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Home My WebLink About204-033 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ Q 4- - 033 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: I 0 {(; (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY ~ DateÕ/ID/Ob Stage 1 If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided III" 111111" 11111/ RESCAN ~or Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. ~her, NolType: C. 1) , D Poor Quality Originals: D Other: NOTES: BY: 0~ria J Date: t; / / tJ IIJ h I I Date: S //0 lob I l 3 x30= 0 Date: $ 0 {)~ Project Proofing BY: ~ Scanning Preparation BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed III" 1111/11111111I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OV~SIZED (Non-Scannable) ¢"09S of various kinds: D Other:: 151 rnP 11111111/111111111I 151 mp los- + / 5 = TOTAL PAGES (Count does not include coversheet) 151 p 11111111/11/1111111 NO 151 W1 f NO 151 11111111/11I11 "III ReScanned BY: Maria Date: 151 Comments about this file: 11111111/1111111111 Quality Checked III "1111111" IIII1 10/6/2005 Well History File Cover Page.doc • ~_ ~,~ _ ~.. MICROFILMED 03!01/2008 DO NOT PLACE A: ,,_ :,~;. ,- . _' ~: ANY NEW MATERIAL UNDER THIS PAGE F:~I.aserFiche\CvrPgs_Inserts~Microfilm Marker.doc t M"'1 Àù ~p DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040330 Well Name/No. PLACER 2 Operator CONOCOPHILLlPS ALASKA INC .5f~J- ~1 ~ ~ \ v¡ API No. 50-103-20488-00-00 MD 9118 f TVD 6939 -- Completion Date 4/8/2004 ~ Completion Status P&A Current Status P&A UIC N Mud Log Yes Samples No --".----~--- . ----~---------- REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Logl Electr ~ Data Digital Dataset Log Log Run Interval OH/ ~~~~~:nt Number Name Scale Media No Start Stop CH Received Comments Directional Survey 5/24/2004 ~g Density .~ '- yl ~"'\.A~ I (\;~~ Blu 8100 9118 Open 5/24/2004 DGRlCTN/SLD ~ 1 Rpt Asc Directional Survey 5/24/2004 J..Qg Density ~ \ ~ \ö.t..t..L l,¡., )(l:: [) ð Blu 5900 6900 Open 5/24/2004 DGRlCTN/SLD - !~g I nd u ction/Resistivity Blu 110 9100 Open 5/24/2004 tž I nd uction/Resistivity Blu 100 6900 Open 5/24/2004 C Lis 12499 See Notes 8113 9056 Open 5/24/2004 4° C Pdt 12762 Gamma Ray 110 9118 1 0/8/2004 OGR, CTN, SLOJ y1o..)j¥-; ~ 12762 Gamma Ray 25 Blu 110 9118 10/8/2004 DGR, CTN, SLD f{t à. ~ 12762 Gamma Ray 25 Blu 110 9118 10/8/2004 DGR, CTN, SLD : ~ pt Report: Final Well R 0 0 8/3/2004 Epoch End of Well Report V w/CD I] S'-ICf See Notes 0 0 8/3/2004 CoreLabs Core Analysis Report w/CD Note: Corrected "Conventional Core Analysis Results" ! ¡~()Q Mltl~ ~t) wI t>~- '{lid new report and CD (7 Jan, Ii; J ~'-a ~ 2005) , ¡vD i ¡Log Mud Log Col 84 9118 Open 1/13/2005 ; ~ Mud Log Col 84 9118 Open 1/13/2005 Drilling Dynamics ~ Mud Log Col 84 9118 Open 1/13/2005 L WD/Lithology tJ.Ø9 See Notes Col 84 9118 Open 1/13/2005 Gas Ratio Log Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2040330 Well Name/No. PLACER 2 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20488-00-00 MD 9118 TVD 6939 Completion Date 4/8/2004 Completion Status P&A Current Status P&A UIC N , ./ Cuttings t....... 60 9118 1138 -eore chips 8188-8219 --------- ----- ADDITIONAL INFORMATION Well Cored? Q/ N Chips Received? (3/ N (IN Daily History Received? Y/N ~'/N Formation Tops Analysis Received? --- ----- -------- Comments: -. -- -".- .- - lL Compliance Reviewed By: Date: J N) À..-U--,-\ ç. ) ) Conocó'PhilUps TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage AK 99510-0360 RE: Placer 2 PERM IT 204-033 DATE: 01/13/2005 TO: Helen Warman Alaska Oil & Gas Conservation Commission 333 W. ih Ave, Suite 100 Anchorage, Alaska 99501-3539 Transmitted: Hardcopy report and CDROM diaital well data REVISION (1/07/2005) _Placer 2; Epoch-Final Well Report; Mud logging data; Morning reports; LAS Data; PDF Color image files and hardcopy; DML; Lithology Remarks; logged 4/03/04 Formation Log (MD), Formation Log (TVD), Drilling Dynamics (MD), LWD/Lithology (MD), Gas Ratio Log (MD) Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records To all data recipients: All data is confidential until State of Alaska designated AOGCC release date Data marked PROPRIETARY is indefinitely confidential and is available only to owners and partners z/--. ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: I j~¡;S- / GIS-Technical Data Management I ConocoPhlÏlips I Anchorage¡ Alaska I Ph: 907.265.69471 Sandra. D. Lem,ke(iiJConocoPhi//ios. com ;'. (.J \.1- ~ 1J / r-" / /'--, I ~_. ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, 0Ø!fa \o\,\lD4- P.I. Supervisor ~~~( { DATE: August 13, 2004 FROM: Jeff Jones, Petroleum Inspector SUBJECT: Location Clearance Well Site Inspections Exploration NPRA Placer 2 PTD 2040330 Spark 4 PTD 2040080 Spark 8 August 13, 2004: I traveled with CPAI representative Chris Brown via helicopter to inspect Conoco-Phillips Alaska Inc.'s (CPAI) Placer #2, Spark #4 and Spark #8 exploration well sites for the purpose of final location clearances. The Placer #2 exploration well has been plugged & abandoned and a site inspection revealed several large chunks of concrete on the surface that should be buried or removed prior to final approval. A small amount of "ponding", depressions left from drilling activities filling with water, was visible at this site and may require a small amount of additional fill material prior to approval. The Spark #4 exploration well has been plugged and abandoned and a site inspection revealed several large cement chunks that should be buried or removed and a "ponding" condition that will require more fill to meet the AOGCC requirements for final approval. The Spark #8 exploration well was not drilled but a conductor hole was drilled and subsequently filled in. This site also exhibited a "ponding" condition and will require additional fill material prior to final approval. During this trip I also was able to inspect the Carbon #1 and Placer #1 wellheads, which were wrapped with a black plastic to protect them from nesting ravens. I noted six old 55-gallon drums near the Carbon #1 wellhead of unknown origin. Chris Brown indicated she would have the substandard items corrected and notify the AOGCC when completed. Summary: I inspected CPAl's exploration well sites Placer #1 & #2, Carbon #1, and Spark #4 & #8 in the NPRA. ') ) Placer #1 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC I nspector Jeff Jones August 13, 2004 Placer #1 wellhead Placer #2 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 Placer #2 - cement chunks, ponding 2 ) ) Spark #4 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC I nspector Jeff Jones August 13, 2004 I Spark #4 location Spark #4 - cement chunks, ponding 3 4 Carbon # 1 wellhead Carbon #1 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC Inspector Jeff Jones August 13, 2004 Spark #8 - conductor only; ponding I Spark #8 (ConocoPhillips) Location Clearance Inspection Photos from AOGCC I nspector Jeff Jones August 13,2004 ) ') ) ) ConocÓPhillips TRANSMITTAL CONFIDENTIAL DA TA FROM: Sandra D. Lemke, AT01486 ConocoPhillips Alaska, Inc. P.O. Box 1 00360 Anchorage AK 99510-0360 RE: Placer 2 PERMIT 204-033 DATE: 5/24/2004 TO: Alaska Oil and Gas Commission 333 W. th Avenue, Suite 100 Anchorage, Alaska 99510 Transmitted: Diaital data - Sperry Sun LDWG L WD LIS log data; Image views files (PDF. cgm, tiff, emf+viewer) it 6bft) ~ J À ..." 't cr _ Sperry Sun definitive Directional Survey 4/4/2004 1, (} ~t'f\ j Report Binder _ Halliburton Sperry Sun- Directional survey IIFR SVY363 and MWD SVY 360 report - hardcopy ~ ..~)j Hardcopy Loa data - 1 print Sperry Sun MWD logs _ROP/DGR/EWR, 2"&5" MD ~ ~ b""" \ _DGR/EWR 2"&5" TVD ~ tt ~ ~} Please check off each item as received, promptly sign and return one of the two transmittals to address below. The other copy is for your records To a/l data recipients: A!I data is confidential until State of Alaska designated AOGGG release date Data marked PROPRIETARY is indefinitely confidential and is available only to owners and partners cc: ~' CT!J:::9ist Receipt: ( . , Return receipt to: ConocoPhillips Alaska, Inc. ATTN: S. Lemke, ATO-1486 700 G. Street Anchorage, AK 99501 Date: RECEIVED MAY 2 4 2004 Pre~tWl ~á:IDlsLêømmission ConocoPhillips A~allè? Global Information IS-Tech Data Management 907.265.6947 Sandra.D. Lemke@ConocoPhillips.com Jv íJ <t - <r)) ) ) Paul Mazzolini Exploration DrillingTeam Leader Drilling & Wells ConocóPhillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4603 May 5, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for Placer #2 (204-033 I 304-103) Dear Commissioner: On behalf of itself and other owners, ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recently abandoned exploration well Placer #2, Drilling Permit No. 204-033 as specified in 20 AAC 25.071. Other attachments with this package include the daily drilling summary, directional survey, as-built, P&A summary and P&A photos. The core analysis and logs will be sent at a later date. We request that this data be held confidential as required under AS 31.05.035(c) and 20 AAC 25.537(d). If you have any questions regarding this matter, please contact me at 263-4603. Sincerely, 7~11~ P. Mazzolini Exploration Team Leader CPAI Drilling PM/skad RECEIVED MAY 062004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil D Gas U Plugged U Abandoned 0 Suspended D WAGD 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development D Exploratory [2] GINJ 0 WINJ D WDSPL D No. of Completions _ Other - Service D Stratigraphic Test D 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: April 8, 2004 .I 204-033 1 304-103 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510-0360 ., 50-1 03-20488-00 March 21, 2004 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: .¡ .I Placer #2 Surface: 999' FSL, 20' FEL, Sec. 32, T12N, R7E, UM April 3, 2004 At Top Productive 8. KB Elevation (ft): 15. Field/Pool(s): Horizon: 1695' FNL, 987' FEL, Sec. 33, T12N, R7E, UM RKB 54' Total Depth: 9. Plug Back Depth (MD + TVD): Exploratory 1567' FNL, 761' FEL, Sec. 33, T12N, R7E, UM surface 4b. Location of Well (State Base Plane Coordinates): ¡ 10. Total Depth (MD + TVD): 16. Property Designation: ¡ 9118' MD 16939' TVD / Surface: x- 451252 y- 5976417 Zone-4 ADL 25552 1 390305 TPI: x- 455573 y- 5978976 Zone-4 11. Depth where SSSV set: 17. Land Use Permit: / 5979102 ,I Total Depth: x- 455800 ' y- Zone-4 none n/a 18. Directional Survey: Yes [2] NoU 19. Water Depth, if Offshore: 20. Thickness of N/A feet MSL Permafrost: 1509' MD 21. Logs Run: GR/Res l 22. CASING, LINER AND CEMENTING RECORD I:. SETTING DEPTH MD .1 CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 290 sx AS 1 9.625" 40# L-80 Surface 2662' 12.25" 416 bbl ÀS III Lite, 20 bbl LiteCrete P&A plug #1: 9110'-7821' cement retainer set @ 2559' surface plug @ 285' to 40' 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) n/A n/a none 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9110'-8541' 255 sx Class G, 244 sx Class G cement retainer @ 2559' 90 sx Class G surface plug at 285' 90 sx AS I 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) n/a abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL CHOKE SIZE GAS-OIL RATIO n/a Test Period --> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) press. psi 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". -- RECEIVED ' , '. ~8fL ~Þt'f 13 2004 ..-i·.'.f·¿?i: MAY o 6 2004 ~··~.A~·~_ TO BE SENT UNDER SEPARATE COVER Alaska Oil & Gas Cons. Commissiol1 Anchorage Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ORIGINAL ./ 'j r 28. -, J GEOLOGIC MARKERS 29. J FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intelVals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Placer 2 Top Kuparuk Base Kuparuk 8210' 8220' 6070' 6079' N/A RECEIVED MAY 0 {; 2004 Alaska Oil & Gas Cons. Commission . . . - ';1 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, As-Built, P&A summary, P&A photos 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mark Chambers @ 265-1319 printedNa~ P.~ Signature ~ Pf, Title: Exoloration Drillina Team Leader Phone Date o.s¡06/2064- Prepared by Sharon Alfsup-Orake 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 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 abour 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 wen 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 ()~~\tG\NAL . .... . .... .... ....... .....: . ...... . . .... . ...... .... ....... ...... .................. ........... . . .. .... ..' . .. . . .. . .. ...... . ... . .... . . i' ··..·mb~qÇ~r~ifli~~~lij~~~... .. ... ..... ..... .... .¢)·p~r~t.i'~"'$..·~¡y..m···I1T)··~·~y..¡~·~.p,<:)rt,....· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 .·:H···. ·.o'.·..·.u·.··.r·.·s·.·..·.·,...... ··'0· ··.··.0·: ·.·,.d. e·.··.· .Sub ·.:·····,.8.···h·,.·a·s'· e'.· .. ·'Cþdê Start: 3/18/2004 Rig Release: 4n /2004 Rig Number: Spud Date: 3/19/2004 End: 4n/2004 Group: 3118/2004 00:00 - 04:00 4.00 RIGMNT RSRV MOVE Slip off 1600" drilling line and string up new spool of line.Coil and save cutoff line 04:00 - 13:30 9.50 MOVE DMOB MOVE Replace Teflon slides in TD torque tube. RIU liner in cellar. and clean cellar. NIU inner annulus companion flange and guage. Steam clean rig mats and cellar. Clean out cellar box. Repair safety clamp on TD mud line. rlu spinners, X/O elevators and tongs. Lube TD rail. XIO pill pit valve. Warm up rig mooving system. Vac out final cleanup in cellar. Blow down water lines on floor. Move cuttings tank and out buildings. clean out diverter spill box disconnect camp coms line. 13:30 - 14:00 0.50 MOVE SFTY MOVE PJSM on rig move 14:00 - 15:00 1.00 MOVE MOVE MOVE Move rig off Placer #1 well. 15:00 - 19:00 4.00 MOVE RURD MOVE Remove rig mats and liner. Chip and bag ice and snow shovle and sweep snow from old liner and fold liner Set up new liner and final clean up under cellar mats. 19:00 - 22:00 3.00 MOVE RURD MOVE Set up double liner in cellar. Lay cellar and rig mats 22:00 - 00:00 2.00 MOVE POSN MOVE Spotand level rig. Berm entire rig. 3/19/2004 00:00 - 05:00 5.00 DRILL RIRD RIGUP Accept rig at 00:00 am 3/19/04 Set up berms around rig and ancillary units. Load 10.0 ppg spud mud in pits. 05:00 - 14:00 9.00 DRILL RIRD RIGUP R/U diverter, flow nipple, flow line, conductor valves and chink air leaks in cellar 14:00 - 16:00 2.00 DRILL OTHR RIGUP Function test diverter. Function test alarm system. Drawdown test Accumulator system. Test witnessed by J. Crisp of AOGCC. 16:00 - 00:00 8.00 DRILL OTHR RIGUP Rig Totco alarm system not functional. While trouble shoot alarms and wait on service hands: repair hub ram on #1 shaker, rlu fuel dock berm, lId 4 3/4" jar and plu 6 1/2" jars and rack back, M/U MWD BHA and rack back, rebuild spare mud pump pop off, Install rubber in TT line camlock. 3/20/2004 00:00 - 21 :00 21.00 DRILL OTHR RIGUP Repair rig alarm system. Remove overhead storage from pits. Repair pit cart winch line. Install whip-checks on air lines in boiler room. Service topdrive. Grease choke manifold. Remove circulating manifold from cellar and take to shop for service. Load 9 5/8" casing tools into pipe shed. Start loading casing to shed. Function test Totco alarm system. 21 :00 - 22:30 1.50 DRILL RIRD RIGUP Fill hole and test mud motor. 4" conductor wing valves leaking. Drain stack and redo valves and swedges. 22:30 - 00:00 1.50 DRILL RIRD RIGUP Fill hole. Riser air boot seal leaking. Drain stack and UD BHA. Start RID riser for repair. 00:00 - DRILL SFTY RIGUP Held diverting shallow gas and accumulator drill wI Ron Matteson's crew prior to getting off work on 3/20104. Held pre spud meeting with Ron's crew and directional driller 3/20104. Discussed Placer # 2 surface hole. Discussed safety and environmental top priority. Mud weights were discussed. 3/21/2004 00:00 - 02:00 2.00 DRILL RIRD RIGUP Change out riser boot seal and NIU riser. 02:00 - 03:00 1.00 DRILL RIRD RIGUP Fill riser and test trip tank fill up line, knife valve, and riser seals. 03:00 - 03:45 0.75 DRILL SFTY SURFAC Accept rig from repair rate. Pre spud safety and Pre job meeting with rig crew and all service hands. 03:45 - 04:15 0.50 DRILL PULD SURFAC PUlMU BHA #1 04:15 - 06:15 2.00 DRILL DRLG SURFAC Tag cement or ice in conductor @ 87', drill to 224'. Drill wI 400 gpm, 750 psi, WOB 5k, Rotate @ 45 rpm. PU, SO and Rot wt 30k. 06:15 - 07:00 0.75 DRILL TRIP SURFAC Blow down top drive. POOH to install MWD tools. 07:00 - 09:00 2.00 DRILL PULD SURFAC PU Sperry MWD. Plug in and surface test. PU (3) FLEX 8" DC's. 09:00 - 10:00 1.00 DRILL OTHR SURFAC Log in hole f/143' to 224'. 10:00 - 12:00 2.00 DRILL DRLG SURFAC Drill f/224' to 337'. Drill wI up to 473 gpm, 1150 psi, WOB 10-15k, Printed: 4/30/2004 3:11 :10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 :HÞûts ··:·ç~døi icf~~e, Phase· Start: 3/18/2004 Rig Release: 4n /2004 Rig Number: Spud Date: 3/19/2004 End: 4n/2004 Group: . ". . '. ... .' . . '. ". '.". .... '." . .. q~~qriptiQrlQfqRØ~~tiqQ~: ....<.... .. 3/21/2004 10:00 - 12:00 2.00 DRILL DRLG SURFAC Rotate @ 45 RPM. PU, SO and Rot wt 44k. Total slide time @ noon 1.25 hrs. Total rot time @ noon 2.56 hrs. Total hrs on bit 3.81 hrs. 12:00 - 13:30 1.50 DRILL DRLG SURFAC Drill f/337' to 451'. Drill wi up to 473 gpm, 1150 psi, WOB 10-15k, Rotate @ 45 RPM. PU, SO and Rot wt 47k. AST 1 hr, ART .33 13:30 - 14:00 0.50 DRILL CIRC SURFAC Circ, proir to POOH. 14:00 - 14:30 0.50 DRILL TRIP SURFAC POOH fl 451- to 175'. 14:30 - 16:15 1.75 DRILL PULD SURFAC PU/MU (6) 61/4" DC's and 61/4" jars. 16:15 - 00:00 7.75 DRILL DRLG SURFAC Pump up survey, Drill fl 451' to 925'. Drilled wi 400 gpm @ 1250 psi, 12 - 20 K WOB, Rotate 40 - 60 rpm. PU = ROT = SO = 65K #. 24 hr. bit totals: TST = 7.0 hrs TRT = 3.16 hr. TBT = 10.16 hr. 3/22/2004 00:00 - 11 :30 11.50 DRILL DRLG SURFAC Drill fl 925' to 1710'. Drilled wi 400-500 gpm @ 1250-2170 psi, 15 - 30 K WOB, Rotate 40 - 60 rpm. PU = 75k ROT =74k SO = 68K #. AST = 8.5.0 hrs ART = 1.21 hr. TBT = 19.87 hr. 11 :30 - 12:30 1.00 DRILL CIRC SURFAC Circ samples out of hole. Stand back a stand, finish circ hole clean. Circ total 540 bbls(2+ BU). 12:30 - 15:00 2.50 DRILL WIPR SURFAC Blow down top drive. Short trip to 350'. Backream 1350-1270'. Work tight spots @ 970'-950',870' and 770'. 15:00 - 16:00 1.00 DRILL WIPR SURFAC RIH fl 350' to 1139'. Push ahead @ 862'-1005'. Wash @ 1080'. 16:00 - 18:00 2.00 DRILL REAM SURFAC Ream & wash fl 1139' to 1556' 18:00 - 18:30 0.50 DRILL SFTY SURFAC Pre spud safety meeting wi new crew in doghouse. Table top discussed accumulator drill, diverting shallow gas drill. 18:30 - 19:00 0.50 DRILL REAM SURFAC Finish reaming to bttm 1556' to 1710'. 19:00 - 00:00 5.00 DRILL DRLG SURFAC Drill fl 1710' to 2135'. PU = 82K. SO =67K. ROT = 75K. Torque = 4000 ftlb on I 3000 ftlb off. Pump at 525 gpm & 2650 psi on 12500 psi off. Rotate @ 60 rpm. AST = 1.56 hr. ART = 2.17 hr Total bit time = 23.6 hr 3/23/2004 00:00 - 11 :00 11.00 DRILL DRLG SURFAC Drill from 2135' to 2650' 11 :00 - 11 :30 0.50 DRILL CIRC SURFAC Rotate, recriprocate and circulate for geologic samples for casing point pick. 11 :30 - 12:00 0.50 DRILL DRLG SURFAC Drill to casing setting TD at 2672'. PU = 80 K. SO = 70 K. Rot. = 75 K. Circ at 175 spm/525 gpm. wi 2550 psi off and 2700 psi on. Rotate at 80 RPM wi 4000 ftlb off and 6000 ftlb on. Total interval sliding hrs = 18.22 Total interval rotating hrs = 14.27 Total Bit hours = 32.49 12:00 - 14:30 2.50 DRILL CIRC SURFAC Circ and condition hole. Pump two Hi-Vis sweeps. 14:30 - 15:00 0.50 DRILL OBSV SURFAC Blow down top drive and observe well for flow. Hole stable. 15:00 - 17:30 2.50 DRILL TRIP SURFAC POOH Pumped out first stand. Tight 2040 - 2020,1400 -1300'. Stand back DP, HWDP, SWDP, Jars and 61/8" DC. 17:30 - 19:30 2.00 DRILL PULD SURFAC LD NM DC. 19:30 - 21 :00 1.50 DRILL PULD SURFAC Down load MWD tools and LD MWD. LD Motor. 21 :00 - 00:00 3.00 CASE RURD SURFAC R/U to run 9 5/8" casing. Make dummy run with 9 5/8" landing joint. 3/24/2004 00:00 - 00:30 0.50 CASE RURD SURFAC UD landing joint and confirm spacout. Finish rig up to run 9 5/8" casing. 00:30 - 01 :00 0.50 CASE SFTY SURFAC PJSM for surface casing. 01 :00 - 04:30 3.50 CASE RUNC SURFAC P/U shoe track and test floats. RIH 10 Jts to 393'. Break circ and continue in hole to 1340'. PU = 80 K and SO = 65 K No indicatioins of hole problems. Full returns. Casing ledged out at 1340'. 04:30 - 08:30 4.00 CASE RUNC SURFAC Work casing from 1340" to 1500' in ledgy hole. Work weight and speed to total slack off. Work pump to 6 bpm at 350 psi. Maintained full circ with no packoff, sticking or excessive returns. ( Hole angle builds from 20 to 30 degrees wi 7 degree dogleg in this interval) Printed: 4/30/2004 3: 11 : 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 3/18/2004 Rig Release: 4n /2004 Rig Number: Spud Date: 3/19/2004 End: 4n/2004 Group: : Date ·Frdrrl··~··T() ··Hqù~S: .¢()dè~óU:éi. ..RlÍásè . . . . . . ,... ...... .... . ..' .... . .,. .. ... ... ··[)escripti9h()fOÞ~r~ti9n$··· 3/24/2004 08:30 - 10:30 2.00 CASE RUNC SURFAC Continue RIH from 1500' with no pump to 2630'. M/U casing hanger and Land casing. PU = 105K and SO = 85K. 10:30 - 12:00 1.50 CEMEN CIRC SURFAC Circulate and condition for cementing at 5 bpm. 12:00 - 12:30 0.50 CEMEN PULD SURFAC MU double plug cementing head with two plugs. 12:30 - 15:30 3.00 CEMEN CIRC SURFAC Circulate and condition for cementing at 6 bpm @ 370 psi. Recriprocate pipe at PU = 115 K & SO = 90 K. 15:30 - 16:00 0.50 CEMEN SFTY SURFAC PJSM while C&C. 16:00 - 18:15 2.25 CEMEN PUMP SURFAC Recriprocate and MIX and Pump 10 bbl CW 10. Test lines to 3500 psi. Mix and pump 40 bbl CW 100 @ 5.5 bpm & 284 psi. wi 34 % returns. Drop bottom plug. Mix and pump 50 bbl Mudpush III @ 10.5 ppg @ 4.5 bpm & 230 psi. Mix and pump 416 bb110.7 ppg ASL lead at 6.3 bpm & 435 psi wi 36 % returns. Mix and pump 20 bbl Litecrete at 12.0 ppg at 6.4 bpm, 490 psi wi 34 % returns. Landed casing and continue tail cement to total of 83 bbl. Drop top plug. Cement returns to surface. 18:15 - 19:00 0.75 CEMEN DISP SURFAC Displace cement with rig pumps. Taking returns to vac trucks. Displace wi 175.5 bbl (2490 stks) 10.1 ppg mud at 6 bpm wi 463 psi FCP. Bump plug and pressure to 1150 psi. Check floats. Floats holding. 130 bbl cement returned to Vac trucks. 19:00 - 21 :00 2.00 WELCT SURFAC Wash diverter stack, RD cement head & casing tools. LD landing joint. 21 :00 - 00:00 3.00 WELCT SURFAC ND diverter line. ND diverter. 3/25/2004 00:00 - 01 :30 1.50 CASE SURFAC Continue N/D diverter Temp -27 F, WC-69 F 01 :30 - 03:30 2.00 CASE SURFAC NIU DSA. Change several studs. 03:30 - 09:00 5.50 WELCT SURFAC N/U 11" x 5M BOP stack using rigu up slings due to wellhead height. 09:00 - 12:30 3.50 WELCT SURFAC MIU test plug. R/U test equipment. Function test BOPE. Pressure test all BOPE to 250 psi lowl 5000 psi high except annular preventer which was tested to 250 psi low/3500 psi high. Jeff Jones, AOGCC, waived witnessing the BOP test due to Phase 2 road conditions. 12:30 - 14:00 SURFAC RID test equipment. Pull test plug. Set wear ring. RILDS. Blowdown kill line. 14:00 - 15:00 1.00 RIGMNT RSRV SURFAC Change out bails. Change out tongs. Service topdrive. 15:00 - 18:30 3.50 DRILL PULD SURFAC MU BHA. Load MWD. Test motor and MWD. Blow down TD. 18:30 - 20:30 2.00 DRILL TRIP SURFAC RIH. Took Weight at 2532'. PU = 75K, SO = 55K, Rot. = 65K 20:30 - 22:30 2.00 DRILL REAM SURFAC Wash to Plugs at float collar at 2578'. Mud badly contaminated. Circ & condition at reduced rate due to thick mud. 22:30 - 23:00 0.50 CASE SFTY SURFAC PJSM for casing pressure test. 23:00 - 00:00 1.00 CASE DEQT SURFAC Pressure test casing. Noted pressure buildup deviation while pumping. Bleed off and break out and Blow down topdrive. R/U circulation hose and pressure to 2500 psi. 3/26/2004 00:00 - 01 :00 1.00 CASE DEQT SURFAC Hold safety meeting and test casing to 2500 psi for 30 minutes. Bled off 70 psi in 30 minutes 01 :00 - 02:00 1.00 CEMEN DSHO SURFAC Drill float collar and cement to 2615' 02:00 - 04:30 2.50 CEMEN CIRC SURFAC Circulate and condition thick mud. Cleanout suction on #1 Mud Pump 04:30 - 04:45 0.25 CEMEN DSHO SURFAC Finish drilling shoe track and clean out old hole to 2672'. 04:45 - 05:00 0.25 DRILL DRLG SURFAC Drill from 2672' to 2692' 05:00 - 05:30 0.50 DRILL OTHR SURFAC Thaw cuttings chute 05:30 - 05:45 0.25 DRILL CIRC SURFAC Displace well wi new LSND mud @ 10.0 ppg 05:45 - 06:00 0.25 CEMEN LOT SURFAC Perform LOT to 14.7 ppg EMW. (Broke @ 542 psi @ 2230' TVD wi 10.0 ppg mud in the hole). Pressure bled to 390 psi in 10 minutes. 06:00 - 07:30 1.50 CEMEN FIT SURFAC Circulate and condition mud and redo FIT test to 16.2 ppg EMW. (720 psi @ 2230' TVD wi 10.0 ppg mud in hole.) Pressure bled to 330 psi in 10 minutes. 07:30 - 08:30 1.00 DRILL DRLG INTRM1 RIH and drill from 2692' to 2805'. ART = 0.87 hr. 08:30 - 09:00 0.50 DRILL TRIP INTRM1 POOH to shoe Printed: 4/30/2004 3: 11: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 3/18/2004 Rig Release: 4/7/2004 Rig Number: Spud Date: 3/19/2004 End: 4/7/2004 Group: .SÜb.· F=ro/Î1HTo:Höûrs ·Cödè (jóde 3/26/2004 09:00 - 11 :30 11 :30 - 12:00 12:00 - 14:00 14:00 - 16:30 16:30 - 18:00 18:00 - 19:00 19:00 - 23:30 3/27/2004 23:30 - 00:00 00:00 - 12:00 2.50 DRILL 0.50 DRILL 2.00 DRILL 2.50 DRILL 1.50 DRILL 1.00 DRILL OTHR TRIP TRIP TRIP TRIP REAM INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 INTRM1 4.50 DRILL DRLG INTRM1 0.50 DRILL 12.00 DRILL OTHR INTRM1 DRLG INTRM1 12:00 - 14:15 2.25 DRILL DRLG INTRM1 14:15 - 15:00 0.75 DRILL OTHR INTRM1 15:00 - 18:00 3.00 DRILL DRLG INTRM1 18:00 - 21:15 3.25 DRILL DRLG INTRM1 21:15-00:00 3/28/2004 00:00 - 05:45 05:45 - 06:45 06:45 - 07:30 07:30 - 12:00 12:00 - 00:00 3/29/2004 00:00 - 12:00 12:00 - 22:15 2.75 DRILL DRLG INTRM1 5.75 DRILL 1.00 DRILL 0.75 DRILL 4.50 DRILL DRLG INTRM1 OTHR INTRM1 CIRC INTRM1 DRLG INTRM1 12.00 DRILL DRLG INTRM1 12.00 DRILL DRLG INTRM1 10.25 DRILL DRLG INTRM1 ; :.' .; ", pt()Þør~m)nä ..... ... Evaluate LOT and FIT RIH and attempt to survey. MWD pulsar not sending signal to surface POOH Drain motor and download MWD. Change out pulsar. Upload MWD. RIH M/U TD and wash to bottom with last stand. Thick mud PWD ECD = 10.8 ppg Directional drill from 2805' to 3181 '. PU = 74 K, SO = 60 K, Rot = 67 K. TD Torque = 3800 - 5000 on /3100 - 4200 off. Pump at 196 spm, 470 gpm, 2150 psi on /1950 off. ART = 2.63 hr. AST = 0.48 hr. TRT = 3.98 hr. Service top drive. Drill from 3181' to 3942' (TVD=3052') ART=6.3 hrs, AST=.73 hrs, ADT =7.03 hrs. Pump 30 bbl weighted sweep @ 3278' . Pump at 500 gpm & 2200 psi on /2000 off. Rotate at 80 rpm w/4800 ftlb on /4500 off. Drill from 3942' to 4164'. Plugged flowline. Unplugged flowline with gumbo. Drill from 4164' to 4320'. Heavy gumbo plugging in flow line Mud vis and pump pressure rising. Added "Claygard" to mud to reduce flowline plugging. Mud very thick. Pump pressure increased from 2200 psi @ 200 spm to 3000 psi @ 80 spm. Circulate and condition mud. Treated system w/ Desco CF and water. Dumped possumbellys and flush flowlines to cuttings tank. Lowered viscosity, gells and low gravity solids while weighting back w/ barite to appropriate mud weight. Controled drill at +/- 120 fph instantaneous bit ROP for hole cleaning drill from 4320' to 4509'. (3415' TVD). ART = 5.17 hr. AST = 0.0 hr. 24 hr total bit hrs. = 12.2 hr. Pumped at 490 gpm @ 2740 psi on /2590 off. Rotated 80 rpm w/5400 ftlb on /5100 off. PU = 78K. SO = 80 k. Rot. = 77 K. WOB 5 -15 K. Drill from 4509 to 4885'. Pump high weight sweep @ 4704' M/U head pin and circ @ 3 bpm while replacing washpipe. Circulate and condition mud @ 11.5 bpm Drill from 4885' to 5175'. Pump high weight sweep @ 5100'. AST =.59hrs, ART =6.47 hrs. ECD=11.4 ppg. Pump pressure= 2950 psi on/2800 psi off. Torque= 6800 ft-Ibs on/5600 ft-Ibs off. Rotary= 85 rpm, WOB= 5-15 k. Pump 1=95 spm, Pump 2=100 spm--480 gpm Drill from 5175' to 6147'. HI -Vis sweep at 5600' and 5930'. PU = 115K , SO = 75K, ROT = 93K. Torque = 7400 -8200 ftlb on /7000 - 7600 off. Pump at 200 spm = 490 gpm w/3500 psi on /3200 psi off. Avg ECD = 11.3 ppg. Max ECD = 11.6 ppg when sweeping. Hole condition appears even and good. AST = 0.83 hr. ART = 7.16 hr. 24 hr total bit time = 15.05 hr. Drill 8-1/2" hole from 6147' to 7065'. TVD = 5113'. Pumped weighted sweeps @ 6315',6015' and 7000'. ART=7.48 hrs, AST=.77 hrs, ADT= 8.25 hrs. P/U = 106k, S/O = 95k, Rot= 100k, Pump pressure= 3600 psi on/3300 psi off. Torque=9000 ft-Ibs on/8000 ft-Ibs off. Rotary= 85 rpm, WOS= 10/20k, Pump strokes = 90 spm#1, 95 spm #2 (470 gpm) Drill 8-1/2" hole from 7065' to 7633'. Tight when backreaming at 7425' at end of slide. Drill ahead rotating with no overpull. Start slides to drop angle. PU = 147K. SO = 85K. Rot = 110K. WOB = 12 -15 K. RPM = 85 Torque = 10700 ftllb. Pump at 460 gpm w/3550 psi on and 3200 Printed: 4/30/2004 3: 11: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 3/18/2004 Rig Release: 4/7/2004 Rig Number: Spud Date: 3/19/2004 End: 4/7/2004 Group: T[)åtê< ... Fr()r:rr~t().· · Hours GÖêfè ... tofe 3/29/2004 12:00 - 22:15 10.25 DRILL DRLG INTRM1 22:15 - 23:15 OTHR INTRM1 1.00 DRILL 23:15 - 00:00 0.75 DRILL CIRC INTRM1 3/30/2004 3.00 DRILL 00:00 - 03:00 TRIP INTRM1 03:00 - 04: 15 04:15 - 04:30 04:30 - 12:00 1.25 DRILL 0.25 DRILL 7.50 DRILL TRIP INTRM1 REAM INTRM1 DRLG INTRM1 12:00 - 14:30 2.50 DRILL DRLG INTRM1 ps i. off. Made connection at 7549 and noted top drive pipe graber release sticking. Drill stand down to 7633' (5548' TVD). Backream last stand and survey at 7573'. AST = 2.31 hr. ART = 4.48 hr. 24 hr. bit total = 15.04 hr. Pump weighted sweep and circulate on slips while servicing top drive. Found obstructed grabber control solenoid valve. Drain, clean and reinstall solenoid. Continue circ and PIU to 175 K wlo pipe movement. Stroke pipe to 175 K up and 60 K down wI no change. Start rotary and pipe was free immediately. Backream first stand wlo unusual torque or drag. ECD max = 11.6 ppg. ECD avg = 11.5 ppg. Short trip. Pump out wI PU = 135K. for first 5 stands. Hole fill OK. Pull 1 1/2 stands wlo pump at PU = 150K. Hole swabbing. Swabbed 3 bbl. Pump out to 6400'. Hole fill OK. Gas peak at 550 units from swabed interval . Background gas before trip was 80 units. RIH wlo Pump. SO steady at 85 K. Wash last stand to bottom at 7633' Drill from 7633' to 8047', TVD=5916'. ART=2.71 hrs, AST=2.29 hrs,ADT =5.00 hrs, ECD=11.3 ppg. PIU = 165k, S/O=85k, Rot= 112k, Pump = 95 spm #1, 95 spm #2, (465 gpm) @ 3600 psi on bottom/3300 psi off bottom. Torque= 10500 ft-Ibs on/9500 ft-Ibs off. rotary=80 rpm Drill from 8047' to 8188', TVD=6049'. Control drill from 8100' to 8188' @ <60 fph to pick core point ADT 1.92 hrs. ART- 1.92 hrs. WOB - 5/15 k RPM 80 GPM 465 @ 3500 psi String wt. PU 122 SO 115 ROT 118 Torque onloff btm - 10,900 I 9800 ft. Ibs ECD - 11.2 14:30 - 17:30 3.00 DRILL CIRC INTRM1 Circulate and condition- pumped 2 weighted hi vis sweeps -while rotating and reciprocating drill string.- monitor well - static 17:30 - 20:00 2.50 DRILL TRIP INTRM1 Wiper trip fl 8188' to 6781' - pulled to 7728' (5 stds) improper fill - monitor well static - pump out 5 stds to 7343' OK - Pulled on trip tank to 6781' - hole fill OK 20:00 - 21 :00 1.00 DRILL TRIP INTRM1 RIH - wash & ream last std to TD (8188') hole slick going in 21 :00 - 23:00 2.00 DRILL CIRC INTRM1 Pump sweep & circulate hole clean for trip - monitor well static 23:00 - 00:00 1.00 DRILL TRIP INTRM1 POOH - pumping fl 8188' to 7728' (5 stds) 3/31/2004 00:00 - 05:00 5.00 DRILL TRIP INTRM1 Pump 5 stands out of the hole. Blow down top drive and continue POOH on trip tank. 05:00 - 06:00 1.00 DRILL CIRC INTRM1 Circulate and condition mud @ shoe 140 spm @ 1600 psi 06:00 - 08:30 2.50 DRILL TRIP INTRM1 POOH Stand back drillpipe, HWDP and flex collars. 08:30 - 10:30 2.00 DRILL PULD INTRM1 Drain BHA, break bit, download MWD and UD BHA 1 0:30 - 1 0:45 0.25 CORE CIRC INTRM1 Pre-job safety meeting on picking up core barrels. 10:45 - 12:30 1.75 CORE PULD INTRM1 PIU core barrels and space out inner barrels. 12:30 - 14:30 2.00 CORE TRIP INTRM1 RIH wI coring assembly for Core #1 to 9 5/8" shoe - filling pipe every 10 stds 14:30 - 15:00 0.50 CORE CIRC INTRM1 Circulate bottoms fl 9 5/8" shoe - 318 gpm @ 770 psi ( service TD while circ) 15:00 - 16:30 1.50 CORE SURV INTRM1 Continue to RIH wI core bbl. fl 2663' to 5500' 16:30 - 17:00 0.50 CORE CIRC INTRM1 Circulate @ 5500' 294 gpm @ 1200 psi 17:00 - 19:00 2.00 CORE TRIP INTRM1 Continue RIH wI core bbl. - fill pipe & circulate last 88' - Tag bottom 19:00 - 20:45 1.75 CORE CIRC INTRM1 Circulate bottoms up ICR 196 gpm @ 740 psi - FCR 294 gpm @ 1285 psi - drop ball - obtain SPR Printed: 4/30/2004 3: 11: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 . . .. . "... . SUb·.·.. Ffbh1+tö ··HþÜr$ .... G(jde ·q()d~ . Start: 3/18/2004 Rig Release: 4/7/2004 Rig Number: Spud Date: 3/19/2004 End: 4/7/2004 Group: . ", ". .... .". . . '" . .... . ....... . ... ",' ......... .. ........." '" ..... '. . ..... . . ... pØ$cripfióppf"OÞØratiqri$ Recover core #1 cut 32' recovered 32' - LD outtercore bbls.& bit MU stack washer & flush stack - Blow down TD RU - Pull wear bushing - Set test plug - Prep to test BOPE Test BOPE to 250/5000 psi, John Crisp, AOGCC, waived witnessing the BOP test. Pull test plug. Blow down kill line and test equipment Install wear ring. Run in 4 LDS's. UD setting tool P/U bit, motor, MWD tools. Orient and upload MWD. Do shallow test and MWD (directional module failed-accelerometer quit) UD hang oft collars, Change out DM hang oft collar, Upload MWD and pulsar not reading. Change out electrical connection between hang oft collars Continue to upload MWD. MWD computer in shack crashed and had to reload softwar Upload MWD and load nukes RIH w/ three stands of SWDP-Shallow test MWD and blowdown top drive Cut and slip drilling line. Check crown-o-matic RIH f/ 600' to 2663' Circulate & calibrate Accustic caliper MWD tool Continue RIH f/ 2663' to 8135' - (fill pipe every 10 stds) Break circulation - (tighten belts on MP#1) wash & ream f/ 8135' to 8220' (running MAD pass w/ MWD tools) Drill 8 1/2" hole f/ 8220' to 8229' MD - 6087' TVD ADT - .25 hrs. WOB - 15 RPM - 80 GPM 450 @ 3280 psi String wt. PU 185 SO 87 Rot 125 Torque on/oft btm - 11,300/9700 ft. Ibs. 4.75 DRILL DRLG INTRM1 Drill 8 1/2" hole f/ 8229' to 8424' - 6272' TVD - ADT - 8.42 hrs. WOB -10/20K RPM 75 GPM 470 @ 3700 psi String wt. PU 140 SO 125 Rot. 130 Torque on/oft btm - 13,000/ 11,500 ft. Ibs ECD - 11.3 Drill 8 1/2" hole f/ 8424' to 8824' - 6656' TVD - (ADT - 8.42 hrs. 8229' M.D to 8824' M.D.) Circulate and condition mud. Pump 1 low vis and 1 hi vis sweep. Geologist evaluating samples and logs Continue drill from 8824' to 9118'-6939' TVD ADT =5.13 hrs WOB=10/15k, RPM=75 rpm, Pump=470 gpm @ 3700 psi P/U=147k, S/O=125k, Rot=137k, Torque=13k oft/14k on ECD=11.07 Circulate and survey. Prep to pump sweeps Time change for daylight savings time Circulate hi vis weighted sweep and low vis weighted sweep around. Circulate and pump out 5 jts Replace wash pipe in swivel Pump out 5 more joints and UD. Pump out 15 stands of d.p. Blow down top drive and POOH to shoe Circulate and calibrate acoustic caliper tool. Blow down top drive POOH 3/31/2004 4/1/2004 20:45 - 00:00 3.25 CORE CORE INTRM1 00:00 - 10:00 10.00 CORE CORE INTRM1 10:00 - 17:00 7.00 CORE TRIP INTRM1 17:00 - 18:30 1.50 CORE TRIP INTRM1 18:30 - 22:00 3.50 CORE RCVR INTRM1 22:00 - 23:00 1.00 DRILL OTHR INTRM1 23:00 - 00:00 1.00 WELCT OTHR INTRM1 00:00 - 06:30 6.50 WELCT BOPE INTRM1 06:30 - 07:00 0.50 WELCT NUND INTRM1 07:00 - 08:00 1.00 WELCT NUND INTRM1 08:00 - 09:00 1.00 DRILL PULD INTRM1 09:00 - 12:15 3.25 DRILL OTHR INTRM1 4/2/2004 12:15 - 14:00 1.75 DRILL PULD INTRM1 14:00 - 14:30 0.50 DRILL TRIP INTRM1 14:30 - 16:00 1.50 RIGMNT RSRV INTRM1 16:00 - 17:00 1.00 DRILL TRIP INTRM1 17:00 - 17:30 0.50 DRILL CIRC INTRM1 17:30 - 22:00 4.50 DRILL TRIP INTRM1 22:00 - 23:45 1.75 DRILL REAM INTRM1 23:45 - 00:00 0.25 DRILL DRLG INTRM1 4/3/2004 00:00 - 04:45 04:45 - 13:00 8.25 DRILL DRLG INTRM1 13:00 - 14:30 1.50 DRILL CIRC INTRM1 14:30 - 23:30 9.00 DRILL DRLG INTRM1 23:30 - 00:00 0.50 DRILL CIRC INTRM1 4/4/2004 00:00 - 01 :00 1.00 DRILL OTHR INTRM1 01 :00 - 03:30 2.50 DRILL CIRC INTRM1 03:30 - 04:30 1.00 RIGMNT RGRP INTRM1 04:30 - 06:30 2.00 DRILL TRIP INTRM1 06:30 - 09:30 3.00 DRILL TRIP INTRM1 09:30 - 10:00 0.50 DRILL SURV INTRM1 1 0:00 - 10:30 0.50 DRILL TRIP INTRM1 Cut core # 1 f/ 8188' to 8192' Core from 8192' to 8220'. Cut 32' of core total. POOH w/ Core #1 @ 3 minutes / stand as per tripping procedure Continue to POOH w/ core #1 @ 6 mins/std as per tripping procedure Printed: 4/30/2004 3: 11: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 Start: 3/18/2004 Rig Release: 4/7/2004 Rig Number: Spud Date: 3/19/2004 End: 4/7/2004 Group: .. . . . . '. ..". . . . .. . . . .. . .. . . . ..;q~sçript!bn·.;()f.··qPßr~Ùoh$·· . b~te ..: Ftom..m<f . H()uh~GQd~ ,~ôuJè 4/4/2004 UD ghost reamer and HWDP Download MWD LD BHA - clean up rig floor RU tongs - PJSM - MU 3 1/2" mule shoe & PU 48 jts. 3 1/2" tbg for cmt stringer Change handling equipment for 4" DP RIH w/3 1/2" cmt stringer on 4" DP to 9110' RU & circulate bottoms up - Prep to set P&A plug #1 PJSM - Set P&A plug #1 (1st. stage) wI Open end tbg set @ 9110' set ." Cmt plug fl 9110' to 8541' wI as follows: Pumped 5 bbls water - test lines to 2500 psi - pumped 5 bbls water - Mixed & pumped 52.6 bbls(255 sxs) Class G wI additives @ 15.8 ppg - Displaced to equalize- CIP @ 0115 hrs. ABANDN Pulled out wI 6 stds to 8541' - Circulate btms up - Dumped 12 bbls+l- cmt & 95 bbls +1- contaminated mud - circ & condition for Stage #2 of plug #1 1.00 ABAND PLUG ABANDN PJSM - Set stage #2 of P&A plug #1 as follows: WI Open end tbg set ,/ @ 8541' - Pumped 5 bbls water - test lines to 2500 psi - pumped 5 bbls water - Mixed & pumped 50.5 bbls(244 sxs) Class G wI additives @ 15.8 ppg - Displaced to equalize - Calc top @ 7821' - CIP @ 0615 hrs. ABANDN POOH wI 12 stds DP fl 8541' to 7405' ABANDN Circulate bottoms up @ 7405' - no cmt or contaminated mud to surface ABANDN POOH fl 7405' - Stand back 10 stds in derrick - Pull out & LD remainiing drill pipe ABANDN RD drill pipe handling equipment & RU tbg handling equipment - LD tbg stinger(48 jts.) ABANDN Change handling tools back for DP ABANDN MU Baker Cmt retainer - RIH to 2588' ABANDN Attempt to set cement retainer - Retainer wouldn't take weight after setting - Pushed retainer down hole to 2623' - while trying to get ret. to set 3.00 ABAND PLUG ABANDN Cement retainer wouldn't take weight aftger setting - bottom slips not engaged - pushed down to casing collar @ 2624' - retainer took wt. - Attempt to pressure test csg to confirm retainer set - pressure up to 650 psi - lost 400 psi - bleed oft pressure- retainer still not set - push retainer out into open hole to 2816' (153' below shoe) Pull back into 9 5/8" shoe - no indication of retainer on DP while pulling through shoe Circulate btms. up POOH - LD Baker running tool Rig down Sperry Sun equip. fl draw works & stand pipe manifold MU wash tool on DP & RIH to 2816' to confirm location of cement retainer POOH - LD 2 jts. Dp & wash tool Service rig RU Baker K-1 cement retainer - RIH to 2559' (104' above shoe) Set cement retainer @ 2559' - Establish injection rate - 2 bbls/min @ 250 psi - unsting & test csg to 1000 psi - OK by John Crisp AOGCC Circ - PJSM - Batch mix cement Set shoe plug as follows: Sting into retainer - Pump 5 bbls water & test lines to 1500 psi - pumped 18.7 bbls Class G wI additives @ 15.8 ppg - pumped 3 bbls water & displace w/22.2 bbls mud (14.6 bbls cmt below retainer) - Unsting fl retainer & pull 2 stds DP - dumping 4 bbls cmt on 10:30 - 13:00 2.50 DRILL PULD INTRM1 13:00 - 14:30 1.50 DRILL OTHR INTRM1 14:30 - 16:30 2.00 DRILL PULD INTRM1 16:30 - 18:30 2.00 ABAND TRIP INTRM1 18:30 - 19:30 1.00 ABAND INTRM1 19:30 - 22:30 3.00 ABAND INTRM1 22:30 - 00:00 1.50 ABAND INTRM1 00:00 - 01 :15 1.25 ABAND ABANDN 4/5/2004 01:15 - 05:15 05:15 - 06:15 06:15 - 07:15 07:15 - 08:30 08:30 - 15:15 15:15 - 18:00 18:00 - 18:30 18:30 - 21 :00 21 :00 - 00:00 4/6/2004 00:00 - 03:00 03:00 - 04:00 1.00 ABAND ABANDN 04:00 - 05:30 1.50 ABAND ABANDN 05:30 - 06:15 0.75 ABAND ABANDN 06:15 - 08:00 1.75 ABAND ABANDN 08:00 - 09:30 1.50 ABAND TRIP ABANDN 09:30 - 10:00 0.50 RIGMNT RSRV ABANDN 10:00 - 12:00 2.00 ABAND PLUG ABANDN 12:00 - 13:00 1.00 ABAND PLUG ABANDN 13:00 - 14:00 1.00 ABAND CIRC ABANDN 14:00 - 14:45 0.75 ABAND PLUG ABANDN Printed: 4/30/2004 3: 11: 1 0 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PLACER #2 PLACER #2 ROT - DRILLING n1433@ppco.com Nordic 3 . ·C·· . ode ·.$Ûþ .....' ..p'. ..',..h··.·:.a:.· :s: ·.e.:· ....'..'...,'. ....:.:....... ...çqq~: 4/6/2004 14:00 - 14:45 0.75 ABAND ABANDN 14:45 - 15:45 1.00 ABAND ABANDN 15:45 - 17:00 1.25 ABAND ABANDN 17:00 - 17:30 0.50 ABAND ABANDN 17:30 - 20:30 3.00 ABAND ABANDN 20:30 - 21:15 0.75 ABAND ABANDN 21:15 - 22:45 1.50 ABAND ABANDN 22:45 - 00:00 1.25 ABAND ABANDN 417/2004 00:00 - 01 :45 ABANDN 01 :45 - 03:00 ABANDN 03:00 - 08:30 ABANDN 08:30 - 12:00 ABANDN Start: 3/18/2004 Rig Release: 4/7/2004 Rig Number: Spud Date: 3/19/2004 End: 4/7/2004 Group: :. (Je$ctiþtiqhotQÞØrciti(jh$ .:...... top of retainer Circulate 2X btms. up - No cement to surface RU & pressure test csg & retainer to 2500 psi for 30 mins. Cmt job & pressure test witnessed & approved by John Crisp AOGCC Blow down & RD cmt lines - RU to LD DP POOH LD excess DP & Baker running tool RIH to 600' w/ open end DP - RU to circulate Circulate - Spot Hi-vis pill (25 bbls) f/600' to 285' - Pull up to 285' Circulate hole clean w/50 bbls. water - Set surface plug f/285' to 40' - ./ Pump 3 bbls water - test line to 1000 psi - Pumped 18.5 bbls AS1 - Pump 3 bbls water - CIP @ 2359 hrs. MU BOP stack washing tool- Wash stack with fresh water - Blow down F-1000 MPs & surface lines - Vac all fluids to truck UD last 2 stds 4" DP from derrick - Pull wear bushing and remove all test tools from rig floor. N/D BOP system and set back on bop stump. Secure from rig move. - Cleaning pits Cleaning pits - Prepare rig for move - Rig release 12:00 hrs (417/04) Printed: 4/30/2004 3: 11 : 1 0 PM Halliburton Sperry-Sun North Slope Alaska ConocoPhillips Exp Exploration 2004 Placer 2 -~! Job No. AKZZ2978409, Surveyed: 3 April, 2004 Survey Report 6 April, 2004 Your Ref: API 501032048800 Surface Coordinates: 5976417.44 N, 451251.65 E (70020' 46.9298" N, 150023' 44.5287" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '- Surface Coordinates relative to Project: 22.56 S, 97.35 W (Grid) Surface Coordinates relative to Structure: 23.19 S, 97.20 W (True) Kelly Bushing Elevation: 56.00ft above Mean Sea Level Kelly Bushing Elevation: 56.0Off above Structure 5pE!r'r"Y-SUl! DFUL.L.ING SERVices A Halliburton Company Survey Ref: svy363 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Placer 2 Your Ref: API 501032048800 Job No. AKZZ2978409, Surveyed: 3 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -56.00 0.00 O.OON 0.00 E 5976417.44 N 451251.65 E 0.00 AK-6 BP _IFR-AK - IIFR+MS 110.00 0.000 0.000 54.00 110.00 0.00 N 0.00 E 5976417.44 N 451251.65 E 0.000 0.00 197.95 0.450 112.610 141.95 197.95 0.13 S 0.32 E 5976417.31 N 451251.97 E 0.512 0.20 290.83 0.570 65.780 234.83 290.83 0.08S 1.08 E 5976417.35 N 451252.73 E 0.452 0.88 384.19 0.970 60.720 328.18 384.18 0.49 N 2.19 E 5976417.92 N 451253.84 E 0.434 2.13 -' 469.32 2.130 52.670 413.27 469.27 1.81 N 4.08 E 5976419.22 N 451255.74 E 1.383 4.42 565.32 3.060 48.730 509.18 565.18 4.58N 7.42 E 5976421.97 N 451259.10 E 0.986 8.72 659.83 4.860 49.270 603.46 659.46 8.85N 12.35 E 5976426.21 N 451264.06 E 1.905 15.15 752.94 6.460 49.600 696.11 752.11 14.82 N 19.33 E 5976432.14 N 451271.08 E 1.719 24.21 845.45 8.040 53.310 787.88 843.88 22.06 N 28.48 E 5976439.32 N 451280.27 E 1.780 35.79 937.86 10.690 59.320 879.05 935.05 30.30 N 41.04 E 5976447.47 N 451292.88 E 3.053 50.80 1029.85 12.310 60.590 969.19 1025.19 39.47 N 56.92 E 5976456.54 N 451308.82 E 1.782 69.13 1122.56 14.680 56.640 1059.34 1115.34 50.78 N 75.34 E 5976467.73 N 451327.32 E 2.741 90.75 1215.64 18.240 52.900 1148.59 1204.59 66.06 N 96.82 E 5976482.87 N 451348.90 E 3.989 117.03 1309.70 20.770 53.120 1237.24 1293.24 84.95 N 121.90 E 5976501.60 N 451374.10 E 2.691 148.28 1404.97 24.250 55.210 1325.24 1381.24 106.26 N 151.49 E 5976522.71 N 451403.83 E 3.748 184.62 1499.11 30.250 60.300 1408.91 1464.91 129.06 N 188.01 E 5976545.28 N 451440.49 E 6.832 227.67 1594.00 37.090 60.910 1487.83 1543.83 154.85 N 233.82 E 5976570.76 N 451486.48 E 7.217 280.22 1688.33 40.820 61.700 1561 .18 1617.18 183.30 N 285.85 E 5976598.88 N 451538.68 E 3.989 339.46 1783.37 43.230 62.580 1631.77 1687.77 213.02 N 342.10 E 5976628.23 N 451595.12 E 2.610 402.97 1877.36 46.730 62.340 1698.25 1754.25 243.74 N 400.99 E 5976658.57 N 451654.22 E 3.728 469.26 1972.45 51.300 61.180 1760.60 1816.60 277.72 N 464.20 E 5976692.13 N 451717.65 E 4.893 540.93 2066.69 52.750 61.500 1818.58 1874.58 313.34 N 529.39 E 5976727.33 N 451783.06 E 1.562 615.14 .~ 2161.50 53.190 60.480 1875.68 1931.68 350.05 N 595.58 E 5976763.61 N 451849.49 E 0.976 690.77 2255.82 53.500 59.140 1931.99 1987.99 388.10 N 660.98 E 5976801.23 N 451915.14 E 1.186 766.42 2350.57 53.730 56.070 1988.21 2044.21 428.96 N 725.37 E 5976841.67 N 451979.79 E 2.620 842.67 2446.20 53.570 56.120 2044.89 2100.89 471.92 N 789.29 E 5976884.22 N 452044.00 E 0.173 919.60 2540.47 53.360 55.420 2101.01 2157.01 514.53 N 851.92 E 5976926.42 N 452106.90 E 0.637 995.24 2604.11 53.060 55.950 2139.12 2195.12 543.26 N 894.01 E 5976954.88 N 452149.18 E 0.817 1046.13 2748.47 53.220 55.330 2225.72 2281.72 608.45 N 989.36 E 5977019.44 N 452244.95 E 0.361 1161.46 2842.94 53.020 54.840 2282.41 2338.41 651.70 N 1051.32 E 5977062.29 N 452307.19 E 0.466 1236.86 2935.53 50.510 57.260 2339.72 2395.72 692.33 N 1111.63 E 5977102.53 N 452367.76 E 3.400 1309.49 3030.02 50.150 56.870 2400.04 2456.04 731.87 N 1172.67 E 5977141.67 N 452429.06 E 0.496 1382.19 3124.86 49.230 58.490 2461.39 2517.39 770.54 N 1233.78 E 5977179.94 N 452490.41 E 1.624 1454.49 3218.38 48.890 57.960 2522.67 2578.67 807.74 N 1293.83 E 5977216.75 N 452550.71 E 0.562 1525.13 6 April, 2004 - 16:28 Page2of5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Placer 2 Your Ref: API 501032048800 Job No. AKZZ2978409, Surveyed: 3 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 3312.68 48.440 58.940 2584.96 2640.96 844.79 N 1354.17 E 5977253.41 N 452611.29 E 0.915 1595.93 3408.72 48.690 60.090 2648.51 2704.51 881.32 N 1416.22 E 5977289.53 N 452673.57 E 0.935 1667.93 3503.39 48.490 59.490 2711.13 2767.13 917.04 N 1477.58 E 5977324.85 N 452735.16 E 0.520 1738.92 3597.91 48.670 60.500 2773.66 2829.66 952.49 N 1538.96 E 5977359.90 N 452796.77 E 0.824 1809.78 3690.18 49.090 60.640 2834.34 2890.34 986.64 N 1599.50 E 5977393.66 N 452857.53 E 0.469 1879.26 - 3787.20 50.200 60.280 2897.17 2953.17 1023.09 N 1663.82 E 5977429.69 N 452922.09 E 1.179 1953.16 3882.17 50.380 60.460 2957.84 3013.84 1059.21 N 1727.32 E 5977465.40 N 452985.83 E 0.239 2026.19 3977.20 50.300 60.090 3018.49 3074.49 1095.49 N 1790.86 E 5977501.26 N 453049.59 E 0.311 2099.32 4071 .60 50.210 60.090 3078.85 3134.85 1131.68 N 1853.77 E 5977537.04 N 453112.74 E 0.095 2171.89 4166.07 50.020 60.620 3139.43 3195.43 1167.54 N 1916.77 E 5977572.48 N 453175.98 E 0.475 2244.35 4260.97 50.200 60.230 3200.29 3256.29 1203.47 N 1980.10 E 5977608.01 N 453239.54 E 0.368 2317.14 4354.94 50.220 59.680 3260.43 3316.43 1239.63 N 2042.60 E 5977643.76 N 453302.27 E 0.450 2389.33 4451 .13 50.470 60.370 3321.81 3377.81 1276.63 N 2106.75 E 5977680.34 N 453366.66 E 0.610 2463.37 4547.26 49.910 57.680 3383.37 3439.37 1314.62 N 2170.06 E 5977717.92 N 453430.21 E 2.227 2537.20 4641 .22 49.810 57.610 3443.94 3499.94 1353.06 N 2230.74 E 5977755.96 N 453491.14 E 0.121 2609.01 4736.36 48.540 57.270 3506.14 3562.14 1391.80 N 2291.42 E 5977794.31 N 453552.07 E 1.362 2680.99 4829.97 48.620 57.210 3568.07 3624.07 1429.79 N 2350.45 E 5977831.91 N 453611.35 E 0.098 2751.16 4923.57 48.300 56.780 3630.14 3686.14 1467.95 N 2409.20 E 5977869.69 N 453670.35 E 0.485 2821.18 5019.70 48.540 59.010 3693.94 3749.94 1506.16 N 2470.11 E 5977907.50 N 453731.50 E 1.753 2893.07 5113.48 48.510 58.760 3756.05 3812.05 1542.47 N 2530.26 E 5977943.42 N 453791.89 E 0.202 2963.33 5209.45 48.730 58.150 3819.49 3875.49 1580.14 N 2591.63 E 5977980.69 N 453853.50 E 0.529 3035.34 5304.15 49.090 61.760 3881.74 3937.74 1615.86 N 2653.40 E 5978016.01 N 453915.50 E 2.898 3106.68 5399.08 49.210 61.180 3943.84 3999.84 1650.16 N 2716.48 E 5978049.89 N 453978.81 E 0.479 3178.41 ---- 5491.90 48.530 60.970 4004.89 4060.89 1683.97 N 2777.68 E 5978083.31 N 454040.22 E 0.752 3248.27 5588.31 48.250 60.850 4068.91 4124.91 1719.02 N 2840.67 E 5978117.94 N 454103.44 E 0.305 3320.30 5683.57 47.930 60.210 4132.54 4188.54 1753.89 N 2902.39 E 5978152.42 N 454165.38 E 0.602 3391.16 5776.80 47.240 59.780 4195.42 4251.42 1788.31 N 2961.99 E 5978186.45 N 454225.21 E 0.815 3459.98 5871.49 46.830 59.670 4259.96 4315.96 1823.24 N 3021.83 E 5978220.99 N 454285.28 E 0.441 3529.26 5966.63 46.400 59.400 4325.31 4381.31 1858.30 N 3081.43 E 5978255.66 N 454345.10 E 0.497 3598.40 6062.11 47.550 59.170 4390.46 4446.46 1893.95 N 3141.44 E 5978290.92 N 454405.34 E 1.217 3668.19 6155.90 48.630 59.300 4453.11 4509.11 1929.65 N 3201.41 E 5978326.23 N 454465.55 E 1.156 3737.99 6250.97 49.400 58.770 4515.46 4571.46 1966.58 N 3262.95 E 5978362.76 N 454527.32 E 0.913 3809.75 6345.48 48.990 59.220 4577.22 4633.22 2003.43 N 3324.27 E 5978399.21 N 454588.88 E 0.564 3881.29 6440.16 48.230 58.520 4639.82 4695.82 2040.15 N 3385.07 E 5978435.53 N 454649.92 E 0.976 3952.32 6533.56 49.630 58.980 4701.18 4757.18 2076.68 N 3445.27 E 5978471.66 N 454710.35 E 1.544 4022.73 6 April, 2004 - 16:28 Page 30f5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Placer 2 Your Ref: API 501032048800 Job No. AKZZ2978409, Surveyed: 3 April, 2004 ConocoPhillips Exp North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 6629.85 49.210 58.560 4763.82 4819.82 2114.59 N 3507.80 E 5978509.17 N 454773.13 E 0.548 4095.87 6724.52 48.600 59.060 4826.05 4882.05 2151.54 N 3568.83 E 5978545.72 N 454834.40 E 0.757 4167.21 6818.94 47.870 59.080 4888.94 4944.94 2187.74 N 3629.24 E 5978581.53 N 454895.05 E 0.773 4237.63 6913.13 47.380 58.920 4952.42 5008.42 2223.58 N 3688.89 E 5978616.98 N 454954.92 E 0.535 4307.22 7007.67 46.490 58.630 5016.97 5072.97 2259.38 N 3747.95 E 5978652.40 N 455014.22 E 0.968 4376.29 ~ 7102.24 45.670 59.660 5082.57 5138.57 2294.32 N 3806.43 E 5978686.95 N 455072.92 E 1.169 4444.40 7196.06 43.770 59.690 5149.23 5205.23 2327.65 N 3863.41 E 5978719.91 N 455130.11 E 2.025 4510.41 7291.63 41 .080 59.850 5219.77 5275.77 2360.11 N 3919.11 E 5978752.01 N 455186.02 E 2.817 4574.87 7386.21 38.490 58.840 5292.45 5348.45 2390.95 N 3971.17 E 5978782.51 N 455238.29 E 2.822 4635.38 7480.32 35.840 58.510 5367.44 5423.44 2420.50 N 4019.74 E 5978811.75 N 455287.04 E 2.824 4692.23 7573.44 34.840 59.010 5443.40 5499.40 2448.44 N 4065.79 E 5978839.38 N 455333.28 E 1.118 4746.09 7671 .22 33.480 58.910 5524.30 5580.30 2476.75 N 4112.83 E 5978867.39 N 455380.50 E 1.392 4800.99 7766.10 30.340 59.210 5604.84 5660.84 2502.53 N 4155.84 E 5978892.89 N 455423.67 E 3.314 4851.14 7861.04 26.210 58.980 5688.43 5744.43 2525.62 N 4194.42 E 5978915.73 N 455462.41 E 4.352 4896.10 7955.28 21.780 61.430 5774.51 5830.51 2544.72 N 4227.63 E 5978934.61 N 455495.74 E 4.817 4934.40 8050.29 20.290 62.060 5863.18 5919.18 2560.87 N 4257.66 E 5978950.56 N 455525.88 E 1.586 4968.45 8130.41 19.530 61.520 5938.51 5994.51 2573.76 N 4281.70 E 5978963.30 N 455550.00 E 0.976 4995.70 8146.26 19.330 61.640 5953.46 6009.46 2576.27 N 4286.34 E 5978965.78 N 455554.66 E 1.287 5000.97 8240.46 19.320 60.470 6042.35 6098.35 2591.36 N 4313.62 E 5978980.69 N 455582.03 E 0.411 5032.11 8335.11 18.690 60.900 6131.84 6187.84 2606.45 N 4340.49 E 5978995.61 N 455609.00 E 0.682 5062.92 8428.60 17.920 60.080 6220.60 6276.60 2620.91 N 4366.05 E 5979009.90 N 455634.65 E 0.868 5092.27 8524.48 16.950 60.260 6312.08 6368.08 2635.20 N 4390.97 E 5979024.03 N 455659.67 E 1.013 5120.99 8618.31 16.110 60.590 6402.03 6458.03 2648.38 N 4414.19 E 5979037.05 N 455682.97 E 0.901 5147.67 -- 8714.45 15.680 61.540 6494.49 6550.49 2661.12 N 4437.23 E 5979049.64 N 455706.09 E 0.523 5173.98 8809.33 15.670 60.240 6585.84 6641.84 2673.59 N 4459.62 E 5979061.97 N 455728.57 E 0.370 5199.60 8906.50 15.540 60.770 6679.43 6735.43 2686.46 N 4482.37 E 5979074.69 N 455751.40 E 0.199 5225.73 9002.80 15.220 59.730 6772.28 6828.28 2699.13 N 4504.55 E 5979087.22 N 455773.66 E 0.439 5251.26 9033.41 15.110 59.880 6801.83 6857.83 2703.16 N 4511.47 E 5979091.20 N 455780.61 E 0.382 5259.26 -- 9118.00 15.110 59.880 6883.49 6939.49 2714.22 N 4530.54 E 5979102.14 N 455799.75 E 0.000 5281.31 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB=56' Above MSL. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 58.810° (True). 6 April, 2004 - 16:28 Page 4 of 5 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Exploration 2004 - Placer 2 Your Ref: API 501032048800 Job No. AKZZ2978409, Surveyed: 3 April, 2004 ConocoPhillips Exp North Slope Alaska Based upon Minimum Curvature type calculations, at a Measured Depth of 9118.00ft., The Bottom Hole Displacement is 5281.37ft., in the Direction of 59.074° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~ 9118.00 6939.49 2714.22 N 4530.54 E Projected Survey Survey tool program for Placer 2 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 9118.00 6939.49 AK-6 BP _IFR-AK - IIFR+MS --- 6 April, 2004 - 16:28 Page 50f5 DrillQuest 3.03.06.002 ) ) y ConocoPhillips Alaska, Inc. Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage AK 99510 phone 907.263.4859 TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. 99510 DATE: APRIL 13,2004 AIRBILL: Airland 5271836 AFT#: CPBV04-04-13-34 CHARGE CODE: N.AK.EXPL. OPERATOR: ConocoPhillips Alaska, Inc. SAMPLE TYPE: DRY CUTTINGS NUMBER OF BOXES: 25 NAME: SCOUT #1 PLACER #1 SAMPLES SENT: PLACER #2 PNE COMPLETE SET OF DRY CUTTING FROM PLACER #1. PLACER #2 AND SCOUT #1 AS RECEIVED FROM THE RIG. e:-l (1c.f- VJIL.[ PLACER #1 100'-7761' 11- 1(37 #- II 3 å "/f.-/( 3q ~ ij t( - ())) PLACER #2 J.ð'1-0~(.o SCOUT #1 0'-9118.7' 450'-8050' UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COpy OF THIS TRANSMITTAL TO: RECEIVED BY: tJ (J JlJ ConocoPhillips Alaska Inc. BA YVIEW GEOLOGIC FACILITY 619 E. Ship Creek Ave. ANCHORAGE, AK. 99510-0360 ATTN: D. L. Przywojski ABV-100 DATE: I~ ~';J. ~1 Cc: A. ANDREOU CPAI G. WILSON CPAI r'tl .~ ) ) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: ~~.~~~~rvisor í"<q1 if(lÁ(OZr DATE: April 8, 2004 FROM: John Spaulding, Petroleum Inspector SUBJECT: Surface Abandonment Placer 2 PTD 204-033 Thursdav April 8. 2004: I traveled to Conoco Phillips' wildcat well Placer 2 location to inspect the casing cut-off and surface abandonment of the well. All casing strings were found to be cut off approximately 4 feet below original grade. The outer annulus was full of cement to surface, the inner string of casing had solid cement at 5' 9" down. The mud and green cement was bailed from the inner string and was filled with dry cement. A 3/4 inch thick marker plate was welded to the conductor casing with the required information welded to it. SUMMARY: I inspected the surface cement plug, casing cut-off and the P&A marker plate on the Placer 2 well and found all to be in order. Attachments:· Placer 2 cutoff showing depth of cement.jpg Placer 2 plate on well.jpg Placer 2 plate.jpg NON-CONFIDENTIAL 2004-0408_ Surface _Abandonment_Placer#2.Js.doc e . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg,. ~êát? Jj(q(ð4- P. I. Supervisor {t DATE: April 6, 2004 FROM: John Crisp, Petroleum Inspector SUBJECT: Con()co/Phillips Placer #2 PTD204-033 Casing x Open hole Segregation Plug & PT April 6. 2004: I traveled to Conoco/Phillips Placer #2 Exploratory well to witness the Casing x Open hole segregation plug set & pressure tested. I witnessed an unsuccessful attempt to RIH & set a Baker K-1 cement retainer @ 2587'. The retainer would not pass pressure test before cementing. Decision was made to push the Retainer out of surface casing & 150' into open hole to allow another Retainer to be run. I witnessed a Retainer set successfully @ 2558' MD. A variance from the 100' minimum setting depth regulation was granted. The Retainer was set 104' from surface casing shoe. I requested and received a pressure test of 1000 psi. on the retainer before cementing. A volume of 15.8 ppg Arctic Set cement of sufficient length to cover 100' of open hole below casing shoe was squeezed thru retainer. 52' of 15.8 cement was left on top of retainer. I witnessed a pressure test of segregation plug along with entire surface casing string to 2500 psi. Good test no problems witnessed. Summary: I witnessed Plug & Abandon work performed Placer #2. Attachment: None CONFIDENTIAL Plug & Abandonment Placer #2 04-06-04 JC.doc Placer #2 - PM summa" e Nordic Ria 3 (Downhole): Plug 1: Set cement plug from TD @ 9,110' MD to 7,821' MD (calculated top w/ 35% excess). Plug was placed in 2 stages: Stage #1 set from 9,110' MD to 8,361' MD (749' plug length). Cement volume was 52.6 bbls (255 sxs) - Pipe was pulled up to 8,541' MD (calculated top w/ 0% excess) - Bottoms up was circulated and +/- 100 bbls of contaminated mud was hauled away for disposal. Stage #2 set from 8,541' MD to 7,821' MD (720' plug length). Cement volume was 50.5 bbls (244 sxs) - Pipe was pulled up to 7,405' MD - Bottoms up was circulated with no indication of cement contaminated mud - Pipe was POOH and 3 1/2" tubing stinger (48 joints) layed down. AOGCC waived witnessing the placement of this plug. Plug 2: Set Baker K-l cement retainer @ 2,559' MD (104' above the top of the 9 5/8" casing shoe @ 2,663' MD) - Mixed and pumped 18.7 bbls (90 sxs) 15.8 ppg cement. Squeezed 14.7 bbls cement below retainer. Layed 4 bbls cement on top of retainer. 7.0 bbls cement for open hole volume below 95/8" shoe from 2,663' MD to 2,763' MD 7.7 bbls cement for 104' of 95/8" csg below retainer 4.0 bbls cement for 50' of 9 5/8" csg above cement retainer Following placement of plug 2, the 9 5/8" casing was pressure tested to 2500 psi for 30 minutes. This procedure was witnessed & approved by John Crisp AOGCC. Plug 2 recuired two Baker K-l cement retainers. The first retainer was RIH, with no apparent problems, to planned setting depth of 2,588' MD (75' above the 9 5/8" casing shoe @ 2,663' MD). The retainer was set and the running tool was released. An attempt was made to sting back into the retainer and establish an injection rate. The retainer would not take weight and began moving down hole. Several attempts were made to set the retainer with no success. The retainer was pushed into open hole to a depth of +/- 2,816' MD. The string was POOH and the running toollayed down. A piece of the retainer was recovered from the clay around the bow spring of the running tool. The piece was about 3" long with a bevel on one side. A second retainer was RIH and set, as outlined above, at 2,559' MD. 15.8 ppg Class G Cement with additives was utilized for Plug 1 and Plug 2. Plug 3: Set cement plug from 275' MD to Surface with 18.5 bbls (90 sxs) Arctic Set 1 @ 15.7 ppg. This plug was not witnessed by the AOGCC. Post Ria (Surface): · AOGCC was notified, 24 hrs in advance of final P&A on Placer 2. · Location around wellhead and conductor was excavated to 3' below tundra level. · Base plate and cellar box were removed. · Conductor and inner casing string cut off 3' below tundra level. · Marker plate was welded in place with the following information: PHILLIPS ALASKA, INC. PLACER #2 PTD# 204-033 API# 50-103-20488-00 · Excavation was filled with original material. · John Spaulding, with AOGCC, witnessed the final P&A. · All equipment was de-mobilized and the location was cleaned of debris. MAC 04/15/04 .. e e Placer #2 (ConocoPhillips) Surface Abandonment Inspection Photos from AOGCC Inspector John Spaulding April 8, 2004 Marker Plate Casing cutoff 4 ft below grade; top of cement measurement Marker Plate in place 2004-0408_ Surface_AbandonmenCPlacer#2~s.doc . ..:: ConocoPhillips Alaska, Inc. . Bayview Geological Facility 619 East Ship Creek Ave., Suite 102 Anchorage, AK 99510 phone 907.263.4859 TO: AOGCC 333 WEST 7TH ANCHORAGE, AK. 99510 DATE: April 5, 2004 AIRBILL: Airland 5269699 AFT#: CPBV04-04-05-01 CHARGE CODE: N.AK.EXPL. OPERATOR: ConocoPhillips Alaska, Inc. SAMPLE TYPE: CORE CHIPS NUMBER OF BOXES: 1 NAME: PLACER #2 SAMPLES SENT: ONE COMPLETE SET OF DRY CUTTING AS RECEIVED FROM THE RIG SAMPLE #1-#32 8188-8219.9 SEE ATTACHED LIST. UPON RECEIPT OF THESE SAMPLES PLEASE NOTE ANY DISCREPANCIES AND SEND A SIGNED COPY OF THIS TRANSMITTAL TO: RECEIVED BY: ~ð /.L{ ConocoPhillips Alaska Inc. BAYVIEW GEOLOGIC FACILITY 619 E. Ship Creek Ave. ANCHORAGE, AK. 99510-0360 ATTN: D. L. przywojski ABV-100 DATE: f- A.tJ ÅÞð i Cc: A. ANDREOU CPAI G. WILSON CPAI ~~\{ -073 il/3 g F/l ConocoPhillips Placer #2 Kuparuk Field . . Alaska State Samples 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 8188.0 8189.0 8190.0 8191.0 8192.0 8193.0 8194.0 8195.0 8196.0 8197.0 8198.0 8199.0 8200.0 8201.0 8202.0 8203.0 8204.0 8205.0 8206.0 8207.0 8208.0 8209.0 8210.0 8211.0 8212.0 26 27 28 29 30 31 32 8213.0 8214.0 8215.0 8216.0 8217.0 8218.0 8219.0 March 23, 2004 CL File 104083 ~ð~-O]) iÞll~J fr/~ · STATE OF ALASKA A ALASKA OIL AND GAS CONSERVATION COMrZlON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Á @YJ<> 1,( I J 12( 1- Suspend 0 Repair well 0 Pull Tubing 0 1. Type of Request: Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99515 7. KB Elevation (ft): 54' RKB 8. Property Designation: ADL 25552 / 390305 11. Total Depth MD (ft): 8800' Casing Structural Conductor Surface Total Depth TVD (ft): Effective Depth MD (It): surface Length Size 115' 2608' 16" 9.625" Intermediate Production Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: Operational shutdown 0 o o Perforate 0 Stimulate 0 Plug Perforations Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 Service 0 Variance 0 Annular Dispos. 0 Time Extension 0 Other 0 Re-enter Suspended Well 5. Permit to Drill Number: 204-033 6. API Number: 50-103-20488-00 9. Well Name and Number: Placer #2 10. FieldlPools(s): Exploratorv PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) TJunk (measured): surface cement retainer @ 2537' and at surface MD TVD Burst 115' 2662' 115' 2230' Perforation Depth TVD (ft): N/A Packers and SSSV MD (ft): Tubing Size: n/a none 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 4/3/2004 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact Printed Nam¡ If. Mazzolini Title Exploration Drilling Team Leader SignatureJpJ' ~ ~jj¡¡"-¿üj IÚ.. '- 1 ~ore 263-4603 / J COMMISSION USE ONLY Conditions of approval: N6tify Commission so that a representative may witness Plug IntegrityR. BOP Test 0 Mechanical Integrity Test 0 Location Clearance X Otha,-r "'~ ""1 '"¿)"" \' \' \ús ",,~\j ~ ~ \"C"Ü<=¿) N:> ~"0) \J« \ <t\J<><\\<' RECE IVE 0 w", \ <c <;.ç¿ 1 ('o.~\ -\- t \...JÐ\\~ \\"SVltc\.c\-. -Çùç D\>ÇJOC-\-..Jf\c\-X~ - 2 2004 Subsequent Form Require 0'" \-0 ~\\ ~~~'S.~ ~ \0 (<;.X.\-\Ü.....t ç .k..\...r ·1& . . _ ' F:: \, ,~:) AlaSka t Gas Cons. Commission / ~'t ~ 'I~ BY ORDER OF Anchorage / / / APproved~: I ~~I' 'W A COMMISSIONER THE COMMISSION Date: If-hz..1 ðJ./Í L/ ~ '-- U :'"( I G 11\1·1\ L., / I I RSDM5BtL. ~Ii lUU~ Form 10-403 Revised 2/2003 Collapse Tubing Grade: n/a Tubing MD (ft): n/a none Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Mark Chambers @ 265-1319 Date 4 / ~tv r Sundry Number: 3DY-Æ3 SUBMIT IN DUPLICATE DESCRIPTION DESCRIPTION 1) BASIS OF HORIZONTAL & VERTICAL LOCATION IS USGS MONUMENT WOODS. 2) COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4, NAD 27. 3) GEOGRAPHIC COORD. ARE NAD 27. 4) ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL DATUM. 5) ALL DISTANCES SHOWN ARE TRUE. 6) ICE PAD IS ROTATED 13" WEST FROM NORTH. 7) DATE OF SURVEY: 2/16/04. FB L04-02, pp 64-66. 7 ¡ a/\ J---~_. '" ¡-ì '.,.,'1 I ""\~-;_.; ,. i t../J i \ 1 î t -----... -'-'"f~'T- .- ~-r¡., \"'¡ ¡ î9 ~ ! \ íR\ \ 21 .\~ ¡ 2 \. ¡) \\ .,,<, ; ( " ;r \:' ¡Ç\---+-.- \, .,¿ \\; ! i ; \ ¡~; \ Î\, ''4. ! \ ;"\.. " \~ <¡(~, ~<r.. ¡ \ ~ ; , \ \ ¡ '\ S , \! '0 17 21 "" 2~ ,. r' '\ \ \ \ '-./) 3e\ :a \ 31 \ PI I ?\ .32 a" r~'~ , r' ., VICINITY MAP Scale: 1" = 2 Miles PLACER 1 LOCATED WITHIN PROTRACTED SECTION 33, T 12 N. R 7 E UMIAT MERIDIAN LAT.= 70"20'47.021" LONG.= 150'23'43.392· Y = 5976426.45 x = 451290.60 19' F.W.L, 1009' F.S.L GROUND ELEV. = 21.6' RIG PAD ELEV. = 25.0' \.....:5' ~ Rood '3 - r; (.fl. ~ -- ~~~"-.., ~..~c OF ...._ .-. ~~............. 't . ~\ ~..., ....., 10 ." "'~" . ... ... 9;¡ _M.' ~ ~ . ~¡ - ~ - . . ~ If .....:...... ... .... ..... ... .1 ..... i ~ ~ I. .......... .... ... ... ....................." ... ~ ~ : ~- \~ \. LA J. ROOKUS ~¡ : ,~ II), ", ~LS-8~3M ,.' - ~. ~ð""', L~ "i .. () Þn~ ..."fa, . þ.~Q.. SURVEYOR'S CERTIFICATE -....'TOF"E:SSION>.\..\.. ~... '.._",,~~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF FEBRUARY 16, 2004. \ \ L- \Ce ?a~ -- "E. -- ~ 77'0($00 PLACER 2 32+33 514 LOCATED WITHIN PROTRACTED SECTION 32, T 12 N. R 7 E UMIAT MERIDIAN LA T.= 70·20'46.930· LONG.= 150"23'44.529" Y = 5976417.44 y X = 451251.65 .- 20' F.E.L, 999' F.S.L ' GROUND ELEV. = 22.2' RIG PAD ELEV. = 25.0' ßl LOUNSBURY & ASSOCIATES, INC. SVlIVBYORS BNtmIDRS PLAIIIIIRS , MODULE: XXXX UNIT: M1 PLACER 1 AND 2 EXPLORA TION WELL CONDUCTORS AS-BUILT LOCATION CEA-M1 XX-601 D541 PART: 1 OF 1 REV: 1 ~ ConocoPhillips Alaska, Inc. DRAWING NO: AREA: 00 CADD FILE NO. LK601D541 ~ ¡Iii Exploration Wen - Confidential Conductor: 16", 62.58# 9-5/8" casing cemented to surface with 416 bbls ASL3 (10."7 ppg) lead cement and 83 bbls LiteCRETE (12.0 ppg) tail cement. Surface Casing: 9-5/8" 40# L -80 BTC Float Collar to Surface Casing Set (ã) 2.6.6:/:' MD I 2.230' TVD-RKB -~-~_...- K1 8.108' MD /5.974' TVD-RKB Top Kuparuk 8,209' MD (Est) Base Kuparuk 8.213' MD (Est) J4 (Jurassic UJU) 8,800' MD (Est) TO Planned Belo\!'LJhE) J4 !Estimated Depth @ 8.800' MD - ActuaLJds.u;¡th TBD) 8-%" Open Hole 10.50 PPG LSND Mud 300' Cement Plua Set From Surface to 300' MD 140 sacks Arctic Set 1 Slurry Weight Slurry Yield Thickening Time 15.7 ppg 0.93 cu-ftlsk 2.5 Hrs 225' Cement Plug Set From 2.537' MD to 2.762' MD (50' Above and 175' Below Baker K-1 Cement Retainer) Cement Retainer Set @ +/- 2.587' MD (75' Above Casing Shoe) 90 sacks Class G + Additives Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.17 cu-ft/sk 3.0 Hrs 800' Cement P&A Plug set from TD to +/- 8 000' MD (Top Cement Planned @ 200' MD Above Top Kuparuk) Plan to Set Cement Plug in 2 Staaes 340 sacks Class G + Additives Slurry Weight Slurry Yield Thickening Time 15.8 ppg 1.16 cu-ftlsk 3:15 - 3.30 Hrs Cement Volume Based on 35% Excess Actual Cement Volumes Will Be Recalculated When Final TO Is Determined. Placer 2 - PM Schematic v1.0 prepared by Mark Chambers 04/02/04 · Placer 2 - PM Procedure . Confidential 04/02/04 1. Notify AOGCC 24 hours in advance of all well abandonment operations. Hold pre-job meeting with all personnel to discuss objectives, as well as safety and environmental issues. 2. Mobilize and rig up D/S for well P&A operation. 3. Spot a balanced cement plug #1 from TD @ 8,800' MD to 8,000' MD (approx. 200' above top of the Kuparuk at estimated 8,209' MD). This plug can be laid in two sections as needed. Total interval is approximately 800' in length. 4. Pump cement plug #2 as per AOGCC regulations. Pump sufficient cement through the retainer to extend 175' below (75' of casing volume plus 100' of open hole) and lay a 50' cement cap on top of the retainer. Weight test retainer before pumping cement. Leave 10.5 ppg mud above and below the plug (Weight of mud needed to TD the hole) Pressure test plug to 1500 psi for 30 minutes. 5. Spot a balanced Arctic Set 1 cement plug #3 from 300' to surface. Note: To prevent plug from running down hole plan to spot cement on top of wiper plug. 6. Clear lines and shut down pumps. Rig down cementing unit and clean up. 7. Cut off wellhead and all casing strings at 3 feet below ground level. Send casing head with stub to Materials for repair / re-dressing. 8. Weld cover plate (at least 18" in diameter) over all casing strings with the following information bead welded into the top: PHILliPS ALASKA, INC PLACER #2 PTD# 204-033 API# 50-103-20488-00 9. Remove cellar. Back fill cellar with gravel as needed. Back fill remaining hole to ground level with gravel. Clear ice pad location and demob all materials and equipment. MAC 01/30/02 e . JO~-o~ S Placer #2 - Weekly Progress Report ( Thru 03/21/04 ) Well Date Operations Summary Placer #2 03/18/04 Rig released to move (Placer #1 to Placer #2) at 24:00 on 03/17/04. Performed rig cleaning and maintenance. Moved Nordic Rig 3 off Placer #1. Repositioned rig matts and liner. Moved Nordic Rig 3 onto Placer #2. Continued rigging up. Placer #2 03/19/04 Accepted riq at 00:00 03/19/04. Finished rigging up. Performed diverter test witnessed by AOGCC representative (Totco audible alarms not functional). Performed general maintenance and spud preparation while trouble shooting Totco Problems. Placer #2 03/20/04 Repair rig alarms. Repair conductor valves and riser boot seals. Placer #2 03/21/04 PU BHA and spud well at 04:15. Drill to 224' MD. POOH and PU LWD Tools. RIH and continue directional drilling to 925' MD. Placer #2 03/22/04 Drilled from 925' MD to 1710' MD. Circulated and conditioned for Short trip. Short triped to BHA and back to bottom. Drilled to 2135' MD. Placer #2 03/23/04 Drill from 2135' MD casing point at 2672' MD. Circulate and condition to run 9- 5/8" casing. POOH and LD BHA. RU to run 9-5/8" casing. Placer #2 03/24/04 Run 9 5/8" casing to 2663' MD. Circulate and cement casing. ND diverter. Placer #2 03/25/04 N/D diverter. N/U BHA. Test BOP. Test witness waived by AOGCC. M/U BHA and RIH. Wash contaminated mud from 2532' MD to 2578' MD. Test casing to 2500 psi. Placer #2 03/26/04 Test casing to 2500 psi for 30 minutes. Drill out to 2692' MD. Perform LOT to 14.7 ppg EMW and redo test as FIT to 16.2 ppg. Drill to 2805' MD. Evaluate FIT/LOT. POOH for MWD failure. Change out MWD and Placer #2 03/27/04 Drill from 3181' MD to 4146' MD. Gumbo PO in FL. Clean FL and drill to 4320' MD. Circ and condition for Gumbo. Drill to 4509' MD. Placer #2 03/28/04 Drill from 4509' MD to 4885' MD. Replace wash pipe in swivel. Drill from 4885' MD to 6147' MD. . . Placer #2 - Weekly Progress Report ( Thru 03/21/04 ) <)0\.4 - O~ ~ Well Date Operations Summary Placer #1 03/18/2004 Riq released to move (Placer #1 to Placer #2) at 24:00 on 03/17/04. Performed rig cleaning and maintenance. Moved Nordic Rig 3 off Placer #1. Repositioned rig matts and liner. Moved Nordic Rig 3 onto Placer #2. Continued rigging up. Placer #1 03/19/2004 Accepted riq at 00:00 03/19/04. Finished rigging up. Performed diverter test witnessed by AOGCC representative (Totco audible alarms not functional). Performed general maintenance and spud preparation while trouble shooting Totco Problems. Placer #1 03/20/2004 Repair rig alarms. Repair conductor valves and riser boot seals. Placer #1 03/21/2004 PU BHA and spud well at 04:15. Drill to 224'. POOH and PU LWD Tools. RIH and continue directional drilling to 925' MD. Re: Placer #2 - Permit to Drill Variance e e Subject: Re: Placer #2 - Permit to Drill Variance From: Thomas Maunder <tom_maunder@admin.state.ak.us> ~O l..\ -C):, ~ Date: Fri, 19 Mar 2004 10:40:59 -0900 To: "Chambers, Mark A" <Mark.A.Chambers@conocophillips.com> CC: "Mazzolini, Paul" <Pau1.Mazzolini@conocophillips.com>, "Allsup-Drake, Sharon K" <Sharon.K.Allsup- Drake@conocophillips.com> Mark, et al: Your plan still targets ~e BHL originally planned. Since the well has not been spudded and the BHL has~hanged more than 500', 20 AAC 25.015(a) (2) allows this revision with no further paperwork needed. Your modification is accepted. I will place a copy of this message in the well file. Tom Maunder, PE AOGCC Chambers, Mark A wrote: Tom: After reviewing MDT results from the Placer #1 well (9.9 ppg EMW reservoir pressure) CPAI plans to long string the Placer #2 well, not top set as outlined in our Approved Permit to Drill. This change will allow us to recover a larger diameter core as well as preserve the option for an open hole sidetrack to a 3rd BHL if required. Our revised program is outlined below: Drill 12-1/4 Hole to 2,724' MD / 2,282' TVD-RKB Run 9-5/8" Casing and Cement to surface Drillout and perform LOT / FIT to 16.0 ppg EMW Drill 8-1/2" Hole to Top Kuparuk Core Drill 8-1/2" Hole to 8,424' MD / 6,323' TVD-RKB Run 7" Casing and Cement - Top Cement planned @ 800' MD above top Kuparuk Run 3-1/2" Completion GR / RES / PWD tools are planned for the entire 8-1/2" interval. Neutron / Density tools would be added to our BHA after coring is complete. A revised completion schematic and directional plan have been attached to this e-mail for your review. Please let me know if any other information is required. Mark Chambers Sr. Exploration Drilling Engineer ConocoPhillips Alaska, Inc 907-265-1319 Office 907-240-5868 Cell «Plan Placer 2 (wp05) Approved.pdf» «Placer 2 Completion Schematic.doc» 1 of 1 3/19/2004 10:41 AM Conductor: 16", 62.58# Set @ +1- 115' MD Surface Casing 9-5/8" 40# L-BO BYC - Float Collar to Surface Roat Collar: Weatherford - Single Valve 9-5/8" 32-53# BYC Box x Pin (2) Joints Casing: 9-5/8" 40# L-BO BYC Roat Shoe: Weatherford - Single Valve 9-5/8" 32-53# BYC Box Up e Placer 2 Proposed Completion Schematic Exploration Well - Confidential (Success Case [KeeperC)f Long String) e Conoc6Phillips 1D 12-114" Hole 11II 2 724' MD I 2 282'lVD - RKB Production Casing 7' 26# L-BO BYC - Aoat Collar to Surface Roat Collar: Weatherford - Single Valve 7' 20-35# BYC Box x Pin (2) Joints Casing: 7' 26# L-BO BYC Roat Shoe: Weatherford - Single Valve 7' 20-35# BYC Box Up 1D 8_112" Hole 11II8 424' MD I 6 323'lVD - RKB Success Case Depth ~ 200' MD Below Kuparuk J L Tubing Hanger: FMC Gen V Hanger wI 3-1/2" L-BO EUE Brd Mod pup joint installed (Special Drift Hanger to 2.910" wI Pup Joint Installed). Spaceout Tubing Pups (as required): 3-1/2" 9.3# L-BO EUE 8rd Mod (Special Drift Tubing to 2.910") Tubing (as required): 3-1/2" 9.3# L-BO EUE 8rd Mod (Special Drift Tubing to 2.910") Landing Nipple: 3-1/2" Cameo IŒ-NippleCWI 2.875" No-Go Profile set @ +1- 500' MD IlVD-RKB (CS Lock = 2.906" 00) Tubing (as required): 3-1/2" 9.3# L-BO EUE Brd Mod Gas Un: Mandrel (4 Total): 3-1/2" x 1" Cameo IKBUGml.M wI dummy valves and latches, 6' handling pups installed on top and bottom Position (;1 M~in the following location.<;· 1m 1W Tubing (as required): 3-1/2" 9.3# L-BO EUE Brd Mod Gas Un: Mandrel (1 Total): 3-1/2" x 1-1/2" Cameo II'S!IMG[]]jL.M wI Dump Kill Valve (3000 psi casing to tubing shear). 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 9.3# L-BO EUE 8rd Mod Sliding Sleeve: Baker 3-1/2" CMU Sliding Sleeve wI 2.813" Cameo DS No-Go profile (Lock = 2.856" OD), EUE Brd Box x Pin, 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 9.3# L-BO EUE Brd Mod PBR ( Paclœr Assembly (Packer Setting Depth ìBD): Handling Pup Joint: 3-1/2.", 9.3#, L·BO, EUE Brd ~1od (6 foot length) Polished Bore Reœptide with Seal Stem: Baker, 3-1/2" BO-4D PBR wI 12 ft of seal travel Tubing Anchor: Baker, t·1odel KBH-22 wI Tubing Seal Nipple Packer: Baker, 3-1/2" x l" SAB- 3 Permanent Packer PlalLtQ..SetJJ<idseL1OO'.to.15.Q'..MD--ª.boll.e.tQ¡:t¡¡ed'Q[¡¡tiQ.D Crossover Sub: Baker, 4" LTC Box x 3-1/2" EUE 8rd Pin Handling Pup Joint: 3-1/2", 9.3#, L-BO, ElJE 8rd Mod (6 foot length) Tubing I Pup Joints (as required): 3-1/2",9.3#, L-BO, EUE 8rd Mod Landing Nipple: 3"1/2" Camco D-NippleCWI 2.750" No-Go Profile Tubing I Pup Joints (as required): 3-1/2", 9.3#, L-BO, EUE 8rd Mod Wlreline Re-entry Guide I Shear Out Sub: 3-1/2" Baker Plan to set tubing tail 50' "bow tQp perfor"tion Placer 2 Schematic v1.0 prepared by Mark Chambers 07/21/03 . . FRANK H. MURKOWSKI, GOVERNOR AI/ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Paul Mazzolini Drilling Team Leader ConocoPhillips (Alaska), Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Placer #2 ConocoPhillips (Alaska), Inc. Permit No: 204-033 Surface Location: 4280' FNL, 20' FEL, SEC. 32, T12N, R7E, UM Bottomhole Location: 1584' FNL, 836' FEL, SEe. 33, Tl2N, R7E, UM Dear Mr. Mazzolini: A review of our files has indicated that the approval letter for the subject well was not complete. Here is the correct approval letter for the above referenced exploration well. The approval date remains the same, which was January 30, 2003. This 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. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. In your application, it is indicated that testing of the productive intervals in the well may be performed. A Sundry Application (Form 403) detailing the planned activities should be submitted for approval. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) ofthe diverter function test and BOPE tests must be given so that a representative of the Commission may witness t tests. Notice may be given by contacting the Commission petroleum field inspector on t S er at 659-3607. BY ORDER OFJ!¥ COMMISSION DATED THIS 4day of February, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . . k"J-{~ ~ PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill~ RedrillU 1b. Current Well Class: Exploratory ~ Development Oil U Multiple Zone D Re-entry D Stratigraphic Test D Service D Development Gas D Single Zone 0 2. Operator Name: 5. Bond: 0 Blanket D Single Well 11. Well Name and Number. ConocoPhillips Alaska, Inc. Bond No. 59-52-180 Placer #2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): "' "' P.O. Box 100360 Anchorage, AK 99510-0360 MD: 8720' TVD: 6606' 4a. Location of Well (Govemmental Section): 7. Property Des~nation: > Exploratory Surface: 4280' FNL, 20' FEL, Sec. 32, T12N, R7E, UM ,- Apt... 'JD3C A L 25552 Áb Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1671' FNL, 981' FEL, Sec. 33, T12N, R7E, UM NIA March 15, 2004 Total Depth: 9. Acres in Property: 14. Distance to ~t ,t .- Nearest Property: ....1oe'M" at Targe~t> 1584' FNL, 836' FEL, Sec. 33, T12N, R7E, UM 2560 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest , t Zone- Surface: x- 451252 y- 5976417 4 54' AMSL "' Well within Pool: none, 16. Deviated wells: 17. Anticipated Pressure (see 20 Me 35.035) I - Kickoff depth: 350 ft. Maximum Hole Angle: 49° , Max. Downhole Pressure: 3123 psig I Max. Surface Pressure: 2428 psig 18. Casing Program Setting Depth Quantity of Cement Size Specifications Top Bottom c. I. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 63# B PEB 80' Surface Surface 115' 115' 230 sx AS I 12.25" 9.625" 40# L-80 BTC 2791' Surf. Surf. 2821' 2345' 490 sx AS III Lite & 190 sx LiteCrete 8.5" 7" 26# L-80 BTC-M 8106' Surf. Surf. 8136' 6054' 180 sx Class G + additives 6.125" 3-1/2" 9.3# L-80 EUE-8rd .i8!JO' ~ Surf. 8720' 6606' 100 sx Class G + additives 'lS4 ~,\Ç;'b æ.""" 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (It): Total Depth TVD (It): Plugs (measured) Effective Depth MD (It): Effective Depth TVD (It): Junk (measured) Casing Length Size Cement Volume MD TVD Structural -- - Conductor rs:r 'I ~I-IVt-1 J Surface Intermediate . r:r: D .. C1 ^^^.. Production '''' LJ I LVV't Liner .. - ^- - " Perforation Depth MD (ft): Perforation Depth TVD (ft): !~nChOr~ê 20. Attachments: Filing Fee 0 BOP Sketch EJ Drilling Program0 Time v. Depth Plot D Shallow Hazard Analysis 0 Property Plat D Diverter Sketch 0 Seabed Report D Drilling Fluid Program 0 20 AAC 25.050 requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Chambers @ 265-1319 Printed Name P. Mazzolini Title Drilling Team Leader Signature ?~rv1~ Phone 2'-3-4'03 Date ð 2/ q /2.cx:A- prðn~Tf,rI h" C::h~ron All Commission Use Only permitto~_ API Number: Permit APprov~ ,~0 k;l See cover letter Number: -63:3 50- /ó3 .. 2ð¥'ßB-~ Date: i. for other requirements Conditions of approval : Samples re d §Yes D No Mud log requireb fyes D No Hydro suit" e measures Yes ø No Directional survey required Yes D No Other: ~St~ ~' ~~ ~C)\? ~~~\- ¿. ¿t/ ~r0r: I BY ORDER OF Approved by:-,-- /, l COMMISSIONER THE COMMISSION Date: ' Z Y": L/ ~\../" '- - 7 S~Lit in du ~icate - Form 10-401 Revised 3/2003 . , ( \fØIIIBFl fEB 2 3 200' , p "-:141 · . ConocoPhillips Alaska, Inc. General Drillina Procedure Placer #2 1. MIRU Nordic Rig 3 over pre-installed 16" conductor casing. Weld landing ring on conductor. 2. NU Diverter and function test same. Notify regulatory agencies 48 hours prior to test. 3. PU Directional BHA and prepare to spud. v" 4. Spud well and directionally drill 12-1/4" hole to 9-5/8" surface casing point at +/- 2,821' MD / 2,345' TVD as outlined in directional plan. Run MWD / LWD'logging tools in drill string as required for directional monitoring and formation data gathering. 5. Circulate and condition well bore. Perform short trip. POOH to Run Casing. 6. Run and cement 9-5/8" 40# L-80 BTC casing to surface. Note: Light weight permafrost cement lead slurry and Dowell LiteCrete high compressive, lightweight tail slurry will be utilized to assure cement returns to the surface in a one-stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. A Top Job may only be performed after consultinq with the AOGCC. 7. ND Diverter System. Install and test BOPE. 8. PU Directional BHA. RIH and cleanout to top of float equipment. Test casing to 2500 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. Drill out cement, float collar¡ float shoe and 20' to 50' of new hole. Perform LOT / FIT not to exceed 16.0 ppg EMW. These test results must demonstrate that the integrity of the casing shoe will be sufficient to contain the anticipated we II bore pressures. v 9. Directionally drill 8-1/2" hole to 7" intermediate casing point at +/- 8,136' MD / 6,054'TVD as outlined in directional plan. Run MWD / LWD rógging tools in drill string as required for directional monitoring and formation data gathering. 10. Circulate and condition well bore. Perform short trip. POOH to Run Casing 11. Run and cement 7" 26# L -80 BTC casing to surface. 12. PU Directional BHA and RIH. Cleanout to top of float equipment. Test casing to 2500 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. Drill out cement, float collar, float shoe and 20' to 50' of new hole. Perform LOT / FIT not to exceed 13.5 ppg EMW. 13. Directionally drill 6-1/8" hole to core point. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 14. Circulate and condition well bore. POOH to core. 15. PU Coring equipment,'RIH and core well as required. 16. POOH and LD Coring Equipment. 17. PU Directional BHA and RIH a ~" , , idl · . ConocoPhillips Alaska, Inc. 18. Directionally drill 6-1/8" hole to planned TD at +1- 8,419' MD I 6,322'TVD as outlined in directional plan. Run MWD I LWD logging tools in drill string as required for directional monitoring and formation data gathering. 19. Circulate and condition well bore. Perform short trip. POOH to run open hole Logs. 20. RU E-Line Unit. RIH and Log Well as required. RD E-Line Unit. 21. PU Drill Pipe Conveyed Logging Tools. RIH and Log Well as required. POOH and LD Drill Pipe Conveyed Logging Tools Note: Log results will determine plan to Complete or PluQ and Abandon weUbòre. 22. RIH to TD. 23. Circulate and condition well bore. Perform short trip. POOH to run Production Liner. 24. Run and cement 3-1/2" 9.3# L-80 EUE 8rd Mod production liner. 25. Circulate out any excess cement and displace well to seawater. 26. POOH laying down 4" drill pipe. 27. RIH and install 3-1/2" 9.3# L-80 EUE 8rd Completion Assembly. Prior to stinging into liner top wI completion assembly, test casing to 3500 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. 28. Sting into SBE and land tubing hanger. With annulus open, pressure test tubing to 3500 psi for 5 minutes and monitor annulus for returns. 29. Bleed down pressure in tubing to 1500 psi. While holding 1500 psi on tubing pressure 3-1/2" x 7" annulus to 3500 psi for 5 minutes. Bleed pressure in tubing to zero and shear RP valve in lower GLM. 30. ND BOPE, NU Tree and Test to 5000 psi. Freeze protect well with Diesel. Rig down and move off Nordic Rig 3. Note: Well bore will either be tested. temporarily suspended or P&A'd as oerAOGCC regulations 31. MIRU well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either re-injected into the formation or trucked to Kuparuk or Alpine production facilities. 32. Upon completion of testing, plug and abandon or temporarily suspend the well as per AOGCC regulations. 33. Thoroughly clean location and block off further ice road access to ice location. o é~"1 , "'WI · . Co no coP hill ips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Placer #2 DrillinQ Fluid Properties: Placer #2 Property Grids Surface Hole (Extended Bentonite) Soud to Base of Permafrost Base of Permafrost tototal Denth Initial Value Final Value Initial Value Final Value Density (ppg) 10.0 10.0 10.0 10.0 Funnel Viscosity 150 120 - 150 120 - 150 75 - 120 (seconds) Yield Point 45 - 60 45 - 60 45 - 60 25 - 45 (cP) Plastic Viscostiy 25 - 35 20 - 35 20 - 35 20 - 30 (lb/100 sf) 10 sec Gel Strength 20 - 30 15 - 25 15 - 25 12 - 20 (lb/l00 sf) 10 min Gel Strength 45 - 65 40 - 60 40 - 60 35 - 45 (lb/100 sf) PH 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 8.5 - 9.5 API Filtrate (cc) 8 - 15 <8 <8 <6 Solids (%) 5-8 5-8 5-8 6 - 10 / Intermediate Hole (LSND) Initial Value Final Value Final Value Final Value Final Value Through C-40 Through Through HRZ TO Morraine Density (ppg) 9.5 - 9.8 10.0 10.6 10.8 11.4 Funnel Viscosity 35 - 41 38 - 45 40 - 50 40 - 50 45 - 55 (seconds) Yield Point 22 - 26 25 - 32 25 - 34 25 - 34 25 - 34 (cP) Plastic Viscostiy 10 - 15 15 - 20 18 - 22 18 - 24 18 - 24 (lb/l00 sf) Chlorides < 600 < 600 < 600 < 600 < 600 PH 9 -9.5 9 -10 9 -10 9 -10 9 -10 API Filtrate <6 4-5 4-5 4-5 4-5 ..... HTHP Filtrate < 10 < 10 <10 < 10 < 10 MBT < 20 < 20 < 20 < 20 < 20 Solids (%) <11 < 12 < 14 < 14 < 18 or(·p~ \f f l ~, ".~ · . ConocoPhillips Alaska, Inc. Production Hole (LSND) Kuparuk Density (ppg) 11.0 - 11.4 Funnel Viscosity 45 - 55 (seconds) Yield Point 25 - 35 (cP) Plastic Viscostiy 18 - 24 (lb/lOO sf) Chlorides < 600 PH 9 - 9.5 API Filtrate <6 HTHP Filtrate < 10 MBT < 20 Solids (%) < 18 ./ Note: The oossibilitv exists that Placer #2 is in communication wi Kuoaruk and reservoir pressure is elevated due to - iniection. Therefore. the Drillinq Fluid Prooerties referenced above are based on actual results from Palm (3S- Pad) and not the attached Seismic Pore Pressure Analysis. DrillinG Fluid System: Equipment for Nordic Rig 3 is on file with AOGCC. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. Maximum Anticipated Surface Pressure and CasinG DesiGn: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Size Casing Setting Depth Fracture Pore Formation MASP Drilling Gradient Pressure Pore Gradient Pressure 16" 115' MD / 115' TVD 11.80 ppg 8.90 ppg 53 psi NA 9-5/8" 2,821' MD / 2,345' TVD 13.10 ppg 8.90 ppg 1085 psi 58 psi 7" 8,136' MD / 6,054' TVD 16.40 ppg 10.00 ppg 3148 psi 1339 psi 3-1/2" 8,420' MD / 6,322' TVD 16.50 ppg 9.50 ppg 3123 psi ./ 2428 psi Permit 8,720' MD / 6,606' TVD Requested Permit Depth To Allow For Depth Control Uncertainty - - * FPP = TVD x MW x .052 Note: MASP Information, outlined above, is based on the attached Seismic Pore Pressure Analysis. OR , ,,"iC!' · . ConocoPhillips Alaska, Inc. Procedure for Calculating Maximum Anticipated Surface Pressure: MASP is determined as the lesser of 1) surface pressure at breakdown of the formation at the 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) MASP = [(FG x 0.052) - 0.11] x D Where: MASP = Maximum Anticipated Surface Pressure FG = Fracture Gradient at the casing seat in Ib/gal 0.052 = Conversion factor from Ib/gal to psi/ft 0.11 = Gas Gradient in psi/ft (above 10,000' TVD) D = True vertical depth to casing seat in ft from RKB -OR- 2) MASP = FPP - (0.11 x D) Where: FPP = Formation Pore Pressure at the next casing seat MASP Calculations 1. Drilling below 16" Conductor Casing MASP = [(FG x 0.052) - 0.11] x D = [(11.8 x 0.052) - 0.11] x 115' =~ -OR- MASP = FPP - (0.11 x D) = 1085 - (0.11 x 2345') = 827 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.1 x 0.052) - 0.11] x 2345' MASP = 1339 Dsi -OR- MASP = FPP - (0.11 x D) = 3148 - (0.11 x 6054') = 2482 psi 3. Drilling below 7" Intermediate Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(16.4 x 0.052) - 0.11] x 6054' MASP = 4497 psi -OR- MASP = FPP - (0.11 x D) = 3123 - (0.11 x 6322') = 2428 Dsi v' Casing Design Performance Properties Size Weight Grade Connection Burst Collapse Tensile Yield (ppf) (psi) (psi) 16" 63.0 B PEB Conductor Casing 9-5/8" 40.0 L-80 BTC 5,750 3,090 916 M 7" 26.0 L-80 BTC Mod 7,240 5,410 604 M 3-1/2" 9.30 L-80 EUE-8rd Mod 10,160 10,530 207 M 10 CJI ,~ ~.~ · 111 .<: .t .~ ; '.... . . ConocoPhillips Alaska, Inc. Well Proximity Risks: None. DrillinQ Area Risks: Shallow Hazards: Examination of the offset wells, Colville #1, Kookpuk #1, Atlas #1, reveal no subsurface hazards such as abnormal v pressure or lost circulation zones. A Seismic Analysis was performed for the Placer #1 and Placer #2 wells and Pore Pressure / Fracture Gradient Curves derived. Again, no indications of abnormal pressure or weak formations were seen particularly at shallow depths. The mud weights planned for Placer #2 are conservatively based on those used during drilling of the Palm offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this ...... well with specific regards to potential shallow gas hazards. Seismic Pore Pressure Analvsis was previously submitted with the Placer #1 APD and is currently on file with the AOGCC. Drillina Risks: See attached Drilling Hazards Summary. Annular PumpinQ Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The Placer #2 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the Intermediate/production cement jobs to cover those formations. PAl may request approval to inject or dispose of fluids in the, Placer #2, 9-5/8" x 7" annulus at a later date. This request would be made after sufficient data is available to meet the requirements of AOGCC's 20 MC 25.080. GeoloQv: Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: Formation Deoth Uncertainty Possible Fluid Pore Pressure (TVD-SS) Img Estimated (osi) Permafrost - Base 1375' +/- 250' .. 618 West Sak - Top 1580' +1- 200' 711 West Sak - Base 2040' +/- 200' ... 918 C-80 2390' +/- 200' 1075 C-40 / K-5 2880' +/- 200' 1296 K-3 3975' +/- 200' 1788 K-2 / Moraine - Top 5280' +/- 150' Oil . .¥< 2376 C-30 / Moraine - Base 5398' +/- 150' 2429 HRZ - Top 5710' +/- 150' 2569 C-20 (Mid-Upper HRZ) 5870' +/- 50' 2641 HRZ - Base 5910' +/- 50' 2659 K-l Marker 5990' +1- 50' 2695 Kuparuk C-Sand 6060' +/- 50' Oil " 3500-3700 Miluveach (LCU) 6080' +/- 50' . 2987 Total Depth (Planned) 6268' Total Depth (Permitted) 6552' .' Estimated pressures use calculated gradients derived from Palm 1 MDT data. :0 , q ~, f~ · . Co no coP hill ips Alaska, Inc. Formation Evaluation: Anticipated logging, coring and testing for this well is as follows: I. Logging 12-1/4" Surface Interval LWD: 8-112" Intermediate Interval LWD: GRI Res .' GRI Res ./ 6-1/8" Production Interval LWD: E-Line 1 DP Conveyed: GR 1 Res 1 Neu 1 Den 1 PWD ./ Sonic 1 MDT (Pressure Only) 1 CMR 1 Rotary Sidewall Cores (Optional) II. Coring One conventional full hole core planned in the Kuparuk. III. Mudlogging ,./ Mudlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include ROP on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Thirty-foot (30') wet and dry samples will be collected from Surface to Surface Casing Point. Thirty-foot (30') wet and dry samples will be collected from Surface Casing Point to Intermediate Casing Point. Thirty-foot (30') wet and dry samples will be collected from Intermediate Casing Point to well TD. Ten-foot (10') wet and dry samples, or continuous, collected across all shows and all target intervals. IV. Flow Testing Currently, ConocoPhillips plans to complete and test the Placer #2 well. Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. Reservoir stimulation may be performed in the form of an acid or frac treatment. The flow period will be determined on-site in response to analysis of initial flow period, PBU and fluid properties. The well will be flowed to temporary surface production facilities consisting of gas separation and fluid storage tanks. Produced fluids will either be trucked to an existing production facility or re-injected into the formation following completion of the flow testing operations. 10[;1' - , 9 . . ConocoPhillips Alaska, Inc. Placer #2 DrillinG Hazards Summary (Post in Rig Floor Doghouse Prior to Spud) 12-114" Hole / 9-5/8" CasinG Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Gas Hydrates Moderate '" Mud gas detection, Increased mud weight, Decreased mud viscosity, Decreased circulating times, Controlled drilling rates, Low mud temperatu res. Abnormal Pressure in Surface Moderate ./ Diverter drills, increased mud weight. Reduced I Cautious Formations trip speeds while drilling surface hole. Geologist on location to assist in picking surface casing shoe depth above the CBO/K10 marker. Hole swabbing on trips Moderate Reduced trip speeds, Mud rheology, Proper hole filling (use of triD sheets). PumDinq out of hole Flow checks. Sticky Clay I Tight Hole Moderate Attention to hole cleaning, Wiper trips . Running Sands and Gravels Low Maintain planned mud parameters; Elevated mud viscosity from sDud, Hiqh density sweeps. Lost Circulation Low Reduced pump rates, Mud rheology, Lost circulation material, Use of low density cement slurries 8-112" Hole / 7" CasinG Interval Event Risk Level Mitigation Strategy Abnormal Reservoir Pressure High >" Well control drills, Increased mud weight, Top set casing string. Sticky Clay I Tight Hole Moderate Attention to hole cleaning, Wiper trips Hole swabbing on trips Moderate Reduced trip speeds, Mud rheology, Proper hole filling (use of trip sheets), Pumping out of hole Flow checks. Lost circulation Moderate Reduced pump rates, reduced trip speeds, mud rheology, lost circulation material Differential Sticking Low Good drilling practices, Mud lubes, Keep string moving, Avoid stoDDinq wi BHA across sands. Hydrogen Sulfide gas Low ,/ H2S drills, detection systems, alarms, standard well control Dractices, mud scavengers 6-118" Hole / 3-1/2" Liner Interval Event Risk Level Mitigation Strategy Abnormal Reservoir Pressure High Well control drills, increased mud weight, contingencies for top set casing string. Differential Sticking Moderate Good drilling practices, Mud lubes, Keep string moving, Avoid stopping wi BHA across sands. Lost circulation Moderate Reduced pump rates, reduced trip speeds, mud rheology, lost circulation material Hydrogen Sulfide gas Low ý H2S drills, detection systems, alarms, standard well control practices, mud scavengers o I '. · Placer 2 Propos:!" Completion Schematic Exploration Well - Confidential (Success Case "Ke~rH / Top Set) @onocòPhillips Conductor: 16", 62.58# Set @ +/- 110' MD J Surface Casing 9-5/8" 40# L-80 BTC - Float Collar to Surface Float Collar: Weatherford - Single Valve 9-5/8" 32-53# BTC Box x Pin (2) Joints Casing: 9-5/8" 40# L-80 BTC Float Shoe: Weatherford - Single Valve 9-5/8" 32-53# BTC Box Up TD 12-114" Hole (â) 2.821' MD/2.34S' TVD-RKB Intermediate I Production Casing 7" 26# L-80 BTC - Float Collar to Surface Float Collar: Weatherford - Single Valve 7" 20-35# BTC Box x Pin (2) Joints Casing: 7" 26# L-80 BTC Float Shoe: Weatherford - Single Valve 7" 20-35# BTC Box Up TD 8-1/2" Hole (â) 8,136' MD 1 6.0S4' TVD-RKB TD 6-1/8" ODen Hole (â) 8.420' MD 1 6.322' TVD-RKB Success Case Depth ~200' MD Below Kuparuk TD 6-1/8" Open Hole (â) 8.720' MD 1 6.606' TVD-RKB .I Permitted Depth ~500' MD Below Kuparuk L Tubing Hanger: FMC Gen V Hanger w/ 3-1/2" L-80 EUE 8rd Mod pup joint installed (Special Drift Hanger to 2.910" wI Pup Joint Installed). Spaceout Tubing Pups (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod (Special Drift Tubing to 2,910") Tubing (as required):. 3-1/2" 9.3# L-80 EUE 8rd Mod (Special Drift Tubing to 2.910") Landing Nipple: 3-1/2" Camco 'DS-Nipple' w/ 2.875" No-Go Profile set @ +/- 500' MD I TVD"RKB (CS Lock = 2.906" OD) Tubing (as required): 3"1/2" 9.3# L-80 EUE 8rd Mod Gas Lift Mandrel (4 Total): 3-1/2" xl" Camco 'KBUG' GLM w/ dummy valves and latches, 6' handling pups installed on top and bottom Position GLM's in thê following locations: 1m IY.D. Tubing (as required): 3-1/2" 9.3# L-80 EUE 8rd Mod Gas Lift Mandrel (1 Total): 3-1/2" x 1-1/2" Camco 'MMG' GLM wI Dump Kill Valve (3000 psi casing to tubing shear). 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 93# L-80 EUE 8rd Mod Sliding Sleeve: Baker 3"Y2" CMU Sliding Sleeve wI 2.813" Cameo DS No-Go Profile (Lock = 2.856" OD), EUE 8rd Box x Pin, 6' handling pups installed on top and bottom Tubing (1 Joint): 3-1/2" 93# L-80 EUE 8rd Mod Liner Top Packer I Hanger Assembly (Non-Rotating): Packer Setting Depth Planned (â) 150' above 7" Casing Shoe. Packer: Baker 5" Xl" ZXP Liner Top Packer (5.969" OD, 4.408" 10) Nipple: Baker 5" RS Nipple (5.563" OD, 4.375" 10) Hanger: Baker 5" x 7" HMC Liner Hanger (5.924" OD, 4.408" 10) Seal Bore Receptacle (SBR): Baker 80-40 Casing Seal Bore Receptacle 17' wI 15' öf Effective Seals (5" OD, 4" ID) Crossover Sub: Bakèr 5" BTC Box x 3-1/2" EUE 8rd Mod Pin Production Liner: 3-1/2" 93# L-80 EUE 8rd Mod Landing Collar: Baker w/ 3"1/2" EUE 8rd Mod Box x Pin (1) Joints Casing: 3-1/2" 9.3# L-80 EUE 8rd Mod Float Collar: Baker - Single Valve wI 3-1/2" EUE 8rd Mod Box x Pin (2) Joints Casing: 3-1/2" 93# L-80 EUE 8rd Mod Float Shoe: Baker - Single Valve w/ 3-1/2" EUE 8rd Box Up I 1 Placer 2 Schematic v1.0 prepared by Mark Chambers 02/17/04 Rig: Nordic 3 Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 2/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com < TOC at Surface Previous Csg. < 16", 62.6# casing at 110' MO < Base of Permafrost at 1,497' MO (1,429' TVO) < Top of Tail at 1,800' MO < 95/8",40.0# casing in 12 1/4" OH TO at 2,821' MO (2,345' TVO) Mark of Schlumberger SehtuIDherg8P Preliminary Job Design based on limited input data. For estimate purposes oniy. Volume Calculations and Cement Systems . Volumes are based on 350% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 1,800' MD. "\ Lead Slurry Minimum pump ti~~}~~ min. (pump time plus .90 min.) ARCTICSET Lite @ 10.7 ppg - 4~fSk 0.7632 ft3fft x (110') x 1.00 (no excess) = 84ft3 0.3132 ft31ft x (1497' - 110') x 4.50 (350% excess) = 1954.8 ft3 0.3132 ft3fft x (1800' - 1497') x 1.35 (35% excess) = 128.1 ft3 84 ft3 + 1954.8 ft3+ 128.1 ft3 = 2166.9 ft3 2166.9 ft3 14.43 ft3/sk = 489.1 sks Round up to 490 sks Have 300 sks of additional Lead on location for Top Out stage, if necessary. Tail Sturrv Mln;mum pumg-~ 140 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg -ÖSk 0.3132 ft31ft x (2821' - 1800') x 1.35 (35% excess) = 431.7 ft3 0.4257 ft3/ft x 80' ¡Shoe Joint) = 34.1 ft3 431.7ft3+ 34.1 ft = 465.8ft3 465.8 ft3f 2.47 ft3/sk = 188.6 sks Round up to 190 sks BHST = 54°F, Estimated BHCT = 6JOF. (BHST calculated using a gradient of 2. 6°F f1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW100 5.0 10.0 2.0 .... 2.0 Pressure test lines 0.0 0.0 10.0 . 12.0 CW100 5.0 40.0 8.0 '.. 20.0 Drop Bottom Plug 0.0 0.0 5.0 25.0 MudPUSH II 6.0 50.0 8.3 . 33.3 ASL III 7.0 387.0 55.3...... 88.6 LiteCRETE 5.0 84.0 16.8 105.4 Drop Top Plug 0.0 0.0 5.0 110.4 Mud 7.0 193.0 27.6 138.0 Slow & bump plug 3.0 15.0 5.0 143.0 MUD REMOVAL Recommended Mud Properties: 10.0 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, Pv? 17-21, Ty ? 20-25 Centralizers: Recommend 1 per joint on lower 700' M D '0/.·..1 § \:.' I Rig: Nordic 3 Location: Exploration Client: ConocoPhillips Alaska, Inc. Revision Date: 2/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Previous Csg. < 95/8",40.0# casing at 2,821' MD < Top of Tail at 7,300' MD < 7",26.0# casing in 8 1/2" OH TO at 8,136' MD (6,054' TVD) ScblulbePlfJP Volume Calculations and Cement Systems Volumes are based on 75% excess. Tail slurry is designed for 800' MO above target - (836' MD annular length). Tail Slurrv Minimum thickening time: 160 min. (Pump time plus 90 15.8 ppg Class G + 0.2%D46, 0.3%065, 0.35% D167 + 0,02% B1 retarder to give desired thickening time) k (adjust 185.5 ft3 17.2ft3 202J ft3 173,2 sks BHST = 150°F, Estimated BHCT = 116°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 5.0 5.0 1.0 . 1.0 Pressure test lines 0.0 0.0 10.0 11.0 CW100 5.0 15.0 3.0 14.0 Drop Bottom Plug 0.0 0.0 5.0 19.0 MudPUSH II 6.0 30 5.0 24.0 Tail Slurry 5.0 38 7.6 31.6 Drop Top Plug 0.0 0.0 5.0 .. 36.6 Mud 7.0 288 41.1 77.7 Slow & bump plug 3.0 20 6.7 84.3 MUD REMOVAL Recommended Mud Properties: 11.4 ppg, As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 13.0 ppg MudPUSH* II, Pv? 19-22, Tv? 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. o \,;.~ Rig: Nordic 3 Location: Exploration Client: ConocoPhillips Alaska Revision Date: 2/16/2004 Prepared by: Mike Martin Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 229-6266 email: martin13@slb.com Top of Tail at < 7,786' MO < Liner Top at 7,986' MO Previous Csg. 7",26.0# casing at 8,136' MO < 31/2",9.3# casing in 6 1/8" OH TO at 8,420' MO (6,322' TVO) Ichlollbepgep Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 60% excess. Displacement is calculated with a 4.0"- 14.0# drill string. ". Tail Slurrv Minimum thickening time: 120 min. (pump time plus 90 min.) ¡-. ) 15.8 ppg Class G + 2.0 gps D600G + 0.02% B155 + 0.3% D65 + 0.2 gps D4 -1.16_" ft3/sk '-........./. Liner Cap: 0.1276 ft3/ft x 200' x 1.00 (no excess) = Liner Lap..: 0.1480 ft3/ft x (8136' - 7986') x 1.00 (no excess) = Annular Volume: 0.1378 ft3/ft x (8420' - 8136') x 1.60 (60% excess) = Shoe Volume: 3 0.0488 ft 1ft x 80' x 1.00 (no excess) = Totals: 25.5 ft3 + 22.2 ft3 + 62.6 ft3 + 4.4 ft3 = 114.7 ft3/1.16 ft3jsk = Round up to 100 sks ) BHST = 157°F, Estimated BHCT = 121°F. (BHST calculated using a gradient of 2.6°F/100 ft. below the permafrost) 25.5 ft3 22;2 ft3 62.6 ft3 4.4ft3 114.7 ft3 98,9 sks PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume (bbl) Cumulative Stage Time Time (min) (min) CW100 5.0 5.0 1.0 1.0 Pressure test lines 0.0 0.0 10.0 11.0 CW100 5.0 5.0 1.0 12.0 MudPUSH II 5.0 15.0 3.0 15.0 Tail Slurry 5.0 21.0 4.2 .... 19.2 Drop Wiper Plug 0.0 0.0 5.0 24.2 Mud 5.0 80.0 16.0 40.2 Slow above XO & 3.0 10.0 3.3 43.5 bump plug '. MUD REMOVAL Recommended Mud Properties: 11.0 ppg. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.5 ppg MudPUSH* II, Pv? 19-22, Tv? 22-29 Centralizers: Recommend 1 per joint from 8100' MD to TD for proper cement placement. Mark of Schlumberger ·1 L '- ~ I J . . ·~Ph··········· ..... _II·· Conoco .... ··I..lps ConocoPhillips Alaska Inc. (Exploration) Exploration 2004 Placer Placer 2 Placer 2c Plan: Plan: Placer 2C (wp03) Standard Planning Report 13 February, 2004 SpE!l'l'y-sun DRIL.LING· SERViCeS A HALLIBURTON COMPA. 'IY t illi Engineering Exploration Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based o o o "..... ~ :±: :5 o z ';' :c "5 o (J) G UIi Engineering Exploration Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based "'II'" I : I A UAl,U6l'1{T()N CUi\U'A..'\,\; 30.000 0.000 58.813 30.000 0000 0.000 0.00 0.00 0.00 0.00 350.000 0000 58.813 350.000 0.000 0000 000 0.00 0.00 0.00 "" 1971.760 48653 58.813 1783.770 335.647 554.492 3.00 3.00 0.00 58.81 7011.183 48.653 58.813 5112.916 2294.735 3790.932 0.00 0.00 0.00 0.00 7999.609 19000 58.813 5924.896 2576.500 4256.411 3.00 -3.00 0.00 180.00 8199.609 19000 58.813 6114.000 2610.218 4312.114 0.00 0.00 0.00 0.00 Placer 2c T1 8419.609 19000 58.813 6322014 2647.308 4373388 0.00 0.00 0.00 0.00 .I 8719.609 19.000 58.813 6605.670 2697.886 4456.942 0.00 000 0.00 0.00 2/13/200411.4736AM of6 COMPASS 2003.5 Iii sun A itALLWt.l{TON C01\U'.M'\' 30.000 0.000 58.813 30.000 0.000 0.000 0.000 0.00 0.00 0.00 SHl (4280' FNL &. 20'FEL1Sec32-T12N-R7E) 100.000 0.000 58.813 100.000 0.000 0.000 0.000 0.00 0.00 0.00 200.000 0.000 58.813 200.000 0.000 0.000 0.000 0.00 0.00 0.00 300.000 0.000 58.813 300.000 0.000 0.000 0.000 cwo 0.00 0.00 350.000 0.000 58.813 350.000 0.000 0.000 0.000 0.00 0.00 0.00 Begin Dir @ :tOO: 350'MD, 350' TVD 400.000 1.500 58.813 399.994 0.339 0.560 0.654 3.00 3.00 0.00 500.000 4.500 58.813 499.846 3049 5.037 5.887 3.00 3.00 0.00 600.000 7.500 58813 599.287 8.461 13978 16.339 3.00 3.00 0.00 700.000 10.500 58.813 698044 16.561 27.359 31.981 3.00 3.00 0.00 800.000 13.500 58.813 795.848 27.326 45.143 52.770 3.00 3.00 0.00 900.000 16.500 58.813 892.429 40.727 67.282 78.649 3.00 3.00 0.00 1000.000 19.500 58.813 987.524 56.728 93.715 109.547 3.00 3.00 0.00 1100.000 22.500 58.813 1080.872 75.283 124369 145.379 3.00 3.00 0.00 1200.000 25.500 58.813 1172.216 96.343 159.160 186.048 3.00 3.00 0.00 1300.000 28.500 58.813 1261.306 119.850 197.994 231.442 3.00 3.00 0.00 1400.000 31.500 58.813 1347.899 145.739 240.763 281.437 3.00 3.00 0.00 1496.658 34.400 58.813 1429.000 172.960 285.733 334.004 3.00 3.00 0.00 Base Permafrost 1500.000 34.500 58.813 1431.756 173.939 287.350 335.894 3.00 3.00 0.00 1600.000 37. 500 58.813 1512.649 204.374 337.628 394.666 3.00 3.00 0.00 1700.000 40.500 58.813 1590.354 236.959 391459 457.591 3.00 3.00 0.00 1758.163 42.245 58.813 1634.000 256.865 424.345 496.032 3.00 3.00 0.00 Top West Sak 1800.000 43.500 58.813 1664.660 271.605 448.695 524.496 3.00 300 0.00 1900.000 46.500 58.813 1735.363 308.218 509.179 595.199 300 3.00 0.00 1971.760 48.653 58.813 1783.770 335.647 554.492 648167 3.00 3.00 0.00 End Dir, Start Sail @48.653; 1971.760' MD, 1783.770' TVD 2000.000 48.653 58.813 1802.426 346.625 572.629 669.368 000 0.00 000 2100.000 48.653 58.813 1868.488 385.500 636.852 744.440 0.00 0.00 0.00 2200.000 48.653 58.813 1934.550 424.376 701074 819.512 0.00 0.00 0.00 2300.000 48.653 58.813 2000.612 463.251 765.296 894.584 0.00 0.00 0.00 2400.000 48.653 58.813 2066.674 502.126 829.519 969.656 0.00 0.00 0.00 2441.364 48.653 58.813 2094.000 518.207 856.084 1000.709 0.00 0.00 0.00 Base West Salt 2500.000 48.653 58.813 2132.736 541.001 893.741 1044.728 0.00 0.00 0.00 2600.000 48653 58.813 2198.798 579.877 957.964 1119.800 0.00 000 0.00 2700.000 48.653 58.813 2264.860 618.752 1022.186 1194.872 0.00 0.00 0.00 2800.000 48.653 58.813 2330.922 657.627 1086.409 1269.944 0.00 0.00 0.00 2821.000 48.653 58.813 2344.795 665.791 1099.895 1285.709 0.00 0.00 0.00 9 5t8" @ 2821' MD 2900.000 48.653 58.813 2396.984 696.502 1150.631 1345.016 0.00 0.00 0.00 2971.169 48.653 58.813 2444.000 724.170 1196.338 1398.444 0.00 000 0.00 C80 3000.000 48.653 58.813 2463.046 735.378 1214.853 1420.088 0.00 0.00 0.00 3100.000 48653 58813 2529.108 774.253 1279.076 1495.160 0.00 0.00 0.00 3200.000 48.653 58.813 2595.170 813128 1343.298 1570.232 0.00 0.00 0.00 3300.000 48.653 58.813 2661.233 852.003 1407.521 1645.304 000 0.00 0.00 3400.000 48.653 58.813 2727.295 890.879 1471.743 1720.376 0.00 0.00 0.00 3500.000 48.653 58.813 2793.357 929.754 1535.966 1795.448 0.00 0.00 0.00 2/13/2004 114736AM A l:L,\Lf.llit:R'rON CU1\U'.;\J\\' 3712.896 48.653 58.813 2934.000 1012.518 1672.693 1955.273 0.00 0.00 0.00 C40 K-5 3800.000 48.653 58.813 2991.543 1046.380 1728.633 2020.664 0.00 0.00 0.00 3900.000 48.653 58.813 3057.605 1085.255 1792.855 2095.736 0.00 0.00 0.00 4000.000 48.653 58.813 3123.667 1124.130 1857. 078 2170.808 0.00 0.00 0.00 4100.000 48.653 58813 3189.729 1163.005 1921.300 2245.880 000 0.00 0.00 4200.000 48.653 58.813 3255.791 1201.881 1985.523 2320.952 0.00 0.00 0.00 4300.000 48.653 58.813 3321.853 1240.756 2049.745 2396.024 0.00 0.00 0.00 4400.000 48.653 58.813 3387.915 1279.631 2113.967 2471.096 0.00 0.00 0.00 4500.000 48.653 58.813 3453.977 1318.506 2178.190 2546.168 0.00 0.00 0.00 4600.000 48.653 58.813 3520.039 1357. 382 2242.412 2621.240 0.00 0.00 0.00 4700.000 48653 58.813 3586.101 1396.257 2306.635 2696312 0.00 0.00 0.00 4800.000 48.653 58813 3652163 1435.132 2370.857 2771.384 0.00 000 0.00 4900.000 48.653 58.813 3718.225 1474.007 2435080 2846.456 0.00 0.00 0.00 5000.000 48.653 58.813 3784.287 1512.883 2499302 2921.528 0.00 0.00 0.00 5100.000 48.653 58813 3850.349 1551.758 2563.524 2996.600 0.00 0.00 0.00 5200.000 48.653 58.813 3916.412 1590.633 2627.747 3071.672 0.00 0.00 0.00 5300.000 48.653 58.813 3982.474 1629.508 2691.969 3146.744 0.00 0.00 0.00 5370.429 48.653 58.813 4029.000 1656.888 2737.200 3199.616 0.00 0.00 0.00 (K-3) 5400.000 48.653 58.813 4048.536 1668.384 2756.192 3221.816 0.00 0.00 0.00 5500.000 48.653 58.813 4114.598 1707.259 2820.414 3296.888 0.00 0.00 0.00 5600.000 48.653 58.813 4180.660 1746.134 2884.637 3371.960 0.00 0.00 0.00 5700.000 48.653 58.813 4246.722 1785.010 2948.859 3447.032 0.00 0.00 0.00 5800.000 48.653 58.813 4312.784 1823.885 3013.081 3522.104 0.00 0.00 0.00 5900.000 48.653 58.813 4378.846 1862.760 3077304 3597.176 0.00 0.00 0.00 6000.000 48653 58.813 4444.908 1901.635 3141.526 3672.248 0.00 0.00 0.00 6100.000 48653 58.813 4510.970 1940.511 3205.749 3747.320 0.00 0.00 0.00 6200.000 48.653 58.813 4577.032 1979.386 3269.971 3822.392 G.OO 0.00 0.00 630G.000 48.653 58.813 4643094 2018.261 3334.193 3897.464 0.00 0.00 0.00 6400.000 48.653 58.813 4709156 2057.136 3398.416 3972.536 0.00 0.00 0.00 6500.000 48653 58.813 4775.218 2096.012 3462.638 4047.608 0.00 0.00 0.00 6600.000 48.653 58.813 4841.280 2134887 3526.861 4122.680 0.00 0.00 0.00 6700.000 48.653 58.813 4907.342 2173.762 3591.083 4197.752 0.00 0.00 0.00 6800000 48653 58.813 4973.404 2212.637 3655.306 4272.824 GOO 0.00 0.00 6900.000 48.653 58.813 5039.466 2251.513 3719.528 4347.896 0.00 0.00 0.00 7000.000 48.653 58.813 5105.528 2290.388 3783.750 4422.968 0.00 0.00 0.00 7011.183 48.653 58.813 5112.916 2294.735 3790.932 4431.363 0.00 0.00 000 Begin [)ir @ :tOO; 7011.184'MD,5112.911'TVD 7100.000 45.988 58.813 5173.119 2328.544 3846.785 4496.652 3.00 -3.00 0.00 7200.000 42.988 58.813 5244.451 2364.828 3906.727 4566.720 3.00 -3.00 0.00 7300.000 39988 58.813 5319.351 2399.130 3963.393 4632.959 3.00 -3.00 0.00 7319.040 39.417 58.813 5334.000 2405.428 3973.798 4645.122 3.00 -3.00 0.00 Moraine (K-2) 7400.000 36.988 58.813 5397.616 2431.354 4016.628 4695.187 3.00 -3.00 0.00 7467.209 34.972 58.813 5452.000 2451.800 4050.406 4734.671 3.00 -300 0.00 C30 (Base Moraine) 7500.000 33.988 58.813 5479.030 2461.413 4066.286 4753.234 3.00 -3.00 0.00 7600.000 30.988 58.813 5563.371 2489.224 4112.231 4806.941 3.00 -3.00 0.00 ?lOO.OOO 27988 58.813 5650.406 2514.712 4154.337 4856.160 3.00 -3.00 0.00 7800.000 24.988 58.813 5739.899 2537.806 4192.488 4900.756 3.00 -300 0.00 7826.506 24.193 58.813 5764.000 2543.517 4201.924 4911.786 3.00 -3.00 0.00 Top HRZ 7900.000 21.988 58.813 5831.602 2558.442 4226.580 4940.608 3.00 -3.00 0.00 7998.661 19.028 58.813 5924.000 2576340 4256.147 4975.169 3.00 -3.00 0.00 C20 (mid-upper HRZ) 11.47'36AM lips i~ HALLU:¡CKfON (:{)M!'A-t\\ End Dir, Start Sail @ 19.000; 7999.610' MD, 5924.897' TV!) 8000.000 19.000 58.813 5925.266 2576.565 4256.520 4975.605 0.00 0.00 0.00 8040.966 19.000 58.813 5964.000 2583.472 4267.929 4988.943 0.00 0.00 0.00 Base HRZ 8100.000 19.000 58.813 6019.818 2593.425 4284.371 5008.162 0.00 0.00 0.00 8125.576 19.000 58.813 6044.000 2597.737 4291.495 5016.489 0.00 0.00 0.00 1<-1 8136.152 19.000 58.813 6054.000 2599.520 4294.440 5019.932 0.00 0.00 0.00 7" @ 8136' MD 8199.609 19.000 58.813 6114.000 2610.218 4312.114 5040.592 0.00 0.00 0.00 Target: 8200' MD, 6114' TVD; (1671'FNl &. 581'FEl, Sec33-T12N-R7E) - Kuparuk C - Placer 2<: T1 8200.000 19.000 58.813 6114.370 2610.284 4312.223 5040.719 0.00 0.00 0.00 8220.762 19.000 58.813 6134.000 2613.784 4318.005 5047.478 0.00 0.00 0.00 Miluvea<:h (lCU) 8300.000 19 000 58.813 6208.922 2627.143 4340075 5073.276 0.00 0.00 0.00 8400.000 19.000 58.813 6303.473 2644.002 4367.926 5105.833 0.00 0.00 0.00 8419.609 19.000 58.813 6322.014 2647.308 4373.388 5112.217 0.00 0.00 0.00 TO @ 84i5.G05'MD, G322.014'TVD (iG34'FNl &. SiS'FEL, Sec33-T12N-R7E 8500.000 19.000 58.813 6398.025 2660.862 4395.778 5138.389 0.00 0.00 0.00 8600.000 19.000 58.813 6492.577 2677.721 4423.629 5170.946 0.00 0.00 000 8700.000 19.000 58.813 6587.129 2694.580 4451.481 5203.503 0.00 0.00 0.00 8719.609 19.000 58.813 6605.670 2697.886 4456.942 5209.887 0.00 0.00 0.00 Permitted TD: 87iS.GOS'MD, G60S.670'TVD; (1S84'FNL &. 83G'FEL, Sec33-T12N_R7E) - 61/8" 2821000 8136.152 8719.609 2344.795 9518" @ 2821' MD 6054.000 7" @ 8136' MD 61/8" 9.625 7.000 6.125 12.250 7.500 6125 211312004 1147.36AM COMPASS A H,-\.t.t.MlU{To.N COM.I'Al'Ù 1496658 1429.000 Base Permafrost 0.00 1758.163 1634.000 Top West Sak 0.00 2441.364 2094.000 Base West Sak 0.00 2971.169 2444.000 C80 0.00 3712896 2934.000 C40 K-5 0.00 5370.429 4029.000 (K-3) 000 7319040 5334.000 Moraine (K-2) 000 7467.209 5452000 C30 (Base Moraine) 0.00 7826.506 5764.000 Top HRZ 0.00 7998.661 5924.000 C20 (mid-upper HRZ) 0.00 8040.966 5964.000 Base HRZ 0.00 8125.576 6044.000 K-1 0.00 8199.609 6114.000 Kuparuk C 0.00 8220.762 6134000 Miluveach (LCU) 0.00 30.010 350002 1971759 7011.184 7999.609 8199.609 8419.609 8719.609 30.010 350.002 1783.770 5112.917 5924.896 6114.000 6322.014 6605.670 0.000 0.000 335.647 2294.736 2576.500 2610.218 2647.308 2697886 0.000 0000 554.492 3790.933 4256.411 4312.114 4373.388 4456.942 SHL (4280' FNL & 20'FEL fSec32-T12N-R7E) Begin Dir @ 3.00: 350'MD, 350' TVD End Dir, Start Sail @ 48.653; 197"1.760' MD, 1783.770' TVD Begin Dir @ 3.00; 7011.184'MD,5112.917'TVD End Dir, Start Sail @ 19.000; 7999.E¡10' MD, 5924.897' TVD Target: 8200' MD, 6114' TVD; ("1671'FNL & 981'FEL, Sec33-T12N-R7E TD @ 8419.609'MD, 6322.0i4TVD (1634'FNL & 919'FEL, Sec33-T12~ Permitted TD: 8719609'MD, 6605 670'TVD; (1584'FNL & 836'FEL, Se( 2/13/2004 .. Halliburton Sperry-Sun GeoReport .. li5l:Jlll"T'y-sun q""It...LING £;¡Ê"VI!::"S " ",Uut1lt-'R'f~n~""" Survey: Start Date: Company: Engineer: Tool: Tied-to: Survey 30.00 0.000 58.813 30.00 -24.00 0.00 0.00 5976418.140 451251.430 SHL (4280' FNL & 20' FEL; 100.00 0.000 58.813 100.00 46.00 0.00 0.00 5976418.140 451251.430 200.00 0.000 58.813 200.00 146.00 0.00 0.00 5976418.140 451251.430 300.00 0.000 58.813 300.00 246.00 0.00 0.00 5976418.140 451251.430 350.00 0.000 58.813 350.00 296.00 0.00 0.00 5976418.140 451251.430 Begin Dir @ 3°/1000 @ 350 400.00 1.500 58.813 399.99 345.99 0.34 0.56 5976418.475 451251.992 500.00 4.500 58.813 499.85 445.85 3.05 5.04 5976421.156 451256.486 600.00 7.500 58.813 599.29 545.29 8.46 13.98 5976426.509 451265.461 700.00 10.500 58.813 698.04 644.04 16.56 27.36 5976434.521 451278.894 800.00 13.500 58.813 795.85 741.85 27.33 45.14 5976445.169 451296.746 900.00 16.500 58.813 892.43 838.43 40.73 67.28 5976458.424 451318.969 1000.00 19.500 58.813 987.52 933.52 56.73 93.72 5976474.250 451345.503 1100.00 22.500 58.813 1080.87 1026.87 75.28 124.37 5976492.604 451376.275 1200.00 25.500 58.813 1172.22 1118.22 96.34 159.16 5976513.435 451411.199 1300.00 28.500 58.813 1261.31 1207.31 119.85 198.00 5976536.686 451450.181 1400.00 31.500 58.813 1347.90 1293.90 145.74 240.76 5976562.293 451493.114 1496.66 34.400 58.813 1429.00 1375.00 172.96 285.73 5976589.218 451538.256 Base Permafrost 1500.00 34.500 58.813 1431.76 1377.76 173.94 287.35 5976590.186 451539.879 1600.00 37.500 58.813 1512.65 1458.65 204.37 337.63 5976620.289 451590.350 1700.00 40.500 58.813 1590.35 1536.35 236.95 391.46 5976652.520 451644.387 1758.16 42.245 58.813 1634.00 1580.00 256.86 424.35 5976672.210 451677.398 Top West Sak 1800.00 43.500 58.813 1664.66 1610.66 271.60 448.70 5976686.789 451701.842 1900.00 46.500 58.813 1735.36 1681.36 308.21 509.18 5976723.003 451762.558 1971.76 48.653 58.813 1783.77 1729.77 335.64 554.50 5976750.132 451808.042 End Dir, Start Sail @ 48.6 2000.00 48.653 58.813 1802.43 1748.43 346.62 572.63 5976760.993 451826.250 2100.00 48.653 58.813 1868.49 1814.49 385.49 636.86 5976799.445 451890.718 2200.00 48.653 58.813 1934.55 1880.55 424.37 701.08 5976837.897 451955.186 2300.00 48.653 58.813 2000.61 1946.61 463.24 765.30 5976876.349 452019.654 2400.00 48.653 58.813 2066.67 2012.67 502.12 829.53 5976914.801 452084.122 2441.36 48.653 58.813 2094.00 2040.00 518.19 856.09 5976930.706 452110.788 Base West Sak 2500.00 48.653 58.813 2132.74 2078.74 540.99 893.75 5976953.253 452148.590 2600.00 48.653 58.813 2198.80 2144.80 579.86 957.97 5976991.705 452213.058 2700.00 48.653 58.813 2264.86 2210.86 618.74 1022.19 5977030.157 452277.527 2800.00 48.653 58.813 2330.92 2276.92 657.61 1086.42 5977068.609 452341.995 2821.00 48.653 58.813 2344.80 2290.80 665.78 1099.90 5977076.684 452355.533 9 5/8" Csg PI @ 2821' MD 2900.00 48.653 58.813 2396.99 2342.99 696.49 1150.64 5977107.061 452406.463 2971.17 48.653 58.813 2444.00 2390.00 724.15 1196.35 5977134.427 452452.343 C80 3000.00 48.653 58.813 2463.05 2409.05 735.36 1214.86 5977145.514 452470.931 3100.00 48.653 58.813 2529.11 2475.11 774.24 1279.09 5977183.966 452535.399 3200.00 48.653 58.813 2595.17 2541.17 813.11 1343.31 5977222.418 452599.867 3300.00 48.653 58.813 2661.23 2607.23 851.98 1407.53 5977260.870 452664.335 3400.00 48.653 58.813 2727.30 2673.30 890.86 1471.75 5977299.322 452728.803 3500.00 48.653 58.813 2793.36 2739.36 929.73 1535.98 5977337.774 452793.271 3600.00 48.653 58.813 2859.42 2805.42 968.61 1600.20 5977376.226 452857.739 3700.00 48.653 58.813 2925.48 2871.48 1007.48 1664.42 5977414.678 452922.207 3712.89 48.653 58.813 2934.00 2880.00 1012.49 1672.70 5977419.636 452930.519 C40 K-5 3800.00 48.653 58.813 2991.54 2937.54 1046.36 1728.65 5977453.130 452986.675 3900.00 48.653 58.813 3057.61 3003.61 1085.23 1792.87 5977491.582 453051.143 4000.00 48.653 58.813 3123.67 3069.67 1124.11 1857.09 5977530.035 453115.611 Of' .. Halliburton Sperry-Sun GeoReport .. ~y-sun DRILLING SIIiRVICIUII 00. n~u~R''r(N ~"'."'''' 4100.00 48.653 58.813 3189.73 3135.73 1162.98 1921.31 5977568.487 453180.079 4200.00 48.653 58.813 3255.79 3201.79 1201.85 1985.54 5977606.939 453244.548 4300.00 48.653 58.813 3321.86 3267.86 1240.73 2049.76 5977645.391 453309.016 4400.00 48.653 58.813 3387.92 3333.92 1279.60 2113.98 5977683.843 453373.484 4500.00 48.653 58.813 3453.98 3399.98 1318.48 2178.21 5977722.295 453437.952 4600.00 48.653 58.813 3520.04 3466.04 1357.35 2242.43 5977760.747 453502.420 4700.00 48.653 58.813 3586.10 3532.10 1396.23 2306.65 5977799.199 453566.888 4800.00 48.653 58.813 3652.17 3598.17 1435.10 2370.87 5977837.651 453631.356 4900.00 48.653 58.813 3718.23 3664.23 1473.97 2435.10 5977876.103 453695.824 5000.00 48.653 58.813 3784.29 3730.29 1512.85 2499.32 5977914.555 453760.292 5100.00 48.653 58.813 3850.35 3796.35 1551.72 2563.54 5977953.008 453824.760 5200.00 48.653 58.813 3916.41 3862.41 1590.60 2627.77 5977991.460 453889.228 5300.00 48.653 58.813 3982.48 3928.48 1629.47 2691.99 5978029.912 453953.696 5370.42 48.653 58.813 4029.00 3975.00 1656.85 2737.22 5978056.991 453999.097 (K-3) 5400.00 48.653 58.813 4048.54 3994.54 1668.35 2756.21 5978068.364 454018.164 5500.00 48.653 58.813 4114.60 4060.60 1707.22 2820.43 5978106.816 454082.632 5600.00 48.653 58.813 4180.66 4126.66 1746.10 2884.66 5978145.268 454147.100 5700.00 48.653 58.813 4246.73 4192.73 1784.97 2948.88 5978183.720 454211.569 5800.00 48.653 58.813 4312.79 4258.79 1823.84 3013.10 5978222.172 454276.037 5900.00 48.653 58.813 4378.85 4324.85 1862.72 3077.33 5978260.624 454340.505 6000.00 48.653 58.813 4444.91 4390.91 1901.59 3141.55 5978299.076 454404.973 6100.00 48.653 58.813 4510.97 4456.97 1940.47 3205.77 5978337.529 454469.441 6200.00 48.653 58.813 4577.04 4523.04 1979.34 3269.99 5978375.981 454533.909 6300.00 48.653 58.813 4643.10 4589.10 2018.22 3334.22 5978414.433 454598.377 6400.00 48.653 58.813 4709.16 4655.16 2057.09 3398.44 5978452.885 454662.845 6500.00 48.653 58.813 4775.22 4721.22 2095.96 3462.66 5978491.337 454727.313 6600.00 48.653 58.813 4841.28 4787.28 2134.84 3526.89 5978529.789 454791.781 6700.00 48.653 58.813 4907.35 4853.35 2173.71 3591.11 5978568.241 454856.249 6800.00 48.653 58.813 4973.41 4919.41 2212.59 3655.33 5978606.693 454920.717 6900.00 48.653 58.813 5039.47 4985.47 2251.46 3719.55 5978645.145 454985.185 7000.00 48.653 58.813 5105.53 5051.53 2290.34 3783.78 5978683.597 455049.653 7011.18 48.653 58.813 5112.92 5058.92 2294.68 3790.96 5978687.896 455056.859 Begin Dir @ 3°/100lt; 7011 7100.00 45.988 58.813 5173.12 5119.12 2328.49 3846.81 5978721.339 455112.929 7200.00 42.988 58.813 5244.46 5190.46 2364.78 3906.75 5978757.228 455173.100 7300.00 39.988 58.813 5319.36 5265.36 2399.08 3963.42 5978791.155 455229.983 7319.03 39.417 58.813 5334.00 5280.00 2405.37 3973.82 5978797.383 455240.423 Moraine (K-2) 7400.00 36.988 58.813 5397.62 5343.62 2431.30 4016.66 5978823.029 455283.421 7467.20 34.972 58.813 5452.00 5398.00 2451.74 4050.43 5978843.250 455317.324 C30 (Base Moraine) 7500.00 33.988 58.813 5479.04 5425.04 2461.36 4066.31 5978852.760 455333.269 7600.00 30.988 58.813 5563.38 5509.38 2489.17 4112.26 5978880.269 455379.389 7700.00 27.988 58.813 5650.41 5596.41 2514.65 4154.36 5978905.479 455421.656 7800.00 24.988 58.813 5739.91 5685.91 2537.75 4192.51 5978928.321 455459.952 7826.50 24.193 58.813 5764.00 5710.00 2543.46 4201.95 5978933.969 455469.422 Top HRZ 7900.00 21.988 58.813 5831.61 5777.61 2558.38 4226.61 5978948.733 455494.175 7998.65 19.028 58.813 5924.00 5870.00 2576.28 4256.17 5978966.434 455523.852 C20 (mid-upper HRZ 7999.60 19.000 58.813 5924.89 5870.89 2576.44 4256.44 5978966.592 455524.117 End Dir, Start Sail @ 19°, 8000.00 19.000 58.813 5925.27 5871.27 2576.51 4256.55 5978966.659 455524.229 8100.00 19.000 58.813 6019.82 5965.82 2593.37 4284.40 5978983.335 455552.187 8136.14 19.000 58.813 6054.00 6000.00 2599.46 4294.47 5978989.362 455562.292 7" Cgs PI @ 8136'MD 8199.60 19.000 58.813 6114.00 6060.00 2610.16 4312.14 5978999.944 455580.033 Placer 2c T1 8200.00 19.000 58.813 6114.38 6060.38 2610.22 4312.25 5979000.010 455580.145 8220.75 19.000 58.813 6134.00 6080.00 2613.72 4318.03 5979003.471 455585.947 Miluveach (LCU) or:' '0 r. .. .. Halliburton Sperry-Sun ~~:~ GeoReport ~ UU.UM:-Rf«'i I.;U".._"'....- 8300.00 19.000 58.813 6208.93 6154.93 2627.08 4340.10 5979016.686 455608.103 8400.00 19.000 58.813 6303.48 6249.48 2643.94 4367.95 5979033.362 455636.061 8419.60 19.000 58.813 6322.01 6268.01 2647.25 4373.41 5979036.630 455641.542 TD @ 8420' MD Open Hole 8500.00 19.000 58.813 6398.03 6344.03 2660.80 4395.81 5979050.037 455664.020 8600.00 19.000 58.813 6492.58 6438.58 2677.66 4423.66 5979066.713 455691.978 8700.00 19.000 58.813 6587.14 6533.14 2694.52 4451.51 5979083.389 455719.936 8719.60 19.000 58.813 6605.67 6551.67 2697.82 4456.97 5979086.657 455725.416 61/8" Open Hole Wellpath: Placer 2c Drilled From: Well Ref. Point Tie-on Depth: 30.00 It Current Datum: SITE Height 54.00 It Above System Datum: Mean Sea Level Magnetic Data: 12/15/2003 Declination: 24.75 deg Field Strength: 57471 nT Mag Dip Angle: 80.67 deg Vertical Section: Depth From (TVD) +N/-S +EI-W Direction It It It deg 30.00 0.00 0.00 58.813 Targets 30.00 350.00 1971.76 7011.18 7999.60 8199.60 8419.60 8719.60 30.00 350.00 1783.77 5112.92 5924.89 6114.00 6322.01 6605.67 SHL (4280' FNL & 20' FEL; Sec32-T12N-R7E Begin Dir @ 3°/100ft @ 350' MD End Dir, Start Sail @ 48.6°; 1972'MD, 1784' TVD Begin Dir @ 3°/1001t; 7011'MD, 5113TVD End Dir, Start Sail @ 19°, 8000'MD, 5925'TVD Target: 8200'MD, 6114'TVD; (1671'FNL & 981'FEL, TD @ 8420' MD Open Hole Permitted TD @ 8720'MD o , ~i .. .. ConocJP'hillips RECEIVED FEB 1 9 2004 ·ÄIaIM 01/ &. Gas ('.008. Camm_n Anchomge Post Office Box 100360 Anchorage, Alaska 99510-0360 Mark Chambers Phone: (907) 265-1319 Fax: (907) 265-1336 Email: Mark.A.Chambers@conocophillips.com February 17, 2004 Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 333 West th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill: Placer #2 (Exploratorv I Delineation Test) Surface Location: Target 1 Location (Kuparuk C-Sand): Bottom Hole Location (Planned): Bottom Hole Location (Permitted): 4280' FNL, 20' FEL, 1671' FNL, 981' FEL, 1634' FNL, 919' FEL, 1584' FNL, 836' FEL, See. 32, T12N, R7E, UM Sec. 33, r12N, R7E, UM See. 33, 112N, R7E, UM Sec. 33, T12N, R7E, UM Dear Commissioner: ConocoPhillips Alaska, Ine. hereby applies for a Permit to Drill an onshor{ exploratory well, the Placer #2, from the location referenced above approximately 9 miles North West of the Kuparuk River Unit's 2M Pad. This well will be accessed via ice road originating from 2M Pad and drilled using Nordic Rig 3. The Placer #2 is designed to penetrate, evaluate and test the production potential of the objective sands. As indicated in the attachments, the drilling program will entail drilling a 6-1/8" well bore through the objective with a full logging suite for evaluation. Based upon favorable log data, ConocoPhillips plans to run a 3-1/2" production liner. The proposed casing program will utilize 9 5/8" surface casing, 7" intermediate casing, 3-1/2" production liner and 3-1/2" tubing. Please find attached information as required by 20 MC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 MC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 MC 25.005 (c) (1). .. .. 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 MC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Nordic Rig 3) as required by 20 MC 25.035 (a) (1) and (b). Previouslv submitted with the Placer #1 APD and currently on file with the AOGCC. 5) A complete proposed casing and cementing program is attached as per 20 MC 25.030. A well bore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 MC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 MC 25.061(a). Previously submitted with the Placer # 1 APD and currentlv on file with the AOGCC. 8) PHILLIPS does not anticipate the presence of H2S in the formations to be encountered in this well. However, H2S monitoring equipment will be functioning on the drilling rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Complete mudlogging operations such as type log generation and sample catching are planned. The following are ConocoPhillip's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 MC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 MC 25.071) Justine Boccanera, Geologist 263-4236 Please note that Placer #2 is planned as a delineation of the Placer #1 well. Therefore, the bottom hole location, formation tops, pressure estimates, etc. are all subject to change based on the results from Placer #1. If any significant changes are identified, the AOGCC will be notified prior to spud. The anticipated spud date for this well is March 15, 2004. If you have any questions or require further information, please contact Mark Chambers at (907) 265-1319 or Paul Mazzolini at (907) 263-4603 Sincerely, ui~ Mark Chambers Sr. Exploration Drilling Engineer cc: CONFIDENTIAL Paul Mazzolini Mark Chambers Andy Andreou Mike Morgan Placer #2 Well File ATO-1570 ATO-1566 ATO-1312 ATO-1438 ADL .. .. ·. .. TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER HO-Lr¿r ;)() c(~Ó33 .______. ~Ploration Stratigraphic WELL NAME 2- PTD# Development Service CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API num ber Production. should continue to be reported as last two (2) digits a function' of the original API number. stated are between 60-69) above. P~OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for we)) (name on permit). SPACING Tbe permit is approved subject ·to fun EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing exception tbat may //" occur. / DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Well Name: PLACER 2 Program EXP _ Well bore seg nitial Classrrype EXP I PEND GeoArea 89L- Unit 11160 On/Off Shore On Annular Disposal 0 Administration Permit fee attacheJl Yßs 2 LeasenumberapRropJiate Yes Surtace LQcation ADL .39Q3.05;Top ProJl IntervaJ &TDJo ADL 25552 . . - ~ - - ~ 3 .U.nique wellnarnß.aod ol.!mb.er ........ Yßs - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 Well IQcated ina. defjneJlpool. No. Exploration welldJilIed.within ÞOl.!ndarjes pf the KuparukRiver Uoil; tar9-et is thßKuparuk ~ands. . 5 WeJlJocated proper distance. from driJling unitb.ound.ary. Yes Oofy well within.S.. 33, T"12N, R7E, UM;3ßOQ' from nearest prpperty Jioe. . . - - - - - - 6 WellJocatßd proper .distance. from otber weUs. . - - - - - Yes More than 7,500' from PJa.cer. t at target depth, . . - - - -- - - - - - - 7 .Sµfficient acreageayailable In. drilliog unit. Yßs - - - - - - - - - - 8 Ifdßviated, js. weJlbore platilJcJuded . . . . . . Yßs - - - - - - - - - - - - - - 9 Operator Only affected party. . . . - - - - Yes - - - - - - - - - -- 10 .Operator has.apprppriateJ~ond inJorce . . . . . . . . . . . . . . .. .. .Yßs - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - 11 Pßrmit ~o be iSSl.!ed witbout conservation order. . - - - - Yßs - - - - Appr Date 12 Permitc.all be issued witbo.ut ad.ministrativ:eapprpvaJ . Yes - - - - - - - - SFD 2/23/2004 13 Can permit be approved before 15-day wait Yes 14 Well located within area and. strata .authorized by Illjectipo Order # (put 10# in. cP01rneots) (For.NA - - -- . 15 AJI WeUs.Withtn.1l4.mite.area.of reyieW idelltified (Fpr ~ervjc..e.we!l Only). . . . . . . . . . . . . . . NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - 16 Pre-produçed i!lj~ctor; duratiQnof pre-productioo less. than. 3 montbs. (Fors~rvtce welt onJy) . NA - - - - - - - - - - - - -- · 17 ACMP. FInding of Consiste!lCY. h.as bee.n .is.sued for. tbis prpiect . . .Yes Dec..ember5, 2002:. Kaye Lau.Qblin.deemed projed con$i$te!lt with ihe.ACMF'. . - - - - Engineering 18 .C.o!ldu.ctor strIng.provid~d . . . . . . - - - - - - - - - - - - . . Yes - - - -- - - -- 19 .S.uúaceca$ingpJoted~ aiL known USDWs . - - - - · .Yßs No USDWs.. Pr.operly setand cementedsurfa.ce casin.Q .as plaoned willsatisy jntent of25..03Q(c)(3).SFD 20 CMTvptad~Qu.ate.to circµlate.onCOlJductor& SUJfcsg . . - - - -- .Yes - - - - - - - - - - 21 .GMT v.ot adequate. to tie-tnJong .stri!lg to surf csg. . .. No. ~lJnutar disp.osal rn.ay be proposed. . - - -- - - - - 22 CMTwill coyer.all klJow.npro.ductiYe bori;¡!:ons. Yßs - - - - - -- 23 .C.asi!lg desig!lS adequate fpr c,r, B&.permafrost . . .Yes - - - - - - - - - - - - - - - - - - - - 24 .AJlequate.tankage.oJ re.seI"Ye pit. - - -- .Yßs Rig is. equipped.with steelpjts.. NQ r~se.rv:e.pjtpta!lOed, Wa.ste.to approved annulµs or disposal well, . 25 Ifare-drilL has a to-403 fOJ abandOnment beell aRPJov~d . - - - - -- · .NA - - - - - - - - - - - - - - 26 AJlequate.we!lbore ~eparatio.n.proposed. . . . _ . . . . . . . . . . . . . . . . . . . . . .Yßs Placer :I jsAO·.a.w.ay at.s.uúac.e, No direction.at difficuJties are .e?<Reçted.. . . . . . . . . . . . . . _ . . . . . . . . . . . 27 Kdjvecter req.uired, does it meet r~gulaJioos. . . Yes - - - - - - - -- Appr Date 28 .DJiUiog fluid program sch~matic.& eq.uip Jistadequatß. Yes Max expecte.d.6HP. !i.5, pla!loed MW "11.0 0 11..4.. - - - - - - - - - Tift;:J(2004 29 6QPEs,d.oJhey me~tr~gulation . Yßs - - - - - · 30 .6QPE.press ratiog appropriate; .test to.(put psig i)1.com01eots). . . Yßs MAS¡=> calcuJatedat 2428 psi, 35QO.pst approprjate. . CPAJ IjkelyJo tesUO 5QOO psi. 31 .C.hoke.manifold complies w/APIRFJ-53 (May 84). . . - - - - - · .Yes - - - - - - - - -- - - - - - - - - - 32 WQrk will occ.ur withoutoperatjon .shutdow.n. . - - - - - Yßs - - - - - · 33 I~ pres.e!lce. Qf H2S gas. prQbabl~ . - - - - - No Rig is e.quipped.with sensorsalld alarrns. 34 MeçbanicaLcpodjt[o!l Pfwells within ~OR yertfied (for service welJ only). NA - - - - - - - - - - - ~. Geology 35 Permit cao be tSSl.!ed wlo hydrogen. sulfide meas.ures . .Yes No oaturally .occurring H2S is. known withjn.the ioterval.to be drilled. Well wil! be mudJo.Qged. Sensors used, 36 .D.atapres~oted on. pote.ntial oveJpres.s\.lre .ZOnes. . .. .Yes Seismic pore pr~ss.ure. analys.is. pe.rformeØ, but desigo pressure gradient ts .more conservative. based. on 3.S-FJa.dw Appr Date 37 Sßts01icanalysjs. of sballow gasZOlJes . . . Yes Justine.6oççanera, CF'AI:.No evid~oc.eof shalJow. gas seen.in 3D sei~mic. SFD 2/23/2004 38 .Seabedconditipo survey -<if off-shpre) . . NA - - - -- 39 . CQnta.ct narn.elphoneJQrwe~kly progres.sreports [exploratory .o!lly). .Yes Mark Chambers., 90"(-263-4603 - - Geologic Engineering Date Public Date Commissioner Date: Commissioner Commissioner ISI'1 1{ G1) 1- e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. , I I I I I I I I I I I I I I I I I I I Core Lab RESERVOIR OPTIMIZATIOIf AŒtó CORE LABORATORIES Cer¿ vtpnf- 1"" ~r<-1/¡;';~ fr'1. eo ~ in kJaat:: of r4' ð\-1- J (j ~I '- ð 3 3> ~--"_.._"'....~---~_._~...~. I CONFIDENTIAL, CORE ANALYSIS RESULTS CONOCOPHILLlPS ALASKA, INC. PLACER #2 WELL COLVILLE RIVER FIELD CL FILE 57111-104104 Performed by: Core Laboratories 3430 Unicorn Road Bakersfield, CA 93308 (661) 392-8600 I Petroleum Services Division 3430 Unicorn Road Bakersfield. California 93308 Tel: 661-392-8600 Fax: 661-392-0824 www.corelab.com I [ore LaI:Î RESERVOIR OPTIMIZATION I I I Andreas Andreou ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 July 9, 2004 Subject: Transmittal of Conventional Core Analysis Data Placer 2 Well Colville River Field CL File No. 57111-104104 I I I Dear Mr. Andreou: Core Laboratories field personnel provided handling services for conventional aluminum inner-barrel cores recovered from the subject well. Upon completion of coring, the recovered core was packaged and shipped to our Anchorage, Alaska laboratory for initial processing. I Upon arrival at the laboratory the core was scanned for natural gamma radiation. The scanned core was removed from the aluminum barrels and was slabbed uSing a one-quarter/three-quarter cut. The one- quarter slabs were mounted in slab boxes for photography and description, and the three-quarter sections were wrapped with Saran and foil, dipped in CoreSeal and boxed. Horizontal and/or vertically oriented plug samples were drilled from the bulk core segments at sites selected by ConocoPhillips' representatives. Drilled plugs were shipped to our Bakersfield, California laboratory for analysis. Slabbing and plug drilling was performed using Isopar as the coolant/lubricant. I I The one-quarter slabbed core was photographed under white light and ultra-violet light for presentation with our Core Viewer. Both the horizontally and vertically oriented samples were analyzed by Dean-Stark methods. Porosity and permeability were determined using the CMS-300 automated core measurement system. . I I I I I Core and sample remnants were sent to ConocoPhillips' Bayview Geological Facility in Anchorage, Alaska. We appreciate this opportunity to have been of service and look forward to working with you again in the future. I I I Distribution: 1 Core Book, 1 CD : addressee CLB III!II!II MISE Justine Boccanera ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 A (); tt October 8, 2004 Subject: Transmittal of Conventional Core Analysis Data Placer 2 Well Colville River Field CL File No. 57111-104104 Dear Ms Boccanera: As you brought to my attention on October 7, 2004 there did seem to be "rounding" problem between the permeability data presented in the Analysis Results and CMS Perm sections. Thus far I have been unsuccessful in determining the source of the problem but we have established a more rigorous proof reading procedure for data review. I have replaced the data in the Analysis Results Section with the corrected values. I'm sorry that we didn't catch the error ourselves and hope that it didn't cause any undue confusion. We appreciate this opportunity to have been of service and look forward to working with you again in the future. J Distribution: 1 CD : addressee ConocoPhillips Alaska Inc Placer 2 Colville River Field File No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date : October 8, 2004 Care lab Conventional Core Analysis Results 1 8210.7 0.6 0.5 12.3 12.0 83.3 0.14 95.3 2.70 (3) Sltst gry sdyl cly-slt lam no stn no flor 2 8211.1 2.9 2.7 13.9 6.3 91.8 0.07 98.0 2.71 (3) Sltst gry vfgr sdyl cly-slt lam no stn no flor 3 8211.6 9.6 8.7 15.4 32.2 59.4 0.54 91.6 2.74 (3) Sst Ibm vf-pbly vslty m stn dgld flor 4 8212.1 9.1 8.7 24.7 77.3 12.9 5.99 90.2 3.00 (3) Sltst brnl vf-pbly sd m stn dgld flor 8 8212.2 6.1 5.7 25.2 79.0 13.5 5.87 92.5 2.98 (3) Sltst brn! vf-pbly sd/ calc lam m stn dgld flor 5 8212.8 16.5 15.0 13.7 12.4 80.3 0.15 92.7 2.67 (3) Sst bm vf-pbly vslty/mdst lam d stn dgld flor 6 8213.3 25.1 22.7 15.4 5.9 88.9 0.07 94.9 2.80 (3) Mdst gryl vf-gran sst lam frac no stn no flor 7 8214.1 4.7 4.1 14.2 15.6 81.3 0.19 96.9 2.75 (3) Mdst gry frac no stn no flor , * See Procedures page for method descriptions. ------------------- ConocoPhillips Alaska Inc Placer 2 Colville River Field File No. : 57111 - 104104CP API No. : 50 - 103 - 20488 Date : May , 2004 Conventional Core Analysis Results 1 8210.7 0.6 0.5 12.3 12.0 83.3 0.14 95.3 2.70 (3) Sltst gry sdy/ c1y-slt lam no stn no Bor 2 8211.1 3.0 2.7 13.9 6.3 91.8 0.07 98.0 2.71 (3) Sltst gry vfgr sdy/ cly-slt lam no stn no Bor 3 8211.6 9.7 8.8 15.4 32.2 59.4 0.54 91.6 2.74 (3) Sst Ibm vf-pbly vslty m stn dg1d flor 4 8212.1 9.2 8.8 24.7 77.3 12.9 5.99 90.2 3.00 (3) Sltst brnl vf-pbly sd m stn dgld Bor 8 8212.2 6.2 5.8 25.2 79.0 13.5 5.87 92.5 2.98 (3) Sltst brnl vf-pbly sd/ calc lam m sm dgld Bor 5 8212.8 16.4 15.0 13.7 12.4 80.3 0.15 92.7 2.67 (3) Sst brn vf-pbly vslty/mdst lam d sm dg1d flor 6 8213.3 25.2 22.9 15.4 5.9 88.9 0.07 94.9 2.80 (3) Mdst gry/ vf-gran sst lam fmc no stn no flor 7 8214.1 4.8 4.2 14.2 15.6 81.3 0.19 96.9 2.75 (3) Mdst gry frac no stn no flor * See Procedures page for method descriptions. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. .. ConocoPhillips Alaska Inc Placer 2 Colville River No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date : May , 2004 Conventional Core Analysis Procedures and Conditions Arbor Cut Drilled Dri11ed Carved Drilled N/A Liquid Nitrogen Isopar N/A Brine Lead Lead None None N/A Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Dean Stark (Toluene) Retort Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Pore Vol Boyle's Law (Helium) Boyle's Law (Helium) Bulk Vol-Grain Vol Bulk Vol-Grain Vol Summation Of Fluids Pore Vol + Grain Vol Pore Vol + Grain Vol Mercury Displacement Mercury Displacement Mercury Displacement Air Air CMS-300 Air Air Common Conditions Sleeved Sample Seating Pressure: N/A Confining Pressure Pore Vol & Permeability: 800 psig Perm Only Samples Dried At 235 Degrees Fahrenheit Additional Extraction by Soxhlet with Methylene Chloride/Methanol Oil Density used in Calculation: 0.85 grms/cc .. .. - - - - .. - - - - .. .. - - - .. - .. - - ConocoPhmips Alaska Inc. Placer #2 Colville River Field CL File No. : 57111 -104104CP CMS-300 Permeability (Horizontal Samples) 1 8210.7 0.617 0.545 8.51 E+OO 3.94E+09 6.70E+00 0.236 0.157 3.28E+01 1.02E+12 5.40E+02 2 8211.1 2.92 2.68 5.29E+00 8.79E+10 7.71E+02 0.338 0.308 5.71E+00 3.30E+10 3.54E+01 3 8211.5 9.63 8.73 5.61E+00 2.19E+10 6.24E+02 1.58 1.43 5.55E+00 1.01 E+09 4.95E+00 4 8212.1 9.05 8.74 1.96E+00 1.33E+10 3.80E+02 2.42 2.22 4.92E+00 1.16E+11 8.70E+02 8 8212.2 6.12 5.73 3.74E+00 5.16E+10 9.68E+02 2.34 2.19 3.85E+00 4.27E+11 3.11 E+03 5 8212.8 16.5 15.0 5.24E+00 7.49E+09 3.62E+02 2.66 2.30 8.26E+00 5.25E+10 4.15E+02 6 8213.3 25.1 22.7 5.34E+00 5.03E+09 3.72E+02 3.38 3.22 2.61E+00 3.20E+10 3.53E+02 7 8214.1 4.68 4.14 7.42E+00 5.17E+10 7.08E+02 0.523 0.445 9.95E+00 2.47E+12 3.82E+03 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Placer 2 Colville River Field File No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date: May 21, 2004 Core Gamma Surface log 8188.56 30 8189.11 40 8189.67 36 Gamma (API) 8190.22 27 0 50 100 150 8190.78 25 8180 8191.33 31 8191.89 29 8192.45 35 8193.00 50 8193.56 34 8194.11 39 8194.67 39 8195.22 27 8195.78 42 8190 - 8196.34 39 8196.89 44 8197.45 28 8198.00 36 8198.56 51 8199.11 40 8199.67 42 8200.23 42 8200.78 39 8200 8201.34 37 8201.89 38 8202.45 38 8203.00 26 J:: - 8203.56 30 Q. Q 8204.11 37 C 8204.67 38 8205.23 35 8205.78 36 8210 8206.34 38 8206.89 40 8207.45 36 8208.00 40 8208.56 41 8209.12 45 8209.67 33 8210.23 40 8220 8210.78 37 8211.34 23 8211.89 31 8212.45 35 8213.01 45 8213.56 35 8214.12 22 8214.67 34 8215.23 34 8230 8215.78 35 8216.34 34 8216.90 32 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Placer 2 Colville River Field File No. : 57111 = 104104CP API No. : 50 = 103 = 20488 Date: May 21, 2004 Core Gamma Surface log 8188.56 30 8189.11 40 8189.67 36 Gamma (API) 8190.22 27 0 50 100 150 8190.78 25 8180 8191.33 31 8191.89 29 8192.45 35 8193.00 50 8193.56 34 8194.11 39 8194.67 39 8195.22 27 8195.78 42 8190 8196.34 39 8196.89 44 8197.45 28 8198.00 36 8198.56 51 8199.11 40 8199.67 42 8200.23 42 8200.78 39 8200 8201.34 37 8201.89 38 8202.45 38 8203.00 26 ..c ...- 8203.56 30 Q.. Cþ 8204.11 37 C 8204.67 38 8205.23 35 8205.78 36 8210 8206.34 38 8206.89 40 8207.45 36 8208.00 40 8208.56 41 8209.12 45 8209.67 33 8210.23 40 8220 8210.78 37 8211.34 23 8211.89 31 8212.45 35 8213.01 45 8213.56 35 8214.12 22 8214.67 34 8215.23 34 8230 8215.78 35 8216.34 34 8216.90 32 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Placer 2 ~ Colville River Field CorE! Lab Bulk Core Inventory 1 8188.0 - 8190.5 2 8190.5 - 8193.1 3 8193.1 - 8196.0 4 8196.0 - 8199.0 5 8199.0 - 8202.0 6 8202.0 - 8205.0 7 8205.0 - 8208.0 8 8208.0 - 8211.0 9 8211.0 - 8214.0 10 8214.0 - 8217.0 11 8217.0 - 8219.9 File No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date : May 21, 2004 I I I I I I I I I I I I I I I I I I I ConocoPhillips Alaska Inc Placer 2 Core Lab Colville River Field Slabbed Core Inventory 1 8188.0 - 8196.0 2 8196.0 - 8205.0 . 3 8205.0 - 8214.0 4 8214.0 - 8219.9 File No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date: May 21,2004 I I I I I I I I I I I I I I I I I I I Core LaI:Ì ConocoPhillips Alaska Inc Placer 2 Colville River Field Horizontal Sample Inventory 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 8205.25 8206.30 8207.10 8208.10 8209.30 8210.10 8210.70 8211.10 8211.55 8212.10 8212.80 8213.30 8214.10 8215.10 8216.10 8217.10 Late Additions 8198.10 8200.50 8202.80 8203.45 8204.80 8208.60 8209.60 8212.20 CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P P&P P&P P&P P&P P&P P&P P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P CPAI - no P&P P&P File No. : 57111 - 104104CP API No. : 50 - 103 - 20488 Date: May 21,2004 I I I I I I I I I I I I I I I I I I I ,...............'...'.~......... ~.¡,.,. Core LaI:Í ConocoPhillips Alaska Inc Placer 2 Colville River Field Alaska State Samples 1 8188.0 17 8204.0 2 8189.0 18 8205.0 3 8190.0 19 8206.0 4 8191.0 20 8207.0 5 8192.0 21 8208.0 6 8193.0 22 8209.0 7 8194.0 23 8210.0 8 8195.0 24 8211.0 9 8196.0 25 8212.0 10 8197.0 26 8213.0 11 8198.0 27 8214.0 12 8199.0 28 8215.0 13 8200.0 29 8216.0 14 8201.0 30 8217.0 15 8202.0 31 8218.0 16 8203.0 32 8219.0 File No. : 57111 - 104104CP API No. : 50 - 103 - 20488 Date: May 21, 2004 I I I I I I I I I I I I I I I I I I I ;; ~.\.At~ ~ü~~¡ Core Lab ConocoPhillips Alaska Inc Placer 2 Colville River Field File No. : 57111 -104104CP API No. : 50 - 103 - 20488 Date : May 21, 2004 Preserve Inventory 1 8188.30 - 8189.95 17 8204.30 - 8205.00 2 8189.30 - 8190.00 18 8205.30 - 8206.10 3 8190.50 - 8191.00 19 8206.40 - 8207.00 4 8191.35 - 8192.00 20 8207.35 - 8208.00 5 8192.35 - 8193.10 21 8208.30 - 8209.00 6 8193.45 - 8194.00 22 8209.35 - 8210.00 7 8194.35 - 8195.00 23 8210.30 - 8211.00 8 8195.35 8196.00 24 8211.30 - 8212.00 9 8196.45 - 8197.00 25 8212.30 - 8213.00 10 8197.35 - 8198.00 26 8213.35 - 8214.00 11 8198.35 - 8199.00 27 8214.35 - 8215.00 12 8199.55 - 8200.00 28 8215.35 - 8216.00 13 8200.35 - 8201.00 29 8216.40 - 8217.00 14 8201.35 - 8202.00 30 8217.35 - 8218.00 15 8202.40 - 8203.00 31 8218.35 - 8219.00 16 8203.35 - 8204.00 32 8219.35 - 8219.90 AOG(!(! ~ U1-()33 ."....../ ConocoPhUlips FINAL WELL REPORT PLACER #2 CONOCOPHILLIPS ALASKA, INC. Approved by : Compiled by : Tim Smith Ralph Winkelman Dick Ebright Howard Lamp ~sed: Date: 11912005 1fll2~ · · · '.." ConocoPhillips PLACER #2 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW.. ........ ........................ ................ ........ .... ............. .............. ...........2 1.1 Equipment Summary ....................................................................... ........................................... ... ... ..... 2 1 .2 Crew....... .... ............... ............... ..... ...... ............ ..... .... ................ '" .................... ........................................2 2 GENERAL WELL DETAILS ........... ...... ............ ......... ................ ..... .... ........... ..... .................. ...... ..... ...........3 2.1 Well Summary..... ... .............................................................. .... ................................................... ....... ....3 3 GEOLOGICAL DATA.................................... ......................................................... .....................................4 3.1 Lithostratigraphy..................... .... ....... ........ ...... ........................ ................................. ...... .... ....................4 3.2 Mudlog Summary ................... ......... ......... ............. ..... .............. ..... .................................... ............... ......5 3.3 Gas Samples ................. .................. ...... ...... ........ ...... ......... .... ................ ........... ..... ........ ........................9 3.4 Connection Gasses................................................................... ....................... ......................................9 3.5 Sampling Program / Sample Dispatch ............................................................ ........... ......................... 1 0 4 PRESSURE / FORMATION STRENGTH DATA.....................................................................................11 4.1 Formation IntegritylLeak Off Tests ......................................................................................................11 4.2 Wireline Formation Tests ........ .................... ............ ............ ............ ................. .............. ......................11 4.3 Pore Pressure Evaluation Introduction ................................................................................................11 4.4 Pore pressure evaluation ..... ......... .............. ....... .......................... ....... .......... ........ ................. .............. 12 5 DRILLING DATA ........ ... .............. ...................................... ...... ................ ...................... ............................13 5.1 Survey Data.... ...... ................. .... ..................... .... ........ ......... ........ ...... .............. ....... ..............................13 5.2 Bit Record ... ...... ................ ....... ......................... ..... .......... ...................... ...................... ........ ................. 16 5.3 Mud Record. ..... ........................................................ ............. ............ ..... ..... .................... ....... ..............16 Enclosures 2"/100' Formation Log (MD) 2"/100' Formation Log (TVD) 2"/100' Drilling Dynamics Log 2"/100' Gas Ratio Log 2"/100' LWD / Lithology Log n EPOCH 1 . . ",,' ConocoPhillips PLACER #2 1 MUDLOGGING EQUIPMENT & CREW 1.1 EauiDmentSummarv Parameter D~ch gas 1.2 Crew Un~ Type Un~ Number Artic Series 10 Skid ML015 . Total Downtime Comments Possum belly repeatedly becoming plugged with clay cuttings and restricted mud flow to astra. 0:15:00 Mudloggers Years D~ls Sample Catchers Years Days Technician Days Trainees Days '1 Ralph Winkelman 13 5 Eamon Kuklok 0.6 5 Pete Ramsev 1 Tim Smith 9 5 Garrett Abbott 0.6 5 Dick Ebriaht 4 10 Howard Lamp 3 4 '1 Years experience as Mudlogger '2 Days at wells~e between spud and total depth of well Additional Comments Technician required to work on DAC box [:I EPOCH 2 . . . Cono~Phillips PLACER #2 2 GENERAL WELL DETAILS 2.1 Well Summarv Well Placer #2 AFE --NA Classification Excloration License 204-033 Rig Name I Nordic 3/ Arctic Triple Surface 70° 20' 45.816" N Water Depth N/A RT Elevation 56' AMSL Type Co-Ordinates 150° 23' 55.813" W Primary Target Kuparuk C Sand Primary Target 8209' MDRT Secondary None Secondary N/A Depth (-6013' TVDSS) T araet Target Depth Spud Date 3/21/04 TD Depth 9118' MDRT TD Formation Miluveach TD Date 04/03/200 (-6883' TVDSS) 4 Completion P&A Suspension 04/07/04 Days Drilling 13 Days Testing 0 Status Date Hole Maximum Depth Mud Weight Deviation Casing Shoe Depth FIT Section MDRT TVDSS TD Formation (ppg) (Oinc) Coring I MDRT TVDSS (ppg) Cft) Cft) Liner Cft) Cft) Conductor 115 -59 Undifferentiated N/A 0 - 20" 115 59 N/A 12 1/4" 2672 -2180 Clavstone/siltstone 10.2 53 - 9 5/8" 2663' -2174 16.2 81/2" 9118 -6883' Clavstone/siltstone 10.6 15.11 8188-8220 MD- NA NA NA Additional Comments [:I EPOCH 3 · · · ..../ ConocoPhillips PLACER #2 3 GEOLOGICAL DATA 3.1 Lithostratiaraphv Drilling picks & actual wireline tops refer to provisional picks provided by the YÆllsite Geologist. PROGNOSED ACTUAL WIRELlNE PICK HIGHILOW FORMATION MDRT TVDSS MDRT TVDSS (ft) Cft) Cft) Cft) Cft) Base Permafrost 1526 -1400 1493 -1404 4L Top West Sak 1740 -1568 1693 -1564 4H Base West Sak 2431 -2035 2422 -2030 5H C80 (K-10) 2875 -2328 2929 -2336 18L C40 K-5 3966 -3048 4025 -3049 1L K-3 5402 -3995 5527 -4028 33L Moraine (K-2) 7381 -5325 7292 -5220 105H C30 (Base Moraine) 7528 -5445 7478 -5365 80H TopHRZ 7808 -5690 7781 -5618 72H C20 (mid-upper HRZ) 8023 -5890 8010 -5826 64H Base HRZ 8065 -5930 8049 -5863 67H K-1 8117 -5980 8107 -5917 63H Kuparuk C 8212 -6070 8209 -6013 57H Miluveach (LCU) 8233 -6090 8214 -6017 73H Upper Jurassic Unc. 8653 -6435 Nuiqsut 8843 -6619 TO 8433 -6278 9118 -6883 a F,POCH 4 ..... ConocoPhillips PLACER #2 · 3.2 Mudloa Summary The following text provides a brief summary of the defining lithological and drilling characteristics for that part of the well over which drill cuttings were collected. Tabulated data for each interval or section does not consider footage lost due to DAC box failure (in the case of drill rate) or for packed off possum belly/gas trap (in the case oftotal gas). For more detail the reader is referred to the 2"=100' scale mudlog included in this report. T ophole to Base of Permafrost First Returns 115' to 1493' MDRT (-33' to -1404' TVDSS) Cuttings returns were dominated by unconsolidated sand and conglomeratic sand. The siliclastic fragments ranged from lower very fine quartz to metalithic pebbles in excess of 20 mm (as observed). Clay and claystone were secondarily abundant in the viewed samples. An undetermined portion went into the spud mud and more was lost in sample washing and preparation. All clay material was characterized by localized silt-content variation and trended to brownish gray hues toward the section's bottom from medium grays at the top. The adhesive and hydrophilic nature of the clay retums contributed to gas data gaps on the mudlog. Excessive ssum bell ackin muffled and choked off as tra mud streams. Drill Rate ftlhr Total Gas % Maximum Minimum Maximum Minimum 158 8 83 305 o 5 · Base of Pennafrost to Top West Sak 1493' to 1693' MDRT (-1404' to -1564' TVDSS) Increases in siltstone and silt content in the dominating clay/claystone typify this interval. Clay character differed little from that seen above. Sand/conglomeratic sand showed a marked decrease and much of what was seen in sample returns may have come from uphole. The adhesive and hydrophilic nature of the clay returns contributed to gas data gaps on the mudlog. Excessive possum belly packing muffled and choked off gas trap mud streams. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Averaae 213 12 99 64 2 19 Top West Sak to Base West Sak 1693' - 2422'MDRT (-1564' to -2030' TVDSS) This section is dominated by conglomerate and conglomeratic sand. This conglomerate is interbedded with large quantities of gray brown claystone. The claystone, and conglomerate pebbles combined with high penetration rates caused the possum belly to become plugged with clay on numerous occasions. This restricted or cut off entirely mud flow to the gas trap resulting in the intervals of low gas noted th I on e oa. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 191 6.5 100 52 1 18 · U EPOCH 5 · · · .../ ConocoPhillips PLACER #2 Base West Sak to C801K10 2422' to 2929' MDRT (-2030' to -2336' TVDSS) This section is nearly all mushy pasty gray to grayish brown claystone of nearly homogeneous character. Similar possum belly packing off to that noted above was also seen here. The 9 5/8" casing was set in this interval. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 226 16 136 106 0 31 C80/K10 to C40/K5 2929' to 4025' MORT (-2336' to -3049' TVDSS) Claystone nearly identical to that described above for the Base West Sak to C801K10 interval continued into this interval. Gray siltstone and very rare sandstone were also encountered. Possum belly/gas trap plugging was especlallV severe in this interval. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 302 15 127 98 0 40 C40/K5 to K3 4025' to 5527' MORT (-3049' to -4028' TVOSS) Claystone continued to dominate returns. The cuttings returns became increasingly less silty and near1y sand- free. Toward the bottom of the section siltstone increased, accompanied by a small amount of black carbonaceous material. Otherwise the bulk of the returns continued to be the massive, amorphous and adhesive cia seen in the recedin intervals. Drill Rate ftlhr Maximum Minimum Maximum 187 o 44 23 113 232 K3 to Top Moraine 5527' to 7292' MDRT (-4028' to -5220' TVDSS) Claystone continued to dominate returns, however abundant carbonaceous matter occurs in the top 200'. Sandstone and siltstone are an increasing percent of total returns until 6600' where claystone again becomes pr d . t CI t d . t th tu t th b fth·· t I e omlnan. aVSlone omlna es ere rns 0 e aseo IS In erva .. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 369 6 115 1005 0 114 ~ EPOCH 6 · · · IS In erva IS mos :IV san 5 one. Drill Rate fftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 132 16 90 259 108 161 ......... ConocoPhiUips PLACER #2 Top Moraine to Base Moraine 7292' to 7478' MORT (-5220' to -5365' TVDSS) Th· . t I· tl d t Base Moraine to Top HRZ 7478' to 7781' MORT (-5365' to -5618' TVDSS) Maximum Maximum 189 92 10 252 Top HRZ to Base HRZ 7781' to 8049' MDRT (-5618' to -5863' TVOSS) 59 140 The HRZ is characterized by carbonaceous siltstone, carbonaceous shale and black carbonaceous matter in this well. The percentage of carbonaceous shale gradually increases below about 7850 until it reaches SOOk of the total sample at the base. This interval is conspicuous because of its very dark color. Gas readings of over 200 its . d th h tth . t I un were carne rougl ou e In erva . Drill Rate (ftIhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 173 21 100 776 92 273 Base HRZ to K1 8049' to 8107' MDRT (-5863' to -59176' TVDSS) This unit is almost entirely very dark brown carbonaceous shale as described above. It a eared as a continuation of the revious interval. Drill Rate ftIhr Maximum Minimum Maximum 130 48 95 363 K1 to Top Kuparuk C Sand 8107' to 8209' MORT (-5917' to -6013' TVDSS) 139 253 This unit is almost entirely very dark brown carbonaceous shale as described above. It a eared as a continuation of the revious interval. Drill Rate ftIhr Maximum Minimum Maximum 133 1 58 223 ~ EPOCH 26 144 7 · · · ,..... ConocoPhillips PLACER #2 Top Kuparuk C Sand to Top Muluveach 8209' to 8214' MORT (-6013' to -6017' ìVOSS) This short interval was cored from 8188 to 8220' The interval consists of mostly siltstone with only a very small interval of sandstone. Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Average Maximum Minimum Average 125 1 60 122 15 83 Top Miluveach to J4 8214' to 8653' MORT (-6017' to -6435' TVDSS) This interval consisted of mostly siltstone, along with a minor amount of carbonaceous shale, in the top 500' S d t b th d . t lith I . th b I 75' f th . t I an s one ecame e omlnan o ogy In e asa 0 e In erva . Drill Rate (ftlhr) Total Gas (%) Maximum Minimum Averaae Maximum Minimum Average 159 4 76 133 26 84 J4 to TD 8653' to 9118' (TO) MDRT (-6435' to -6883' ìVOSS) Sandstone dominated this interval to a depth of 8840, below which siltstone was dominant. Several of the sand bodies carried relativel small as shows. Total de th for this well was reached in this interval. Drill Rate ftlhr) Total Gas % Maximum Minimum Avera e Maximum Minimum 140 194 42 83 5 73 ~ EPOCH 8 · · · ~illips PLACER #2 3.3 Gas Samples Depth Units C1 C2 C3 C4 C5 (feet) (ppm) (ppm) (ppm) (ppm) (ppm) 1440 13 2634 0 0 0 0 1780 32 6578 0 0 0 0 2030 9 1859 0 0 0 0 2280 14 2910 0 0 0 0 2530 24 4950 0 0 0 0 3280 30 6013 50 0 0 0 3530 44 8662 82 0 0 0 3780 67 12965 143 0 0 0 4032 12 2523 44 0 0 0 4252 39 7780 123 9 0 0 4500 41 7689 204 51 27 6 4750 36 6308 232 72 34 18 5000 74 13425 724 260 93 28 5250 84 14835 1034 473 208 73 5500 104 17251 1559 764 300 97 5750 159 13835 1748 1502 1195 729 6000 53 5942 523 348 280 228 6250 70 7999 670 401 218 142 6500 44 5212 439 303 186 116 6750 140 18732 1359 892 532 281 7000 63 7877 619 415 274 159 7250 58 9530 785 480 303 178 7500 126 13143 1575 1166 740 428 7617 224 26989 2906 1868 1114 648 7633 238 27158 3195 2072 1222 768 7750 145 17403 1613 1068 718 446 8000 385 59022 4397 1822 809 381 8188 112 15687 1357 661 340 175 8250 107 16441 909 340 159 79 8509 78 10995 837 468 260 124 8757 76 10644 658 406 229 96 8900 94 11844 782 680 416 167 9010 43 4764 359 376 270 128 9118 50 6204 426 403 263 123 3.4 Connection Gasses De th Units feet 4320 75u/1.5% 14655 101 9 n EPOCH 9 eonoa;-Phillips PLACER #2 . 3.5 Samplina Proaram / Sample Dispatch . . Set T e / Pu ose Unwashed Biostratigraphy Four set owners: CPAI ExxonMobil Chevron ASRC Washed, screened & dried Reference Samples Five set owners: CPAI, ExxonMobil, Chevron, AOGCC, ASRC Gas bags Routine intervals and significant peaks above bac round Interval 90' - 1500' 1500' - 9118" 8188'-8218" 90' - 1500' 1500' - 9118' 8188' - 8218' 60' 30' 10' 60' 30' 10' Dis atched to Bayview Warehouse ConocoPhillips Alaska, Inc. ABV 100 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. P o·skilM. McCracken Bayview Warehouse ConocoPhillips Alaska, Inc. ABV 100 8105 Eleusis Drive Anchorage, AK 99502 Attn: D. P o·skilM. McCracken 250'& as gas returns dictated 60' - 1500' 60' 1500' - 9118' 30' 8188'-8218' 10' Sample frequency was locally altered according to drill rate constraints. A B C D Onsite Samplex Samples 1500'- 9118' [:I EPOCH Isotech Laboratories, Inc. 1308 Parkland Court Champaign,IL 61821 Retained in unit pending directive 10 .... ConocoPhillips PLACER #2 · 4 PRESSURE / FORMATION STRENGTH DATA 4.1 Fonnation InteGrity/Leak Off Tests FORMATION Cia one 4.2 Wireline Formation Tests No Wireline Formation tests were performed on the Placer #2 4.3 Pore Pressure Evaluation Introduction Trend Indicators The following pore pressure parameters are considered to provide reliable indicators for pore pressure trends during the drilling of a well; Background Gas (BG) Resistively (RES) Hole Conditions (HC) · Quantitative Methods During the drilling of the well no quantitative estimates were made from derived Corrected D exponents (DXC). Factors such as controlled drill rates, hole inclination, and absence of clean shale baselines to establish compaction trends precluded reliable estimation. Qualitative estimation was limited to consideration of increases in background gas, appearance and trends of connection gasses, and surface manifestations of hole conditions. Trip Gas (TG) Mud Weight (MW) Corrected D exponent (DXC) Connection Gas (CG) · [:I EPOCH 11 . . ...../ ConocoPhillips PLACER #2 . 4.4 Pore pressure evaluation Formation Primary Interval Tops Pore Pressure EMW) Source of Quantitative MDRT TVDSS Min Max Trend Indicators Interval Lithology (ft) (ft) (ppg) (ppg) Trend Estimate Base Permafrost ClystlSd 1493 -1404 8.5 +ve BG N/A Top West Sak ClystlSd 1693 -1564 8.5 +ve BG N/A Base West Sak ClystlSltst 2422 -2030 - 8.5 +ve BG F.l.T. C80 (K-1 0) ClystlSltst 2929 -2336 - 8.5 +ve BG N/A C40 K-5 ClystlSltst 4025 -3049 - 8.5 +ve BG,CG N/A (K-3) ClvstlSltstlSh 5527 -4028 - 8.5 +ve BG,CG N/A Moraine (K-2) ClvstlSltstlS h 7292 -5220 - 8.5 +ve BG N/A C30 (Base Moraine) ClystlSltst 7478 -5365 - 8.5 - BG N/A Top HRZ ClystlSltstlSd 7781 -5618 - 8.5 +ve BG,CG N/A ISh C20 (mid-upper HRZ) ClystlSh/Sltst 8010 -5826 - 8.5 +ve CG,BG N/A Base HRZ ClystlSh/Sltst 8049 -5863 - 8.5 +ve CG,BG N/A K-1 ClvstlSh/Sltst 8107 -5917 - 8.5 +ve CG,BG N/A Kuparuk SstlSh 8209 -6013 - 9.9 +ve MDT MDT ON PLACER #1 Miluveach (LCU) Sh/Clvst 8214 -6017 - 8.5 -ve BG N/A Upper Jurassic Unc. ClystlSltstlSd 8653 -6435 8.5 +ve BG N/A Nuiqsut Sd/SstlSltst 8843 -6619 8.5 +ve BG N/A Total Depth Sh/Clyst - 8.5 - BG N/A NOTE: Clyst=Claystone/clay Sd=Sand Sltst=Siltstone Sh=Shale Sst=Sandstone ~ EPOCH 12 ....... ConocoPhillips PLACER #2 · 5 DRilLING DATA · · 5.1 Survey Data Measured Vertical Northings Eastings Vertical Dogleg Depth Incl. Azim. Depth Section Rate (ft) (ft) (ft) (ft) (ft) (-/10Oft) 0 0 0 0 O.OON O.OOE 0 0 110 0 0 110 O.OON O.OOE 0 0 197.95 0.45 112.61 197.95 0.13S 0.32E 0.2 0.51 290.83 0.57 65.78 290.83 0.08S 1.08E 0.88 0.45 384.19 0.97 60.72 384.18 0.49 N 2.19E 2.13 0.43 469.32 2.13 52.67 469.27 1.81 N 4.08E 4.42 1.38 565.32 3.06 48.73 565.18 4.58N 7.42E 8.72 0.99 659.83 4.86 49.27 659.46 8.85N 12.35 E 15.15 1.9 752.94 6.46 49.6 752.11 14.82 N 19.33 E 24.21 1.72 845.45 8.04 53.31 843.88 22.06 N 28.48 E 35.79 1.78 937.86 10.69 59.32 935.05 30.30 N 41.04 E 50.8 3.05 1029.85 12.31 60.59 1025.19 39.47 N 56.92 E 69.13 1.78 1122.56 14.68 56.64 1115.34 50.78 N 75.34 E 90.75 2.74 1215.64 18.24 52.9 1204.59 66.06 N 96.82 E 117.03 3.99 1309.7 20.77 53.12 1293.24 84.95 N 121.90 E 148.28 2.69 1404.97 24.25 55.21 1381.24 106.26 N 151.49 E 184.62 3.75 1499.11 30.25 60.3 1464.91 129.06 N 188.01 E 227.67 6.83 1594 37.09 60.91 1543.83 154.85 N 233.82 E 280.22 7.22 1688.33 40.82 61.7 1617.18 183.30 N 285.85 E 339.46 3.99 1783.37 43.23 62.58 1687.77 213.02 N 342.10 E 402.97 2.61 1877.36 46.73 62.34 1754.25 243.74 N 400.99 E 469.26 3.73 1972.45 51.3 61.18 1816.6 277.72 N 464.20 E 540.93 4.89 2066.69 52.75 61.5 1874.58 313.34 N 529.39 E 615.14 1.56 2161.5 53.19 60.48 1931.68 350.05 N 595.58 E 690.77 0.98 2255.82 53.5 59.14 1987.99 388.10 N 660.98 E 766.42 1.19 2350.57 53.73 56.07 2044.21 428.96 N 725.37 E 842.67 2.62 2446.2 53.57 56.12 2100.89 471.92 N 789.29 E 919.6 0.17 2540.47 53.36 55.42 2157.01 514.53 N 851.92 E 995.24 0.64 2604.11 53.06 55.95 2195.12 543.26 N 894.01 E 1046.13 0.82 2748.47 53.22 55.33 2281.72 608.45 N 989.36 E 1161.46 0.36 [:I EPOCH 13 . . . "",J ConocoPhillips PLACER #2 Measured Vertical Northings Eastings Vertical Dogleg Depth Incl. Azim. Depth Section Rate (ft) (ft) (ft) (ft) (ft) (O/10Oft) 2842.94 53.02 54.84 2338.41 651.70 N 1051.32 E 1236.86 0.47 2935.53 50.51 57.26 2395.72 692.33 N 1111.63 E 1309.49 3.4 3030.02 50.15 56.87 2456.04 731.87 N 1172.67 E 1382.19 0.5 3124.86 49.23 58.49 2517.39 770.54 N 1233.78 E 1454.49 1.62 3218.38 48.89 57.96 2578.67 807.74 N 1293.83 E 1525.13 0.56 3312.68 48.44 58.94 2640.96 844.79 N 1354.17 E 1595.93 0.91 3408.72 48.69 60.09 2704.51 881.32 N 1416.22 E 1667.93 0.93 3503.39 48.49 59.49 2767.13 917.04 N 1477.58 E 1738.92 0.52 3597.91 48.67 60.5 2829.66 952.49 N 1538.96 E 1809.78 0.82 3690.18 49.09 60.64 2890.34 986.64 N 1599.50 E 1879.26 0.47 3787.2 50.2 60.28 2953.17 1023.09 N 1663.82 E 1953.16 1.18 3882.17 50.38 60.46 3013.84 1059.21 N 1727.32 E 2026.19 0.24 3977 .2 50.3 60.09 3074.49 1095.49 N 1790.86 E 2099.32 0.31 4071.6 50.21 60.09 3134.85 1131.68 N 1853.77 E 2171.89 0.1 4166.07 50.02 60.62 3195.43 1167.54 N 1916.77 E 2244.35 0.48 4260.97 50.2 60.23 3256.29 1203.47 N 1980.10 E 2317.14 0.37 4354.94 50.22 59.68 3316.43 1239.63 N 2042.60 E 2389.33 0.45 4451.13 50.47 60.37 3377.81 1276.63 N 2106.75 E 2463.37 0.61 4547.26 49.91 57.68 3439.37 1314.62 N 2170.06 E 2537.2 2.23 4641.22 49.81 57.61 3499.94 1353.06 N 2230.74 E 2609.01 0.12 4736.36 48.54 57.27 3562.14 1391.80 N 2291.42 E 2680.99 1.36 4829.97 48.62 57.21 3624.07 1429.79 N 2350.45 E 2751.16 0.1 4923.57 48.3 56.78 3686.14 1467.95 N 2409.20 E 2821.18 0.48 5019.7 48.54 59.01 3749.94 1506.16 N 2470.11 E 2893.07 1.75 5113.48 48.51 58.76 3812.05 1542.47 N 2530.26 E 2963.33 0.2 5209.45 48.73 58.15 3875.49 1580.14 N 2591.63 E 3035.34 0.53 5304.15 49.09 61.76 3937.74 1615.86 N 2653.40 E 3106.68 2.9 5399.08 49.21 61.18 3999.84 1650.16 N 2716.48 E 3178.41 0.48 5491.9 48.53 60.97 4060.89 1683.97 N 2777.68 E 3248.27 0.75 5588.31 48.25 60.85 4124.91 1719.02 N 2840.67 E 3320.3 0.3 5683.57 47.93 60.21 4188.54 1753.89 N 2902.39 E 3391.16 0.6 5776.8 47.24 59.78 4251.42 1788.31 N 2961.99 E 3459.98 0.81 5871.49 46.83 59.67 4315.96 1823.24 N 3021.83 E 3529.26 0.44 5966.63 46.4 59.4 4381.31 1858.30 N 3081.43 E 3598.4 0.5 6062.11 47.55 59.17 4446.46 1893.95 N 3141.44 E 3668.19 1.22 [:I EPOCH 14 · · · .... .' ConocoPhiUips PLACER #2 Measured Vertical Northings Eastings Vertical Dogleg Depth Incl. Azim. Depth Section Rate (ft) (ft) (ft) (ft) (ft) (O/100ft) 6155.9 48.63 59.3 4509.11 1929.65 N 3201.41 E 3737.99 1.16 6250.97 49.4 58.77 4571.46 1966.58 N 3262.95 E 3809.75 0.91 6345.48 48.99 59.22 4633.22 2003.43 N 3324.27 E 3881.29 0.56 6440.16 48.23 58.52 4695.82 2040.15 N 3385.07 E 3952.32 0.98 6533.56 49.63 58.98 4757.18 2076.68 N 3445.27 E 4022.73 1.54 6629.85 49.21 58.56 4819.82 2114.59 N 3507.80 E 4095.87 0.55 6724.52 48.6 59.06 4882.05 2151.54 N 3568.83 E 4167.21 0.76 6818.94 47.87 59.08 4944.94 2187.74 N 3629.24 E 4237.63 0.77 6913.13 47.38 58.92 5008.42 2223.58 N 3688.89 E 4307.22 0.54 7007.67 46.49 58.63 5072.97 2259.38 N 3747.95 E 4376.29 0.97 7102.24 45.67 59.66 5138.57 2294.32 N 3806.43 E 4444.4 1.17 7196.06 43.77 59.69 5205.23 2327.65 N 3863.41 E 4510.41 2.03 7291.63 41.08 59.85 5275.77 2360.11 N 3919.11 E 4574.87 2.82 7386.21 38.49 58.84 5348.45 2390.95 N 3971.17 E 4635.38 2.82 7480.32 35.84 58.51 5423.44 2420.50 N 4019.74 E 4692.23 2.82 7573.44 34.84 59.01 5499.4 2448.44 N 4065.79 E 4746.09 1.12 7671.22 33.48 58.91 5580.3 2476.75 N 4112.83 E 4800.99 1.39 7766.1 30.34 59.21 5660.84 2502.53 N 4155.84 E 4851.14 3.31 7861 .04 26.21 58.98 5744.43 2525.62 N 4194.42 E 4896.1 4.35 7955.28 21.78 61.43 5830.51 2544.72 N 4227.63 E 4934.4 4.82 8050.29 20.29 62.06 5919.18 2560.87 N 4257.66 E 4968.45 1.59 8130.41 19.53 61.52 5994.51 2573.76 N 4281.70 E 4995.7 0.98 8146.26 19.33 61.64 6009.46 2576.27 N 4286.34 E 5000.97 1.29 8240.46 19.32 60.47 6098.35 2591.36 N 4313.62 E 5032.11 0.41 8335.11 18.69 60.9 6187.84 2606.45 N 4340.49 E 5062.92 0.68 8428.6 17.92 60.08 6276.6 2620.91 N 4366.05 E 5092.27 0.87 8524.48 16.95 60.26 6368.08 2635.20 N 4390.97 E 5120.99 1.01 8618.31 16.11 60.59 6458.03 2648.38 N 4414.19 E 5147.67 0.9 8714.45 15.68 61.54 6550.49 2661.12 N 4437.23 E 5173.98 0.52 8809.33 15.67 60.24 6641.84 2673.59 N 4459.62 E 5199.6 0.37 8906.5 15.54 60.77 6735.43 2686.46 N 4482.37 E 5225.73 0.2 9002.8 15.22 59.73 6828.28 2699.13 N 4504.55 E 5251.26 0.44 9033.41 15.11 59.88 6857.83 2703.16 N 4511.47 E 5259.26 0.38 9118 15.11 59.88 6939.49 2714.22 N 4530.54 E 5281.31 0 [1 EPOCH 15 . . . ."...., ConocoPhilUps PLACER #2 5.2 Bit Record Bit Depth Total Bit WOB PP Make Type Jets I TFA In Footage Hrs (klbs) RPM (psi) Wear BHA ft 1 3x15,1x10 1-2-CT -HE-I-NO- TO 1 2 5X14 O-O-NO-A-O-I-NO-CP 2 3 0.74 O-O-NO-A-X-I-NO-CC 2RR 5X14 1-1-EC-N-O-I-NO T.O. Abbreviations MW = ECO = VIS = PV = OIW = Gels OIW Ratio /90-93 1/86-1/92 Mud Weight Gels = Gel Strength Sd = Sand content Effective Circulating Density WL = Water or Filtrate Loss CI = Chlorides Funnel Viscosity FC = Filter Cake Ca = Hardness Calcium Plastic Viscosity Sols = Solids YP = Yield Point Oil to Water ratio [:I EPOCH 16