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Home My WebLink About202-012 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm _ Marker.doc l,.S-Mij\~¿C~ ~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permit to Drill 2020120 Well Name/No. CIRQUE 4 Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20404-00-00 MD 78- NO 78 r-- Completion Date 2/13/2002 r--Completion Status P&A Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number (data taken from Logs Portion of Master Well Data Maint) ,'-' Name Log Log Run Scale Media No Interval Start Stop OHI CH Received Comments Well CoreslSamples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? -"~ Daily History Received? Y/@) Y/f!) '- T I "1 Chips Received? "'"Y71'J Formation Tops Analysis Received? .:!)ß-- ,~. Comments: M-\.",..... ~~\\\... ~ . . Lð '^'" ¿v..J.rv- U\.\.~ ""). ~ "- t' -{ CJ-- ~J..-....J '" ~ Compliance Reviewed By: \~ Date: \ 7 ~ 0,;\.. ~ v I " ... (' MEMORANDUM .:" State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor, CD'\' DATE: Chair, ~ ~ Tom Maunder, ßftJf ~ d- P. I. Supervisor ~o-,\, Lou Grimaldi, SUBJECT: Petroleum Inspector THRU: FROM: February 13, 2002 Surface Abandonment Cirque #4 Phillips Alaska Inc. Ï!:S'.:-'.. Ii'" :",,"'~:A~'d"l."'~' 'J1,~1J\tii.ijau_..e,;;\t~~!>I::' Exploratory Confidential :;I Tuesday. February 12. 2002; I witnessed the subsurface abandonment marker plate on PAl exploratory well "Cirque #4". I arrived the location to find the well ready to have the marker plate welded on. This well had not been drilled any further than the conductor. The 16" had been filled with the gravel that had been taken out when. it was in~talled. The grqvel was packed firmly and should stand up fine. The following info had been bead welded to the marker plate in the following fashion; PhilliPS AlasKa Ine APD#202-0 12 CIRQUE #4 API#50-103 20404-00 This location has Cirque #3 on it that also had the marker plate attached today (see Cirque #3 2-12-02 LG.doc). A location clearance inspection should be performed when.the location is cleaned up this summer. SUMMARY: I witnessed the capping of Cirque #4, No problems observed. Attachments: Surf abandonment Cirque 4 2-12-02 LG.xls Cirque 4 cellar 2-12-02 LG.jpg Cirque 4 monument 2-12-02 LG.jpg Cirque 4 welded cap 2-12-02 LG.jpg CONFIDENTIAL 020212-Surf Abandonement Cirque #4 LG.doc .,I , ~ ( ( {.t ~ ~ ?f5J Y S TATE OF ALASKA y\o:Ç~ \ A~ASKA OIL AND GAS CONSERVATION COMMISSION Surface Abandonment I Location Clearance I Suspended Well (Title 20 AAC 25.170) , FILE INFORMATION: Operator: Phillips Alaska Inc. Well Name: Cirque #4 Address: P.O. Box 100360, PTD No.: 202-012 Anchorage, Alaska 99510-0360 API No. 50- 103-20404-00 Surface Location (From Sec. Line): Unit or Lease Name: Exploration North/South 387 FNL EastlWest 525 FEL Field and Pool: Exploration Section: ~ Township: 9N Range: 7E Meridian: UM Downhole P&A Date: NIA 20 AAC 25.120 - ABANDONMENT MARKER: Insp. Date: I Suñace Monument I . Approval Date: Post OD: (4" min) " Length: - ft. Set on (Wellhead, Csg , In Cmt) - Height above final grade (4' min.): ft. Casing stub - ft. below final grade - Top of Marker Post Closed? - All openings closed? Inspector: Insp. Date: 2/12/02 I Subsuñace Monument I Approval Date: Marker Plate Diameter: 16" " Distance below final grade Level: 5' Thickness: 1/2 " Side Outlets removed or closed: Yes Marker Plate Attached To Conductor --y.... (Y /N) Cement to surface (all strings)? N/A Inspector: Lou Qrimaldi Exact Information Beadwelded Directly to Marker Post or Blind Marker Plate: Insp. Date: 2/12/02 I Note: This well never drilled, conductor only I Approval Date: Phillips ALasKa Inc. APD#202-012 CIRQUE#4 API#50-1 03 20404-00 Inspector: Lou Grimaldi Insp. Date: I 20 AAC 25.170 - LOCATION CLEANUP: I Approval Date: Pit's filled in? Liners Removed or Buried? Debris Removed: Notes: General condition of pad/location: ( Rough, Smooth, Contoured, Flat, Natural) Notes: Type of area surrounding location: ( Wooded,Tundra,Grass,Brush,Dirt,Gravel,Sand) Debris on surrounding area: Notes: Access road present? Type road: ( Dirt, Gravel, Ice, Other) Condition: Condition of road: Notes: Cellar filled in? Type of fill: Height above grade: Notes: .. Type work needed at this location: Inspector: ( If "No" See Reason) RECOMMENDED FOR APPROVAL OF ABANDONMENT Yes No Distribution: orig - Well file c - Operator c - Database c - Inspector Reason: Final Inspection performed? Yes No Final Approval By: Title: DATE: Sheet by loG. 8/5/00 Surf abandonement Cirque 4 2-12-02 LG.xls 3/7/02 '.~J'PEG image 640x480 pixels ... (' (" 8 of 12 3/7/026:09 PM ",; ,~J~EG image 640x480 pixels ( (' .. '" " , """ " .", "\;;'" , \~~f~:';:; , : ;r,', "", :'"",W, ." C"""~ Ai-:' ,,:j,; '"",." ,,' ' " ' " , .t ..., ..,.-"1V'~ . ... , #~~~~~l~~'~~t1,¿..! ~;f;~~~ ~~: t,'i~'~~t:~ j{~" 11 of 12 3/7/02 6:09 PM JPEd image 640x480 pixels ( ( ,< -".' ':~ ~~;~:T'4~ .. .. r - .. 1-)."" ' .,... .",.~,"-""'~ " ;....~~-: . ,', - , '" ',. ".:,",,', .,~,.::~..".,.:,~:~":':':'.-'t;.,~ , ..~'..~ ',,~~:,J..~.,..,. .. '»«:':.,.::': ~.:.:~~~. ~ ~ '; <;<",'.'<:' R',' ....~,.. ,.;'~~:-~~~::;;;" ,(>::":;: "f. '."', , 'f~,,;)..., oJ..' \ J. " " '~,'. ,~ :~ "_,0' . ~- , .."... " ': :;; ", .. -:,.' ,',,' . . " " :';>~(', ,:~::';;:~,~J~;-i":!i~,)«):._L{::~ . ~~,'~Þ~i?,t><ië.'\»Î!m;,.\:., '.' ij¡!"¡¡;' ,," 1 0 of 12 3/7/02 6:09 PM ~. PLDGGI!-1G ,.. ~ ( LOCATION CLE~_~_~CE REPORT State of J._laska .u.i\SXA O¡;: - GAS C=:lSDtVATION CCMMISSION , ?T!) ~O.~O~- 0 ( ;2,. :ease t1nL, ~::j q (Yt7l)-O :':ccæ.t:..CI:. '.'!Q~,--,::-~'-- .-'- -:; ~ Co' -~_":--' ,."-10. -.-.-- ----- - - . -- -. - ~el.l ~T2.!ne C'Çer2.t:r Spuå: '.tJA , TII : '0 c::: vol. 7l~ AJm¿ Date 2' '3 '07-- Caçleted 2-' 13'~ 0:;; ~ote casi:q s~:e, ~, ¿ec~. Sfc Czq: lb tL1ð é c~=ceå.ur8. - ;)1 () . .oS' be ~ A ~5' 1 :'onq C~q: Rev:.ew t.::.e .,.¡ell :::.le, and- comment well head !:.ine: : ?er: ~~er7a~s - ~=ps: stat~s, Well ~eaå. ~~t of~: . Marxer post or ~lat8: ~oca~~cn C~earance: Ccnc.lusions: Cede 3 ~~ O~lÄigneå ~~ ,M~v . }ßì Date -I (tJ.Pd ~ 0"7 , . . . . . (" ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 February 14, 2002 Commissioner Cammy Oechsli- Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Cirque #4 (202-012) Completion Report Dear Commissioner: Phillips Alaska, Inc., as operator of the Cirque #4 exploration well, submits the attached "Well Completion Report" (AOGCC form 10-407) for the P&A operations. The Commission is requested to keep confidential the enclosed information due to the exploratory nature of this well. If you have any questions regarding this matter, please contact me at 263-4603 or Mark Chambers at 265-1319. Sincerely, ?~ f1~ P. Mazzolini Exploration Drilling Team Leader PAl Drilling PM/MC/skad ~~C~/lItD £81S' AI_,. 2 OOr. ,., Oil &. Gis Con. AnM..- \$. CoP»-, """Wage "fill/asian 1'./ '.I-:A. ~.;tLJ c./:-:t..Ji.->"h..~pC-""~ 6IY~'~ "1 ¡.,,-.1.,,'" 1--""--- . / . l "11 t, .'1 . 1-, I ~ / .... '~~;I-'\J-r.~.. {.;"'4-Li'- f~4.?~ 1-<..,."....4 t".., v ¡.-"",-p.......... I .~ '/J.:...,. ./3 .&:.',- , ê /tJ~ (..rl z. ¡&::t:>. ':]. I, o.~, ORIGINAL ( STATE OF ALASKA f ALASKA OIL AND GAS CONSERVATION CúlVlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil D Gas D 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Suspended D Abandoned 0 Service D lOCA TIoN$ Vc;;;;1 i~..4 II' " ~'~ '$..,""- , c :' 7. Permit Number 202-012/ 8. API Number 50-103-20404-00 .' ., 387' FNL, 525' FEL, Sec. 28, T9N, A7E, UM At Top Producing Interval 1099'FNL, 1014'FEL,Sec.29,T9N, A7E, UM AtTotal Depth 1175' FNL, 1631' FEL, Sec. 29, T9N, A7E, UM (as proposed) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 30' AKB ADL 390040 & 375080 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. Not applicable Not applicable Not applicable 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey Not applicable Not applicable YES D No 0 22. Type Electric or Other Logs Run Not applicable 23. (ASP: 455709, 5890531) , >" ~ ,.,; :,i.:, , ;, " 9. Unit or Lease Name Exploration 10. Well Number .." .,..' ,'" . ,"..",'.. (as proposed) , :':' ';-¡;: ~ ~-~-}-~~p: I ¡, ,: ~Ji::::¡I'-::;":' , ~ ' -At)"' \ ~,':::::::,~.:.,~,,~:::~',~': j Cirque #4 11. Field and Pool Exploration 15. Water Depth, if offshore (P&A'd) N/A feet MSL 20. Depth where SSSV set N/A feet MD 16. No. of Completions 0 21. Thickness of Permafrost N/A CASING SIZE 16" WT. PER FT. 62.5# GRADE H-40 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD Surface 78' 24" 210 sx AS I AMOUNT PULLED 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) N/A TUBING RECORD DEPTH SET (MD) N/A PACKER SET (MD) N/A 25. SIZE None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production N/A Date of Test N/A Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Plugged & Abandoned Production for OIL-BBL GAS-MCF Test Period> Calculated OIL-BBL 24-Hour Rate> W A TER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A FES 1 5 2002 Alaska Oil & Gas Coos. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate OR'Gli~AL 29. ( GEOLOGIC MARK.l::tiS 30. ( FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS P&A Summary 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Signed íiJ. fJl~ Paul Mazzolini Title Drillina Team Leader b "LI /4 'D2- Date I j Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". RECE iVED: Form 10-407 rEB 1 5 2002 ORIGl¡!~AL- AfaskaOff & Gas Cons. Commission Anchorage <of ( ( CIRQUE #4 PLUG & ABANDONMENT! CONDUCTOR ONLY) 02/12/2002-02/13/2002 The base plate and the cellar box were cut and removed by GBR and Drilling Tool House. The 16" conductor was cut three feet below the tundra per AOGCC requirements. The 16" conductor was filled with the same gravel that was removed while drilling the conductor. Lou Grimaldi with AOGCC witnessed the conductor being full of gravel and the cap was welded in place with Phillips Alaska, Inc., Cirque #4, API #50-103-20404-00. After the cap was welded, the hole was backfilled with gravel per Lou's suggestion. ;¡C Pyron 2/13/2002 ,.. ~. '. ~. ~V~VŒ (ill~ ~~~~[\~ ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]1M AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Mazzolini Drilling Team Leader Phillips Alaska, Inc. . PO Box' 00360 Anchorage AK 99510-0360 Re: Cirque #4 Phillips Alaska, Inc. Permit No: 202-012 Sur. Loc. 387' FNL, 525' FEL, Sec. 28, T9N, R7E, UM Btmhole Loc. 1175' FNL, 1631' FEL, Sec.' 29, T9N, R 7E, UM Dear Mr. Mazzolini: Enclosed is the approved application for pennit to drill the. above referenced well. The permit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. A weekly status report is required from the time the well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confinned by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission for approval on fonn 10-403 prior to the start of disposal operations. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Cirque #4 must comply with the requirements and limitations of20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. . . 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. Permit No. 202-012 January 29,2002 Page 2 of 2 I' (( I( Blowout prevention equipment (BOP E) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test perfonned before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~Ouu' j~ Cammy <9bchsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 29th day of January, 2002 jjc/Enc1osures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w /0 encl. { STATE OF ALASKA If ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 J1l4 \1" (/7\JDV k. \fa~ 1 a. Type of work: Drill 0 Redrill Re-entry Doeepen 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 387' FNL, 525' FEL, Sec.28, T9N, A7E, UM At top of productive interval 1099' FNL, 1014' FEL, Sec. 29, T9N, A7E, UM At total depth 1175' FNL, 1631' FEL, Sec. 29, T9N, A7E, UM 12. Distance to nearest property line 13. Distance to nearest well 1014' @ Target None 4.f:::j' -\4) <:,,:,ç \)~ Sfeet 16. To be completed for deviated wells Q ~~,,~C,)..~ Kickoff depth: 300 MD Maximum hole angle 56° 18. Casing program size 1b. Type of well. Exploratory 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) AKB 28 feet 6. Property Designation 37>0 fib 21.: ADL 390040 /þ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Exploratory Statewide 8. Well number Number Cirque #4 59-52-180 9. Approximate spud date Amount February 1, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9042 I MD / 5779 ' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2» Maximum surface 2069 psig At total depth (TVD) psig Z. 7iY:> Setting Depth 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0Time vs depth plot Qefraction analysis Beabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true nd correct to the best of my knowledge uestlons. a ar: S. ,,1 /' ß-uÅJIH ll4-Jlg'~(~ Ignect/ j r Title: Drilling Team Leader Paul Mazzolini 0 Top Bottom MD TVD MD TVD 28' 28' 115' 115' 28' 28' 2816' 2318' 28' 28' 9042' 5779' Hole Casin 24" 16" 62.5# B PEB 12.25" 9.625" 40# L-80 BTC 2788' 8.5" 7" 26# L-80 BTCM 9014' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: Plugs (measured) measured true vertical feet feet Effective Depth: Junk (measured) measured true vertical feet feet Casing Conductor Surface Production Size Length Cemented Measured depth Liner Perforation depth: measured true vertical Development Oil 0 Multiple Zone 0 10. Field and Pool Exploration -? True Vertical depth ECEI [:0' ¡¡!.".".. JAN 0 9 2002 ,Alaska Oil & G3S Coos. Commission Anchor.aQe ,,~ Date II ¿¡j(J ¿. \ 01": ~I , ,'I I'~¡ Î \.;i ¡ J J i'~ ' Submit in triplicate Permit Number API number 20J-~O 50- 0 Conditions of approval Samples required ~Yes Hydrogen sulfide measures 0 Yes .~ No Required working pressure for BOPE D2M; 0 3M; 0 5M; Other: \,-ec;.t ~~PE {-ð '300<0 f<..¿.. \¿J6A- ~\ "', ~'-'"........ Original Signed By Approved by - WYDc/-6() 0 No Mud log required l Directional survey required .KI Yes 0 0 10M; 0 0 Commissioner by order of the commission Form 10-401 Rev. 12/1/85. Date (l" " Phillips Alaska, Inc. ( General Drillin Procedure Cirque #4 1. / MIRU Doyon Rig #141 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. / Spud well and directionally drill 12-1/4" hole to 9-5/8" surface casing point at 2,816' MD / 2,318' TVD as outlined in directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. 5. Circulate and condit' well bore. Perform short trip. POOH ~ Run Casing. Run and cement 9-5/8" 40# L -80 BTC casing string to surface. 6. 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 TAM Port Collar will be placed in the 9-5/8" casing at approximately 1000' MD below the ./' surface. Port collar will only be utilized if cement does not circulate to surface. As an alternative, if observations at surface indicate cement top is above the Port Collar, a top job may be performed in lieu of utilizing the port collar. This will be based on the cement thickening time and time required to trip in hole and open Port Collar to perform second stage cement job. A Top Job may only be performed after consulting with the AOGCC ./ / ND Diverter System. Install and test BOPE. Test casing to 2500 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. 7. 8. PU Directional BHA. RIH and drill out ~ment, 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 wellbore pressures. / Directionally drill 8-1/2" hole to TD (7" production casing point) at 9,042' MD / 5,779' 1VD as outlined in directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 9. / 10. Circulate and condition well bore. Perform short trip. POOH to run open hole Logs. 11. RU E-Line Unit. RIH and Log well as required. RD E-Line Unit. 12. PU Drill Pipe Conveyed Logging Tools. RIH and Log well as required. POOH and LD Drill Pipe Conveyed Logging Tools 13. RIH to TD. /1 14. Circulate and condition well bore. Perform short trip. POOH to Run Casing ¿' 15. Run and cement 7" 26# L-80 BTC Casing. ÚJi/UlIIVAL ( Phillips Alaska, Inc. ( 16. RIH with Cleanout Bit and Casing Scraper. Clean out to top of cement and displace well to seawater or kill weight brine. / 17. RU E-Line Unit. RIH and obtain Bond Log (USIT). RD E-Line Unit. / / 18. RIH and install 3-1/2" 9.3# L-80 EUE 8rd Completion Assembly. Test casing to 3000 psi for 30 minutes. Notify regulatory agencies 48 hours prior to test. 19. ND BOP, NU Tree and Test to 5000 psi. Freeze protect with Diesel. Rig down and move off Doyon Rig #141. 20. MI well testing equipment and surface test tanks. Perform production tests as required. Produced fluids will be either reinjected into the formation or trucked to Kuparuk or Alpine production facilities. / 21. Upon completion of testing, plug and abandon or temporarily suspend the well as per AOGCC regulations. 22. Thoroughly clean location and block off further ice road access to ice location. QV' ."";1:\ L flll;Ì II~i A ( Phillips Alaska, Inc. ( DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Cirque #4 Drillin Fluid Pro erties: Cirque #4 Property Grids (Clayseal mud) Surface Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 10.0 10.0 10.0 10.0 Funnel Viscosity 70-95 50- 70 45-60 45-60 (seconds) Yield Point 35-45 27-40 25-35 20- 30 (cP) Plastic Viscostiy (lb1100 14-20 15-22 15-25 15-25 sf) 10 second Gel Strength 10-20 10-20 13-25 13-25 (lb1100 sf) 10 minute Gel Strength 11-21 14-25 13-22 13-22 (lb1100 sf) pH 8.5-9.5 8.5-9.5 8.5-9.5 8.5-9.5 API Filtrate(cc) <15 6 <6 <6 Solids (%) 5-8 6-9 6-10 6-11 Intermediate! Production Initial Value Final Value ./ Density (ppg) 10.2 10.5 ./ Funnel Viscosity 40-55 40-55 (seconds) Yield Point 15-22 18-25 (cP) Plastic Viscostiy (lb1100 10-20 14-22 sf) 10 second gel 10-19 10-19 10 minute gel 13-22 13-22 pH 9.0-9.5 9.0-9.5 API filtrate <6 <6 HTHP filtrate NC <12 Solids % 6-11 6-11 Drillin Fluid S stem: /' Equipment on file with AOGCC for Doyon 141. Drilling fluid practices will be in accordance with the regulations stated in 20 MC 25.033. \¡ jj G i ~ì j ¿i¡jf ¡-¡I L ( Phillips Alaska, Inc. ( Maximum Antici ated Surface Pressure and Casin Desi n: The following information is used for calculation of the maximum anticipated surface pressures for the planned well: Casing Casing Fracture Pore Formation MASP Drilling Size Setting Depth Gradient Pressure Pore Gradient Pressure 16" 115' MD / 115' 1VD 12.0 ppg 8.9 ppg 53 NA 9-5/8" 2816' MD / 2318' 1VD 13.5 ppg 9.0 ppg 1085 59 psi 7" 9042' MD / 5779' 1VD 15.0 ppg / 9.0 ppg 2705 1372 psi Expected Maximum Mud Weights: 12-1/4" Surface Hole to 2,817' MD / 2,318' 1VD: 10.0 ppg 10.5 ppg 8-1/2" Pilot / Production Hole to 9,042' MD / 5,779' 1VD: 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 = [(12.0 x 0.052) - 0.11] x 115' = 59 psi -OR- MASP = FPP - (0.11 x D) = 1085 - (0.11 x 2318') = 830 psi 2. Drilling below 9-5/8" Surface Casing MASP = [(FG x 0.052) - 0.11] x D MASP = [(13.5 x 0.052) - 0.11] x 2318' MASP = 1372 psi MASP -OR- = FPP - (0.11 x D) = 2705 - (0.11 x 5779') = 2069 psi ORIGINAL (' Phillips Alaska, Inc. ~' ( Casing Design Performance Properties Size Weight Grade Connection Internal Collapse Tensile Strength Yield Joint Body 16" 63ppf B PEB Conductor Casing 9-5/8" 40 ppf L-80 BTC 5750 psi 3090 979 M 916 M 7" 26 ppf L-80 BTC-M 7240 psi 5410 667 M 604 M Well Proximi Risks: None. Drillin Area Risks: Shallow Hazards: See attached explanation Drilling Risks: Examination of the offset wells, Tarn #1/#4, Cirque #1/lX/#2, Atlas #l/#lA, Meltwater #1/#2 (See attached mud weight versus depth graphs for these wells), reveal no subsurface hazards such as abnormal pressure or lost circulation zones. The Cirque #1 well did experience well control problems, but not because of abnormal pressures. A Seismic Analysis was performed for the Cirque #4 well 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 Cirque #4 are conservatively based on those used during drilling of the offsets. Prudent and precautionary drilling/tripping techniques will be emphasized while drilling this well with specific regards to the potential shallow gas hazards which have been encountered in the Cirque #1 and in the Tarn Wells 4 miles to the North. Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. Note that cement rinseate will not be in'ected down the dedicated dis osal well but will be rec cled or held for an 0 en annulus. The. Cirque #4 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 production cement job to cover those formations. / ../ PAl may request approval to inject or dispose of fluids in the Cirque #4 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 AAC 25.080. ORIGINAL ~ ( Phillips Alaska, Inc. ( Anticipated geologic markers, depth uncertainty, fluid properties, and pore pressures are as follows: FORMATION ~ U NCERT AINTY POSSIBLE FLUID EST. PORE TYPE PRESSURE. Dsi Top West Sak Sand 1005' 50' 465 Base Permafrost 1140' 50' 528 Base West Sak Sand 1745' 50' Gas 812 (-80 (K-10) 2290' 50' 1054 (-40 (K-5) 3390' 50' 1586 Ice Berq 4000' 50' Gas 2142 Top Bermuda 5105' 50' Oil 2363 Base Bermuda 5225' 50' 2445 (-35 5230' 50' 2448 Top Albian 5340' 50' Oil 2499 Base Albian 5490' 50' 2569 TD 5601' 50' 2621 Formation Eva I uation: Anticipated logging, coring and testing for this well is as follows: I. II. III. IV. Logging Surface Interval (0 - Surface Casing setting depth) LWD: GR / Res / PWD 8-1/2" Production Interval (Surface Casing setting depth to TD) LWD: GR / Res / Density - Neutron / PWD Drill Pipe Conveyed: MDT / CMR with optional FMI or Percussion Sidewall Cores Coring None Planned Mudlogging Mudlogging service should be in operation from the base of the surface conductor casing to TD. Service most likely will include Rap on 5' intervals, lithology, total gas, sample collection, gas analysis of cuttings, gas chromatography, and H2S detection Sixty-foot (60') wet and dry samples will be collected from surface to casing point @ +/-2140' lVD SS Thirty-foot (30') wet and dry samples will be collected from +/- 2140' TVD SS to well TD. Ten-foot (10') wet and dry samples, or continuous, collected across the Bermuda and Albian. Flow Testing Currently, Phillips plans to complete and test the Cirque #4 well. Flow testing and pressure build-up tests will be used to determine formation properties and estimate the commerciality of this exploratory well. A 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 reinjected into the formation following completion of the flow testing operations. Additional prospective intervals may be tested as described above or may be commingled with the previously tested intervals. If commingling is chosen, production logging will be performed during the flow test to determine the productivity of the individual zones. ORIGINAL ( Phillips Alaska, Inc. (' Cirqye #4 Drilling H~zards S~mmarï (to be posted in Rig Floor Doghouse Prior to Spud) 8" Casin Interval Event Conductor Broach Gas Hyd rates Running Sands and Gravels Abnormal Pressure in j Surface Formations Lost Circulation 8-1 2" Hole 7" Casin Interval Event Sticky clay and tight hole first 2000' below shoe Hole cleaning in long, high an Ie tan ent Hole swabbing on trips Thick, low PH mud after drilling the Camp Sands Elevated Pressure in Iceberg Formation Abnormal Reservoir pressur'l" Hydrogen Sulfide gas Differential Sticking Lost circulation Risk Level Low Moderate Low Moderate Low Risk Level Moderate Moderate Moderate Moderate High Moderate Low Low Low Miti ation Strate Monitor cellar continuously during interval. Mud gas detection, Increased mud weight, Decreased mud viscosity, Decreased circulating times, Controlled drilling rates, Low mud tem eratures Additions of Driltreat Lecithin. Maintain planned mud parameters, Elevated mud viscosi from s ud Hi h densi swee s. Diverter drills, increased mud weight. Reduced/Cautious trip speeds while drilling surface hole. Geologist on location to assist in picking surface casing shoe depth above the C80/Kl0 marker. Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries, caution while tri in Miti ation Strate Attention to hole cleaning, PWD tools, wiper trips, mud ro erties Good drilling practices, high RPM, PWD Tools, circulate 3-4 bottoms u rior to tri s flow checks Reduced trip speeds (especially thru the C80 / Camp Sands interval @ +/-2601' MD/2468' TVD), Mud rheology, Proper hole filling (use of trip sheets), Pum in out of hole Flow checks. Raise PH to 10.5-11.0, add thinner prior to trips, circulate above and below interval on trips in / out of hole and when runnin casin . Well bore intersects the Iceberg @ +/-4582' MD/4228' TVD, Frequent flow checks while drilling this interval, PWD tools, Bar on location to weight u Well control drills, increased mud weight, contin encies for to set casin strin . H2S drills, detection systems, alarms, standard well control ractices mud scaven ers Good drilling practices, Mud lubes, Keep string movin Avoid sto in w BHA across sands. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo lost circulation material ORIGINAL '91 " %. "0- ~ (,"?v " 0; i'~. ..f$0 "0" 400 0 400 800 1200 ........... 1600 -t- Q) Q) '+- '-'" 2000 ..c -t- Q. Q) 2400 0 0 2800 U -t- !..... Q) > 3200 Q) ::J !..... 3600 l- I V 4000 4400 4800 5200 5600 6000 ......................................................... ..... Phi111 l ... Inè~ s Alaska, Structure: Cirque 4 Field: Exploration Well: Cirque 4 Location: North Slope, Alaska <- West (feet) 6400 6000 5600 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 800 ~ 400 ..5'e>-r: ..5"':>. ~ 0 0 400 Target Location: 1099' FNL, 1014' FEL Sec. 29,T9N, R7E, UM ~ ~o ~ ..() C' If,. <9,.. ..5'0 "? 0 :f ..5'" ~ (J) 0 c: ..... :J 400 ......... ..... \S'I :g ..... ""-" ~ O.ð ¡;r- \.To .9 Î.f:~ " & 70 C -:J e> \S' . "",9 "'<' <96 <9-þ 05". 0 Î.f: ".5- V 'b '" ~ ~o '"h. \S'I!> ')v <S>. % I!>,.. "?" % 800 I V Estimated Surface Location: 387' FNL, 525' FEL Sec. 28, T9N, R7E, UM Estimated TO Location: 1175' FNL, 1631' FEL Sec. 29, T9N, R7E, UM 1200 Est. RKB Elevation: 178' KOP ~:gg Begin 3Deg Build 6.00 DLS: 2.00 deg per 100 ft 8.00 12.00 DLS: 3.00 deg per 100 ft 15.00 18.00 21.00 T / W Sak Snds 24.00 27.00 B/ Permafrost 30.00 33.00 39.00 45.00 51.00 B/ W Sak Snds EGC 262.99 Azimuth 5810' (To Target) 9 5/8 Casing C80 (K-10) I-¿;~ ~.;~~... ~~ 'j:::~': I~:~ ~:... .":~~~: ~~::;~~b~~äl I Plol Roforonco is Cirquo #4 Version HI. I I Coordinotos ore in foot reference Cirquo 4. I I True Vorticol Depths ore reference Est. (Doyon 141).1 Rill ' ! B~ER I HUGHES 1................................!,~!.~g...........,..........................................1 ~ C40 (K-5) Maximum Angle 56.22 Deg Iceberg Tgt - Mid Bermuda Cirque 4 Berm TGT 20 Dec 01 Bose Bermuda Top Bermuda C-35 Albian Bose Albion TO 400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6400 6000 6800 Vertical Section (feet) -> Azimuth 262.99 with reference 0.00 N, 0.00 E from Cirque 4 ORIGINAL ~ ::c - C") -- 2: )::::.. r- ¡Created by janes For: M Chamber5! Date plotted: 8-Jon-2DD2 I Plot Reference is Cirque #4 Version #1. I ¡ Coordinates are in feet reference Cirque 4. ! ¡ ¡True Vertical Depths are rWJ.~q¡;\1.!1..~Est. (Doyon 141).: ¡ W~~~ ¡ : ~:. I L___IN~... ! ==== '----- Point ----- KOP Begin 3Deg Build T I W Sak Snds BI Permafrost BI W Sak Snds EOC 9 5/8 Casing C80 (K-10) C40 (K-5) Iceberg Top Bermuda Tgt - Mid Bermuda Bose Bermuda IC-35 ¡Albion ¡Bose Albion TO Philli pS Inc. PHilliPS m ' I ~~ Alaska, Structure: Cirque 4 Well: Cirque 4 i Location: North Slope. Alaska [ ..--...........-,..,-..,..,- _..,-,.., Field: Exploration P OF~ COMMENT DATA Dir TVD North East 262.99 300.00 0.00 0.00 262.99 797.47 -5.31 -43.20 262.99 1183.00 -18.83 -153.12 262.99 1318.00 -26.27 -213.56 262.99 1923.00 -84.21 -684.62 262.99 2053.26 -105.30 -856.03 262.99 2318.00 -153.61 -1248.84 262.99 2468.00 -180.99 -1471.40 262.99 3568.00 -381.75 -3103.52 262.99 4178.00 -493.08 -4008.61 262.99 5283.00 -694.75 -5648.15 262.99 5362.99 - 709.35 -5766.83 262.99 5403.00 -716.65 -5826.20 262.99 5408.00 -717.56 -5833.62 262.99 5518.00 - 737.64 -5996.83 262.99 5668.00 - 765.01 -6219.39 262.99 5779.20 -785,31 -6384.39 -...-----...-..-,---..,--..-..----..,',..-....'.."...'..'..'.. ,-..-,', .,.,.."...,.,....,....." ,-"",..,.., .."" ,..,.."" ..', ..,_.., ......' ..,......,......_,........, ...............,.. ..,..,".-""" ==== MD Inc 300.00 0.00 800.00 10.00 1201.87 22.06 1350.00 26.50 2124.24 49.73 2340.68 56.22 281 6.82 56.22 3086.61 56.22 5065.02 56.22 6162.15 56.22 8149.55 56.22 8293.42 56.22 8365.38 56.22 8374.37 56.22 8572.22 56.22 8842.00 56.22 9042.00 56.22 --,.,-,_...._-_.. V. Sect Deg/100. 0.00 -"00 43.52 2.00 154.28 3.00 215.17 3.00 689.78 3.00 862.48 3.00 1258.25 0.00 1 482.49 0.00 3126.91 0.00 4038.82 ~=-; 00; 5690.72 u.OO 5810.30 0.00 5870.11 0.00 5877.58 0.00 6042.03 0.00 6266.27 0.00 6432.50 0.00 f ", ( Phillips Alaska, Inc. Cirque 4 Cirque 4 Cirque 4 Exploration North Slope, Alaska PRO P 0 S A L LIS TIN G by Baker Hughes INTEQ Your ref: Cirque #4 Version #1 Our ref: prop5047 License: Date printed: 8-Jan-2002 Date created: 20-Dec-2001 Last revised: 8-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 456236.103,5890914.340,999.00000,N Slot location is n70 6 42.439,w150 21 19.619 Slot Grid coordinates are N 5890531.027, E 455709.278 Slot local coordinates are 386.38 S 524.66 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( ( Phi 11 ips Alaska, Inc. PROPO5AL LI5TING Page 1 Cirque 4,Cirque 4 Your ref : Cirque #4 Version #1 Exploration,North 5lope, Alaska Last revised : 8-Jan-2002 Measured Inclin Azimuth True Vert R E C TAN G U LA R G RID COO R D 5 G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN A T E 5 Easting Northing COO R DIN ATE 5 0.00 0.00 262.99 0.00 O.OON O.OOE 455709.28 5890531.03 n70 6 42.44 w150 21 19.62 300.00 0.00 262.99 300.00 O.OON O.OOE 455709.28 5890531.03 n70 6 42.44 w150 21 19.62 400.00 2.00 262.99 399.98 0.218 1.73W 455707.54 5890530.82 n70 6 42.44 w150 21 19.67 500.00 4.00 262.99 499.84 0.855 6. 93w 455702.35 5890530.22 n70 6 42.43 w150 21 19.82 600.00 6.00 262.99 599.45 1.925 15.58W 455693.69 5890529.20 n70 6 42.42 w150 21 20.07 700.00 8.00 262.99 698.70 3.405 27.67W 455681.59 5890527.78 n70 6 42.41 w150 21 20.42 800.00 10.00 262.99 797.47 5.315 43.20W 455666.06 5890525.96 n70 6 42.39 w150 21 20.87 866.67 12.00 262.99 862.90 6.875 55.82W 455653.42 5890524.48 n70 6 42.37 w150 21 21.23 966.67 15.00 262.99 960.13 9.725 78. 99W 455630.24 5890521.77 n70 6 42.34 w150 21 21.90 1066.67 18.00 262.99 1056.00 13 .185 107.17W 455602.04 5890518.46 n70 6 42.31 w150 21 22.71 1166.67 21. 00 262.99 1150.25 17.265 140.30w 455568.89 5890514.58 n70 6 42.27 w150 21 23.67 1201.87 22.06 262.99 1183.00 18.835 153.12W 455556.06 5890513.08 n70 6 42.25 w150 21 24.04 1266.67 24.00 262.99 1242.63 21.935 178.28W 455530.89 5890510.13 n70 6 42.22 w150 21 24.77 1350.00 26.50 262.99 1318.00 26.275 213. 56W 455495.59 5890505.99 n70 6 42.18 w150 21 25.79 1366.67 27.00 262.99 1332.88 27.185 221.00W 455488.14 5890505.12 n70 6 42.17 w150 21 26.00 1466.67 30.00 262.99 1420.75 33.015 268.36W 455440.76 5890499.57 n70 6 42.11 w150 21 27.37 1566.67 33.00 262.99 1506.01 39.395 320.21w 455388.88 5890493.49 n70 6 42.05 w150 21 28.87 1666.67 36.00 262.99 1588.41 46.305 376.42w 455332.63 5890486.90 n70 6 41. 98 w150 21 30.49 1766.67 39.00 262.99 1667.74 53.735 436.84W 455272.18 5890479.82 n70 6 41.91 w150 21 32.24 1866.67 42.00 262.99 1743.77 61. 665 501.29W 455207.69 5890472.26 n70 6 41.83 w150 21 34.10 1966.67 45.00 262.99 1816.30 70.065 569.60W 455139.34 5890464.26 n70 6 41. 75 w150 21 36.07 2066.67 48.00 262.99 1885.12 78.925 641. 59W 455067.31 5890455.82 n70 6 41.66 w150 21 38.15 2124.24 49.73 262.99 1923.00 84.215 684. 62W 455024.25 5890450.77 n70 6 41.61 w150 21 39.40 2166.67 51. 00 262.99 1950.06 88.208 717. 05W 454991. 80 5890446.97 n70 6 41. 57 w150 21 40.33 2266.67 54.00 262.99 2010.93 97.888 795.78W 454913.02 5890437.74 n70 6 41.48 w150 21 42.61 2340.68 56.22 262.99 2053.26 105.308 856. 03w 454852.74 5890430.68 n70 6 41.40 w150 21 44.35 2500.00 56.22 262.99 2141.85 121.468 987.47W 454721. 22 5890415.27 n70 6 41.24 w150 21 48.14 2816.82 56.22 262.99 2318.00 153.618 1248.84W 454459.70 5890384.63 n70 6 40.93 w150 21 55.69 3000.00 56.22 262.99 2419.85 172.208 1399.95w 454308.50 5890366.92 n70 6 40.74 w150 22 00.06 3086.61 56.22 262.99 2468.00 180.998 1471.40W 454237.00 5890358.54 n70 6 40.66 w150 22 02.12 3500.00 56.22 262.99 2697.85 222.948 1812.43W 453895.77 5890318.56 n70 6 40.24 w150 22 11.97 4000.00 56.22 262.99 2975.85 273.678 2224.91W 453483.04 5890270.21 n70 6 39.74 w150 22 23.89 4500.00 56.22 262.99 3253.85 324.418 2637.40W 453070.31 5890221.85 n70 6 39.24 w150 22 35.80 5000.00 56.22 262.99 3531. 85 375.158 3049.88W 452657.59 5890173.50 n70 6 38.74 w150 22 47.72 5065.02 56.22 262.99 3568.00 381.758 3103.52W 452603.91 5890167.21 n70 6 38.68 w150 22 49.27 5500.00 56.22 262.99 3809.85 425.898 3462.36W 452244.86 5890125.15 n70 6 38.24 w150 22 59.63 6000.00 56.22 262.99 4087.85 476.628 3874.84W 451832.13 5890076.79 n70 6 37.74 w150 23 11.55 6162.15 56.22 262.99 4178.00 493.088 4008.61W 451698.29 5890061.11 n70 6 37.58 w150 23 15.41 6500.00 56.22 262.99 4365.85 527.368 4287.33W 451419.40 5890028.44 n70 6 37.24 w150 23 23.46 7000.00 56.22 262.99 4643.85 578.108 4699.81W 451006.68 5889980.09 n70 6 36.74 w150 23 35.38 7500.00 56.22 262.99 4921.85 628.848 5112.29W 450593.95 5889931. 73 n70 6 36.23 w150 23 47.29 8000.00 56.22 262.99 5199.85 679.578 5524.77W 450181.22 5889883.38 n70 6 35.73 w150 23 59.20 8149.55 56.22 262.99 5283.00 694.758 5648.15W 450057.77 5889868.92 n70 6 35.58 w150 24 02.77 8293.44 56.22 262.99 5363.00 709.358 5766.85W 449939.00 5889855.00 n70 6 35.44 w150 24 06.20 8365.38 56.22 262.99 5403.00 716.658 5826.20W 449879.61 5889848.04 n70 6 35.36 w150 24 07.91 8374.37 56.22 262.99 5408.00 717.568 5833.62W 449872.19 5889847.17 n70 6 35.36 w150 24 08.12 8500.00 56.22 262.99 5477.85 730.318 5937.25W 449768.49 5889835.02 n70 6 35.23 w150 24 11.12 8572.22 56.22 262.99 5518.00 737.648 5996.83W 449708.88 5889828.04 n70 6 35.16 w150 24 12.84 8842.00 56.22 262.99 5668.00 765.018 6219.39W 449486.19 5889801.95 n70 6 34.89 w150 24 19.27 9000.00 56.22 262.99 5755.85 781. 058 6349.74W 449355.77 5889786.67 n70 6 34.73 w150 24 23.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from Cirque 4 and TVD from Est. (Doyon 141) (178.00 Ft above Mean 8ea Level). Bottom hole distance is 6432.50 on azimuth 262.99 degrees from wellhead. Total Dogleg for wellpath is 56.22 degrees. Vertical section is from wellhead on azimuth 262.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( f Phillips Alaska, Inc. Cirque 4,Cirque 4 Exploration,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: Cirque #4 Version #1 Last revised: 8-Jan-2002 Measured Inclin Depth Degrees Azimuth Degrees True Vert Depth R E C TAN G U LA R COO R DIN ATE S G RID Easting COO R D S Northing G E 0 G RAP HIe COO R DIN ATE S 9042.00 56.22 262.99 5779.20 785.31S 6384.39W 449321.10 5889782.61 n70 6 34.68 w150 24 24.03 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from Cirque 4 and TVD from Est. (Doyon 141) (178.00 Ft above Mean Sea Level). Bottom hole distance is 6432.50 on azimuth 262.99 degrees from wellhead. Total Dogleg for wellpath is 56.22 degrees. Vertical section is from wellhead on azimuth 262.99 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ( f Phillips Alaska, Inc. Cirque 4,Cirque 4 Exploration,North 51ope, Alaska PROPO5AL LI5TING Page 3 Your ref: Cirque #4 Version #1 Last revised: 8-Jan-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 O.OON O.OOE KOP 1201.87 1183.00 18.835 153.12W TI W 5ak 5nds 1350.00 1318.00 26.275 213.56w BI Permafrost 2124.24 1923.00 84.215 684.62W BI W 5ak 5nds 2816.82 2318.00 153.615 1248.84w 9 5/8" Casing 3086.61 2468.00 180.995 1471 . 4 OW C80 (K-I0) 5065.02 3568.00 381.755 3103.52W C40 (K-5) 6162.15 4178.00 493.085 4008.61W Iceberg 8149.55 5283.00 694.755 5648.15W Top Bermuda 8293.44 5363.00 709.355 5766.85w Cirque 4 Berm TGT 20 Dec 01 8365.38 5403.00 716.655 5826.20w Base Bermuda 8374.37 5408.00 717.565 5833.62W C-35 8572.22 5518.00 737.645 5996.83W Albian 8842.00 5668.00 765.015 6219.39W Base Albian 9042.00 5779.20 785.315 6384.39W TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2816.82 2318.00 153.618 1248.84W 9 5/8" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- Cirque 4 Berm TGT 20 449939.000,5889855.000,-2.000 5363.00 709.355 5766.85W 20-Dec-2001 ORIGINAL (' f Phillips Alaska, Inc. Cirque 4 Cirque 4 Cirque 4 Exploration North Slope, Alaska PRO P 0 SA L LIS TIN G by Baker Hughes INTEQ Your ref: Cirque #4 Version #1 Our ref: prop5047 License: Date printed: 8-Jan-2002 Date created: 20-Dec-2001 Last revised: 8-Jan-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on 456236.103,5890914.340,999.00000,N Slot location is n70 6 42.439,w150 21 19.619 Slot Grid coordinates are N 5890531.027, E 455709.278 Slot local coordinates are 386.38 S 524.66 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( Phillips Alaska, Inc. Cirque 4,Cirque 4 Exploration,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 300.00 400.00 500.00 600.00 700.00 800.00 866.67 966.67 1066.67 1166.67 1201.87 1266.67 1350.00 1366.67 1466.67 1566.67 1666.67 1766.67 1866.67 1966.67 2066.67 2124.24 2166.67 2266.67 2340.68 2500.00 2816.82 3000.00 3086.61 3500.00 4000.00 4500.00 5000.00 5065.02 5500.00 6000.00 6162.15 6500.00 7000.00 7500.00 8000.00 8149.55 8293.42 8293.44 8365.38 8374.37 8500.00 8572.22 8842.00 8.00 10.00 12.00 15.00 18.00 21.00 22.06 24.00 26.50 27.00 30.00 33.00 36.00 39.00 42.00 45.00 48.00 49.73 51.00 54.00 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 56.22 0.00 0.00 2.00 4.00 6.00 262.99 262.99 262.99 262.99 262.99 0.00 300.00 399.98 499.84 599.45 698.70 797.47 862.90 960.13 1056.00 1150.25 1183.00 1242.63 1318.00 1332.88 1420.75 1506.01 1588.41 1667.74 1743.77 1816.30 1885.12 1923.00 1950.06 2010.93 2053.26 2141. 85 2318.00 2419.85 2468.00 2697.85 2975.85 3253.85 3531. 85 3568.00 3809.85 4087.85 4178 . 00 4365.85 4643.85 4921.85 5199.85 5283.00 5362.99 5363.00 5403.00 5408.00 5477.85 5518.00 5668.00 R E C TAN G U L A R COO R DIN ATE S 0.00 N 0.00 N 0.21 S 0.85 S 1.92 S 3.40 S 5.31 S 6.87 S 9.72 S 13.18 S 17.26 S 18.83 S 21.93 S 26.27 S 27.18 S 33.01 S 39.39 S 46.30 S 53.73 S 61. 66 S 70.06 S 78.92 S 84.21 S 88.20 S 97.88 S 105.30 S 121. 46 S 153.61 S 172.20 S 180.99 S 222.94 S 273.67 S 324.41 S 375.15 S 381. 75 S 425.89 S 476.62 S 493.08 S 527.36 S 578.10 S 628.84 S 679.57 S 694.75 S 709.35 S 709.35 S 716.65 S 717.56 S 730.31 S 737.64 S 765.01 S 0.00 E 0.00 E 1.73 W 6.93 W 15.58 W 27.67 W 43.20 W 55.82 W 78.99 W 107.17 W 140.30 W 153.12 W 178.28 W 213.56 W 221. 00 W 268.36 W 320.21 W 376.42 W 436.84 W 501. 29 W 569.60 W 641. 59 W 684.62 W 717.05 W 795.78 W 856.03 W 987.47 W 1248.84 W 1399.95 W 1471.40 W 1812.43 W 2224.91 W 2637.40 W 3049.88 W 3103.52 W 3462.36 W 3874.84 W 4008.61 W 4287.33 W 4699.81 W 5112.29 W 5524.77 W 5648.15 W 5766.83 W 5766.85 W 5826.20 W 5833.62 W 5937.25 W 5996.83 W 6219.39 W ( PROPOSAL LISTING Page 1 Your ref: Cirque #4 Version #1 Last revised: 8-Jan-2002 Dogleg Deg/100ft Vert Sect 0.00 0.00 2.00 2.00 2.00 0.00 0.00 KOP 1. 75 6.98 15.69 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 262.99 2.00 2.00 3.00 3.00 3.00 27.88 43.52 56.24 79.58 107.98 Begin 3Deg Build 3.00 3.00 3.00 3.00 3.00 141. 36 154.28 T/ W Sak Snds 179.62 215.17 B/ Permafrost 222.67 3.00 3.00 3.00 3.00 3.00 270.38 322.62 379.26 440.13 505.06 3.00 3.00 3.00 3.00 3.00 573.89 646.42 689.78 722.45 801.78 B/ W Sak Snds 3.00 0.00 0.00 0.00 0.00 862.48 EOC 994.91 1258.25 9 5/8" Casing 1410.50 1482.49 C80 (K-10) 0.00 0.00 0.00 0.00 0.00 1826.09 2241.68 2657.27 3072.86 3126.91 C40 (K-5) 0.00 0.00 0.00 0.00 0.00 3488.46 3904.05 4038.82 4319.64 4735.23 Iceberg 0.00 0.00 0.00 0.00 0.01 5150.82 5566.41 5690.72 5810.30 5810.31 Top Bermuda Tgt - Mid Bermuda Cirque 4 Berm TGT 20 Dec 01 0.00 0.00 0.00 0.00 0.00 5870.11 5877.58 5982.00 6042.03 6266.27 Base Bermuda C-35 Albian Base Albian All data is in feet unless otherwise stated. Coordinates from Cirque 4 and TVD from Est. (Doyon 141) (178.00 Ft above Mean Sea Bottom hole distance is 6432.50 on azimuth 262.99 degrees from wellhead. Total Dogleg for wellpath is 56.22 degrees. Vertical section is from wellhead on azimuth 262.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Level) . ORIGINAL { ( Phillips Alaska, Inc. Cirque 4,Cirque 4 Exploration,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: Cirque #4 Version #1 Last revised: 8-Jan-2002 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth Dogleg Deg/100ft Vert Sect R E C TAN G U L A R COO R DIN ATE S 9000.00 9042.00 781.05 S 785.31 S 6397.59 6432.50 TD 6349.74 W 6384.39 W 0.00 0.00 56.22 56.22 262.99 262.99 5755.85 5779.20 All data is in feet unless otherwise stated. Coordinates from Cirque 4 and TVD from Est. (Doyon 141) (178.00 Ft above Mean Sea Bottom hole distance is 6432.50 on azimuth 262.99 degrees from wellhead. Total Dogleg for wellpath is 56.22 degrees. Vertical section is from wellhead on azimuth 262.99 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Level) . ORIGINAL f (' ~ Phillips Alaska, Inc. Cirque 4,Cirque 4 Exploration,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: Cirque #4 Version #1 Last revised: 8-Jan-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 300.00 300.00 0.00 N 0.00 E KOP 800.00 797.47 5.31 S 43.20 W Begin 3Deg Build 1201.87 1183.00 18.83 S 153.12 W TI W Sak Snds 1350.00 1318.00 26.27 S 213.56 W BI Permafrost 2124.24 1923.00 84.21 S 684.62 W BI W Sak Snds 2340.68 2053.26 105.30 S 856.03 W EOC 2816.82 2318.00 153.61 S 1248.84 W 9 5/8" Casing 3086.61 2468.00 180.99 S 1471 . 40 W C80 (K-10) 5065.02 3568.00 381.75 S 3103.52 W C40 (K-5) 6162.15 4178.00 493.08 S 4008.61 W Iceberg 8149.55 5283.00 694.75 S 5648.15 W Top Bermuda 8293.42 5362.99 709.35 S 5766.83 W Tgt - Mid Bermuda 8293.44 5363.00 709.35 S 5766.85 W Cirque 4 Berm TGT 20 Dec 01 8365.38 5403.00 716.65 8 5826.20 W Base Bermuda 8374.37 5408.00 717.56 S 5833.62 W C-35 8572.22 5518.00 737.64 S 5996.83 W Albian 8842.00 5668.00 765.01 S 6219.39 W Base Albian 9042.00 5779.20 785.31 8 6384.39 W TD Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 2816.82 2318.00 153.618 1248.84W 9 5/8" Casing Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ------------------..---------------------------------------------------------------------------------------- Cirque 4 Berm TGT 20 449939.000,5889855.000,-2.000 5363.00 709.358 5766.85W 20-Dec-2001 ORIGINAL Cir'~e 4 Proposed Completion Schematic (Sheet 1 of 2) Exploration Well - Confidential Conductor: 16",62.58# j Set @ +/- 115' MD ~ TAM Port Collar: 9-5/8" BTC Box x Pin Set @ +1- 1000' MD 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 Ii TD 12-1/4" Hole @ 2817' MD, 2318' TVD (Above the C-80) 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 l TD 8-1/2" Hole @ 9042' MD, 5779' TVD L 6L( ~ ~~st~r~! ~~IP~~~~~tl~~~ Tubing Hanger: FMC Gen V Hanger wI 3-1/2" L-80 EUE 8rd Mod pup joint installed Tubing: (1) Joint 3-1/2" L-80 EUE 8rd Mod installed below tubing hanger Spaceout Tubing Pups ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod Tubing ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod Landing Nipple: 3-1/2" Camco 'OS' wI 2.875" No-Go Profile set at +1-500' MD. Tubing ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod Gas Lift Mandrels: 3-1/2" x 1" Camco 'KBUG' GLM w/dummy valves and latches, 6-foot handling pups installed on top and bottom. Space out w/3-'W', 9.3#, L-80, EUE 8rd Mod tubing as follows: GLM# TVD-RKB MD-RKB , 1 TBD TBD /' 2 TBD TBD 3 TBD TBD 4 TBD TBD Tubing ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod Gas Lift Mandrel: 3-1/2" x 1" Camco 'KBUG' GLM wI Shear Valve pinned for 3000 psi Casing to Tubing differential. 6-foot handling pups installed on top and bottom. Tubing I Pup Joints ( as required): 3-1/2",9.3#, L-80, EUE 8rd Mod Sliding Sleeve: 3-%" Baker 'CMU' Sliding Sleeve wI 2.813" Camco No-Go profile. 12' Pup Joint Critical Landing Nipple: 3-1/2" Camco '0' Nipple w/2.75" No-Go profile. Tubing I Pup Joints (as required): 3-1/2",9.3#, L-80, EUE 8rd Mod PBR I Packer Assembly by Baker Oil Tools: Packer setting depth TBD. See Sheet 2 for Lower ComDletion ( Packer Assembly and Below) Cirque 4 Schematic v1.0 prepared by Mark Chambers t 9A Cir~...e 4 Planned Completion Schematic (Sheet 2 of 2) Exploration Well - Confidential 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 / 9042' MD, 5779' TVD PHilliPS Alaska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY PBR I Packer Assembly, by Baker Oil Tools, consisting of the following: Packer setting depth TBD. (1) Handling Pup Joint: 3-1/2", 9.3#, L-80, EUE 8rd Mod (6 foot length) (1) Polished Bore Recepticle with Seal Stem: Baker Model '80-40' PBR, 12 ft Length w/1 Oft of Seal Travel, Pinned to Shear from PBR with 39 KSI overpull (1) Tubing Anchor: Baker, Model'KBH-22 'Anchor Seal Assembly (1) Packer: Baker Model'SAB-3' Hydraulic Set Permanent Packer, pinned for 1100 psi shear (Fully Set @ 2500 psi) (1) Crossover Sub: Baker, 4" LTC Box X 3-1/2" EUE 8rd Pin (1) Handling Pup Joint: 3-1/2",9.3#, L-80, EUE 8rd Mod (6 foot length) Tubing ( 1 Joint): 3-1/2", 9.3#, L-80, EUE 8rd Mod Landing Nipple: 3-1/2" Halliburton 'XN' Nipple w/2.750" No-Go Profile. Plan to run a 2.75" 'XN' Lock and 2.75" RHC Plug in place. A ball and rod will be dropped to set the packer and retrieved wI wireline. Tubing ( 1 Joint): 3-1/2",9.3#, L-80, EUE 8rd Mod Shear Out Sub I Wireline Re-Entry Guide: Provided by Baker Oil Tools w/3-1/2" EUE 8rd Box Up. PBTD (Top of Float Collar) @ +1- 8954' MD, 5730' TVD Cirque 4 Schematic v1.0 prepared by Mark Chambers Q 0 Schlumberger Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Exploration Client: Phillips Alaska, Inc. Revision Date: 12/26/2001 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 223-8808 email: CAvant@slb.com Volume Calculations and Cement Svstems Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. The top of the tail slurry is designed to be at 1,370' MD. Lead Slurry Minimum pump time: 210 min. (pump time plus 90 min.) ARCTICSET Lite @ 10.7 ppg, Class G + 50%0124, 9%(BWOW)044, 0.6%046, 30%053, 1.5%S1, 1.5%079, 0.5%065 - 4.44 ft3/sk 0.7632 fe/ft x (115') x 1.00 (no excess) = 0.3132 fe/ft x (1350' - 115') x 4.50 (350% excess) = 0.3132 fe/ft x (1370' - 1350') x 1.45 (45% excess) = 87.8 ft3 + 1740.6 fe+ .9.1 fe = 1837.5 fe /4.44 fe/sk = Round up to 420 sks / 87.8 ft3 1740.6 ft3 9.1 fe 1837.5 fe 413.9 sks < TOG at Surface Previous Csg. < 16",62.6# casing at 115' MD < Base of Permaf rost at 1,350' MD (1,318' TV D) < Top of Tail at 1 ,370' MD < 95/8",40.0# casing in 121/4" OH TO at 2,817' MD (2,318' TVD) . Mark of Schlumberger Have 300 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 150 min. (pump time plus 90 min.) LiteCRETE @ 12.0 ppg - 2.40 ft3/sk 0.3132 fe/ft x (2817' - 1370') x 1.45 (45% excess) = 0.4257 fe/ft x 80' (Shoe Joint) = 657.1 fe + 34.1 fe =7 3 3./ 691.2 ft / 2.4 ft /sk = ,i ¡I Round up to 290 sks .; 657.1 fe 34.1 fe 691.2 fe 288 sks BHST = 56°F, Estimated BHCT = 54°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Pump Rate (bpm) Stage Volume Cumulative Stage Time Time (min) (bbl) (min) CW 1 00 6 50 8.3 8.3 Drop Bottom Plug 3.0 11.3 MudPUSH XL 6 50 8.3 19.6 Lead Slurry 6 332 55.3 74.9 Tail Slurry 6 124 20.7 95.6 Drop Top Plug 3.0 98.6 Displacement 6 188 31.3 129.9 Slow Rate 3 20 6.7 136.6 MUD REMOVAL Recommended Mud Properties: 10.0 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* XL, Pv ::::; 17-21, T y ::::; 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR/G/MAt Rig: Doyon 141 Location: Exploration Client: Phillips Alaska, Inc. Revision Date: 12/27/2001 Prepared by: Chris Avant Location: Anchorage, AK Phone: (907) 265-6067 Mobile: (907) 223-8808 email: CAvant@slb.com Previous Csg. < 9-5/8", 40 #/ft Casing at 2,817' MD (2318' lVD) < Top of Lead at 5362' MD it ilil ,!~ "" "". lilli' Ilr < Top of Iceberg at 6162' MD (4178'lVD) ~¡i: < Top of Tail at 7,350' MD < Top of Bermuda at 8150' MD (5283'lVD) < 7", 26.0# casing in 8 1 12" OH TO at 9,042' MD (5,779'lVD) * Mark of Schlumberger Schlumberger . .ùE Preliminary Job Design 7" L.S. Preliminary Job Design based on limited input data. For estimate purposes only. Volume Calculations and Cement Systems Volumes are based on 75% excess in the permafrost and 75% excess below the permafrost. The top of the tail slurry is designed to be at 7,350' MD. Lead Slurry Minimum pump time: 190 min. (pump time plus 90 min.) 13.0 ppg Class G + 0.04% 0800 + 0.2% 0046 + 0.3% 0065 + 8.0% 0020 + 0.6% 0167 - 1.99 ft3/sk 0.1585 feJft x (0') x 1.00 (no excess) = 0 fe 0.1268 feJft x (1330' - 2817') x 1.75 (75% excess) = 0 fe 0.1268 ft3/ft x (7350' - 1330') x 1.75 (75% excess) = 441.1 fe 0 fe + 0 ft3 + 441 .1 fe = 441 . 1 fe 441.1 ft3 I 1.99 ft3Jsk~/ 221.7 sks Round up to 230 sks Have 110 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 180 min. (pump time plus 90 min.) 15.8 ppg GasBLOK - Class G + 3.0% 0053 + 2.0 gps D600G + 0.1 % 0800 + 0.2% 0047 + 0.6%0065 - 1.2 ft3/sk 0.1268 fe/ft x (9042' - 7350') x 1.75 (75% excess) = 0.2148 ft3Jft x 80' (Shoe Joint) = 375.5 ft3 + 17.2 fe /" . 392.7 fel 1.2 ft3/sk = /' Round up to 330 sks 375.5 fe 17.2ft3 392.7 fe 327.3 sks BHST = 146°F, Estimated BHCT = 113°F. (BHST calculated using a gradient of 2.6°F/1 00 ft. below the permafrost) PUMP SCHEDULE Stage Volume Cumulative Stage Time Time (min) Stage Pump Rate (bpm) (bbl) (min) CW 1 00 5 50 10.0 10.0 Drop Bottom Plug 3.0 13.0 MudPUSH XL 5 50 10.0 23.0 Lead Slurry 5 82 16.4 39.4 Tail Slurry 5 71 14.2 53.6 Drop Top Plug 3.0 56.6 Displacement 5 323 64.6 121.2 Slow Rate 3 20 6.7 127.9 MUD REMOVAL Recommended Mud Properties: 10.8 ppg, Pv < 15, T y < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 12.0 ppg MudPUSH* XL, Pv:::: 17-21, T y:::: 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL ( (' PHILLIPS PETROLEUM COMPANY To: Greg Keith laurel Alexander Mark Chambers A TO-1458 A TO-1456 A TO-1566 From: Kathy Heinlein A TO-1346 Date: Pre-Drill Seismic Pore Pressure Prediction for Proposed Well Location: Cirque #3 d/-c-.. ~ ~~ .:.:; ~ vI~,..// ~ aA ¿:L. ,~~.q Ie- ~- ~ (! / If( ú.L- #" </. t<J .e-¡ ( r K LA ~Lh47/~'-I¡~ ~., ONFIDENTI L A-. December 18, 2001 Subject: Summary Seismic velocity data was used to predict pore pressures likely to be encountered at the Cirque #3 proposed well location (main trajectory and sidetrack). A local compaction trend and a local velocity to pressure gradient translation trend model was established using control from the Cirque #2 offset well. The trends calculated at Cirque #2 were compared to trends observed at Tarn and Meltwater and found to be similar. The local compaction trend and translation trend model established from the existing / wells was applied to velocities from 3D seismic data to predict pore pressures. The / predictions show no apparent shallow hazards or large pressure anomalies at the proposed well location. Seismic ProcessinQ.:. The accuracy of seismic geopressure analysis depends critically on the accuracy of the input velocity field. The velocities used were generated using Phillips' A VEL program, an automated high-resolution velocity analysis program developed by ARCO Exploration and Production Technology. This process produces a very accurate velocity field defined at every sample in time and laterally along each seismic line. The output RMS velocities were smoothed over 9 COPs to minimize instabilities in the velocity field that might result from noise, lack of signal or variations in COP fold. ORIGINAL ( ~ Pressure Prediction Procedure: The Cirque #2 offset well was used to establish both a local normal compaction trend line and local velocity vs. pressure translation trend model. This model is similar to the regional models used previously at Tarn and Meltwater. Procedure 1.) Normal Compaction Trend Lines (NCTL) were calculated for a series of 3D seismic lines from the Merged Tarn-Midtarn-Meltwater 3D seismic dataset. The slope of the individual seismic NCTLs matched the slope calculated at Cirque #2, but the intercepts varied slightly from the Cirque #2 NCTL. This is not unexpected as the seismic velocity measures a larger component of horizontal velocity vs the well sonic log which measures primarily vertical velocity. The NCTL calculated from the Cirque #2 sonic log has an intercept of 148; the 3D seismic lines have an average intercept of 160. It was verified that the slope of 160 on the seismic NCTL gave the most accurate pressure prediction from seismic velocities at the Cirque #2 well. The slope of the NCTL line (for both sonic log and seismic data) is -4.5e-5. 2.) The difference between interval transit times (ITT), recorded by wireline sonic logs (L\ T) in the existing wells or by seismic velocities in the proposed wells, and the interval transit times predicted by a downward extension of the NCTL were measured. These values are the travel time differences, L\L\ T. 3.) A translation trend model was established by comparing transit time differences (L\L\ T) to mud weights. This model calculates pressure gradients (PP) using the equation PP = C2* L\L\ T**2 + C1 * L\L\ T + CO Where C2 = -1.34-5, C1 = .0062, CO = .465 4.) Fracture gradients were calculated using the Eaton Method. Inputs are the bulk density, the calculated pore pressure gradient profile, and a Poisson's Ratio profile (from a West Cameron model). OR! INAL ( ( Cirque #2: Figure #1 is the pore pressure gradient calculation for Cirque #2. The left side is the wireline sonic DT (black curve) with the NCTL (red line). The right side is the pore pressure gradient calculation (blue curve), actual mud weight (green curve), and the calculated fracture gradient (red curve). Casing points, areas of hole problems, formation tops, and lithology changes are as labeled. A thin zone of over-pressured gas-charged sand was encountered in the Cirque #2 well at 2171 ft SSTVD (K-10). Similar shallow gas-bearing zones below the permafrost layer are the suspected cause of the blow-out at the Cirque #1 well. Over-pressured free gas may have been encountered in approximately this same interval below permafrost, and additionally gas hydrates may have melted within the permafrost layer as a result of the gas returns from this interval. A false pressure increase is noted at approximately 6532 ft SSTVD. This apparent pressure increase is actually due to a change in lithology which results in slower velocity. Seismic Pore Pressure Prediction (No Shallow Hazards Observed).:. Pressure gradients were predicted from seismic velocities in a 3D cube surrounding the proposed Cirque #3 well location. This report includes displays in time and depth of pressure gradient predictions on 3D inlines and 3D crosslines at the surface and bottom hole locations, in addition to time and depth displays of pressure along the proposed deviated borepath. Predicted Pore Pressure Gradient Displays in De0Œ. Figure # Seismic Line Well Name 2 IL 4993 Cirque #3 Surface Location 4 3D Traverse Cirque #3 Borepath 6 3D Traverse Cirque #3 Sidetrack Borepath Predicted Pore Pressure Gradient Displavs in Time: Fiqure # Seismic Line Well Name 3 IL 4993 Cirque #3 Surface Location 5 3D Traverse Cirque #3 Borepath 7 3D Traverse Cirque #3 Sidetrack Borepath Warmer colors indicate higher predicted mud weights (pore pressure gradients). ~// No shallow hazards or areas of high pressure at depth were observed. ORIGINAL ( { Pore Pressure Gradient Prediction at Proposed Well Location: Figure # Seismic Line Well Name 8 3D Seismic Traverse Cirque #3 Deviated Borepath 9 3D Seismic Traverse Cirque #3 Sidetrack Deviated Borepath The Potential for the Presence of Gas Hydrates and Seismic Pressure Prediction: Gas-charged sands within the permafrost zone are thought to have contributed to the blow-out at the Cirque #1 well. A thin-zone of over-pressured gas-charged sands was observed at the base of permafrost in the Cirque #2 well. Previous analysis (Heinlein, 2000) shows that there is no apparent indication of the presence of gas hydrates within the permafrost layer on either the 20 or the 3D seismic data in the area surrounding the Cirque wells, and that gas-charged sands sitting immediately below the permafrost (in the K-10 interval) may not appear as a potential pressure anomaly on 3D seismic. Conclusions: // 1.) There are no apparent shallow hazards at the proposed Cirque #3 well location (main trajectory and sidetrack). 2.) The NCTL and Translational Trend Model calculated at the Cirque #2 well are similar to NCTLs and Translational Trend Models calculated at Tarn and Meltwater. 3.) A thin zone of overpressured gas-charged sands was encountered below permafrost at the Cirque #2 well. There is the possibility that gas-charged sands exist in this interval in the vicinity of the proposed Cirque #3 well location, but may not be apparent on pressure sections predicted from seismic data. If there are any further questions, please contact me at (907) 263-4761 or via email at kheinle@ppco.com. Kathy Heinlein OR! I P"A,1 IV 1"- CJ ::7{:;1 ~-~_o Ç"::; ~'='-" ~c,c- ~j "-~:~----~ :t~:-- ~ i~-" F!!UH ! !Rf". PE"IP'. RO~EU.P.JIii. ,...O!'Vlin A !I.!V f""nELLir~ - IVi V Ii Ir_i~ I PíOject: Ciíque Well: Cirque 2 NCTL: 148-4.5e-5 Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein r":...",. . '" Ij V II Y u c; I!:. FEEi -170 . ... I . ,., = ¡¡:i~~i1c~laid - bágg perm~mo I I - baae W !M tel I 12000 ! i =-Xm~-K18 "- \ \ ---, --:i-_n~.- --- t'~ -, 3000 6000 ;:, 1~ .'" H 17 He'fL Intercept at Gi. = 14* l.ogarRbmic Slope = -4.k~;! ~ Casing Depiß * ftJc&J! Flew "!" ~ep~at!Orl!alieD Teat ~ ~i~ ~~Te.at 1.:, i"rt:"i!;;<¡¡:m i",~;:;;:"r;;, :;: ¡,,;;'it.:';;-¡;ii i ".n tiPG -e-14t-45-5PL_PPTC (Sonic Hcn: 14*-45E-5 ßDEF, Top Trend Model: PLiESTOCEHE) -*-1~-4-5-5Pl OBG -€r- í~~~-;p,= -rG~Å ~gñ¡ç "CiL: í~-~~-~ U!)~¡:;. flgiMOïi Mci(!g!: W~Si CAMEROn, -Mud Weight MUDj)RILLERS_REP - - -. ~ Lost Circulation Zones .:. Sttir.-k Pipe tocitioñ X Freeform - Formation Top ".. S:ûe1rit~!¡ tõjeftuí;f! ---. ----" Fioure 1 '-' C ::J:J - - ~ - - :c= ~ r-- ~LH! ! H""!~ nETI"',!!"'\,! !::'! Hi!! ,...OMP ^ I\!" Dr~:~~+- ,...' "11 ~h d T d C II rn!LL.U-';::¡ r!::. ! nV!-!::.UIYI ~~ ..! I-\Ê\!! 1_:UJCvl~. vií~üe... IVlel,IO: ran - urve Pore Pressure and Fracture Gradient System {;ross ~ectlon: IL4~~~ Nt; I L: 160-4.5-0 12/18/01 K. Heinlein Model: Pleistocene Seismic Line IL4993 (depth) --"-SM._PM t.:I!Wt :J WIt; At:t JA \V 111111 11111111111111111111111111111111111111111111111111 1 1111111111111 111111111 11111 11 1111 1 11 1 1 -- 00000000000060006000000000000606960000000000000000000006000060000000000000000000006600000000600 ~ 44444444444444444444555555555555555555555555555555555555555555555555566666666666666666666666666 &&&&&111778~88~~~9990000011Îliž2z2ž~~~~~...4.5555566&661 1118&&8899999000001i11122222~3333.4.445 MStfúJ f? ? t ç ç ç ? t ç ç ç ? t ç ; ~ ? t ç ç ç ? t ç ç ç ? t ç ç q ? t ç ç ~ ¿ ~ (> {; {; L 4 G t a z " G t 3 2 " (; t G 3 . {; G 2 4 (; t (I Z 4 (; {; (I Z 4 (; t G £ , {; I> (¡ 2 4 G {; (I 2 4 C I> U Z , G {; (I 4OOOJJ rooo.û D E P 300û.6 T Ii III 5OOII,S 6'})j .û 1000 .0 COP lnt:eniai:;:: IIG í't E m 8.00 8.50 9.00 H19~: 10.50 11.00 11.50 12.00 12.60 13.00 13.50 14.00 14.50 15.00 ~15.50 16.00 18.50 17.00 17.50 ,'=I 18.00 118.50 19.00 ~, ,.-' Figu re 2 C) :::x:J .........-. (;":) ~ ~ ~ r-- PUlL' .p- nr-"'--Lp""8 .""" --......... A ""'IT n L..:-,...- - ~"." =iiiiii isiiiÌíl¡":w--- Ï ... ---- õ;;. ¡;;:'Inv --... ~~.... ..I'!. Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein Dv~:~~... I"':v~..~ I I UJt::l.Il. VII \.jut:: Cross Section: IL4993 Method: Trend Cuî,¡e NGfL: 160-4.5-5 Model: Pleistocene Seismic Line IL4993 (time) 1h-4S-SPL JPr¡ , leb8ic:AcëMJCi_278 l..'IUJI: :j WHrAL:!: ., W E 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 00000000000000000000000000000000000000000000000000000000000000000000000000000000000000000000000 COP 4 4 4 4 4 4 4 4 4 4 4 .. 4 4 4 4 oJ 4 4 4 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 Ii 5 5 5 6 6 (> (> 6 6 6 6 6 I) 6 6 (> 6 I) £; (> 6 6 6 6 6 (> 6 6 6 66 G 66 ? ? 1 ?? 8 88889999900000111 11 222223333344444555556 G 6 667 7 778 S S 8 S 9 99990000011 1 11 222223333 3444445 02468024680246802468024680246802468024680246802468024680368024680246802468024680246602468024680 0.0 - - . , , - . , - . , . . , . . . . . . . . . .. T I 700.0 M E tut 800 .0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 - 1500.0 1600.0 CDP interval :~ 110 ft HI 6.00 8.50 ~9.00 ~ 9.50 10.00 10.50 11.00 11.50 12.00 12.60 13.00 13.60 ~I 14.00 14060 ;;rn 15.00 ~15.50 16.00 16.60 11.00 11.50 18.00 18.50 19.00 ~ ~', Figu re 3 a :J:J ~,.. ~ ~""~~ ~-"';ø ~~ ~ r-- Seismic Traverse along Cirque 3 Deviated Borepath (depth) NW SE ,.--. PPG .~ If 12 --- 8 C¡:g~ ~ro IJ ¡ u tv I Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein Pmject: Cirque Cross Section: 301 raverse Method: Trend Curve NCT L: 160-4.5-5 Model: Pleistocene MiL!!! ! !ne- MET!,"!f"'! ~! HU! J"!'"\!\/'!. n Ji!'\lV rn!!..bU-.':' r!;;.! nvL.!;'VW! \,,;r"-.,nYH-~!'! i SeisrYlic Traverse along Cirque 3 Sidetrack Deviated Borepath (depth) CJ ~j -~.J ~ ~ """=~ ~~ ~ ~-~ r--- - PPG I Ii!iiE - 8 ... ... 1¿ 'f'-,or'" f"'. ¡ yu t;; 0 ~~. ~ - ~> =. """". V è;¿'...., ' "'" """. Co. 1"- ~~-~ t¡ ;,. A IV."'T 10.2 10 9.8 Cï il. 0- on ~ :: ö !.. û.. 9.6 9.4 9.2 9 8.8 . 0 f=UJ! LL1Pt':+- C~TF\!I""_! E_U!\!j! f"ftP..1! n A I'\.!'\" F"nl I,;:) ¡ C ¡ nUL-!::- nil \"VIV¡F"MP4 T Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein rv.:..-...- " n..-..i:-A_-i nn,... IfwU'1Ut: .:; r-i~UI¡;L~U rr-u 1000 .~£",n ùvvv An"" "tVVV 5000 r){H\n ~VVV SSTvD (ff) 6000 Pmject: Ci¡qüe Well: Cirque 3 NCTL: 160-4.5e-s /000 '--. ¡-----::-- -::- '-~ =--=- ì ¡ -+- predicted t-'t-'l-i! , _: ~'o., Figure 8 C) ::0 - - ~ - - ~ r--- 10.4 i () I") IV."" 10 9.8 ('J èi A .... - .... ~i .... .~ -g ~ c. r. r. '-I :-. " , 9.2 - 9 8,8 0 Fal ill I .....- PF""'i"--ø ....U"" _-1111- A N"'" ~--- - -Wk- -- - - -.- - "- -.." - ""'._ono=n- "" ri ¡II-L-II ~ 1::.1 nVLE: ;VI \"ViVir-F-.1 i n~~:~cf.. I"';~~U~ r I Up:::: l. VII Y t::: Well: Cirque 3 ~idetrack NCTL: 160-4.5e-5 Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein C- . ~ ~.ti t ¡,. p d8 t d Dpr: -Irque - ...,1_9 racl~ Ií re - Ic.e . ~ ---, -_..------ ----u--,_....- ._,---- __n i . i ¡ ~ Prc:c::Gicd ppe; ; , - "] --~- - ----.. --- --- -- ----... - - ---------- ~', 1000 3000 4000 5000 6000 2000 .r-........ õ"" (::~'ì ~;:, t ;¡!J H. Figure Ç1 <::) ::J::J - - C:> - - ~ ~ r-- .....H~LL~"""- PETRO" _I I. iii --....-.. ......." ~. M IjJ~ ; -u.;¡;¡' - - i-'¡=-il,,'~¡ "f . .. ....... ~I::. .VI \,.,vUIUh ..1.. Pore Pressure and Fracture Gradient System 12/18/01 K. Heinlein Cirque 3 Predicted PPG and Fractüre Gradient 16 15 J4 . . I " D - II!!! iii '" I II = .~ ¡ 1L Iii I " iO 8--- q ~ D~O:~~"" """:r~u~ I I jt::vl. V, Y t:: Well: Cirque 3 NCTL: 160-4.5e-s -~ , I ; -..- Pr...di,-,pd PPfi : ¡ i ¡ ----- 1'lcûi..."û ha.;iu", (i'dûi" IlL i ---- ---------- ,. ",,;;; ,"';"" "'""" ,.......... ,~.. ,~,~...".... -- -- - -.. ,--. ..""" ",.,... "".", ..,..., -., Figure 8 c ::J:] ~""~ ~J ~~~ ~,~~ ~'c~ :e;:2~ ~ I Dr"":"""""" (";rque I f UjCvl. vi I Well: Cirque 3 Sidetrack NCTL: 160-4.5e-5 ftLHI ! Ine"-. PET"O! E! !lil! ro."(õ.I!M A ",1'-' FnH.~6.U-~ !::! n. L,E;UiV¡ vU!VIi""M.P;; T Pore Pressure and Fracture Gradient System 12/31/01 K. Heinlein CirQue 3 Sidetrack Predicted PPG and Fracture Gradient . - . - - 16 15 í4. Ii - " .'.- . I!!I I!!!!!! ¡¡ II II Ii 12 . Iii i IJ w ') õ I) ;1)1)(1 , 41)(11.' 5('(>1] 20(11) 3(1111) '§; '§: TVD (ft) ! -,-p"",;;,,';1 PPro , l=-----:-:O,-,;jj,;:,;j :~,;:c:v,,; L,;:j;,;;;: j ~, 6(1(ò'} Figure 9 2000 3000 - I- W W U. - J: 4000 ~ w c 5000 6000 7000 a ~~.- -"", -.-.,. 8000 ç- -ç -., €;-~ "'"f' ..¿- . 1000 0 . 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DRilliNG TIME AND MUD WEIGHT CURVE Meltwater North #2 , 1 1 1 ----,-----r----,-----r---- I I , 1 ----,-----r----,-----r---- 1 I I , ----,-----r----,-----r---- I I I I ----,-----r----,-----r---- I I , , I I 1 I --,-----r----,-----r---- I I I I ----,-----r----,-----r---- 1 1 1 I ----,-----r----,-----r---- 1 I 1 I - -19-5/8" set @ 2398' 1- - - - - ~ - - - - I I I I ----,-----r----,-----r---- I I 1 I ----ï-----r----,-----r---- I I I 1 ----ï-----r----,-----r---- I 1 1 I ----ï-----r----,-----r---- 1 I 1 I Drill 8-1/2" Hole I I ---,-----r---- 1 I 1 I ----ï-----~----~-----r---- I I I I ----ï-----~----,-----r---- I I I I I 1 1 1 ----ï-----~----,-----r---- I I I I ----4-----~----~-----r---- I I 1 1 ----ï-----~----~-----r---- I I I 1 ----4-----~----~-----r---- I 1 I I I , I 1 -----r----T----~-----r---- I I I 1 -----r----T----~-----r---- 1 I I 1 -----r----T----~-----r---- I I I I - - - - -r - - - - T - - - - -1- - - - - r - - - - I I I I . ......- Depth - Mud Weight 1 I I I -----r----,-----r----T----- 1 I I I -----r----,-----r----T----- 1 I 1 1 - -----r----,-----r----T----- I I I I -----r----,-----r----T----- I I I I 1 I I 1 -----r----T----~-----r---- , I 1 1 -----r----T----~-----r---- 1 1 1 I -----r----T----~-----r---- , 1 , I -----r----T----~-----r---- 1 I 1 I I I I I -----r----T----,-----r---- 1 1 I 1 -----r----T----,-----r---- I I I I -----~----T----,-----r---- I 1 1 I -----r----T----,-----r---- 1 , 1 I I ----r---- I 1 1 1 -----r----T----,-----r---- , I 1 1 1 -----~----T----,-----r---- I 1 I 1 -----~----T----,-----r---- I I I I I 1 I I -----~----T----,-----r---- 1 I I 1 -----~----T----'-----~---- I 1 1 1 -----~----T----'-----~---- I I 1 1 -----~----T----,-----r---- I 1 I 1 I 1 I I -----r----,-----r----¡----- 1 I 1 1 -----r----,-----r----¡----- I I I I -----r----,-----r----T----~ I 1 1 1 -----r----,-----r----¡----- 1 1 I I I 1 1 I -----r----,-----r----T----- , I 1 I -----r----,-----r----õ----- I I I I -----r----,-----r----õ----- I 1 I I - -----r----'-----~----Õ----- I 1 , 1 1 I I I -----r----,-----r----i----~ I 1 1 1 -----~----,-----r----õ----- I I 1 I -----~----,-----~----T----- 1 1 1 I -----~----~-----r----õ----= I I \ I I I 1 1 -----~----,-----~----T----- I I I 1 - -----~----,-----~----T----- 1 I I I -----~----~-----r----¡----- I I I 1 -----~----,-----~----T----- 1 I I I 1 I 1 I ----4-----r----~-----r---- I I I I ---4-----r----'-----~---- I I I I -----~----~-----r---- I I 1 -----r---- I I I I ----'-----~----'1--- 1 I 1 ----ï-----r----~-----~---- 1 I I 1 ----ï-----~----~-----~---- 1 I I I ----,-----r----~-----r---- 1 I I I 1 I 1 I -----~----~----4-----~---- 1 -----~----~----~-----~---- 1 1 I I ~----~-----t----~-----~---- I I I I -----~----~----~-----~---- I 1 1 I 5 10 TIME TO DRILL (DAYS) 1 1 1 1 -----~----,-----r----¡----- 1 1 1 1 -----~----~-----r----T----- 1 1 I 1 - -----r----'1-----r----¡----- I I t 1 -----~----'1-----~----¡----- 1 I I I 15 prepared by MAC 11/21/01 10.8 10.6 10.4 10.2 ~" 10 9.8 t- 9.6 J: S2 w 3: 9.4 c ::» :æ 9.2 9 8.8~ 8.6 8.4 8.2 20 ( ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 Mark Chambers Phone: (907)265-1319 Fax: (907) 265-1336 Email: mchambe2@ppco.com January 9, 2002 RECEIVED Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 ,JAN 0 9 2002 Alaska Oil & Gas Cons. Gommissìon Anchorage Re: Application for Permit to Drill: Cirque #4 (Exploratory Test) Surface Location: Target Location: Bottom Hole Location: 387' FNL, 525' FEL, Sec. 28, T9N, R7E, UM 1099' FNL, 1014' FEL, Sec. 29, T9N, R7E, UM 1175' FNL, 1631' FEL, Sec. 29, T9N, R7E, UM Dear Ms. Taylor: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore exploratory test well, the Cirque #4, from the referenced location located approximately 4.75 miles North East of the Kuparuk River Unit's 2P Pad. This well will be accessed via ice road originating from the gravel road running between 2N and 2P Pads and drilled using Doyon Rig #141. The Cirque #4 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 an 8-1/2" wellbore through the objective with a full LWD logging suite for evaluation. Based upon favorable log data, Phillips plans to run 7" production casing and test post-rig. The proposed casing program will utilize a 9 5/8" surface casing string, a 7" intermediate / production casing string and 3-1/2" tubing. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) 2) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). OR'\\! II .' ':' "'L '~,I ' ,"', \ ¡ \.;f j iJ ii' ( ( ( A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Diagrams and descriptions of the BOP and diverter equipment to be used (Doyon 141) as required by 20 AAC 25.035 (a) (1) and (b) are on file at the AOGCC office. 5) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well. 6) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 7) Seismic refraction or reflection analysis as required by 20 AAC 25.061(a) are attached in this APD package. 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 rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 3) Complete mudlogging operations such as type log generation and sample catching are planned. The following are PHILLIP's designated contacts for reporting responsibilities to the Commission: 1) Completion Report (20 AAC 25.070) Sharon Allsup-Drake, Drilling Technologist 263-4612 2) Geologic Data and Logs (20 AAC 25.071) Laurel Alexander, Geologist 263-4236 The anticipated spud date for this well is February 01, 2002. 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, U;i~ Mark Chambers Exploration Drilling Engineer cc: CON FIDENTIAL Paul Mazzolini Mark Chambers Mike Morgan Cirque #4 Well File A TO-1570 ATO-1566 ATO-1438 RECEIVED ,JAN 0 9 2002 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL Cirque 3 Shallow Hazzards Information ~Ô~~ Subject: Cirque 3 Shallow Hazzards Information Date: Mon, 7 Jan 2002 14:22:19 -0900 From: "Mark A Chambers" <mchambe2@ppco.com> To: steve_davies@admin.state.ak.us .j (I' ~ Steve: I have attached the most recent Shallow Hazzards Information for the Cirque 3 Well. The change was a result in surface location shift. As you can see the predicted pressures are some what less than earlier versions. As a result we have backed off the expected mud weights to 10.5 ppg from the original 10.7 ppg shown in the Application for Permit to Drill. Also we have settled on drilling 2 wells (Cirque 3 and Cirque 4) as opposed to the original plan of Cirque 3 and a sidetrack Cirque 3A. The bottom hole location for Cirque 4 will be the same as the original Cirque 3A so the shallow hazzards information for the sidetrack should be applicable. Spud date for the Cirque 3 well looks like around 1/15. Call me if there are any questions. Mark (See attached file: Cirque 3 Shallow Hazards Draft Report 12 18 01.doc) (See attached file: Cirque 3 Shallow Hazards Draft Report 12 18 01.ppt) (See attached file: Cirque 3 Shallow Hazards Draft Report 12 31 01.ppt) ,,' '" ; ~ Cirque 3 Shallow Hazards Draft Report 12 18 0 l.doc Name: Cirque 3 Shallow Hazards Draft Report 12 18 01.doc Type: WINWORD File ( application/msword) Encoding: base64 Name: Cirque 3 Shallow Hazards Draft , , Report 12 18 Ol.ppt ; ~Cirque 3 Shallow Hazards Draft Report 12 18 01.pptl Type: Microsoft PowerPoint Show , (application/vnd.ms-powerpoint) I Encoding: base64 , .' , " , " " " '" '. ' ". " ~Cirque 3 Shallow Hazards Draft Report 12 31 01.ppt Name: Cirque 3 Shallow Hazards Draft Report 12 3 1 0 1. ppt Type: Microsoft PowerPoint Show (application/vnd.ms- powerpoint) Encoding: base64 10fl 1/28/20022:59 PM ( ( Phillips Alaska, Inc. P. O. 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Permit No, . API No. . . Production should continue to be reported as a function .of the original API number stated above. In accordance with 2.0 AAC 25.GGS(f), all r~ords, data and logs acquired for the pilot bole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -7.0/80) from records, data and logs acquired for wel' (na.me on permit). Annular disposal has not been requested. . . Annular Disposal. of drilling wastes will not be approved.. . To ~ V'¿1t,ú!s1t d ~+ A- .{ tLft?-v dtL-t~. Annular Disposal of driUing wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. Tbe permit is approved .sùbject to full compliance with 2.0 AAC 25..055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company ~ame) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY PHILLIPS WELL NAME CIRQUE #4 PROGRAM: exp FIELD & POOL 490165 I 000000 INIT CLASS EXPLORATION (OIl) GEOL AREA ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate*. . . . . . . . . . . . . . . . . . . N Phillips has changed it's plans: they originally planned to drill one well (Cirque #3) and a sidetrack 3. Unique well name and number. .: . . . . . . . . . . . . . .. ~$#3A). They have chosen instead to drill two wells. #3 and #4. #4 is beinQ drilled to the #3A BHL. 4. Well located in a defined poo~~. . . . . . . . . . . . . . . - N * Cirque #4 is an exploration (delineation) well located adjacent to Cirque #3. The surface location 5. Well located proper distance from drilling unit boundary. . . . of Cirque #4 lies in ADL 375080, and the top productive interval & T.D. lie in ADL 390040. 6. Well located proper distance from other wells.. . . . . . . . . N ** Cirque #4 is governed by CO 430 (Tarn) between the Iceberg & the C35 marker, a depth range 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N from -6162' to 8374' MD. From 8374' to TO at 9042' MD, the well lies outside of any defined pool. 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . ' N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued without conservation order. . . . . . . . N APPR DATE 12. Permit can be issued without administrative approval.. . . . . N .~Ì) I z-f ..b"2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . N 15. Surface casing protects all known USDWs. . . . . . . . . . . N No USDW's are know to exist in the Meltwater - Cirque area. ~~: g~i~~: :~:~~::::~~~~~I~~~~~t~~~~~c~~~~:~.rf.c~g: : : : : ~ tA&f~-tf ~CL~ ~~1!~t-. 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N ~~: ~~e~~~~~I~~~~a;~g~;~~~:eab~~d~n;"~~t b~e~ ~pp~o~~d: : : ~ ~ ~'Î-I 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N Nt A. 23. If diverter required, does it meet regulations. . . . . . . . . . N ~ -14/ 24. Drilling fluid program schematic & equip list adequate. . . . . N I' 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N U t 26. BOPEpressratingappropriate;testto '3000 psig. N~SP =/~1'L ,,~ ßOfE .jeç,f ht¿(,(J ~ CSc." 7{:eÇ.{. ~ ) ( 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ,N ~~: :~~~~~~~~~rH~~h~~~ ~~~~:~~; ~~u~d~~n: : : : : : : : : : : Y ŒJ 30. Permit can be issued wlo hydrogen sulfide measures. . . . . ~ N *** Offset well Cirque #2 encountered thin, overpressured, Qas-charQed sands at 2171 'I TVDSS. 31. Data presented on potential overpressure zones***. . . . . . . N which were controlled using 10.5 ppg mud. Adjacent well Cirque #3 had normally-pressured gas 32. Seismic analysis of shallow gas zones**** . . . . . . . . . . . Y- N shows across this interval. Cirque #4 mud proQram is based on offset well control and Cirque #3. :~ DATE 33, Seabed condition survey (if off-shore), , , , , , , , , , , " ,AJI{ '¥ N ""*Velocity analysis of 3D seismic data shows no apparent shallow hazards or pressure I. a .0 z.-'34. Contact namelphone for weekly progress reports [exploratory only] é!) N anomalies for the #4 (or~nally #3A) location. No shallow gas indicators are visible in the 3D data. ANNULAR DISPOSAL35. With proper cementing records, this plan CONTACT: Mark Chambers - 265-1319. APPR DATE ~~~ :::: ~~~::~t:~~~:;: ::sU~::::r~o';'~:~eZ~~:i~~ ~~s;e, " ~ ~ ~ 1M U v<!tï V Ji t, f OC/L ( ~ f VVc'i U/ttd ttl (lU rW #:i Vt' . to surface; II ~ (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annuiar COMMISSION: RPC JDH WM CO SFD ~ TErviðQ"M'1 d'\ DTS . WGA ~(¡It- JMH ifMJ:t X dev - redrll serv wellbore seg _ann. disposal para req - 890 UNIT# 011160 ON/OFF SHORE ON ( AP~~ ?f;QEj VJúrr ~o z.. /fJ!J2 y rJ~ -o-:¿ GEOLOGY ( Commentsllnstructions: "29/02. G: \geology\perm its\2020120 - Cirque4- Checklistdoc