoned for safety reasons. (b) A well drilled onshore or'from a fixed offshore platform must be'abandoned before removal of the drill rig unless the well is completed as an oil, gas, or service well or is suspended, or unless well operations are shut down in accordance with 20 AAC 25.072. Each well drilled from a fixed offshore platform must be abandoned before, the platform is removed or dismantled. (c) A well drilled offshore from a mobile bottom-founded structure, jack-up rig, or floating drilling vessel must be abandoned before removal of the drill rig unless (1) the'well is .completed as an oil, gas, or service well; or (2) subsea equipment for well re-entry is properly installed and either the well is suspended or well operations are shut down in accordance with 20 AAC 25.072. I I I I I I I I I I I 38 ! 1 I I I I I I I I I I I I (d) A well drilled from a beach, artificial island, or shifting natural island must be abandoned before removal of the drill rig unless the well is completed as an oil, gas, or service well or is suspended, or unless well operations are shut down in accordance with 20 AAC 25.072 and plans for maintaining the integrity of the location are approved by the commission. (e) An Application for Sundry Approvals (Form 10-403) must be submitted to and approved by the commission before work is begun to abandon a well, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. The commission will attach conditions to its approval as necessary to protect freshwater and hydrocarbon resources. The Application for Sundry Approvals must include (1) the reason for abandoning the well; and (2) a statement of proposed work, including (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and Proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted after beginning work, the name of the representative of the commission who provided oral approval, and the date of the appr°val; and (E) other information pertinent to abandonment of the well. History - Eft. 4/13/80, Register 74; am 4/2/86, Register 97; am 11/7/99, RegiSter 152 Authority - ,AS 31.05.030 20 AAC 25.107 PLUGGING WELL BRANCHES. (a) An operator may plug a well branch before abandoning or suspending the well. If a well branch has not been. completed, the operator shall plug the'well branch before removal of the drill rig, unless well operations are shut down in accordance with 20. AAC 25.072. .(b) An Application for sundry Approvals (Form 10-403) must be submitted to and 'approved by the commission before work is begun to plug.a well branch, except that oral approval may be obtained from the commission if it is fOllowed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. The provisions of. 20 AAC 25.105(e) applyto the application, except that instead of including the reason for abandoning the well, the apPlication must include the reason for plugging the well branch and the reason for not immediately abandoning or suspending the well. 39 I (c) The provisions of 20 AAC 25.112(a) - (c) and (e) - (i) apply to plugging a well branch. (d) This section does not apply to the temporary plugging of a well branch for production control purposes. History - Eft. 11/7/99, Register 152 Authority - I AS 31.05.030 1 SUSPENDED WELLS. (a) If allowed under 20 AAC 25.'105, the cOmmission will, upon application by I the operator under (b) of this section, approve the suspension of a well if (1) the well I (A) encounters hydrocarbons of sufficient quality and quantity to-" 1 indicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive formation evaluation I data; 'for purposes of this paragraph, "paying quantities'' means quantities · sufficient to yield a remm in excess of operating costs; (B) is a candidate for redrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service I wells; and I (2) the operator justifies to the commission's satisfaction why the well ' I should not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include' the (^) unavailability of surface production or transportation facilities; (B) imprudence of security maintenance of a completed well in a I . shut-in status; (C) 'need for p0ol delineation and evaluation to determine the ! prudence of pool development. I (b) An Application for Sundry Approvals (Form 10-403). must be submitted to and approved.by the commission before plugging operations are begun in a well for which I ' 'Suspension is proposed, except that' oral approval may be obtained from the commission if it is followed within three days by the submissi°n of an Application for Sundry ' I Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include I (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (2) a statement of proposed work, including 40 I I I I I I I I I I I I I I I (A) information on abnormally geo-pressured strata; (B) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (D) if the Application for Sundry Approvals is submitted after beginning work, the name of the representative of the commission who provided oral approval, and the date of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, information submitted to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS 31.05.035(c), if the information is described in 20 AAC 25.071 (b); or (2) for the time that the.information has value as a trade secret, if the information is not described in 20 AAC 25.07 l(b) but is determined by the commission to constitute a trade' secret under AS 45.50.940. (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25'.112, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement. plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this. paragraph for a develoPment well drilled from a pad or platform, .if the' commission determines that the level of activity on the pad or platform assures . adequate surveillance of that development well. ' (e) Until a suspended well has been abandoned or re-entered, the operator shall maintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25.170(a)(2) or (b) or with 20 AAC 25.172(c)(2) or (d), as applicable. ., History - . Eft. 4/2/86, Register 97; am 11/7/99,' Register 152 Authority - AS 31'.05'.030 20 AAC 25.112 WELL PLUGGING REQUIREMENTS. '(a) plugging of the uncased.portion of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their respective 41. (d) Plugging of the surface of a well must meet the following requirements: (1) by the displacement method, a cement plug at least 150 feet in length, with the top of the cement no more than five feet below original ground level onshore, or between 10 and 30 feet below the mudline datum offshore, must be placed within the smallest diameter casing string; (2) either (A) all annular space open at the surface onshore, or in communication with open hole and extending to the mudline datum offshore, must be plugged with cement to seal the annular space in a manner satisfactory to the commission; or (B) all casing interior to the surface casing must be recovered to a depth of 100 feet or more below the original ground level onshore or the mudline datum offsh°re and the casing stubs plugged with cement as provided in (c)(2)(A) of this section; if the cement plug is extended to within the distance from the surface specified in (1) of this subsection, the requirement of (1) of this subsection need not be met. (e) Cement used for plugging within zones of permafrost must be designed to set before freezing and have a low heat of hydration. .. (f) Each of the respective intervals of a wellbore between the various plugs'must be filled with fluid of sufficient density to exert a hydrostatic pressure exceeding the greatest formation pressure of permeable formations in the intervals between the plugs at the time of abandonment. .' (g) Except for surface plugs, the operator shall record the actual location and integrity of cement plugs, cement retainers, or bridge plugs required by this section, using one of the following methods, which in the case of a cement retainer or bridge plug may. be performed before cement is placed on top of the plug: (1) placing sufficient weight on the plug to confh'm its location and to confirm that the plug has set and a competent plug is in place; (2) testing the plug to hold a surface pressure of 1,500 psig or 0.25 psi/ft multiplied by the true vertical depth of the casing Shoe, whichever is greater, and tagging the plug to confirm location; however, surface pressure may not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. (h) At' least 24 hours notice of plugging operations must be given to the commission so that a representative of the commission can witness the operations. ' ' . (i) The commission will, in its discretion, approve a variance from the requirements of this section if the variance provides for at least equally effective plugging of the well and prevention of fluid movement into sources of hydrocarbons or. freshwater. History - Eff. 11/7/99, Register 152' Authority -. I I I I 44 WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available' in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ ~ N ~AP~"~/D-AT'Eo'-Z."')-( 12. Permit can.be issued without administrative approval ...... ~_~ N 13. Can permit be approved before 15-day wait ........... N ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs.... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to fie-in long string to surf csg ........ 18. CMT will cover all known productive horizons ..... ' ..... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ....... ; ...... 23. 24. 25. If diverter required, does it meet regulations ......... .. L~ N Drilling fluid program schematic & equip list adequate...... ~ N . BOPEs, do they meet regulation .... ~ ........... ~ ~N ~ --~' . .~~T~ 26. BOPE press rating appropriate; test to ~'C)C3r,~ osig. ¥4~%'~e~'~w,~~,.;;;~-%~ . .... 27. Choke manifold complies w/APl RP-53 (May 84) ......... 28. Work will occur without operation shutdown. · I .~,,..~ . . '. Y wellbore seg ann. disposal para req ON/OFF SHORE 29. Is presence of H2S gas probable ................. GEOLOGY .' ~'~. ~'e~b~' ~,~e~ ' · ' 31. Daa pm~nted on potential ove~mssum zones '. ...... , ' 32. Seismic analysis of shallow gas zones ...... . ....... . AP~R .D~E_, 33. Seabed ~ndJtion suwey (E off-shorn) ............. X ~ { . ~ . o ~ ~. Cona~ namelphone for weekly pmgmss mpoAs [~plomto~ ~y] ~ N ANNU~R DISPOSAL35. With proper ~menting re~s, this plan ' (A) will ~ntain waste in a suitable receiving z0ne~ ........ APPR. DATE (B) will not ~ntaminate freshwater; or ~use d~lling waste... to su~a~;' (C) will not impair mechanical integH~ of the well used. for disposal; (D) will not damage producing fo~ation or intpair m~ve~ from a pool; and (E) will not circumvent 20 ~C 25.252 °r 20 ~C 25.412. GEOLOGY: ENGINEERING: . UlCIAnnular COMMISSION: Comments/Instructions: ~t~lol , , O Z O Z --I 'r . c:~n~soffice\wordian~diana~checklist (rev. 111011100) . . WELL PERMIT CHECKLIST FIELD & POOL COMPANY ~'~.Y~ WELL NAME~,z,~ ~' PROGRAM: exp t~dev ."n:'CL 4s sso ^.E ADMINISTRATION I ENGINEERING 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ~-~v'JAPE. R DATE . 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string .provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ......... CMT will cover all known productive horizons ..... ' ..... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate weilbore separation proposed ....... ; ..... If diverter required, does it meet regulations ...... ' .... GEOLOGY 30. '31. 32. 33. 34. Drilling.fluid program schematic & equip list adequate...... BOPEs, do they meet regulation .... ~ ........... BOPE press rating appropriate; test to ._~L_~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... redrll serv wellbore seg ann. disposal para req UNIT# 0.~'~.~/3 ON/OFF SHORE -- Is presence of H2S gas probable ................. [exploratory only]~7 N Permit can be issued wlo hydrogen sulfide measures ...... Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) ............. . Contact name/phone for weekly progress reports Y N' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface;' (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a . . pool; and (E) will n0.t' circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOLOGY: ENGINEERING: .UlClAnnular . COMMISSION: Y N Com mentsllnstructions: O Z O c:~r~soffice\wordian~diana~checklist (rev. 111011100) PHILLIPS PHILLIPS ALASKA, INC. NANUQ #3 ALPINE SA TELLITE NORTH SLOPE BOROUGH, ALASI~ FINAL WELL REPORT (March 15, 2001) Tim Smith- Sr. Logging Geologist Andrew Buchanan- Sr. L,ogging Geologist EPOCH TABLE OF CONTENTS PHILLIPS PHILLIPS ALASKA, INC. NANUQ #3 ALPINE SATELLITE NORTH SLOPE BOROUGH, ALASKA WELL INFORMATION .................................................................................................... 3 DRILLING AND GEOLOGICAL DISCUSSION ............................................................... 5 LITHOLOGY AND COMMENTS ..................................................................................... 6 DAILY ACTIVITY SUMMARY ....................................................................................... 36 SURVEY INFORMATION .............................................................................................. 38 DAILY MUD PROPERTIES ........................................................................................... 41 BIT RECORD ............. . .................................................................................................. 42 DAILY REPORTS ....................................................................................... APPENDIX A LOGS .......................................................................................................... APPENDIX B EPOCH 2 WELL INFORMATION ~ Phillips Alaska, Inc. Nanuq #3 Company: Well: Field: Region: Location: Coordinates: Elevation: County, State: APl Index: Spud Date: Total Depth: Contractor: Company Representative: Rig/Type: Epoch Logging Unit: Epoch Personal: Company Geologist: Casing Data: Hole size: WELL INFORMATION Phillips Alaska, Inc Nanuq #3 Alpine Satellite North Slope Borough Sec. 24, T. 11N, R4E N70 17' 31.69" W150 59' 25.44" Ground Level: 14.6' Drill Floor: 42.0' North Slope, Alaska 50-103-20365 03102/2001 9112.0" md; 7645.75" TVD Doyon Drilling, Inc. Dearl Gladden Ray Springer Doyon #141 Top drive Triple MLOA3 Tim Smith Andrew Buchanan Dave Bannan Surface: 9 5/8" Main hole: 7 5/8" 12 %" to 1965' 8 %"to 91'12' EPOCH 3 Mud Type: Logged Interval: Electric Logging Co: Logs Run: ~ Phillips Alaska, Inc. Nanuq #3 Bamid 147' to 9112' Sperry-Sun 1,965' to 9112' Gamma Ray-Quad Resistivity Sonic-Pressure While Drilling EPOCH 4 DRILLING AND GEOLOGICAL DISCUSSION ~ Phillips Alaska, Inc. Nanuq #3 DRILLING AND GEOLOGICAL DISCUSSION The Nanuq #3 exploration well has a primary target of the Kuparuk Sandstone, which will be cored, and two other intervals of interest, the Nanuq Sandstone and the Alpine Sandstone. Logging commenced at 147' measured depth at 03101/01, 1300 hrs. Two wet and three dry samples were caught at a 60' interval to 1580' where 30' samples were caught. Surface hole was rotated down to a depth of 400' where the build section began. The directional driller then commenced sliding to achieve the angle required for the well path. The build section was completed by 1800'. The well path was rotated out to surface casing point at 1973'. The well path is at an inclination of 39 degrees and azimuth of 268 degrees. After landing and cementing casing the drilling was continued to the firs zone of interest, the Nanuq Sandstone. 10' samples and 50' gas samples were caught over the interval from 7450' to 7700' measured depth and 6100' to 6350' Total Vertical Depth. This well path continued to 5800' where the inclination was lowered to 23 degrees for core point. Core was cut from 8522' to 8670'. Over this interval Cuttings samples were caught at 10' intervals for observation by the loggers and the company geologist. Gas samples were also caught at 20' intervals over this zone. Once core was recovered, drilling continued with sampling intervals of 30' for cuttings and 50' for gas samples. The final zone of interest is the Alpine Sandstone. For this zone beginning at 8760' measured depth and 7300' Total Vertical Depth and continuing to Total Depth at 9112' measured depth and 7647' True Vertical Depth 10' cuttings samples and 20' gas samples were caught. The time for Total Depth is 03/14101 1500hrs. EPOCH 5 LITHOLOGY AND COMMENTS 7OO 76O 810 845 900 935 98O ~ Phillips Alaska, Inc. Nanuq ~3 CONGLOMERITIC SAND = DARK GRAY TO GREENISH GRAY; MEDIUM LOWER TO COARSE TO PEBBLE SIZE GRAINS; VERY POORLY SORTED; MODERATE SPHERICITY; UNCONSOLIDATED; NO VISIBLE CEMENT; 30% QUARTS, 20% CHERT, 50% META LITHIC FRAGMENTS, (PREDOMINANTLY PHILLITE WITH COMMON OTHER METAMORPHIC ROCKS AND MINERALS), TRACE PYRITE; GRAIN SUPPORTED WITH CLAY MATRIX IN PART; ESTIMATED GOOD TO VERY GOOD POROSITY; NO VISIBLE OIL INDICATORS. SAND/CONGLOMERITIC SAND = LIGHT TO MEDIUM GRAY (SALT AND PEPPER); MEDIUM LOWER TO UPPER COARSE, OCCASIONAL PEBBLE SIZE GRAINS; MODERATE SORTING IN PART TO POOR SORTING; MODERATE SPHERICITY; UNCONSOLIDATED; NO VISIBLE CEMENT; GRAIN SUPPORTED; 40% QUARTZ, 30 % CHERT, 30% META LITHICS; ESTIMATED GOOD POROSITY; NO VISIBLE OIL INDICATORS. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH CLAY IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; COMMON MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH SAND IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; OCCASIONAL MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC; APPEARS TO BE BALLING AT THE BIT. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH CLAY IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; COMMON MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC. CLAY = LIGHT GRAY TO BROWNISH GRAY; SOFT MUSHY; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; OCCASIONAL FINE TO MEDIUM SIZE SAND GRAINS (PRESUMABLE CAVINGS); SILTY IN PART; COMMON VISIBLE GLASS SHARDS; TUFFACEOUS; HYDROPHILLIC IN PART. SANDY CLAYSTONE = LIGHT GRAY TO GREENISH GRAY; SOFT, MUSHY; MASSIVE CUTTINGS, SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; ABUNDANT LOWER MEDIUM TO UPPER COARSE SAND; GRADING TO CLAYEY MATRIX SUPPORTED SAND IN PART; COMMON VISIBLE GLASS SHARDS IN CLAY; TUFFACEOUS, HYDROPHILLIC IN PART. EPOCH 8 455 495 555 635 ~ Phillips Alaska, Inc. Nanuq #3 CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATLY ADHESION; LOW TO MODERATLY COHESION; MODERATLY SOLUBLE; CLAY IN RETURNS 100% AMORPHOUS LUMPS; LUMPY TO CLOTTED CONSISTENCY; DULL TO EARTHY LUSTER; GRITTY TEXTURE; SLIGHTLY TO MODERATLY CALCAREOUS IN PART. SAND = MEDIUM DARK GRAY TO GRAYISH BROWN OVERALL WITH INDIVIDUAL GRAINS PREDOMINANTLY LIGHT GRAY TO MEDIUM GRAY; PREDOMINANTLY UPPER MEDIUM TO LOWER MEDIUM; WELL SORTED; SUBANGULAR TO SUBROUND, OCCASIONAL ANGULAR; MODERATLY TO LOW SPHEROIDAL SPHERICITY; 100% UNCONSOLIDATED GRAINS, 30% QUARTZ, 30% CHERT, 40% METALITHIC FRAGMENTS; MODERATLY TRACE PYRITE AGGREGATE; NO VISIBLE CEMENT; GRAIN SUPPORT INFERRED; GOOD VISIBLE ESTIMATED POROSITY; TRACE MODERATLY YELLOW MINERAL FLUORESCENCE; NO CUT; NO HYDROCARBON INDICATORS. SAND = MEDIUM DARK GRAY TO GRAYISH BROWN OVERALL WITH INDIVIDUAL GRAINS TRANSPARENT TO WHITE TRANSLUCENT TO LIGHT GRAY TO MEDIUM GRAY TO DARK GRAY, OCCASIONAL PALE GREEN TO LIGHT GREEN, RARE GRAYISH PINK TO LIGHT RED; PREDOMINANTLY UPPER MEDIUM TO LOWER MEDIUM, OCCASIONAL RANGING DOWN TO LOWER FINE AND UP TO BROKEN PEBBLE; WELL SORTED; SUBANGULAR TO 'SUBROUND, OCCASIONAL ANGULAR; MODERATLY TO LOW SPHEROIDAL SPHERICITY, OCCASIONAL LOW DISCOIDAL SPHERICITY; 100% UNCONSOLIDATED GRAINS, 30% QUARTZ, 30% CHERT, 40% METALITHIC FRAGMENTS; NO VISIBLE CEMENT; GRAIN SUPPORT INFERRED; GOOD VISIBLE ESTIMATED POROSITY; TRACE MODERATLY YELLOW MINERAL FLUORESCENCE; NO CUT; NO HYDROCARBON INDICATORS. CONGLOMERATIC SAND = MEDIUM DARK GRAY TO OLIVE GRAY; GRAINS RANGING FROM BROKEN PEBBLE SIZE DOWN TO UPPER FINE TO LOWER MEDIUM; VERY POOR SORTED; SUBROUND TO SUBANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; SAMPLE 100% UNCONSOLIDATED WITH NO VISIBLE CEMENT, GRAIN SUPPORT INFERRED; FINER GRAINS PREDOMINANTLY QUARTZ WITH ABUNDANT CHERT, COARSER GRAINS VARIOUS METALITHIC FRAGMENTS (PREDOMINANTLY ARGILLITE, PHYLLITE); ABUNDANT TRACE WOOD FRAGMENTS; RARE PYRITE AGGREGATE; GOOD TO VERY GOOD VISIBLE ESTIMATED POROSITY; NO HYDROCARBON INDICATORS. EPOCH 7 2OO 290 325 390 ~ Phillips Alaska, Inc. Nanuq #3 LITHOLOGY AND COMMENTS SAND = TRANSPARENT TO WHITE TRANSLUCENT, OCCASIONAL MEDIUM GRAY TO MEDIUM DARK GRAY, PALE YELLOWISH GREEN TO GRAYISH GREEN; COARSE TO VERY COARSE, GRADING TO OCCASIONAL BIT BROKEN PEBBLE SIZE, OCCASIONAL GRADING DOWN TO UPPER FINE; POOR SORTED; PREDOMINANTLY SUBROUND WITH OCCASIONAL SUBANGULAR TO ANGULAR; PREDOMINANTLY HIGH TO MODERATLY SPHEROIDAL SPHERICITY; SAMPLE 100% UNCONSOLIDATED WITH NO VISIBLE CEMENT; PREDOMINANTLY QUARTZ WITH ABUNDANT UNDIFFERENTIATED CHERT AND OTHER LITHIC FRAGMENTS; ABUNDANT TRACE PYRITE; BECOMING INCREASING CONGLOMERATIC WITH DEPTH; TRACE WOOD FRAGMENTS BECOMING MORE COMMON WITH DEPTH; VERY GOOD VISIBLE ESTIMATED POROSITY NO HYDROCARBON INDICATORS. CLAYSTONE = MEDIUM GRAY TO OLIVE GRAY; VERY SOFT TO SOFT; MODERATLY ADHESION; LOW COHESION POSSIBLE HIGH SOLUBLE, CLAY IN RETURNS 100% AMORPHOUS LUMPS TO NEAR CURDY; DULL TO EARTHY LUSTER; GRITTY TO GRANULAR TEXTURE; SLIGHTLY CALCAREOUS. CONGLOMERATIC SAND = MEDIUM DARK GRAY TO OLIVE GRAY; GRAINS RANGING FROM BROKEN PEBBLE SIZE DOWN TO UPPER FINE TO LOWER MEDIUM; VERY POOR SORTED; SUBROUND TO SUBANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; SAMPLE 100% UNCONSOLIDATED WITH NO VISIBLE CEMENT, GRAIN SUPPORT INFERRED; FINER GRAINS PREDOMINANTLY QUARTZ WITH ABUNDANT CHERT, COARSER GRAINS VARIOUS METALITHIC FRAGMENTS (PREDOMINANTLY ARGILLITE, PHYLLITE); ABUNDANT TRACE WOOD FRAGMENTS; RARE PYRITE AGGREGATE; GOOD TO VERY GOOD VISIBLE ESTIMATED POROSITY; NO HYDROCARBON INDICATORS. CONGLOMERATIC SAND = MEDIUM DARK GRAY TO OLIVE GRAY; GRAINS RANGING FROM BROKEN PEBBLE SIZE DOWN TO UPPER FINE TO LOWER MEDIUM; VERY POOR SORTED; SUBROUND TO SUBANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; SAMPLE 100% UNCONSOLIDATED WITH NO VISIBLE CEMENT, GRAIN SUPPORT INFERRED; FINER GRAINS PREDOMINANTLY QUARTZ WITH ABUNDANT CHERT, COARSER GRAINS VARIOUS METALITHIC FRAGMENTS (PREDOMINANTLY ARGILLITE, PHYLLITE); ABUNDANT TRACE WOOD FRAGMENTS; RARE PYRITE AGGREGATE; GOOD TO VERY GOOD VISIBLE ESTIMATED POROSITY; NO HYDROCARBON INDICATORS. EPOCH 6 1025 1070 1115 1155 1200 1265 1310 ~ Phillips Alaska, Inc. Nanuq #3 SANDY CLAYSTONE = LIGHT GRAY TO GREENISH GRAY; SOFT, MUSHY; MASSIVE CUTTINGS, SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; ABUNDANT LOWER MEDIUM TO UPPER COARSE SAND; GRADING TO CLAYEY MATRIX SUPPORTED SAND IN PART; COMMON VISIBLE GLASS SHARDS IN CLAY; TUFFACEOUS, HYDROPHILLIC IN PART. CLAY = LIGHT GRAY TO BROWNISH GRAY; SOFT MUSHY; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; OCCASIONAL FINE TO MEDIUM SIZE SAND GRAINS (PRESUMABLE CAVINGS); SILTY IN PART; COMMON VISIBLE GLASS SHARDS; TUFFACEOUS; HYDROPHILLIC IN PART. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH SAND IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; OCCASIONAL MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC; APPEARS TO BE BALLING AT THE BIT. SANDY CLAYSTONE = LIGHT GRAY TO GREENISH GRAY; SOFT, MUSHY; MASSIVE CUTTINGS, SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; ABUNDANT LOWER MEDIUM TO UPPER COARSE SAND; GRADING TO CLAYEY MATRIX SUPPORTED SAND IN PART; COMMON VISIBLE GLASS SHARDS IN CLAY; TUFFACEOUS, HYDROPHILLIC IN PART. SAND -- MEDIUM GRAY; FINE UPPER TO COARSE LOWER; POOR TO MODERATE SORTING; SUBANGULAR TO SUBROUND; LOW TO MODERATE SPHERICITY; UNCONSOLIDATED; SILTY IN PART; VERY CLAYEY; ASSUMED MATRIX SUPPORTED; 30% QUARTZ; 30% CHERT 40% METALITHIC GRAINS (PHILLITE, ARGILLITE, MICA, COMMON CHLORITIZED GRAINS); TRACE COAL CAVINGS; VISIBLE GLASS SHARDS IN CLAY MATRIX; VERY POOR TO POOR ESTIMATED VISIBLE POROSITY, NO VISIBLE OIL INDICATORS. SANDY CLAYSTONE = LIGHT GRAY TO GREENISH GRAY; SOFT, MUSHY; MASSIVE CUTTINGS, SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; ABUNDANT LOWER MEDIUM TO UPPER COARSE SAND; GRADING TO CLAYEY MATRIX SUPPORTED SAND IN PART; COMMON VISIBLE GLASS SHARDS IN CLAY; TUFFACEOUS, HYDROPHILLIC IN PART. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH SAND IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; COMMON MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC. EPOCH 9 1345 1390 1430 1470 1505 1545 1590 ~ Phillips Alaska, Inc. Nanuq #3 CLAY = LIGHT GRAY TO BROWNISH GRAY; SOFT MUSHY; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; OCCASIONAL FINE TO MEDIUM SIZE SAND GRAINS (PRESUMABLE CAVINGS); SILTY IN PART; COMMON VISIBLE GLASS SHARDS; TUFFACEOUS; HYDROPHILLIC IN PART. CLAY = LIGHT GRAY TO GREENISH GRAY; SOFT; MUSHY; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; GRADES TO TUFFACEOUS SILTSTONE IN PART; COMMON GLASS SHARDS VISIBLE IN SAMPLE; TRACE SAND; HYDROPHILLIC IN PART. CLAY = LIGHT GRAY TO LIGHT GREENISH GRAY; SOFT; MUSHY TO PASTEY IN PART; MASSIVE; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; SILTY IN PART; COMMON META LITHIC BIT BROKEN PEBBLES; TRACE COALY MATERIAL; COMMON VISIBLE GLASS SHARDS. TUFFACEOUS CLAYSTONE = LIGHT GRAY; SOFT; MUSHY; INTERBEDDED WITH SAND IN PART; MASSIVE CUTTINGS; SOFT SEDIMENT FRACTURE; COMMON MEDIUM TO COARSE SIZE SAND GRAINS IN CLAY MATRIX; COMMON VISIBLE GLASS SHARDS; HYDROPHILLIC. CLAY = LIGHT GRAY TO LIGHT GREENISH GRAY; SOFT; MUSHY TO PASTEY IN PART; MASSIVE; SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; SILTY IN PART; COMMON META LITHIC BIT BROKEN PEBBLES; TRACE COALY MATERIAL; COMMON VISIBLE GLASS SHARDS. SANDY CLAYSTONE = LIGHT GRAY TO GREENISH GRAY; SOFT, MUSHY; MASSIVE CUTTINGS, SOFT SEDIMENT FRACTURE; CLAY APPEARS TO BE BALLING AT THE BIT; ABUNDANT LOWER MEDIUM TO UPPER COARSE SAND; GRADING TO CLAYEY MATRIX SUPPORTED SAND IN PART; COMMON VISIBLE GLASS SHARDS IN CLAY; TUFFACEOUS, HYDROPHILLIC IN PART. SANDATONE = MEDIUM GRAY TO GREENISH GRAY; FINE UPPER TO COARSE LOWER; MODERATE SORTING; PREDOMINANTLY SUBROUND; MODERATE SPHERICITY; SILTY; CLAYEY; 40% QUARTZ, 30% CHERT, 30% METALITHIC GRAINS; ABUNDANT CHLORITIZED GRAINS; COMMON MICA; ABUNDANT VISIBLE GLASS SHARDS; SAMPLE APPEARS BOTH MATRIX AND GRAIN SUPPORTED IN PART; ESTIMATED FAIR INTERGRANULAR POROSITY; NO VISIBLE OIL INDICATORS. EPOCH 10 ~ Phillips Alaska, Inc. Nanuq #3 1650 SAND = MEDIUM GRAY TO MEDIUM DARK GRAY OVERALL; INDIVIDUAL GRAINS MEDIUM GRAY TO LIGHT GRAY TO TRANSPARENT TO TRANSLUCENT WHITE, OCCASIONAL LIGHT GREENISH GRAY TO LIGHT BLUISH GRAY; PREDOMINANTLY UPPER FINE TO LOWER MEDIUM; WELL TO FAIR SORTED; SUBANGULAR TO SUBROUND WITH OCCASIONAL ANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; UNCONSOLIDATED GRAINS WITH NO VISIBLE CEMENT; PREDOMINANTLY GRAIN SUPPORTED WITH SOME POSSIBLE CLAY MATRIX SUPPORT; SLIGHTLY TRACE CARBONACEOUS MATERIAL; 20-30% QUARTZ, 20-30% CHERT, 4050% METALITHIC FRAGMENTS; GOOD TO FAIR VISIBLE ESTIMATED POROSITY; INTERBEDDED WITH SILTY CLAYSTONE; NO SAMPLE FLUORESCENCE; NO OTHER HYDROCARBON INDICATORS. 1730 CLAYSTONE = MEDIUM DARK GRAY TO GRAYISH BROWN TO OLIVE GRAY; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM; MODERATLY COHESIVE; MODERATLY ADHESIVE; SLIGHTLY TO MODERATLY SOLUBLE; PREDOMINANTLY MUSHY, OCCASIONAL PASTY; FIRMER CUTTINGS CRUMBLY WITH IRREGULAR FRACTURE; EARTHY LUSTER; SILTY TO GRITTY TEXTURE, OCCASIONAL SMOOTH; INTERBEDDED WITH AND GRADING TO SILTSTONE; SLIGHTLY TO MODERATLY CALCAREOUS. 1780 SAND = MEDIUM GRAY TO MEDIUM DARK GRAY OVERALL; INDIVIDUAL GRAINS MEDIUM GRAY TO LIGHT GRAY TO TRANSPARENT TO TRANSLUCENT WHITE, OCCASIONAL LIGHT GREENISH GRAY TO LIGHT BLUISH GRAY; PREDOMINANTLY UPPER FINE TO LOWER MEDIUM; WELL TO FAIR SORTED; SUBANGULAR TO SUBROUND WITH OCCASIONAL ANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; UNCONSOLIDATED GRAINS WITH NO VISIBLE CEMENT; PREDOMINANTLY GRAIN SUPPORTED WITH POSSIBLE CLAY MATRIX SUPPORT IN PART; 20-30% QUARTZ, 20-30% CHERT, 40-50% METALITHIC FRAGMENTS; GOOD TO FAIR VISIBLE ESTIMATED POROSITY; NO SAMPLE FLUORESCENCE. 1845 SILTSTONE = LIGHT BLUISH GRAY TO LIGHT GRAY; SLIGHTLY FIRM TO SOFT; CRUMBLY TO SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON-TO SLIGHTLY CALCAREOUS. 1880 SAND -- MEDIUM GRAY TO MEDIUM DARK GRAY OVERALL; INDIVIDUAL GRAINS MEDIUM GRAY TO LIGHT GRAY TO TRANSLUCENT WHITE TO TRANSPARENT; PREDOMINANTLY UPPER FINE TO LOWER MEDIUM; WELL TO FAIR TO WELL SORTED; SUBANGULAR TO SUBROUND WITH OCCASIONAL ANGULAR; MODERATLY TO HIGH SPHEROIDAL SPHERICITY; UNCONSOLIDATED GRAINS WITH NO VISIBLE CEMENT; GRAIN/MATRIX SUPPORTED; 30-40% QUARTZ; 30-40% CHERT, 20-40% METALITHIC FRAGMENTS; GOOD TO FAIR VISIBLE ESTIMATED POROSITY; NO SAMPLE FLUORESCENCE. EPOCH 11 1935 2O35 208O 2125 2180 2220 ~ Phillips Alaska, Inc. Nanuq ~3 CLAYSTONE = MEDIUM GRAY TO GRAYISH BROWN TO OLIVE GRAY; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM; MODERATLY COHESIVE; MODERATLY ADHESIVE; PREDOMINANTLY MUSHY, OCCASIONAL PASTY; MASSIVE CUTTINGS HABIT; EARTHY LUSTER; SILTY TO GRITTY TEXTURE; INFUSED WITH SAND, DECREASING WITH DEPTH; INTERBEDDED WITH AND GRADING TO SILTSTONE; SLIGHTLY TO NON CALCAREOUS. CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY TO GRAYISH BROWN TO OLIVE GRAY; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY ADHESIVE; PREDOMINANTLY MUSHY, OCCASIONAL PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INFUSED WITH QUARTZ SAND AND GLAUCONITE SAND; POSSIBLE GRADING TO SILTSTONE; NON CALCAREOUS. CLAYSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY TO GRAYISH BROWN TO OLIVE GRAY; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY ADHESIVE; PREDOMINANTLY MUSHY, OCCASIONAL PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INFUSED WITH QUARTZ SAND DECREASING WITH DEPTH; NON CALCAREOUS. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BLUISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TEXTURE, LOCALLY SLIGHTLY GRITTY; NON CALCAREOUS. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BLUISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. EPOCH 12 2260 2300 2345 2385 2425 2465 2510 ~ Phillips Alaska, Inc. Nanuq #3 CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TEXTURE, LOCALLY SLIGHTLY GRITTY; NON CALCAREOUS. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; TABULAR CUTTINGS HABIT, OCCASIONAL PLATY; EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; LOCALLY COMMON CARBONACEOUS MATERIAL LAMINATIONS; INCIPIENT TO SUBFISSILE; NON CALCAREOUS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TEXTURE, LOCALLY SLIGHTLY GRITTY; NON CALCAREOUS. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; TABULAR CUTTINGS HABIT, OCCASIONAL PLATY; EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; LOCALLY COMMON CARBONACEOUS MATERIAL LAMINATIONS; INCIPIENT TO SUBFISSILE; NON CALCAREOUS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. EPOCH 13 2550 2590 2630 2670 2730 2775 ~ Phillips Alaska, Inc. Nanuq #3 SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. CLAYSTONE -- MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TEXTURE, LOCALLY SLIGHTLY GRITTY; NON CALCAREOUS. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. SAND = TRANSLUCENT WHITE TO TRANSPARENT TO VERY LIGHT GRAY, OCCASIONAL YELLOWISH GRAY TO VERY LIGHT BROWNISH GRAY; UPPER FINE TO LOWER MEDIUM, OCCASIONAL LOWER FINE GRADING TO SILT; SUBANGULAR TO ANGULAR, OCCASIONAL SUBROUND; MODERATLY SPHERICITY; 100%. UNCONSOLIDATED GRAINS; NO VISIBLE CEMENT; 50% QUARTZ 40% CHERT, 10% VARIOUS UNDIFFERENTIATED LITHIC FRAGMENTS; ALL GRAINS INFUSING VERY SOFT, STICKY AMORPHOUS CLAY DOMINATING SAMPLE; NO DISCERNIBLE FLUORESCENCE; NO CUT. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM TO MODERATLY HARD; CRUMBLY, OCCASIONAL BRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING LOCALLY; RARE VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. [::1 EPOCH 14 2815 287O 2915 2955 3000 3040 ~ Phillips Alaska, Inc. Nanuq #3 SAND = TRANSLUCENT WHITE TO TRANSPARENT TO VERY LIGHT GRAY, OCCASIONAL YELLOWISH GRAY TO VERY LIGHT BROWNISH GRAY; UPPER FINE TO LOWER MEDIUM, OCCASIONAL LOWER FINE GRADING TO SILT; SUBANGULAR TO ANGULAR, OCCASIONAL SUBROUND; MODERATLY SPHERICITY; 100% UNCONSOLIDATED GRAINS; NO VISIBLE CEMENT; 50% QUARTZ 40% CHERT, 10% VARIOUS UNDIFFERENTIATED LITHIC FRAGMENTS; ALL GRAINS INFUSING VERY SOFT, STICKY AMORPHOUS CLAY DOMINATING SAMPLE; NO DISCERNIBLE FLUORESCENCE; NO CUT. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; NO FLUORESCENCE; NO CUT. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM TO MODERATLY HARD; CRUMBLY, OCCASIONAL BRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING LOCALLY; RARE VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. TUFF/TUFFACEOUS SILTSTONE = LIGHT GRAY TO WHITISH GRAY; SOFT TO VERY SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; MASSIVE CUTTINGS HABIT; DULL TO OCCASIONAL VITREOUS LUSTER; SILTY TEXTURE; VISIBLE GLASS SHARDS; NO VISIBLE OIL INDICATORS. CLAY = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO FIRM; MODERATELY COHESIVE; MODERATELY TO HIGHLY ADHESIVE; PASTEY; MASSIVE CUTTINGS HABIT; DULL EARTHY WITH OCCASIONAL SPARKLY LUSTER; SMOOTH TO GRITTY TEXTURE; NON-CALCAREOUS; OCCASIONAL INTERBEDDED WITH CARBONACEOUS MATERIAL; RARE FLOATING META-LITHIC FRAGMENTS. EPOCH 15 ~ Phillips Alaska, Inc. Nanuq #3 3085 TUFFACEOUS SILTSTONE = LIGHT WHITISH GRAY; WELL INDURATED IN PART; FLAKEY IN PART; ELONGATE TO TABULAR TO IRREGULAR CUTTINGS HABIT; IRREGULAR FRACTURE; EARTHY TO SPARKLY LUSTER IN PART; SILTY TO GRITTY TEXTURE; VISIBLE GLASS SHARDS; COMMON CARBONACEOUS MATERIAL AND VERY FINE SAND GRAINS; OCCASIONAL PYRITE; OCCASIONAL VISIBLE BEDDING; NO OIL INDICATORS. 3140 SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; COMMON CARBONACEOUS MATERIAL AND VERY FINE SAND IN PART; VISIBLE BEDDING IN PART; NO VISIBLE OIL INDICATORS. 3190 TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM TO MODERATLY HARD; CRUMBLY, OCCASIONAL BRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING LOCALLY; RARE VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. 3235 CLAY = MEDIUM GRAY TO BROWNISH GRAY; SOFT TO FIRM; MODERATELY COHESIVE; MODERATELY TO HIGHLY ADHESIVE; PASTEY; MASSIVE CUTTINGS HABIT; DULL EARTHY WITH OCCASIONAL SPARKLY LUSTER; SMOOTH TO GRITTY TEXTURE; NON-CALCAREOUS; OCCASIONAL INTERBEDDED WITH CARBONACEOUS MATERIAL; RARE FLOATING META-LITHIC FRAGMENTS. 3280 SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; COMMON CARBONACEOUS MATERIAL AND VERY FINE SAND IN PART; VISIBLE BEDDING IN PART; NO VISIBLE OIL INDICATORS. 333O SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS; COMMON CARBONACEOUS MATERIAL AND VERY FINE SAND IN PART; VISIBLE BEDDING IN PART; NO VISIBLE OIL INDICATORS. EPOCH 16 3380 3425 3485 354O 3605 3645 ~ Phillips Alaska, Inc. Nanuq #3 TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; SOFT TO VERY SOFT, OCCASIONAL SLIGHTLY FIRM TO MODERATLY HARD; CRUMBLY, OCCASIONAL BRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING LOCALLY; RARE VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SILTSTONE = LIGHT TO MEDIUM GRAY; SOFT TO MODERATELY INDURATED; CRUMBLY IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR CUTTINGS; DULL TO EARTHY LUSTER WITH OCCASIONAL SPARKLY LUSTER IN PART; GRITTY TEXTURE; COMMON VERY FINE TO MEDIUM LOWER SAND GRAINS; GRADING TO VERY FINE SANDSTONE IN PART; OCCASIONAL CARBONACEOUS MATERIAL; VISIBLE LAMINAE IN PART; NO VISIBLE POROSITY; NO VISIBLE OIL INDICATORS. TUFFACEOUS SILTSTONE = LIGHT WHITISH GRAY; WELL INDURATED IN PART; FLAKEY IN PART; ELONGATE TO TABULAR TO IRREGULAR CUTTINGS HABIT; IRREGULAR FRACTURE; EARTHY TO SPARKLY LUSTER IN PART; SILTY TO GRITTY TEXTURE; VISIBLE GLASS SHARDS; COMMON CARBONACEOUS MATERIAL AND VERY FINE SAND GRAINS; OCCASIONAL PYRITE; OCCASIONAL VISIBLE BEDDING; NO OIL INDICATORS. SAND = LIGHT GRAY; VERY FINE LOWER TO FINE LOWER; UNCONSOLIDATED; MODERATE TO GOOD SORTING; MODERATE TO HIGH SPHERICITY; APPEARS MATRIX SUPPORTED; TUFFACEOUS ASH/SILTSTONE MATRIX; POOR VISIBLE POROSITY, PREDOMINANTLY QUARTZ WITH MINOR LITHIC GRAINS; DULL PALE YELLOW FLUORESCENCE IN PART; NO VISIBLE CUT. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO OLIVE GRAY; EASY FRIABLE, OCCASIONAL FRIABLE TO MODERATLY HARD; UPPER VERY FINE GRADING TO SILT; FAIR SORTED; SUBANGULAR TO SUBROUND; HIGH TO MODERATLY SPHEROIDAL SPHERICITY; WEAK CALCAREOUS CEMENT; GRAIN/MATRIX SUPPORTED; HIGH TO MODERATLY ARGILLACEOUS/TUFF PACKED MATRIX; 70-80% QUARTZ, 20- 30% CHERT AND OTHER LITHIC FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; NO DISCERNIBLE SAMPLE FLUORESCENCE; NO CUT; NO OTHER HYDROCARBON INDICATORS. EPOCH 17 3705 3745 3785 3825 3885 3925 3965 ~ Phillips Alaska, Inc. Nanuq #3 CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS; NO FLUORESCENCE; NO CUT. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SANDSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO OLIVE GRAY; EASY FRIABLE, OCCASIONAL FRIABLE TO MODERATLY HARD; UPPER VERY FINE GRADING TO SILT; FAIR SORTED; SUBANGULAR TO SUBROUND; HIGH TO MODERATLY SPHEROIDAL SPHERICITY; WEAK CALCAREOUS CEMENT; GRAIN/MATRIX SUPPORTED; HIGH TO MODERATLY ARGILLACEOUS/TUFF PACKED MATRIX; 70-80% QUARTZ, 20- 30% CHERT AND OTHER LITHIC FRAGMENTS; POOR VISIBLE ESTIMATED POROSITY; NO DISCERNIBLE SAMPLE FLUORESCENCE; NO CUT; NO OTHER HYDROCARBON INDICATORS. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. SILTSTONE = LIGHT GRAY TO LIGHT MEDIUM GRAY TO LIGHT BROWNISH GRAY; SLIGHTLY FIRM TO SOFT; SUBCRUMBLY TO CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS; NO FLUORESCENCE; NO CUT. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. EPOCH 18 4020 4065 4105 4170 4210 4285 ~ Phillips Alaska, Inc. Nanuq #3 SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; TABULAR CUTTINGS HABIT, OCCASIONAL PLATY; EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; LOCALLY COMMON CARBONACEOUS MATERIAL LAMINATIONS; INCIPIENT TO SUBFISSILE; NON CALCAREOUS. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. SILTSTONE = MEDIUM GRAY TO MEDIUM BROWNISH GRAY; FIRM TO WELL INDURATED IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY CALCAREOUS; ABUNDANT MEDIUM AND COARSE GRAINS, PREDOMINANTLY RIP UP CLASTS WITH QUARTZ, CARBONACEOUS MATERIAL AND CALCITE CRYSTALS; OCCASIONAL DULL YELLOW-ORANGE MINERAL FLUORESCENCE; NO VISIBLE OIL INDICATORS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SILTSTONE = MEDIUM GRAY TO MEDIUM BROWNISH GRAY; FIRM TO WELL INDURATED IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY CALCAREOUS; ABUNDANT FINE TO COARSE GRAINS, PREDOMINANTLY RIP UP CLASTS WITH QUARTZ, CARBONACEOUS MATERIAL AND CALCITE GRAINS; OCCASIONAL DULL YELLOW SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; TABULAR CUTTINGS HABIT, OCCASIONAL PLATY; EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE; LOCALLY COMMON CARBONACEOUS MATERIAL LAMINATIONS; INCIPIENT TO SUBFISSILE; NON CALCAREOUS. EPOCH 19 4330 4400 4440 4515 4555 4625 ~ Phillips Alaska, Inc. Nanuq #3 SILTSTONE = MEDIUM GRAY TO MEDIUM BROWNISH GRAY; FIRM TO WELL INDURATED IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY CALCAREOUS; ABUNDANT FINE TO MEDIUM GRAINS, PREDOMINANTLY RIP UP CLASTS WITH QUARTZ, CARBONACEOUS MATERIAL AND CARBOANTE GRAINS; OCCASIONAL DULL YELLOW-ORANGE MINERAL FLUORESCENCE; COMMON PYRITE IN SAMPLE; NO VISIBLE OIL INDICATORS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. CARBONACEOUS SILTSTONE/SHALE = MEDIUM GRAY TO BLACKISH GRAY; PREDOMINANTLY WELL INDURATED; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY TO RESINOUS LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS IN PART; TRACE VERY FINE SAND GRAINS; ABUNDANT FINE COALY MATERIAL; CARBONACEOUS MATERIAL APPEARS ALTERED, SHOWS IRON STAINING AND ABUNDANT PYRITIZATION; CUTTINGS COMMONLY APPEAR SHISTOSE; RARE DULL YELLOW MINERAL FLUORESCENCE; NO VISIBLE OIL INDICATORS. CARBONACEOUS MATERIAL = REDDISH BROWN; HARD, FLAKEY CUTTINGS HABIT; IRREGULAR FRACTURE; RESINOUS TO SPARKLY LUSTER; FRAGMENTS APPEAR PYRITIZED IN PART; AMBER LIKE IN PART; ABUNDANT DISSEM PYRITE; SHOWS COMMON IRON STAINING; APPEARS SOMEWHAT GRAPHITIC IN PART. CARBONACEOUS SILTSTONE/SHALE = MEDIUM GRAY TO BLACKISH GRAY; PREDOMINANTLY WELL INDURATED; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY TO RESINOUS LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS IN PART; TRACE VERY FINE SAND GRAINS; ABUNDANT FINE COALY MATERIAL; CARBONACEOUS MATERIAL APPEARS ALTERED, SHOWS IRON STAINING AND ABUNDANT PYRITIZATION; RARE DULL YELLOW MINERAL FLUORESCENCE; NO VISIBLE OIL INDICATORS. CARBONACEOUS MATERIAL = REDDISH BROWN; HARD, FLAKEY CUTTINGS HABIT; IRREGULAR FRACTURE; RESINOUS TO SPARKLY LUSTER; FRAGMENTS APPEAR PYRITIZED IN PART; AMBER LIKE IN PART; ABUNDANT DISSEM PYRITE; SHOWS COMMON IRON STAINING; APPEARS SOMEWHAT GRAPHITIC IN PART; COMMONLY INTERBEDDED WiTH SlLTSTONE AND TUFFACEOUS ASH/CLAY. EPOCH 20 ~ Phillips Alaska, Inc. Nanuq #3 4675 CARBONACEOUS SILTSTONE/SHALE = MEDIUM GRAY TO BLACKISH GRAY; PREDOMINANTLY WELL INDURATED; IRREGULAR TO SUBBLOCKY FRACTURE; ELONGATE TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY TO RESINOUS LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS IN PART; TRACE VERY FINE SAND GRAINS; ABUNDANT FINE COALY MATERIAL; CARBONACEOUS MATERIAL APPEARS ALTERED, SHOWS IRON STAINING AND ABUNDANT PYRITIZATION; RARE DULL YELLOW MINERAL FLUORESCENCE; NO VISIBLE OIL INDICATORS. 4745 SILTSTONE = LIGHT GRAY TO BROWNISH GRAY; FIRM TO WELL INDURATED IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY TO IN PART RESINOUS LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS; RARE VERY FINE SAND GRAINS; ABUNDANT CARBONACEOUS MATERIAL; NO VISIBLE POROSITY; YELLOW FLUORESCENCE WITH FAST WHITE TO VERY PALE YELLOW CUT. 4800 SILTSTONE = LIGHT GRAY TO BROWNISH GRAY; FIRM TO WELL INDURATED IN PART; IRREGULAR TO SUBBLOCKY FRACTURE; SUBTABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL EARTHY TO IN PART RESINOUS LUSTER; GRITTY TEXTURE; SLIGHTLY CALCAREOUS; RARE VERY FINE SAND GRAINS; ABUNDANT CARBONACEOUS MATERIAL; NO VISIBLE POROSITY; YELLOW FLUORESCENCE WITH FAST WHITE TO VERY PALE YELLOW CUT. 4855 CARBONACEOUS SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLKY TO PLANAR FRACTURE, OCCASIONAL SUB- CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER SMOOTH TEXTURE; MODERATLY TO ABUNDANT CARBONACEOUS MATERIAL LAMINATIONS IN CUTTINGS, MATERIAL PREDOMINANTLY LOOSE IN SAMPLE AS VERY THIN FLAKES; INCIPIENT TO POSSIBLE SUBFISSILE; SLIGHTLY TO NON CALCAREOUS; MEDIUM YELLOW FLUORESCENCE WITH NO CUT. 4930 SANDSTONE = MEDIUM GRAY TO BROWNISH GRAY TO MEDIUM LIGHT GRAY, OCCASIONAL OLIVE GRAY; LOWER VERY FINE TO 'SILT; WELL TO VERY WELL SORTED; SUBANGULAR TO SUBROUND; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FRIABLE; POSSIBLE SLIGHTLY CALCIC CEMENT, O/W HIGH SILT/CLAY MATRIX CONTENT, PACKED AND SUPPORTED BY MATRIX, 20-30% CUTTINGS GRAIN SUPPORTED; PREDOMINANTLY QUARTZ WITH SOME CHERT; FAIR TO POOR VISIBLE ESTIMATED POROSITY; 20-50% MEDIUM YELLOW LOW SAMPLE FLUORESCENCE, OCCASIONAL BRIGHT YELLOW; FAST MULTI- STREAMING TO FAST LEACHING MILKY WHITE TO BRIGHT BLUEWHITE SOLVENT CUT; STRAW TO VERY PALE BROWN VISIBLE LIGHT CUT; MODERATLY YELLOW-WHITE RESIDUAL FLUORESCENCE. [:1 EPOCH 21 ~ Phillips Alaska, Inc. Nanuq #3 5015 NOTE: CARBONACEOUS MATERIAL ASSOCIATED WITH SHALE GIVES VERY SIMILAR MEDIUM TO BRIGHT YELLOW FLUORESCENCE AS THE HYDROCARBON-BEARING SANDSTONE BUT YIELDS NO DISCERNIBLE CUT. 5045 SILTSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SILTY/ARGILLACEOUS SANDSTONE; 10-30% DULL MEDIUM YELLOW SAMPLE FLUORESCENCE WITH MODERATLY TO FAST WHITE CUT. 5O95 5155 CARBONACEOUS SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLKY TO PLANAR FRACTURE, OCCASIONAL SUB- CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER SMOOTH TEXTURE; MODERATLY TO ABUNDANT CARBONACEOUS MATERIAL LAMINATIONS IN CUTTINGS, MATERIAL PREDOMINANTLY LOOSE IN SAMPLE AS VERY THIN FLAKES; INCIPIENT TO POSSIBLE SUBFISSILE; SLIGHTLY TO NON CALCAREOUS; MEDIUM YELLOW FLUORESCENCE WITH NO CUT. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, .RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. 5195 SILTSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SILTY/ARGILLACEOUS SANDSTONE; 10-20% DULL ORANGE-YELLOW SAMPLE FLUORESCENCE WITH MODERATLY YELLOWWHITE CUT. 5245 CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. 5285 CARBONACEOUS MATERIAL = DARK REDDISH BROWN TO DUSKY RED; MODERATLY FIRM TO SOFT PASTY CONSISTENCY; SUBCRUMBLY TO CRUMBLY; TABULAR CUTTINGS HABIT; WAXY LUSTER; FIBROUS TO WOODY TEXTURE; NOTABLY LARGER FRAGMENTS THAN LOOSE SHALE LAMINATION FLAKE; APPEARS NEARLY SUBBITUMINOUS. EPOCH 22 5330 5390 5495 554O 5580 ~ Phillips Alaska, Inc. Nanuq #3 CARBONACEOUS SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLKY TO PLANAR FRACTURE, OCCASIONAL SUB- CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER SMOOTH TEXTURE; MODERATLY TO ABUNDANT CARBONACEOUS MATERIAL LAMINATIONS IN CUTTINGS, VARIES LOCALLY, MATERIAL PREDOMINANTLY LOOSE IN SAMPLE AS VERY THIN FLAKES; SUBFISSlLE; NON TO POSSIBLE SLIGHTLY CALCAREOUS; MEDIUM YELLOW FLUORESCENCE WITH NO CUT. SANDSTONE = LIGHT GRAY TO MEDIUM GRAY; EASY FRIABLE TO FRIABLE; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONAL LOWER FINE, LOCALLY GRADES TO SILT; WELL SORTED OVERALL; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; WEAK CALCAREOUS CEMENT; 50% CUTTINGS PREDOMINANTLY GRAIN SUPPORTED, 50% GRAIN/MATRIX SUPPORT; CUTTINGS WITH LEAST ARG/TUFF MATERIAL HAVE GOOD VISIBLE ESTIMATED POROSITY; PREDOMINANTLY QUARTZ WITH TRACE CHERT AND RARE LITHIC FRAGMENTS; <10% DULL PALE YELLOW SAMPLE FLUORESCENCE; VERY WEAK PALE WHITE-YELLOW LEACH CUT. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE, OCCASIONAL GRADES TO SILTY; LOCAL TRACES CARBONACEOUS MATERIAL LAMINATIONS; SUBFISSILE; NON TO SLIGHTLY CALCAREOUS. SILTSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SILTY/ARGILLACEOUS SANDSTONE; NON TO SLIGHTLY CALCAREOUS. SANDSTONE = LIGHT GRAY TO MEDIUM GRAY; EASY FRIABLE TO FRIABLE; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONAL LOWER FINE, LOCALLY GRADES TO SILT; WELL SORTED OVERALL; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; MATRIX CEMENTED, POSSIBLE WEAK CALCAREOUS CEMENT; PREDOMINANTLY MATRIX SUPPORTED WITH SOME MATRIX/GRAIN SUPPORTED CUTTINGS, RARE OCCASIONAL GRAIN SUPPORTED CTNG POSSIBLE FROM UPHOLE; FAIR TO POOR VISIBLE ESTIMATED POROSITY; PREDOMINANTLY QUARTZ WITH TRACE OTHER LITHIC FRAGMENTS; 5-10% DULL PALE YELLOW SAMPLE FLUORESCENCE; WEAK PALE YELLOW-WHITE SLOW STREAMING/LEACH CUT. EPOCH 23 5655 5705 5745 5785 584O 5900 ~ Phillips Alaska, Inc. Nanuq #3 SAND = TRANSPARENT TO WHITE TRANSLUCENT; UPPER VERY FINE, OCCASIONAL LOWER VERY FINE TO SILT, OCCASIONAL LOWER FINE; WELL TO FAIR SORTED OVERALL; SUBROUND TO RND, OCCASIONAL SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; PREDOMINANTLY QUARTZ WITH SOME CHERT AND OTHER LITHIC FRAGMENTS ASSOC WITH OCCASIONAL SANDSTONE CTNG AND SILTSTONE; NO FLUORESCENCE ASSOCIATED WITH UNCONSOLIDATED SAND IN SAMPLE. CLAYSTONE = MEDIUM LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; MODERATELY FIRM TO HARD IN PART; BRITTLE TO WELL INDURATED; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL TO SUBRESINOUS LUSTER IN PART; SILTY TO GRITTY TEXTURE; COMMON COALY/CARBONACEOUS MATERIAL; OCCASIONAL VERY FINE SAND; TRACE CALCAREOUS; NO VISIBLE POROSITY; NO OIL INDICATORS. SAND LIGHT GRAY; VERY FINE LOWER TO VERY FINE UPPER WITH FINE LOWER; GRADING TO SILTSTONE IN PART; UNCONSOLIDATED; FAIR TO WELL SORTED; HIGH SPHERICITY; SUBROUND TO ROUND; 60% QUARTZ; 10% CARBONACEOUS MATERIAL; 30% LITHIC FRAGMENTS; ASSUMED GRAIN SUPPORTED WITH TUFFACEOUS ASH AND CLAY MATRIX; TRACE DISSEMINATED PALE YELLOW FLUORESCENCE FROM CARBONACEOUS MATERIAL; NO VISIBLE OIL INDICATORS. SiLTSTONE = MEDIUM GRAY TO BROWNISH GRAY; MODERATELY FIRM TO HARD IN PART; BRITTLE TO WELL INDURATED; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL TO SUBRESINOUS LUSTER IN PART; SILTY TO GRITTY TEXTURE; COMMON COALY/CARBONACEOUS MATERIAL; OCCASIONAL VERY FINE SAND; TRACE CALCAREOUS; NO VISIBLE POROSITY; NO OIL INDICATORS. EPOCH 24 ~ Phillips Alaska, Inc. Nanuq #3 5955 SILTSTONE = MEDIUM GRAY TO DARK BROWNISH GRAY; MODERATELY FIRM TO STIFF; BRITTLE TO OCCASIONALLY CRUMBLY; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; COMMONLY INTERBEDDED WITH VERY FINE SANDY HORIZONS; GRADING TO VERY FINE LOWER SANDSTONE IN PART; VERY FINE COALY MATERIAL DISSEMINATED THROUGHOUT SILTS AND SANDS; LAMINAR APPEARENCE OFTEN OBSERVED; NONE TO RARE VERY POOR INTERGRANULAR POROSITY; RARE DULL YELLOW ORANGE FLUORESCENCE OBSERVED IN SANDIER CHIPS; VERY SLOW, VERY WEAK, YELLOWWHITE CUT. 6040 SAND LIGHT GRAY; VERY FINE LOWER TO VERY FINE UPPER WITH FINE LOWER; GRADING TO SILTSTONE IN PART; UNCONSOLIDATED; FAIR TO WELL SORTED; HIGH SPHERICITY; SUBROUND TO ROUND; 60% QUARTZ; 10% CARBONACEOUS MATERIAL; 30% LITHIC FRAGMENTS; ASSUMED GRAIN SUPPORTED WITH TUFFACEOUS ASH AND CLAY MATRIX; TRACE DISSEMINATED PALE YELLOW FLUORESCENCE FROM CARBONACEOUS MATERIAL AND DULL YELLOW-ORANGE FLUORESCENCE FROM COARSER CLEAN SAND; SLOW, VERY WEAK PALE YELLOW-WHITE CUT. 6110 TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. 6150 SILTSTONE = MEDIUM GRAY TO BROWNISH GRAY; MODERATELY FIRM TO HARD IN PART; BRITTLE TO WELL INDURATED; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGE LIKE CUTTINGS HABIT; DULL TO SUBRESINOUS LUSTER IN PART; SILTY TO GRITTY TEXTURE; OCCASIONAL COALY/CARBONACEOUS MATERIAL; OCCASIONAL VERY FINE SAND; TRACE CALCAREOUS; COMMON PYRITE; NO VISIBLE OIL INDICATORS. 6205 SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE, OCCASIONAL GRADES TO SILTY; LOCAL TRACES CARBONACEOUS MATERIAL LAMINATIONS; SUBFISSILE; NON TO SLIGHTLY CALCAREOUS. 6250 TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. [::1 EPOCH 25 6305 6365 6425 6495 6540 ~ Phillips Alaska, Inc. Nanuq #3 SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE, OCCASIONAL GRADES TO SILTY; LOCAL TRACES CARBONACEOUS MATERIAL LAMINATIONS; SUBFISSILE; NON TO SLIGHTLY CALCAREOUS. THIN FLAKES; INCIPIENT TO POSSIBLE SUBFISSILE; SLIGHTLY TO MODERATLY CALCAREOUS; ABUNDANT PYRITE AGGREGATE LOOSE IN SAMPLE. SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO MEDIUM BLUISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE, OCCASIONAL BRITTLE; IRREG TO SUBBLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SANDSTONE; ABUNDANT CARBONACEOUS MATERIAL WITHIN GENERAL SAMPLE AND WITHIN INDIVIDUAL CUTTINGS OF ALL LITHOLOGIES INCLUDING SILTSTONE. SLIGHTLY TO NON CALCAREOUS. SANDSTONE = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT BLUISH GRAY; LOWER VERY FINE, OCCASIONAL UPPER VERY FINE, SOME CUTTINGS GRADATIONAL TO SILTSTONE; WELL TO VERY WELL SORTED; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FIRM; WEAK CALCAREOUS CEMENT, SOME POSSIBLE CALCAREOUS OVERGROVVTHS; LOCALLY CLAY- PACKED AND/OR SUPPORTED, O/W GRAIN SUPPORTED WITH GOOD VISIBLE ESTIMATED POROSITY; CLASTIC COMPONENT PREDOMINANTLY QUARTZ WITH CHERT, RARE GLAUC; TRACE TO LOCALLY ABUNDANT CARBONACEOUS FLECKS WITHIN CUTTINGS. CARBONACEOUS MATERIAL = DARK REDDISH BROWN TO DUSKY RED; MODERATLY FIRM TO SOFT PASTY CONSISTENCY; SUBCRUMBLY TO CRUMBLY; TABULAR CUTTINGS HABIT; WAXY LUSTER; FIBROUS TO WOODY TEXTURE; NOTABLY LARGER FRAGMENTS THAN LOOSE SHALE LAMINATION FLAKE; APPEARS NEARLY SUBBITUMINOUS. SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO MEDIUM BLUISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE, OCCASIONAL BRITTLE; IRREG TO SUBBLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SANDSTONE; ABUNDANT CARBONACEOUS MATERIAL WITHIN GENERAL SAMPLE AND WITHIN INDIVIDUAL CUTTINGS OF ALL LITHOLOGIES INCLUDING SILTSTONE. SLIGHTLY TO NON CALCAREOUS. EPOCH 26 ~ Phillips Alaska, Inc. Nanuq #3 6600 SANDSTONE = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT BLUISH GRAY; LOWER VERY FINE, OCCASIONAL UPPER VERY FINE, SOME CUTTINGS GRADATIONAL TO SILTSTONE; WELL TO VERY WELL SORTED; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FIRM; WEAK CALCAREOUS CEMENT, SOME POSSIBLE CALCAREOUS OVERGROWTHS; LOCALLY CLAY- PACKED AND/OR SUPPORTED, O/VV GRAIN SUPPORTED WITH GOOD VISIBLE ESTIMATED POROSITY; CLASTIC COMPONENT PREDOMINANTLY QUARTZ WITH CHERT, RARE GLAUC; TRACE TO LOCALLY ABUNDANT CARBONACEOUS FLECKS WITHIN CUTTINGS; TRACE MEDIUM TO BRIGHT YELLOW SAMPLE FLUORESCENCE WITH MODERATLY RAPID BRIGHT MILKY WHITE CUT, POSSIBLE FROM UPHOLE CUTTINGS, O/W FAINT DULL YELLOW FLUORESCENCE WITH NO DISCERNIBLE CUT. 669O CLAYSTONE = MEDIUM LIGHT LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; NON TO POSSIBLE SLIGHTLY CALCAREOUS. 6730 SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO MEDIUM BLUISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE, OCCASIONAL BRITTLE; IRREG TO SUBBLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SANDSTONE; ABUNDANT CARBONACEOUS MATERIAL WITHIN GENERAL SAMPLE AND WITHIN INDIVIDUAL CUTTINGS OF ALL LITHOLOGIES INCLUDING SILTSTONE. SLIGHTLY TO NON CALCAREOUS. 6790 CARBONACEOUS SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLKY TO PLANAR FRACTURE, OCCASIONAL SUB- CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER SMOOTH TEXTURE; MODERATLY TO ABUNDANT CARBONACEOUS MATERIAL LAMINATIONS IN CUTTINGS, MATERIAL PREDOMINANTLY LOOSE IN SAMPLE AS VERY THIN FLAKES; INCIPIENT TO POSSIBLE SUBFISSILE; SLIGHTLY TO MODERATLY CALCAREOUS. EPOCH 27 6845 6935 6975 7020 7080 ~ Phillips Alaska, Inc. Nanuq #3 SANDSTONE = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT BLUISH GRAY; LOWER VERY FINE, OCCASIONAL UPPER VERY FINE, SOME CUTTINGS GRADATIONAL TO SILTSTONE; WELL TO VERY WELL SORTED; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FIRM; WEAK CALCAREOUS CEMENT, SOME POSSIBLE CALCAREOUS OVERGROWTHS; LOCALLY CLAY- PACKED AND/OR SUPPORTED, O/W GRAIN SUPPORTED WITH GOOD VISIBLE ESTIMATED POROSITY; CLASTIC COMPONENT PREDOMINANTLY QUARTZ WITH CHERT, RARE GLAUC; TRACE TO LOCALLY ABUNDANT CARBONACEOUS FLECKS WITHIN CUTTINGS; TRACE MEDIUM TO BRIGHT YELLOW SAMPLE FLUORESCENCE WITH MODERATLY RAPID BRIGHT MILKY WHITE CUT, POSSIBLE FROM UPHOLE CUTTINGS, O/W FAINT DULL YELLOW FLUORESCENCE WITH NO DISCERNIBLE CUT. CLAYSTONE = MEDIUM LIGHT LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; NON CALCAREOUS. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO CLAYEY TEXTURE, OCCASIONAL GRADES TO SILTY; LOCAL TRACES CARBONACEOUS MATERIAL LAMINATIONS; SUBFISSILE; NON TO SLIGHTLY CALCAREOUS. SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO MEDIUM BLUISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE, OCCASIONAL BRITTLE; IRREG TO SUBBLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SANDSTONE; ABUNDANT CARBONACEOUS MATERIAL WITHIN GENERAL SAMPLE AND WITHIN INDIVIDUAL CUTTINGS OF ALL LiTHOLOGIES INCLUDING SILTSTONE. SLIGHTLY TO NON CALCAREOUS. CARBONACEOUS MATERIAL = REDDISH BROWN; HARD, FLAKEY CUTTINGS HABIT; IRREGULAR FRACTURE; RESINOUS TO SPARKLY LUSTER; FRAGMENTS APPEAR PYRITIZED IN PART; AMBER LIKE IN PART; ABUNDANT DISSEM PYRITE; SHOWS COMMON IRON STAINING; APPEARS SOMEWHAT GRAPHITIC IN PART; COMMONLY INTERBEDDED WITH SILTSTONE AND TUFFACEOUS ASH/CLAY. EPOCH 28 7130 7190 7280 7335 7375 ~ Phillips Alaska, Inc. Nanuq #3 SILTSTONE = MEDIUM GRAY TO MEDIUM DARK GRAY TO MEDIUM BLUISH GRAY; MODERATLY FIRM TO SLIGHTLY HARD; CRUMBLY TO SUBBRITTLE, OCCASIONAL BRITTLE; IRREG TO SUBBLOCKY FRACTURE; WEDGELIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; INTERBEDDED WITH AND GRADING TO SANDSTONE; ABUNDANT CARBONACEOUS MATERIAL WITHIN GENERAL SAMPLE AND WITHIN INDIVIDUAL CUTTINGS OF ALL LITHOLOGIES INCLUDING SILTSTONE. SLIGHTLY TO NON CALCAREOUS. SANDSTONE = VERY LIGHT GRAY TO LIGHT GRAY TO LIGHT BLUISH GRAY; LOWER VERY FINE, OCCASIONAL UPPER VERY FINE, SOME CUTTINGS GRADATIONAL TO SILTSTONE; WELL TO VERY WELL SORTED; SUBROUND TO SUBANGULAR; HIGH TO VERY HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FIRM; WEAK CALCAREOUS CEMENT, SOME POSSIBLE CALCAREOUS OVERGROWTHS; LOCALLY CLAY- PACKED AND/OR SUPPORTED, O/W GRAIN SUPPORTED.WITH GOOD VISIBLE ESTIMATED POROSITY; CLASTIC COMPONENT PREDOMINANTLY QUARTZ WITH CHERT, RARE GLAUC; TRACE TO LOCALLY ABUNDANT CARBONACEOUS FLECKS WITHIN CUTTINGS; TRACE MEDIUM TO BRIGHT YELLOW SAMPLE FLUORESCENCE WITH MODERATLY RAPID BRIGHT MILKY WHITE CUT, POSSIBLE FROM UPHOLE CUTTINGS, O/W FAINT DULL YELLOW FLUORESCENCE WITH NO DISCERNIBLE CUT. SILTSTONE = MEDIUM GRAY TO DARK BROWNISH GRAY; SOFT TO FIRM TO OCCASIONAL HARD; SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGE LIKE TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; GRITTY TEXTURE; GRADING TO VERY FINE SANDSTONE IN PART; OCCASIONAL CARBONACEOUS MATERIAL; TRACE DULL YELLOW ORANGE FLUORESCENCE IN SANDIER GRAINS; NO DISCERNABLE CUT. CLAYSTONE = MEDIUM LIGHT LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; NON TO POSSIBLE SLIGHTLY CALCAREOUS. SILTSTONE = MEDIUM GRAY TO DARK BROWNISH GRAY; SOFT TO FIRM TO OCCASIONALLY HARD; SUBBRITTLE; IRREGULAR TO SUBBLOCKY FRACTURE; WEDGE LIKE TO TABULAR TO OCCASIONAL MASSIVE CUTTINGS HABIT; EARTHY LUSTER; GRITTY TEXTURE; PREDOMINANTLY QUARTZOSE WITH ABUNDANT CLAYS; OCCASIONALLY GRADING TO VERY FINE SAND STONE IN PART; COMMON COALY MATERIAL; COMMONLY INTERBEDDED WITH CLAYS; TRACE YELLOWORANGE FLUORESCENCE; NO DISERNABLE CUT. EPOCH 29 ~ Phillips Alaska, Inc. Nanuq #3 7435 CLAYSTONE = MEDIUM LIGHT GRAY; SOFT TO MUSHY; LOW TO MODERATLY COHESIVE; MODERATE TO HIGH ADHESIVE;MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; FRACTURE NOT EVIDENT; EARTHY TO DULL LUSTER; CLAYEY TO GRITTY; TRACE CALCAREOUS IN PART. 7475 CARBONACEOUS MATERIAL = REDDISH BROWN; HARD, FLAKEY CUTTINGS HABIT; IRREGULAR FRACTURE; RESINOUS TO SPARKLY LUSTER; FRAGMENTS APPEAR PYRITIZED IN PART; AMBER LIKE IN PART; ABUNDANT DISSEM PYRITE; SHOWS COMMON IRON STAINING; APPEARS SOMEWHAT GRAPHITIC IN PART; COMMONLY INTERBEDDED WITH SILTSTONE AND TUFFACEOUS ASH/CLAY. 7525 SANDSTONE = LIGHT GRAY WITH DARK SPECKS; CONSOLIDATED; VERY FINE LOWER TO OCCASIONAL MEDIUM LOWER; ANGULAR TO SUBROUND; MODERATE SPHERICITY; GRAIN SUPPORTED; MODERATELY TO WELL CEMENTED; SILICEOUS CEMENT; LITTLE TO NO MATRIX MATERIAL; OCCASIONAL COALY MATERIAL ( APPORX. SAME SIZE AS SAND GRAINS); MODERATELY CALCAREOUS; ESTIMATED FAIR INTERGRANULAR POROSITY; SAMPLE SHOWS SLIGHTLY PALE YELLOW FLUORESCENCE; MODERATE TO SLIGHTLY SLOW, MODERATE TO STRONG MILKY YELLOWISH WHITE FLUORESCENT CUT. 7595 SAND/SANDSTONE = LIGHT TO MEDIUM LIGHT GRAY; VERY FINE TO FINE WITH RARE MEDIUM LOWER GRAINS; ANGULAR TO OCCASIONAL SUBROUND; LOW TO MODERATE SPHERICITY; WELL TO MODERATE SORTING; GRAIN SUPPORTED; PREDOMINANTLY UNCONSOLIDATED; COMPOSED OF 60% QUARTZ, 20% CHERT, 20% LITHIC AND COALY GRAINS; SLIGHTLY CALCAREOUS; ESTIMATED GOOD POROSITY; STRONG WHITISH YELLOW FLUORESCENCE; FAST, STRONG, STREAMING, YELLOWlSHWHITE CUT. 766O CARBONACEOUS MATERIAL = DARK REDDISH BROWN TO DUSKY RED, OCCASIONAL OLIVE BLACK; MODERATLY FIRM TO SLIGHTLY HARD, OCCASIONAL SOFT; CRUMBLY TO BRITTLE, OCCASIONAL PASTY; IRREGULAR TO BLOCKY FRACTURE; TABULAR CUTTINGS HABIT, OCCASIONAL PLATY TO FLAKY; DULL TO WAXY LUSTER; SMOOTH TO MATTE TEXTURE; SOME CUTTINGS APPEAR SUBBITUMINOUS EPOCH 30 7720 7805 7845 7895 7940 ~ Phillips Alaska, Inc. Nanuq #3 SANDSTONE = LIGHT GRAY TO LIGHT BLUISH GRAY, OCCASIONAL GREENISH GRAY; FRIABLE TO FIRM FRIABLE, OCCASIONAL MODERATLY HARD; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONAL UP TO UPPER FINE PREDOMINANTLY WELL SORTED; ANGULAR TO SUBANGULAR; MODERATLY SPHEROIDAL SPHERICITY, OCCASIONAL LOW DISCOIDAL SPHERICITY; WEAK CALCAREOUS OVERGROWTH CEMENTATION; LOW TUFF CLAY MATRIX; GRAIN SUPPORTED; 70-80% QUARTZ WITH 10-20% UNDIFFERENTIATED CHERT, TRACE-10% DETRITAL COAL/COALY MATERIAL FRAGMENTS; FAIR TO POOR VISIBLE ESTIMATED POROSITY; POOR ESTIMATED PERMEABILITY; MEDIUM TO BRIGHT PALE YELLOW SAMPLE FLUORESCENCE; MODERATLY TO SLOW MILKY-WHITE BLOOMING CUT; DULL MEDIUM YELLOW RESIDUAL FLUORESCENCEESCENCE. TUFF = VERY LIGHT GRAY TO YELLOWISH GRAY TO WHITE; VERY SOFT TO SOFT; CRUMBLY; IRREGULAR TO SUBBLOCKY FRACTURE; NODULAR CUTTINGS HABIT; DULL TO SLIGHTLY WAXY LUSTER; SMOOTH TEXTURE, OCCASIONAL SILTY; VISIBLE GLASS SHARDS; THIN BANDING IN PART; VERY FAINT DULL YELLOW FLUORESCENCE; NO CUT. SILTSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO VERY FIRM; CRUMBLY TO SUBBRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABLR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TEXTURE GRADING TO SMOOTH AND GRITTY AS LITHOLOGY VARIES & GRADES BETWEEN SILTY SHALE/CLAYSTONE AND SILTY SANDSTONE, THINLY INTERBEDDED AND/OR GRADATIONAL, PREDOMINANTLY VERY SLIGHTLY CALCAREOUS. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITTLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE AS GRADES TO SILTY SHALE/SILTSTONE; RARE TRACES CARBONACEOUS MATERIAL; SUBFISSILE; NON TO VERY SLIGHTLY CALCAREOUS. CLAYSTONE = MEDIUM LIGHT LIGHT GRAY TO LIGHT GRAY, OCCASIONAL GRAYISH BROWN; SOFT TO VERY SOFT, RARE OCCASIONAL SLIGHTLY FIRM; LOW TO MODERATLY COHESIVE; MODERATLY TO HIGH ADHESIVE; MUSHY TO PASTY; MASSIVE CUTTINGS HABIT; EARTHY TO DULL LUSTER; SILTY TO GRITTY TEXTURE; SLIGHTLY TO NON CALCAREOUS. EPOCH 31 7980 8070 8120 8210 ~ Phillips Alaska, Inc. Nanuq #3 SANDSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY TO LIGHT BLUISH GRAY; EASY FRIABLE TO FIRM FRIABLE; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONAL LOWER FINE; PREDOMINANTLY WELL SORTED; SUBANGULAR TO SUBROUND; HIGH TO MODERATLY SPHEROIDAL SPHERICITY; WEAK CALCAREOUS OVERGROWTH CEMENTATION; LOCALLY VARYING AMTS ARGILLACEOUS/TUFFACEOUS CLAY MATRIX AND MATRIX SUPPORT, OCCASIONAL GRAIN SUPPORT POSSIBLE UPHOLE CTNG; 60-80% QUARTZ, BALANCE OTHER LITHIC FRAGMENTS INCLUDING TRACE COALLY FRAGMENTS; POOR TO FAIR VISIBLE ESTIMATED POROSITY, OCCASIONAL GOOD WITH LOW CLAY PACKING; DULL YELLOW TO MEDIUM YELLOW SAMPLE FLUORESCENCE; SLOW, OCCASIONAL MODERATLY MILKY WHITE BLOOMING/LEACHING CUT; DULL DEEP YELLOW RESIDUAL FLUORESCENCE. SILTSTONE = MEDIUM DARK GRAY TO BROWNISH GRAY; MODERATLY FIRM TO VERY FIRM; CRUMBLY TO SUBBRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABLR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TEXTURE GRADING TO SMOOTH AND GRITTY AS LITHOLOGY VARIES & GRADES BETWEEN SILTY SHALE/CLAYSTONE AND SILTY SANDSTONE, THINLY INTERBEDDED AND/OR GRADATIONAL, PREDOMINANTLY VERY SLIGHTLY CALCAREOUS. SANDSTONE = LIGHT GRAY TO MEDIUM LIGHT GRAY TO LIGHT BLUISH GRAY; EASY FRIABLE TO FIRM FRIABLE; LOWER VERY FINE TO UPPER VERY FINE, OCCASIONAL LOWER FINE; PREDOMINANTLY WELL SORTED; SUBANGULAR TO SUBROUND; HIGH TO MODERATLY SPHEROIDAL SPHERICITY; WEAK CALCAREOUS OVERGROWTH CEMENTATION; LOCALLY VARYING AMTS ARGILLACEOUS/TUFFACEOUS CLAY MATRIX AND MATRIX SUPPORT, OCCASIONAL GRAIN SUPPORT POSSIBLE UPHOLE CTNG; 60-80% QUARTZ, BALANCE OTHER LITHIC FRAGMENTS INCLUDING TRACE COALLY FRAGMENTS; POOR TO FAIR VISIBLE ESTIMATED POROSITY, OCCASIONAL GOOD WITH LOW CLAY PACKING; DULL YELLOW TO MEDIUM YELLOW SAMPLE FLUORESCENCE; SLOW, OCCASIONAL MODERATLY MILKY WHITE BLOOMING/LEACHING CUT; DULL DEEP YELLOW RESIDUAL FLUORESCENCE. SHALE = MEDIUM GRAY TO MEDIUM DARK GRAY TO BROWNISH GRAY; VERY FIRM TO SLIGHTLY HARD; BRITTLE TO SUBBRITrLE; BLOCKY TO PLANAR FRACTURE, OCCASIONAL SUB-CONCHOIDAL; PLATY CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE AS GRADES TO SILTY SHALE/SILTSTONE; RARE TRACES CARBONACEOUS MATERIAL; SUBFISSlLE; NON TO VERY SLIGHTLY CALCAREOUS. [:l EPOCH 32 ~ Phillips Alaska, Inc. Nanuq #3 8255 CARBONACEOUS SHALE = MEDIUM GRAY TO OLIVE GRAY, OCCASIONAL MEDIUM DARK GRAY; MODERATLY FIRM TO SLIGHTLY FIRM, OCCASIONAL VERY FIRM; CRUMBLY TO SUBBRITTLE; SUBPLANAR TO BLOCKY FRACTURE; FLAKY TO TABULAR CUTTINGS HABIT; EARTHY TO DULL LUSTER; SMOOTH TO SLIGHTLY SILTY TEXTURE; MODERATLY TO ABUNDANT VERY THIN LAMINATIONS OF CARBONACEOUS MATERIAL WITHIN CUTTINGS AND LOOSE WITHIN SAMPLE; MODERATLY ABUNDANT LOOSE PYRITE AGGREGATE AND NODULES IN ASSOC SAMPLE. 8315 CARBONACEOUS SHALE = MEDIUM BROWNISH GRAY TO BROWNISH BLACK; MODERATELY FIRM; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; FLAKEY TO TABULAR ELONGATE CUTTINGS HABIT; EARTHY TO SUBRESINOUS LUSTER; SMOOTY TO GRITI'Y TEXTURE; APPEARS AS INTERBEDS OF CARBONACEOUS MATERIAL AND SHALE; ABUNDANT PYRITE IN CUTTINGS AND LOOSE IN SAMPLE. 8365 CARBONACEOUS SHALE = MEDIUM BROWNISH GRAY TO BROWNISH BLACK; MODERATELY FIRM; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; FLAKEY TO TABULAR ELONGATE CUTTINGS HABIT; CHIPS INCREASINGLY ELONGATE AND CURVED; EARTHY TO RESINOUS LUSTER; SMOOTY TO GRITTY TEXTURE; APPEARS AS INTERBEDS OF CARBONACEOUS MATERIAL AND SHALE; SAMPLES ARE VERY PYRITIC; PYRITE DISSEMINATED THROUGH OUT CARBONACEOUS LAMINATIONS. 8425 CARBONACEOUS SHALE = MEDIUM BROWNISH GRAY TO BROWNISH BLACK; MODERATELY FIRM; CRUMBLY TO SUBBRITTLE; PLANAR TO BLOCKY FRACTURE; FLAKEY TO TABULAR ELONGATE CUTTINGS HABIT; EARTHY TO SUBRESINOUS LUSTER; SMOOTY TO GRITTY TEXTURE; APPEARS AS INTERBEDS OF CARBONACEOUS MATERIAL AND SHALE; SLIGHT DECREASE IN CARBONACEOUS MATERIAL CONTENT 8430' DOWN; VERY PYRITIC; PYRITE DISSEMINATED THROUGH OUT CARBONACEOUS MATERIAL AS WELL AS OCCURING AS DESCRETE GRAINS. 8490 NOTE: DRILL TO 8522', TRIP OUT OF HOLE TO CORE.CORE FROM 8522' TO .8569'. EPOCH 33 8505 8580 862O 8665 8710 8755 ~ Phillips Alaska, Inc. Nanuq #3 SAND = TRANSPARENT TO YELLOWISH GRAY TO VERY LIGHT BROWN, OCCASIONAL TRANSLUCENT WHITE; PREDOMINANTLY UPPER FINE TO LOWER MEDIUM, OCCASIONAL LOWER FINE, RARE OCCASIONAL UPPER MEDIUM; WELL TO FAIR SORTED; SUBROUND TO SUBANGULAR, OCCASIONAL RND; HIGH SPHEROIDAL SPHERICITY; PREDOMINANTLY UN- CONS QUARTZ WITH TRACE HARD CMTD SANDSTONE, SANDY SILTSTONE, AND OTHER LITHIC FRAGMENTS; PREDOMINANTLY GRAIN SUPPORT INFERRED; GOOD TO VERY GOOD VISIBLE ESTIMATED POROSITY; BRIGHT MEDIUM YELLOW- LOW TO DULL YELLOW-GOLD SAMPLE FLUORESCENCE; INSTANT MILKY-WHITE CUT WITH SLOW STREAMING CUT FROM SANDSTONE AND SILT- STONE; VISIBLE OIL STAINING ON SOME GRAINS. SHALE = REDDISH BROWN TO BROWNISH DARK GRAY; VERY FIRM TO HARD; BRITTLE TO SUBBRITTLE FRACTURE; BLOCKY TO IRREGULAR FRACTURE; TABULAR TO ELONGATE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE; RARE TRACE PYRITE; NON- CALCAREOUS. SHALE = REDDISH BROWN AND BROWNISH DARK GRAY; VERY FIRM TO HARD; BRITTLE TO SUBBRITTLE FRACTURE; BLOCKY TO IRREGULAR FRACTURE; TABULAR TO ELONGATE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TEXTURE; RARE TRACE PYRITE; NON- CALCAREOUS; SUBFISSILE TO FISSILE; MICROMICACEOUS IN PART. SHALE = REDDISH BROWN TO GRAYISH BROWN; FIRM TO OCCASIONAL VERY FIRM; BRITTLE TO SUBBRITTLE FRACTURE; BLOCKY TO IRREGULAR FRACTURE; TABULAR TO ELONGATE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE IN PART; RARE TRACE PYRITE; CALCAREOUS; SUBFISSILE; MICROMICACEOUS IN PART; SLIGHTLY SILTY IN PART. SHALE = REDDISH BROWN TO GRAYISH BROWN; FIRM TO OCCASIONAL VERY FIRM; BRITTLE TO SUBBRITTLE FRACTURE; BLOCKY TO IRREGULAR FRACTURE; TABULAR TO ELONGATE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE IN PART; RARE TRACE PYRITE; CALCAREOUS; SUBFISSILE; MICROMICACEOUS IN PART; SLIGHTLY SILTY IN PART. SILTSTONE = LIGHT GRAY; PREDOMINANTLY QUARTZOSE WITH OCCASIONAL CARBONACEOUS MATERIAL; FIRM TO HARD; BLOCKY TO IRREGULAR FRACTURE; MASSIVE CUTTINGS HABIT; EARTHY LUSTER; SILTY TO GRITTY; NON-CALCAREOUS; TRACE DULL YELLOW- ORANGE FLUORESCENCE WITH NO OBSERVED CUT; SAMPLE CONTAINS ABUNDANT PYRITE; COMMON MEDIUM TO COARSE QUARTZ SAND GRAINS AND TRACE PEBBLE SIZE GRAINS. EPOCH 34 ~ Phillips Alaska, Inc. Nanuq #3 8810 SHALE = REDDISH BROWN TO GRAYISH BROWN; FIRM TO OCCASIONAL VERY FIRM; BRITTLE TO SUBBRITTLE FRACTURE; BLOCKY TO IRREGULAR FRACTURE; TABULAR TO ELONGATE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SMOOTH TO SILTY TEXTURE IN PART; COMMON PYRITE; NON-CALCAREOUS; INCREASINGLY SILTY; RARE GLAUCONITE FROM 8820'. 8855 SANDSTONE/SAND = LIGHT GRAY TO VERY LIGHTGRAY TO LIGHT BLUISH GRAY, OCCASIONAL GRADING TO LIGHT OLIVE GRAY TO GREENISH GRAY; INDIVIDUAL GRAINS TRANSPARENT TO WHITE TRANSLUCENT, OCCASIONAL GRAYISH GREEN; CONSL CUTTINGS PREDOMINANTLY UPPER VERY FINE TO LOWER VERY FINE OCCASIONAL GRADING TO SILT, LOOSE GRAINS PREDOMINANTLY UPPER VERY FINE TO UPPER FINE, OCCASIONAL MEDIUM; OVERALL WELL TO FAIR SORTED, LOCALLY VERY WELL SORTED; SUBROUND TO SUBANGULAR, OCCASIONAL ROUNDED; HIGH SPHEROIDAL SPHERICITY; FIRM FRIABLE TO EASY FRIABLE, OCCASIONAL MODERATLY HARD; WEAK TO MODERATLY CALCAREOUS OVERGROWTH/CEMENT; PREDOMINANTLY GRAIN SUPPORTED; 70-80% QUARTZ, 20-30% UNDIFFER CHERT, TRACE TO5% GLAUCONITE; LOCALLY VARYING AMTS ARGILLACEOUS CLAY PACKING AND SILTY CONTENT; FAIR TO GOOD VISIBLE ESTIMATED POROSITY; 10- 50% BRIGHT PALE YELLOW SAMPLE FLUORESCENCE; MODERATLY TO SLOW MULTI STREAMING MILKY BLUE-WHITE CUT; MODERATLY CRUSH CUT; VERY PALE STRAW VISIBLE LIGHT CUT PALE YELLOW-WHITE RESIDUAL FLUORESCENCE. 8970 SILTSTONE = MEDIUM LIGHT GRAY TO MEDIUM GRAY TO BROWNISH GRAY; FIRM TO MODERATLY HARD; CRUMBLY TO BRITTLE; IRREGULAR TO BLOCKY FRACTURE; TABULAR TO WEDGELIKE CUTTINGS HABIT; DULL TO EARTHY LUSTER; SILTY TO GRITTY TEXTURE; LOCALLY INTERBEDDED WITH SHALE AND SANDSTONE; BECOMING MORE GRADATION- AL BETWEEN SILTSTONE AND SANDSTONE WITH DEPTH; SLIGHTLY CALCAREOUS, OCCASIONAL NON CALCAREOUS. 9020 SANDSTONE = LIGHT GRAY TO OLIVE GRAY TO PALE YELLOWISH BROWN, OCCASIONAL BLUISH GRAY TO GREENISH GRAY HUES; LOWER VERY FINE TO UPPER VERY FINE GRAIN, OCCASIONAL LOWER FINE TO UPPER FINE, OVERALL BECOMING MORE SILTY WITH DEPTH; WELL SORTED; SUBANGULAR TO SUBROUND; HIGH SPHEROIDAL SPHERICITY; EASY FRIABLE TO FIRM FRIABLE, OCCASIONAL MODERATLY HARD; MODERATLY CALCAREOUS OVERGROWTH/CEMENT; SLIGHTLY TO MODERATLY ARGILLACEOUS PACKED; GRAIN TO SOME MAT- RIX SUPPORTED; FAIR TO POOR VISIBLE ESTIMATED POR- OSITY, OCCASIONAL GOOD; BRIGHT PALE YELLOW SAM- PLE FLUORESCENCE; MODERATLY TO SLOW MULTI- STREAMING TO BLOOMING MILKY BLUE- WHITE CUT; LIGHT STRAW TO PALE LIGHT BROWN VISIBLE CUT; DULL TO PALE MEDIUM YELLOW RESIDUAL FLUORESCENCE. EPOCH 35 DAILY ACTIVITY SUMMARY ~ Phillips Alaska, Inc. Nanuq #3 DALLY ACTIVITY SUMMARY 03/02/01 0600 hrs: Pick up 5" drill pipe to make up stands; pick up and run in BHA; held safety meeting for all personal and service hands; continued to pick up BHA and load MWD; flood conductor barrel and check for leaks. Started to drill ahead surface hole at 140' measured depth. WOB: 18-23, PP: 1350, RPM rotating: 80. The 0600hrs depth was 1140' measured depth. 03/03/01 0600 hrs: Drilled ahead 1.2 %" surface hole build section with surveys as required. The drilling parameters were WOB: 18-23, PP: 1350-1375, RPM rotating: 80. Drilling continued to surface casing point at 1973' measured depth. Then bottoms up were circulated before the wiper trip; circulated and conditioned mud for casing run; observe well; pump dry job and pull put of hole for casing; lay down bottom hole assembly. 03/04/01 0600hrs: Lay down MWD, mud motor and bit; rig to and run casing; circulate and condition mud for cement; rig to and run cement; nipple up BOPE. 03/05/01 0600hrs: Continue rigging up and test B.O.P.E.: 250 psi Iow and 5000 psi high - okay. Install wear ring; Pick up 5" drill pipe and stand back. Conducted a spill drill. Continue picking up 5" drill pipe and standing back. Pick and make up BHA #2. Conducted D6 drill (stripping into hole). Test annular to 2500 psi for 5 minutes. Blow down Choke and kill lines; trip into hole and tag cement at 1872'. Test casing to 2500 psi. Drill out cement and shoe. 03/06/01 0600hrs: Conduct FIT - result was Iow. Circulated hole clean and pull out of hole for cement squeeze. Lay down BHA; run into hole slick and rig to and run cement; squeeze for 6 hours. 'Pull put of hole and make up BHA #3. 03/07/01 0600hrs: Continue to pick up bottom hole assembly; run into hole and tag cement at 1782'. Drill out cement from 1782'-2013'; continue to drill formation to 2022'. Circulate hole clean and run FIT (Iow). Returned to bottom and Drill ahead 8 %" deviated hole to 3047'. Pump high viscosity, high-density sweep to control rising ECD's. Continued to drill ahead to a 0600hrs depth of 3271'. The drilling parameters were: W.O.B. 3-7k, RPM rotating 40, Pump Pressure 1600- 1700psi. 03/08/01 0600hrs: Continued to drill ahead 8 %' directional hole to a depth of 4005'. Circulated hole clean and pumped a weighted high viscosity sweep before the wiper trip to 1965'. Ran into hole washing and reaming to bottom as required. Drilled ahead to a 0600hrs depth of 4492' with the drilling parameters: W.O.B. 3- 20K, RPM rotating 70, Pump Pressure 1800-2200 psi. 03/10/01 0600hrs: Continued to drill ahead 8 %" directional hole to 6234' with the parameters W.O.B. 3-12K, RPM 60, Pump Pressure 2000-2300 psi. Circulated gl EPOCH 36 ~ Phillips Alaska, Inc. Nanuq #3 hole clean and pumped a weighted high viscosity sweep before starting the wiper trip to 4000' 03/10/01 0600hrs: Continue wiper trip; run into hole and wash to bottom; circulate hole clean to control ECD's. Start drilling with: 5-25K W.O.B; 2000-2400 Pump Pressure and 60 RPM. Broke circulation and removed a joint of pipe to work on swivel packing. Picked up joint of pipe and continued drilling ahead with the same parameters to a 0600hrs depth of 7373'. 03/11/01 0600hrs: Continued to drill ahead to core point at 8522' with 8-30K W.O.B.; 2400 to 3000 psi Pump Pressure and 70 rpm rotating. Circulated hole clean and begin wiper trip back 14 stands. 03/12/01 0600hrs: Continue wiper trip and run back to bottom washing and reaming as required. Circulate bottoms up; pump sweep; and pull out of the hole to pick up core assembly. Once logging tools reached surface Sperry-Sun downloaded the dat, then the rest of the BHA was racked back. Tested B.O.P.E.'s (okay) and serviced rig; started to picked up core assembly and BHA. 03/13/01 0600hrs: Continued to pick up Bottom hole assembly and run into the hole. Attempted to shallow test MWD and PWD discovered Kelly hose was frozen. Spent several hours thawing out the Kelly hose before the MWD and PWD could be shallow tested. Continued running into the hole washing and reaming as required. 03/14/01 0600hrs: Drilled core from 8522' to 8570' with 8-15 Klbs, 750 psi pump pressure and 80 rpm. Pulled out of the hole and laid down core. Laid down core assembly and picked up BHA. Ran into the hole washing and reaming as required. Encountered torque problems from 8400' to 8570'. Drilled ahead from 8570' to Total Depth at 9112'. The dilling parameters were 2400-2600 psi pump pressure, 40 rpm, and 10-15KIbs W.O.B. Circulated bottoms up; pump sweep; short trip; circulate bottoms up and pump slug; pull out of the hole to the logging tools and down load Sperry-Sun data. EPOCH 37 SURVEY INFORMATION ~ Phillips Alaska. Inc. Nanuq #3 SURVEY INFORMATION Measured TVU Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Degrees Degrees E(+) W(-) N(+) S(-) Degrees!30' 205.47 205.47 0.09 40.64 0.04 0.03 0.14 290.88 290.88 0.09 212.00 0.03 0.04 0.21 386.20 386.19 1.42 266.06 -0.11 -1.18 1.~ 478.07 477.99 3.05 267.39 -0.30 -4.75 1.77 568.53 568.18 5.59 265.75 -0.74 -11.55 2.81 658.84 657.86 7.89 267.33 -1.35 -22.13 2.55 "750.56 748.44 10.15 272.15 -1.34 -36.50 2.60 842.73 8,,38.71 13.14 271.61 -0.74 -55.09 3.25 932.33 925.04 17.78 271.94 +0.01 -78.96 5.18 1026.05 1012.88 22.92 272.39 -111.51 1.27 5.49 1 t 17.72 1096.26 26.17 270.53 -149.56 2.20 3.64 ' i210.3g' 1i77.47 , 3i.36 268.99' -194.14 1.96 5.67 1303.16 1255.30 34.55 270.18 '244.60 i.61 3.51 1396.33 1330.80 37.18 269.14 -299.18 1.27 2.89 1488.83 1403.91 38.38 267.51 -355.81 -0.39 1.69' 1581.43 1476.70 37'.99 267.74' -413.01 -2.77 0.45 1675.14 1550.37 38.37 265.75 -470.83 -6.06' '1.37 1767.33 1622.03 , , 39.60 263.32 -528'.55 -11.60 2.13 1859.84 1693.45 39.33 264.77 -587.03 -17.7i 1.04 ,, , , , 1908.11 1730.81 39.26 264.79 -617.47 -20.49 0.15 1976.16 1783.68 , , 38.78 263.68 -660.10 -24.79 1.24 2068.90 1855.91 38.91 ,262.12 -717.81 -31.98 1.06 2161.11 1927.24 38.74 264.27 -775.83 -38.90 1.73 '2254.10 1998.34 40.53 266.28 -835.56 -43.82 1.63 2347.22 2069.44 39.93 269.85 -895.64 -45.87 2.56 2439.89 2140'76' r 39'.45 271.64 '954.82 -45.11 1.34 2532.26 2212.27 39'09 271.58'' '1013.26 '-43~46 0.39 2625.98 2284.67 39.74 270.98 '1072.75 -42.18 0.84 " 2718.02 2355.38 39.87' 270.06 '1131.67 -41.70 0.59 2811.02 2426.73 40.13 268.89 '1191.64 -42.25 0.85 2902.1'7 2496.52 39.73' 268.04 '1249.93 -43.82 0.75 2995.79 2568'72 39.36 266.59 '1309.46 -46.60 1.06 3089'67 , 2641'26 39.45 267.98 '1368.99 -49.42 0.94 " 3182.93 2713.39 39.22 267.07 '1428.05 -51'97 0.66 32?6'08 2785~10 40.i0 266'51 '1487.40 -55.30 1.02 3368.94 2856.18 40.00 266.73 '1547.05 -58.02 0.18 '3461.38 2927.07 39.84 267.64 '1606.30 -61.74 0.65 , ,, EPOCH 38 ~ Phillips Alaska, Inc. Nanuq #3 Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Degrees Degrees E(+) W(-) N(+) S(-) Degrees!30' 3555.05 2998.71 40.38 267.51 -1666.59 -64.29 0.59 3647.48 3069.06 40.50 267.49 -t726.49 -66.91 0.13 3739.57 3139.09 40.50 267.82 -1786.25 -69.35 0.23 3832.76 3209.93 40.54 267.56 -1846.75 -71.79 0.19 3924.28 3279.47 40.55 267.22 -1906.18 -74.51 0.24 4018.63 3350.93 40.98 267.17 -1967.71 -77.52 0.45 4111.52 3421.07 40.95 266.10 -2028.5 -61.10 0.76 4200.65 3488~99 39.78 266.98 -2086.12 -84.59 1.45 4296.64 3562.93 39.46 267.33 -2147.26 -87.62 '0.41 4390.90 3635.86 39.16 266.45' -2206.88 -90.86 0.68 4484.31 3708.14 39.46 267.11 -2265.96 -94.19 0.55 4574.76 3778.17 39.06 266.14 -2323.10 -97.56 0.80 4667.53 3849.87 39.72 268.08 -2381.89 -100.52 1,51 4761.17 3921.89 39.73 268.09 -2441.7 -102.51 0.01 4854.10 3993.40 39'.66 268.04 -2501.02 -104.52 0.08" 4947.36 4065.15 39.74 267.64 -2560.55 '106.77 0.29 5039.90 4136.27 39.82 266.48 -2619.68 -109.81 0.81 5132.62 4207.66 39.48 267.71 -2678.77 -112.81 0.93 5225.82 4279.55 39.57 267.47 -2738.03 -i15.30 0.19 5317.42 4350.15 39.59 266.69 -2796.31 -118.27 0.55 " 5409.94 4421.47 39.55 266.21 -2855.14 -121.92 0.33 5502.64 4492;92 39.62 267.43 -2914.11 -125.19 0.84 5596.03 4564.81 39.71 267.14 -2973.66 -128.02 0.22 ' 5688.59 4636.00 39.73 ' '267.74'-3032.74 -130.66 0.4i 5781.11 4707.17 39.71 267.72'" -3091.82 -133.00 0.02 5874.42 4778.94 39.72 267.53 -3t51.39 -135.47 0.13 5967.12 4850.46 39.31 269.88 -3210.35' -136.81 i.68 6060.. 10 4922.56 39.01 269.54 -3269.06 -137.10 0.40 , ,, , 6151.17 4993.45 38.76 269.62 -3324:23 -137.52 0.28 .6246.21 5067.62 . 38.65 26.27 -3385.65 -138.09 0.25 6339.24 6t40.9.7 37.26 269.57 -3442.87 -138.67 1.51 6432.43 5215.71 36.09 269.83 -3498.53 -138.97 1.27 6525.38 5291.36 34.95" 269.36 -3552.53 -139.35 1.27 6618.43 5368.21 33.69 269.10 -3604.98 -140.05 1.36 6712.00 5447.01 31.57 268.07' -3655.42 -141.29 2.33 6803.84 5526.22 29.21 268.93 -3701.87 -142.52 2.61 6896.51 5607.92 27.11 269.99 -3745.59 -142.94 2.34 6989.61 5691.39 25.45 '270.19 -3786.81 -142.88 1.78 · , 7082.07 5??5.20 24.53 270.74 -3825.87 -142.56 1.03 7175.15 5860.03 24.06 271.79 -3864.15 -141.72 0.68 EPOCH 39 ~ Phillips Alaska. Inc. Nanuq #3 Measured TVD Inclination Azimuth Coordinates Dog Leg Depth Feet Feet Degrees Degrees E(+) W(-) N(+) S(-) Degreesl30' 7268.71 5945.62 23.60 272.34 -3901.92 -140.36 0.55 7361.09 6030.48 22.97 271.56 -3938.42 -139.11 0.76 7454.5t 6116.41 23.22 271.52 -3975.05 -138.13 0.28 7644.26 6198.74 23.69 272.54 -4010.76 -136.86 0.69 7640.25 6286.25 24.84 272.44 -4050.17 -135.15 1.20 , ;]'32.85 6370.24 24.97 273.01 -4089.12 -133.29 0.29 7825.t0 6454.01 24.53 272.57 -4127.69 -131.41 0.52 7918.51 6539.07 24.30 272.92 -4166.25 -129.56 0.29 80tl.52 6623.92 24.07 272.68 -4204.31 -127.70 0.27 8103.29 6707.82 23.73 272.29 -4241.46 '126.09 0.41 · 8196.48 6793.18 23.58 272.00 -4278.82 -124.69 0.20 8289.60 6878.62 23.27 271".43 -4315.83 -123~58" ' 0.41 8382.32 6963.96 22.76 271.79 -4352.07i22.56 0.57 8439.78 7017.04 22.27 271.82 -4374.07 -121.87 0.85 8565.79 7133.68 22,18 271.55 -4421.72 -120.46 0.11 8660.52 7221.59 21.58 271.01 -4457.01 -119.67 0.67 ' 8753.48 7308.34 20.53 272.09 -4490.39 '118.78 1.20 8844.90 7394.13 19.90 272.35 -4523.08-117.56 0.69 8938.48 7482.t5 19.81 271.88 -4553.73 '116.38 0.20 9027.51 7566.03 19.34 272.16 -4583.54 -115.33 0.54 ,, , , 9112.00 7645.75 19'34 272.16 -4611.51 -114.28 0.01 . , , , , · ,, , ,, · [:1 EPOCH 40 DALLY MUD PROPERTIES ~ Phillips Alaska, Inc. Nanuq #3 DAILY MUD PROPERTIES Date Depth Den. vis PV YP Gels HTHP Fil. Cake Solids Oil/Water Sand PH C! Ca 0310110t 0 10.0 152 55 39 11120 (~250 0.0 2/0 7.5 0.0/92.5 0 9.6 300 20 03102101 724 10.0 147 38 45 19143 (~250 0.0 2/0 7.5 0.0/92.5 0.6 9.4 500 20 03103101 1973 10.0 53 24 ' 16 4/6 ~,250 0.0 2/0 7.9 0.0192.5 0.25 9.0 1200 56 0310410t 1973 t0.0 53 24 16 4/6 ~,250 0.0 2/0 7.9 0.0192.5 0.25' 9.0 t200 56 03105/0t 2013 9.6 44 8 10 2/3 ~250 0.0 110 5.8 0.0/94.2 trace 11.t 700 12 03106101 2950 9.6 43 14 14 4/6 ~,250 0.0 2/0 6.0 0.0194.0 0.2 10.1 900 120 03107101 4200 9.6 45 14 15 618 ~250 0.0 2/0 8.0 0.0/92.0 0.2 9.8 800 100 03108101 6000 9.6 43 12 14 5/7 ~250 0.0 2/0 9.0 1.0/91.0 0.2 9.5 400 100 03109101 7257 9.8 44 10 15 618 ~,,250 0.0 2/0 9.0 1.0190.0 0.2 9.0 400 100 03110101 8375 9.8 44 1 t 15 618 ~,250 0.0 112 8.5 2.5189.0 0.2 9.5 400 100 0311t101 85t3 9.8 45 11 t6 6/9 ~250 7.8 112 8.5 2.5189.0 0.2 9.0 400 100 031t2/01 8572 9.8 47 12 17 618 ~250 7.9 112 8.5 2.5189.0 0.2 8.8 400 100 03/13/01 8572 9.8 45 12 16 618 ~250 0.0 2/0 8.5 2.5189.0 0.2 8.7 400 100 03114/0t 9112 9.8 46 12 t6 6/9 ~?.50 0.0 110 8.5 2.5189.0 0.2 10.0 350 100 ~ EPOCH 41 BIT RECORD ~ Phillips Alaska, Inc. Nanuq #3 BIT RECORD Bit Gradin I O D L B G O R N U U O E A T E N T L C A U H A E E L A R G E S R R T I E R O C I N N R R H O G C O O ^ N S H P W W R A U S S R L L D Bit # Size Make Type SIN Jets Depth In Depth Ddlled Hours Ave Ave Ave Ave Out Ft/Hr WOB rpm psi I 12 %" STC FGSC lX12 3X15 140 1973 1833 23.0 76.0 11.8 6.9 1404 2 8 %" HYCA D570 FNPU 200349 6X12 1973 8524 6552 70.8 111.5 6.2 56.9 ' 2087.6 2 I' 8 %" HYCA D570 FNPU 200349 6X12 8569 9112 543 7.7 78.9 9.2 44.0 2550.9 ,I , , [:1 EPC"~H 42 LOGS 1004183878 III. O'R KS' Core GR GR COIgPRNY PH ILL IPS PETROLEUM I.,IFLL NFINUQ ~t 3 F IELO COUNTY RPI no. Location STATE ALASKA , Filin~ No. SEC TWP RGE Permanent datum Log measured from Drilling measured from ~Run No. JOep~h - Orillem ' JOeptb - Logger Bo~ Logged Top Logged P-asin.c1 - Or¥'l Casin~ - Logger ( Bi~ Size Type Fluid Den [ Vi~. Ph ] Fluid Loss Sample Source Rm · Maas. Tamp Rmf ~ Maas. Temp Rmc ~ Maas. Tamp Source Rmf I Rmc Service Order Time End Circ' Time on Bottom Max. Rec. Temp EiqU i P NO. Recorded By 8SS8.00 F 8S21.00 F Elev. Rbove P. O. KB DF GL 8S00 B~BB