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MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm_ MaIker,doc {3 FtJ~ ^~~ ,\ DATA SUBMITTAL COMPLIANCE REPORT 1/26/2004 Permit to Drill 2012290 Well Name/No. KUPARUK RIV U MELT 2P-448 Operator CONOCOPHILLIPS ALASKA INC s~ ;{~/kM'v l API No. 50-103-20396-00-00 MD 8663 - 1VD \ 5458 ,---- Completion Date 1/8/2002 ".- Completion Status P&A Current Status P&A UIC N -------------------- ------------- -- ---------------------------- --------------------- --- ----- ----- ------------- -------- ----------- --------------------- -------------------- ---------------- ------------------------------------------------------------------- ------ ----- REQUIRED INFORMATION ------------------ -- Di~ecti~1 Su rvey ~~- -- -- Mud Log No Samples No --------- ------------- ---- ------------- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset ¡ED"-- ~!~i"-t..~:r .~:::tes - - , ~ - - D D 1 0764 LIS VerifiCation --------------------------,------------~~--_...:.. - Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint) t Log Log Run Interval Scale Media No Start Stop -- ------------ 1 110 8663 OH/ CH Received Comments -------------------------- Case 12/6/2002 Digital Well Log data, including PB1 1 52 8608 Open 4/19/2002 ------------ ------- -------------------- ------__.___n______- Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? ~ Chips Received? ~ Daily History Received? ~ 6}N (' Formation Tops Analysis Received? ~ --- -- -------------------------- ------------------,----- -------------------------------------------..- -,-------- --..------ ,---- ------ ,---, -,---------, , ---- ,- -------------- ---- - - - ------ -- ------ ----------- --- -------- - - ---- --------- --- --- ------- - --------------- -- .. ---- -,------- ---- ---- -----,------------.._--------------,------,--,----------------, Comments: ~O~Plian~e- Re::~y: ~ ~-=I-ç¿ -- - =---=- -= ~ - -==- D ~ t:-- ~ -:l;;:,-~ c~ = ( ( a ol~~¿)9 It 35tp WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 i\nchorage,Alaska 99501 December 03, 2002 RE: MWD Formation Evaluation Logs 2P-448, AK-MM-l1214 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., i\nchorage, AK 99518 2P-448: Digital Log Images 1 CD Ron1 RECEIVED DEC 06 2002 Alaska Oi1 & Gas Cons. Commission Anchorage dO/~~a9 ( :~ WELL LOG TRANSMJr.'AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7tJl Avenue, Suite 100 J\nchorage,Alaska April 18, 2002 RE: MWD Formation Evaluation Logs 2P-448, AK-MM-11214 1 LDWG formatted Disc with verification listing. AJPI#: 50-103-20396-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNJNG A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. i\nchorage, Alaska 99518 Sign~ úSkp. ..J ~ r-- --'" '"' 10 ", ", . ' rî, . '- -,' " 'î ¡'-,;": \. ; :J :~~ t.., Alaska Oil & Gas Cons. Commission .l\nchorage SENT BY: 3-25- 2 ;11:04AM ;PHILLIPS AK-DRILLING~ :# 1/ 2 ( Phone: 263-4612 Fax RECE\\!f.D tl\þp, 2- 5 2GG2. i "', ,'- '-.11)-' "C l' ..-"-;" , G¡\ & üös ".",,) ~-, . Mas\<3. !\ nrJ"1; '~f,\-,'~ To: Mr. Bob Fleckenstein from: Sharon Allsup-Drake Fax: 9~907 -276-7542 Date: March 25, 2002 Phone: 79$-1224 P;l8e$: 2 -----..-- R.: 2P-448 cc; C1 Urgent 0 For Review 0 Please Comment 0 Please Reply 0 Plea",. R*cye:l. .Comment8: Mr. Fleckenstein; Here is the additional information for 2P-448 as requested by Mr. Steve Davies. It is the 2nd page of the completion repon for 2P-448 with the geologic markers listed. If you have any questions, please feel free to call me at 263-4612. P11) f)qO !)oiY Thanks, Sharon ,~ :,l PLuGGING & LOCATION CLEF_~_~CE REPORT State: of J._laska .u.;\SM or:. 8: ~ C::NSE.AVA"rION CCMMISSICN , :cca.t:.cz¡ '.~ Q~,- --:: -,:...- --. - -::-.: -: c.. .:.--':: --' ,.."-10. .--.-- ----- - - - -- -. ",-iell ~r2.!I1e Cper2.t== TD:~ ~bz3, Sp~ci: Q I)¡' C) { ~cte casi.:.c; s:.:e" wt:" ¿e~n:.!:... c:::: 7°1.. Sfc C.:;q: ~., ""ß ~Qnq C.:;q: (;:..g(j ~ine:r: ..,._~ ~er= ~:er7a~s - ~=p8: Rev:.ew t.::.e well ::.le" and' c:=:mm,ent on plu~C;, well head ::::~'-:P~=~3~dd~¡ prað hh¡~leah~c~. ~", ~ ,- ' . ' r- 'U Well ~eaci C:-..1: of:E: . OJ) 0 ., Harxe= ";Iost or plata: AJ 0 JJlð > A ÆL~ Conclusiona: -W5 Code r Q~ Signe~ '" C'-ç' ~ ;Sf ~"¿j, Date - ' ~~? b~ ' , , :5' /nelJ? !lL~ ;2;) (ry~ ð 7.. - . , . .' . (' ( PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 March 21, 2002 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2P-448 and 2P-448A (201-229/302-009) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Meltwater well 2P-448. It includes the P&A report for 2P-448 and the report for the sidetrack well 2P-448A. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sincerely, '~~. R. Thomas - Greater Kuparuk Team Leader P AI Drilling RT/skad RECEIV'ED t"U P ?? 'JOO2 ' ,. \. \ I- '- C Alaska OU & Gas Cons. Commission Anchorage ORIGINAL (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ¡<"e- , , 1. Status of well Classification of Service Well Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 0 2. Name of Operator 7. Pennit Number Phillips Alaska, Inc. ,~. 201-229 / 302-009 3. Address St~~., 8. API Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20396-00 .,' , ' 4. Location of well at surface ;' ,:( H =-....... '. 9, Unit or Lease Name ~.,. - , ,-' 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM (asp's: 443543',šã~§5~~ Kuparuk River Unit At Top Producing Interval 10. Well Number not available 2P-448 At Total Depth 11. Field and Pool 1393' FSL, 987' FWL, Sec. 18, T8N, R7E, UM (asp's: 438115,5866035) Kuparuk River Field 5, Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. RKB 253 feet AMSL ADL 373112 ALK 4998 Meltwater Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. & 15. Water Depth, if offshore 16. No. of Completions December 22, 2001 January 7, 2002 January 8, 2002 (P&A'd) N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19, Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8663' MD / 5458' TVD 3800' MD / 2874' TVD YES 0 No 0 N/A feet MD 1488' (approx) 22. Type Electric or Other Logs Run G R/Res/Neu/Den 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# B Surface., 110' 42" 64.9 bbls AS 1 7.625" 29.7# L-80 Surface 2976' 9-7/8" 391 sx AS Lite, 202 sx LiteCrete set balanced plug from 4400' to 3800' 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 4400'-3800' 30.7 bb117.0 ppg cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & 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 WATER-BBL OIL GRAVITY - API (corr) Press. 24-Hour Rate> 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A t.P\R 2 Z 2002 Alaska Oil & Gas Cons. CommiSon AnchOrage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE () r~ 1(;1 NAL- Submit in duplicate l>ç SENT BY: 3-25- 2 ;11:04AM ;PHILLIPS AK-DRILLING~ '# 2 I ') , ...,/ ,-, .', 29- 30. GEOLOGIC MARKER" FORMATION TESTS MEAS.DEPTH TRUI': VERT. DEPTH Inclutie inlcMIIIAillp.c:I, pressure data. all fluIds r~('.o\lerF>d Elmf çmwl1y, GOA, and 1ime 01 ~;,)ch phase. NAME C.80 C-50 0-40 C-37 T.7 C-35 2992' 3911' 4471' 4730' 6893' 7840' 2449' 2936' 3238' 3380' 4517' 5020' N/A , ,-",-,----,-"'~~ :31, LIST OF ATTACHMENrS Summary of 2p.44S SIdetrack Plug & Abandonment Operations. 32. I hereby ccrUfy that ~he following is trulf and correct to th~ best of my knowledge. , . _.._""---,--"..,,---~ QlIes1ion!:l? Call Pal Reilly 265-6040 Sig"çr;! ., Title Kuvàr'uk Team Leader Dale -'._---'--"----'-" R. Thomas . ----,'- -.. '" '" ProP;)(t~ bV $'u~r'()n IIflm.lp.rkR/(e INSTRUCTIONS Generill: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in AIÇlska. n.m 1: Classification of Service wells: Gas injection. water injection, steam inj9ction, aír injection, salt water disPQsal, water supply for injection. observation, injection for in-situ combustion. Item 5: Indicate which etevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form Çlnd in any attachments. Item 16 and 24: If this well is completed for separate produc1ion from more than one interval (multiple completion), 90 state in item 16, and in item 24 show the producing intervals for the interval reported ín item 27. Submit A !ìAparate fòrm for eaoh additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF. 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 toot. Iten. 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". Form 1 0-407 /",:f' ¡ ,..'"'~ /'~ ,"'/""",..." , ,c~ <', ,,' ",'" """"'-"', "" -""",1 ,,'" ,'~ i""""",' "/.",, / ,(,' ,/' ¡J' , ..- """" "" I' """,'" "".."", ~,;'.,-," r ' 'I' "II""""""'",",'", ,,"""""',.,';;;¡'-" '""', , """'",',,"" -"""'""""""""" .",I/~ ' ..." """""~, "",.. ",.... "../ 29. \ GEOLOGIC MARKERS 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. Not available N/A 31. LIST OF ATTACHMENTS Summary of 2P-448 Sidetrack Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Pat Reilly 265-6048 s;gne~~~ Title R. Tho as KuDaruk Team Leader Date "3 (":2 \" I'D <» - c....., 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 (OF, 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". Form 10-407 PHilliPS ALASKA INC. Qpe'rations Summary Report Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase I . Code 12/21/2001 00:00 - 03:00 3.00 MOVE RURD MOVE 03:00 - 16:00 13.00 MOVE MOVE MOVE 16:00 - 22:00 6.00 MOVE RURD SURFAC 22:00 - 00:00 2.00 DRILL PULD SURFAC 12/22/2001 00:00 - 05:00 5.00 DRILL PULD SURFAC 05:00 - 06:00 1.00 DRILL PULD SURFAC 06:00 - 07:00 1.00 WELCT BOPE SURFAC 07:00 - 08:00. 1.00 DRILL SFTY SURFAC 08:00 - 10:00 2.00 DRILL PULD SURFAC 10:00 - 11 :00 1.00 DRILL CIRC SURFAC 11:00 - 00:00 13.00 DRILL DRLG SURFAC 12/23/2001 00:00 - 14:00 14.00 DRILL DRLG SURFAC 14:00 - 15:00 1.00 DRILL CIRC SURFAC 15:00 - 19:00 4.00 DRILL TRIP SURFAC Page 1 of 12 Spud Date: 12/22/2001 End: 1/~2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations' Prep rig for rig move to 2P-448, Move rig from 2P-429 to 2P-448, spot modul es and R/U Accept rig at 1600 hrs. 12/21/01. R/U divert er system, install 4" valves on conductor pi pe, install bell nipple and flow lines, Ready rig floor for 4" DP, Load4" DP in pipe shed and strap pipe. P/U 4" DP and stand back in derrick P/U and stand back in derrick 4" DP.- total 7500' of pipe P/U and stand back in derrick HWDP Test diverter and accumulator, hold diverter and accum. drills, witnessed by AOGCC ins pector. Hold Pre-spud meeting with crews and servi ce personal involved in well P/U BHA Fill stack, check for leaks on flowline, mud lines and associated equipment. Test lines Drill ahead to 843' RT = 4.3 hrs. AST = 2.0 hrs. Drill from 843' 0 2040' MD, 1898' TVD ART = 5.9 hrs. AST Circ. sweep and clean up hole While making wiper trip at 2041', we pul led the first 2 stands with no drag or swabbi ng. The third stand pulled good the first 30' then started to get tight at 1851'. We work ed the pipe up to 75k over pull on a couple strokes, but it cleaned up and pulled free. T he forth stand started to get tight after pulli ng 15', worked the pipe in 25k increments u p to 125k overpull. We opted to pump out of the hole. Screwed Into the top drive and br oke circ. and started rotation, as we were p ulling up we packed off and stalled rotation. Attempted to go back down, but couldn't. W orked 4th stand out of hole pulling up in 25k increments to 125k overpull. Worked 5th st and up 25' (1632') working up and down pull ing in 25k increments to 175k overpull. Pipe is good for 50 Ok tensile. Started to torque and slump pipe to see if it would work down and start turning, torque up to 20k ft. Ibs. P ipe started to turn 2 different times, then pi pe spun backwards because brake was not 0 n and unscrewed pipe 45' from surface. Scre wed back into pipe and torque pipe to 20k ft . Ibs. Continue torque and slump method, ja rs were working on the up stroke. Pipe start ed rotating, work pipe while rotating to get some free area to try and regain circulation. Printed: 1/21/2002 10:27:43 AM ( Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/23/2001 15:00 - 19:00 4.00 DRILL TRIP SURFAC 19:00 - 23:00 4.00 FISH PULD SURFAC 23:00 - 00:00 1.00 FISH PULD SURFAC 12/24/2001 00:00 - 02:00 2.00 FISH PULD SURFAC 02:00 - 04:00 2.00 FISI-;i WASH SURFAC 04:00 - 04:30 0.50 FISH FISH SURFAC 04:30 - 05:00 0.50 FISH JAR SURFAC 05:00 - 06:00 1.00 FISH CIRC SURFAC 06:00 - 08:00 2.00 FISH TRIP SURFAC 08:00 -10:30 2.50 WAlTON EOIP SURFAC 10:30 - 12:00 1.50 FISH PULD SURFAC 12:00 - 13:30 1.50 FISH WASH SURFAC 13:30 -14:00 0.50 FISH MILL SURFAC 14:00 - 16:00 2.00 FISH JAR SURFAC 16:00 -18:30 2.50 FISH TRIP SURFAC 18:30 -19:30 1.00 FISH PULD SURFAC 19:30 - 20:30 1.00 FISH WASH SURFAC 20:30 - 00:00 3.50 FISH JAR SURFAC 12/25/2001 00:00 - 04:00 SURFAC 4.00 FISH JAR Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations Pull pipe up until we had overpull and pipe started bouncing like it was up against a ro ck. The pipe then came free and we regaine d circulation. Brought pumps up to drilling r ate and seen we had lost 900 psi circ. press ure. String weight didn't seem any different than when we were drilling. POOH and found the drilling jars were parted in the threads on the hydraulic pressure chamber of the jar s. Jars had never went off wi more than 5 Ok overpull. Top of fish is at 1264.13'. P/U 6 3/4" Drill collars to be u Ishin g, while waiting on Baker Fishing out of Dea dhorse Offload fishing tools and P/U to go in the ho Ie M/U fishing assembly, 8 1/4" overshot w/4 3 14" grapple, bumper sub, oil jars, 9 - 6 1/2" DC's, and excellerator RIH, washed from 500' to 1264', (top of fish ) Work control head and 4 3/4" grapple over fi sh Jar down on fish with bumper sub, fish didn' t move Attempt to jar up on fish, grapple slipped of f fish, set back over fish, but grapple would n't hold, circ bottoms up Trip out of hole with overshot, control head had circular wear marks on it with a 5 1/4" pattern. Grapple was worn smooth Having a overshot built with mill section ins ide to dress top of fish back to 4 3/4". Wait on tool to be delivered from Deadhorse M/U fishing assembly to mill and catch 4 3/4 " fish, TIH to 500' Wash overshot to top of fish, from 500' to 1 264' Dress off top of fish to 4 3/4", engage grapp Ie over fish Jar down on fish, found no movement down, attempt to jar up, after third jar up the grap pie come off fish attempt to grab fish, but w ouldn't hold POOH with fishing assembly Change out grapple to a 4 5/8" RIH, wash overshot from 500' 1'01264', slip over top of fish Jar on fish, pulling up to 150k over, made 4' coming up, but couldn't get fish to jar back down. Waiting on Schlumberger wire line to run free point and back off. Jar on fish, made another 2' up but couldn't Printed: 1/21/2002 10:27:43 AM ,r' Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 12/25/2001 00:00 - 04:00 4.00 FISH JAR SURFAC 04:00 - 07:00 3.00 FISH CPBO SURFAC 07:00 - 08:00 1.00 RIGMNT RGRP SURFAC 08:00 - 13:30 5.50 FISH JAR SURFAC 13:30 - 15:30 2.00 FISH CPBO SURFAC 15:30 - 17:00 17:00 - 19:00 1.50 FISH 2.00 FISH TRIP SURFAC PULD SURFAC 19:00 - 20:30 1.50 FISH RURD SURFAC 20:30 - 21 :00 21 :00 - 23:00 0.50 RIGMNT RSRV SURFAC 2.00 FISH TRIP SURFAC 23:00 - 00:00 1.00 FISH FISH SURFAC 12/26/2001 00:00 - 01 :30 1.50 FISH TRIP SURFAC 01 :30 - 03:00 1.50 FISH TRIP SURFAC 03:00 - 06:30 3.50 FISH TRIP SURFAC 06:30 - 09:30 3.00 FISH TRIP SURFAC 09:30 - 11 :00 11 :00 - 12:00 1.50 FISH TRIP SURFAC 1.00 RIGMNT RSRV SURFAC 12:00 - 13:30 13:30 - 15:00 1.50 FISH TRIP 1.50 WAlTON EQIP SURFAC SURFAC 15:00 - 15:30 0.50 FISH ELiN SURFAC Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Descriptio'n of Operations go down. Total of 6' has been made ¡aring up, top of fish at 1258' R/U Schlumberger wireline to free point pipe , made a dummy run to see if we could get t hrough the top of the fish. Made 3 attempts with various configurations on bottom of too I, but couldn't get through separated drillin g jars. RID wireline Attempt to release from overshot. Top drive kept kicking out breakers while torquing. Attempt to release overshot from fish, but g rap pie wouldn't release, torque and jar with no movement R/U wireline, run string shot in overshot, to rque pipe, shot string shot and overshot rei eased. POOH LID fishing tools, M/U new overshot w/4 5/8" grapple, bumper sub and jars Change out top drive saver sub and grabber s to 5" Rig service, check drill line and top drive RIH with fishing tools, picking up 5" DP, tor quing DP to 25,000 ft. Ibs. Work over fish with 4 5/8" grapple, had prob lems getting it to grab. Latch onto fish and w ork left hand torque, getting ready for a me chanica I (blind) back off. POOH, found we had backed off on top of fis hing jars, left fishing assembly in hole. TIH with screw in sub, screw into fishing jar s, POOH with fishing tools. Replace 4 5/8" grapple in overshot, RIH, Lat ch onto fish and attempt a mechanical back off, POOH, recovered a 5.35' section of the drilling jars, the top of fish had a split appr ox. 6" long through the female threads. TIH with 4 3/4" grapple in overshot, latch on to fish and attempt a mechanical back off POOH, no recovery Service rig and top drive, inspect drilling Ii ne and check for loose fittings, bolts and c onnections which could had been caused by jarring. Wait on fishing tools from Baker fishing in Deadhorse. TIH with 4 5/8" grapple in overshot, latch on to fish, attempt mechanical backoff, acted a s if we had a back off, pull up hole 30' RIH with collar locator and sinker bar on wir eline, tagged up in overshot and couldn't go deeper. It was thought we had some of the fish in overshot. Printed: 1/21/2002 10:27:43 AM - - - - . , ,- , ' , ,.... PHilliPS ALASKA INC. - - Operations Summary : Report,}: Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 From - To Hours Code Sub Phase Code 12/26/2001 15:30 - 16:30 16:30 - 19:00 19:00 - 21:30 21 :30 - 00:00 12/27/2001 00:00 - 02:00 02:00 - 03:30 03:30 - 04:30 04:30 - 05:30 05:30 - 08:30 08:30 - 09:00 09:00 - 10:00 10:00 - 11 :00 11:00 -18:00 18:00 - 21:00 12/28/2001 21:00 - 21:30 21 :30 - 00:00 00:00 - 15:00 15:00 - 16:00 16:00 - 19:30 19:30 - 00:00 12/29/2001 00:00 -11:30 11 :30 - 13:00 13:00 - 15:00 15:00 - 18:00 1.00 FISH 2.50 FISH 2.50 DRILL 2.50 DRILL TRIP SURFAC PULD SURFAC TRIP CIRC SURFAC SURFAC 2.00 WAlTON EOIP SURFAC 1.50 CEMEN TRIP SURFAC 1.00 CEMEN CIRC SURFAC 1.00 CEMEN PLUG SURFAC 3.00 CEMEN CIRC SURFAC 0.50 CEMEN TRIP SURFAC 1.00 CEMEN PLUG SURFAC 1.00 CEMEN TRIP 7.00 WAlTON CMT 3.00 WAlTON CMT 0.50 DRILL 2.50 DRILL 15.00 DRILL 1.00 DRILL 3.50 DRILL 4.50 DRILL 11.50 DRILL 1.50 DRILL 2.00 DRILL 3.00 DRILL SURFAC SURFAC SURFAC REAM SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC DRLG SURFAC DRLG SURFAC CIRC SURFAC WIPR SURFAC WIPR SURFAC Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations POOH, no recovery Brake out and LID all fish tools and wireline equipment. Make up 9 7/8" bit and RIH to 1264', wash ti ght hole from 600' to 1264' Circ. and cond mud for setting balanced cem ent plugs. LID 5" DP, while waiting on Dowell Schlumb erger for cementing RIH w/4" DP and mule shoe to 1260' Circ. while waiting on cementers Hold pre-job safety meeting, pump 7 bbls wa ter, test lines to 2000 psi, pump 52 bbls CI. G cement at 17 ppg. (280 sx), pump 1 bbl w ater and displace for a balanced plug, pull u p hole with DP to 690' Circ while waiting on cement to cure, didn't see any cement in returns RIH to 865' and tag hard cement Circ. bottoms up, pump 7 bbls water, 20 bbl s CI. G cement at 17 ppg. (110 sx), pump 1 bbl water and displace for a balanced plug, pull up hole to 480' Circ. bottoms, no cement in returns, POOH Wait on cement to cure, LID 6 1/2" DC's, ch ange TDS saver sub back to 4" HT-38, Slip and cut drill line P/U side track BHA while waiting on cement to cure Wash and ream to 738', found good cement Drill cement from 738' to 935' Drill from 935' to 1955' MD, 1840 TVD ART = 6.8 hrs AST = 3.4 hrs Circ, and cond for wiper trip Wiper trip to 700', started pulling tight at 1 860' and had to work pipe out of hole to 147 8'. Worked pipe up to 30,000 overpull and 3 0,000 set down, pipe pulled free from 1478' to 700'. Pipe went to bottom with no proble m, no fi II. Drill from 1955' to 2244' MD, 2040' TVD AR T = 0.9 hrs AST = 1.9 hrs Drill from 2244' to 2990' MD, 2447' TVD AR T = 7.3 hrs AST = 1.5 hrs Circ. and cond mud and hole for wiper trip, pump 2 sweeps, shakers cleaned up. Short trip pipe, hole started getting tight at 2790', work pipe with 30k up and back down , pipe became stuck at 2736' with 30 k over pull and wouldn't go back down. Jar down on BHA, had problems getting jars to fire going down, had to work jars in the n eutral position several time before setting d Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Date From - To Hours Code Sub Phase Code 12/29/2001 15:00 - 18:00 18:00 - 19:00 19:00 - 22:00 22:00 - 00:00 12/30/2001 00:00 - 02:00 02:00 - 04:00 04:00 - 06:00 06:00 - 08:00 08:00 - 11 :00 11 :00 - 12:00 12:00 - 15:30 15:30 - 00:00 12/31/2001 00:00 - 02:30 02:30 - 05:00 05:00 - 07:00 07:00 - 10:30 3.00 DRILL WIPR SURFAC 1.00 DRILL WIPR SURFAC 3.00 DRILL 2.00 FISH 2.00 FISH 2.00 FISH 2.00 FISH 2.00 FISH 3.00 FISH 1.00 FISH 3.50 FISH 8.50 FISH 2.50 FISH 2.50 DRILL 2.00 DRILL 3.50 DRILL WIPR SURFAC ELIN ELIN SURFAC SURFAC CPBO SURFAC TRIP SURFAC RURD SURFAC PULD SURFAC CIRC SURFAC PULL SURFAC PULL SURFAC TRIP TRIP SURFAC SURFAC CIRC SURFAC TRIP SURFAC Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations own to get them to fire. Started using the to rque and slump method going down and got pipe to start rotating with 10,000 to 13,000 ft Ibs of torque. Worked pipe while rotating with 10,000 ft Ib s of torque, pipe wouldn't go down but could rotate up. Attempt to regain circ. with slow rate, pipe immediatly stuck when drill pipe caught pressure. Now pipe is stuck at 2716' Attempt to torque and slump pipe, jar down on pipe and seen no movement, Baker Fishin g tool man showed and attempted his magic, but could not get pipe movement. R/U Schlumberger, run free point tool in hol e, found pipe free all the way to the Sperry Sun MWD tool. Finish free point with Schlumberger, found p ipe free all the way to the MWD tools, POOH with wire line RIH W/backoff shot, back pipe off one DC a bove to MWD tool, 2612', POOH with wire lin e. POOH, LID 2 non-mag DC's Change TDS saver sub to 4 1/2" IF connecti on for 5" DP, bring fishing tools to rig floor P/U fishing assembly, 4 1/2 IF screw in sub, bumper sub, fishing jars, 6 1/2" DC's, exce Ilerator and 5" DP, RIH to 2600' Circ and cond mud and hole at 2601, rotatin g and reciprocating pipe Screw into fish, torque connection to 25,000 ft Ibs, fish started to rotate, rotate and ba ck ream without circ, torque running from 15 ,000 to 7,000 ft Ibs. Backream out of hole w ithout circ to 2600' bit depth, overpull from 10 to 30k, pipe stuck a few times with DP pr essure when trying to circ. At 2600' bit dept h we seen a free spot, stopped and worked p ipe in free spot, this is where we had circ. prior to screwing into fish. Brought mud pum p on and regained circulation. Circulate and back ream tight hole to 800', pipe came free where we were able to p,ull p ipe without reaming, pull to DC's at report t ime POOH and LID fish, (Directional BHA) RIH with 9 7/8" hole opener on 5" drill pipe to bottom, had one slight tight spot that too k 20k and wiped right out at 2600' to 2630' and nothing else to bottom Circ and cond hole for casing run POOH LID 5" DP and 6 1/2" DC's Printed: 1/21/2002 10:27:43 AM Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From,- To Hours I Code Sub Phase Code 12/31/2001 10:30 - 12:00 1.50 DRILL RIRD SURFAC 12:00 - 16:00 4.00 CASE RUNC SURFAC 16:00 -19:00 3.00 CASE CIRC SURFAC 19:00 - 19:30 19:30 - 20:00 20:00 - 22:30 0.50 CEMEN RURD SURFAC 0.50 CEMEN SFTY SURFAC 2.50 CEMEN PUMP SURFAC 22:30 - 00:00 1.50 CEMEN PULD SURFAC 1/1/2002 00:00 - 02:30 2.50 CASE NUND SURFAC 02:30 - 04:30 2.00 CASE NUND PROD 04:30 - 08:30 4.00 CASE NUND PROD 08:30 - 09:30 1.00 CASE RURD PROD 09:30 - 15:30 6.00 WELCT BOPE PROD 15:30 - 19:30 4.00 DRILL PULD PROD 19:30 - 21:00 . PROD 1.50 DRILL TRIP 21 :00 - 22:00 1.00 CASE DEOT PROD 22:00 - 23:00 1.00 CASE CIRC PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 1/2/2002 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:30 0.50 WELLS NUND PROD 02:30 - 03:30 1.00 WELLS NUND PROD 03:30 - 04:30 1.00 WELLS NUND PROD 04:30 - 07:30 3.00 WELLS Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations R/U to run 7 5/8" casing, hold pre-job safet y meeting RIH with 69 jts 7 5/8" 29.7# L-80 BTCM casi ng and set at 2976.3', had no tight hole goi n gin. Circ. and Cond hole for cementing, thin out mud, reciprocate pipe while circulating R/U Franks fill up tool and cement head Hold pre-job safety meeting With Schlumberger Dowell Well, we pumped 10 bbls CW-100, test lines to 3500 psi, pum p 30 bbls CW-100, drop bottom plug, pump 5 0 bbls 10.5 ppg Mud Push, 316 bbls lead ce ment at 10.7 ppg, 65 bbls tail cement at 12 ppg, drop top plug, pump 5 bbls water and d is place with rig pump, bump plug with 500 P si over, floats held. We was suppose to pum p 90 bbls of tail cement, but cement silo's a nd hopper line became plugged and couldn't mix. We were short 25 bblsof tail cement. r ecover 55 bbls of good 10.7 ppg cement to s urface. Reciprocated pipe until it started to get sticky, half way thru cement job. Clean cement out of stack and related equip ment, LID cement head and casing equipmen t, clear floor, LID casing landing jt. N/D Diverter System N/U Csg head & orient - Test to 1000psi hol d 5 min "OK" B/U BOPs C/O Saver Sub on TD Test BOPs - Test BOPs & choke manifold 25 0/3000 psi - Hold ea. test 5 min - Chart for AOGCC - AOGCC did not respond back from notification to Rig - Pull test plug - Install wear ring P/U BHA #4 - P/U Bit & Motor and orient - S cribe tolls - up load MWD - Load RA sources TIH - (Rotate slowly thru TPC @ 1013') Tag up @ 2884' Circu air from system - R/U to Test Csg - At tempt Csg Integrity Test - Pack off failed @ 600 psi. Blew seal and thread lock ring on FMC Gen V Csg Head Circu to balance mud system for TOH TOH - SIB all possible BHA Con't TOH - LID MWD & HO sub Pull wear bushing - clear floor N/D BOPs C/O leaking Csg Head - Top seal bad. Lock nut ring not inguaged N/U BOPs Printed: 1/21/2002 10:27:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Hours Code I Sub Code Date From - To 1/2/2002 07:30 - 08:30 08:30 - 10:00 10:00 -11:00 11 :00 - 12:00 12:00 - 13:00 13:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 19:00 19:00 - 19:30 19:30 - 00:00 1/3/2002 00:00 - 12:00 12:00 - 00:00 1/4/2002 00:00 - 05:30 05:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 12:00 12:00 - 00:00 1/5/2002 00:00 - 06:00 06:00 - 07:00 07:00 - 12:00 12:00 - 19:00 19:00 - 20:30 20:30 - 21 :30 21 :30 - 22:30 22:30 - 23:30 23:30 - 00:00 1/6/2002 00:00 - 12:00 Phase 1.00 WELCT BOPE PROD 1.50 DRILL PULD PROD 1.00 DRILL 1.00 CASE 1.00 CASE 2.00 DRILL 0.50 DRILL 0.50 DRILL 1.00 DRILL 2.00 DRILL 0.50 DRILL 4.50 DRILL 12.00 DRILL 12.00 DRILL 5.50 DRILL 1.50 DRILL 1.00 DRILL TRIP PROD DEOT PROD DEOT PROD OTHR PROD DRLG PROD CIRC PROD FIT PROD DRLG PROD OTHR PROD DRLG PROD DRLG PROD DRLG PROD DRLG PROD CI RC PROD WIPR PROD 0.50 RIGMNT RSRV PROD 1.00 DRILL WIPR PROD 2.50 DRILL 12.00 DRILL 6.00 DRILL 1.00 DRILL 5.00 DRILL 7.00 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 1.00 DRILL 0.50 DRILL 12.00 DRILL DRLG PROD DRLG PROD DRLG PROD CIRC PROD DRLG PROD DRLG PROD CIRC PROD WIPR PROD WIPR PROD CIRC PROD DRLG PROD DRLG PROD Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations Re-Test Body & Choke line breaks P/U MWD & HO sub - Orient - Load RA sourc es TIH to 2872' Circu air from system Test Csg to 2500 psi -Hold 30 min on chart - Loss 30 psi Drlg FC,CMT & FS to 2990' (Old TD) Drlg 2990' to 3020' MD (2463' TVD) Circu Hole clean - C/O mud to good conditio ned 9.7ppg clean system Preform FIT - Pressure to 807psi @ 2463' T VD w/ 9.7ppg mud = 16.0 EMW - hold 10min - loss 80 psi Drlg & Slide 3020' to 3160' MD CBU to clean hole - Preform Base line test f or PWD tools Drlg & Slide 3160' to 3450' MD (2688' TVD) ART 2.7 hrs, AST 0.5 hrs Drlg & Slide 3450' to 4080' MD (3026' TVD) ART 8.6 hrs , AST 1.2 hrs Drlg & Slide 4080' to 4700' MD (3363' TVD) ART 9.3 hrs , AST 0.3 hrs Drlg & Slide 4700' to 4982' MD (3512' TVD) ART 3.4 hrs , AST 1.5 hrs Pump Wt sweep - Circu hole clean Wiper Trip - TOH to 7 5/8" Shoe - No Swab - No overpull - Hole in good shape Service Rig & TD Wiper Trip - TIH to 4982' - No tight hole - N 0 fill Drlg & Slide 4982' to 5130' MD (3590' TVD) ART 2.1 hrs , AST 0.0 hrs Drlg & Slide 5130' to 5750' MD (3918' TVD) ART 8.2 hrs , AST 1.3 hrs Dir Drlg & Slide 5750' to 6063' MD (4085' T VD) ART 3.9 hrs , AST 0.8 Tool failed- No signal from pulsor - Work to 01 & cycle pumps in attempt to regain signal - Pump sweep - Re-Gained Signal from tool s Dir Drlg & Slide 6063' to 6422' MD ( 4274' T V D) Dir Drlg & Slide 6422' to 6806' MD ( 4472' T VD) ART 5.0 hrs , AST 0.5 hrs Pump Wt / Hi vis sweep - Circu hole clean TOH to 4800' - No excss drag - No swab TIH - Wash 90' to Bttm - No fill CBU - Clean hole - MAX ECD 10.85 - BU Gas 73 units Dir Drlg & Slide 6806' to 6820' MD ( 4479' T VD) AST 0.2 hrs Dir Drlg & Slide 6820' to 7574' MD ( 4876' T Printed: 1/21/2002 10:27:43 AM Legal Well Name: 2P-448 Common Well Name: 2P-448 Event Name: ROT - DRILLING Contractor Name: Doyon Rig Name: Doyon 141 Date From - To Hours Code Sub . Phase Code 1/6/2002 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 13:30 1.50 DRILL CIRC PROD 13:30 - 00:00 10.50 DRILL DRLG PROD 1nl2002 00:00 - 04:00 4.00 DRILL DRLG PROD 04:00 - 06:00 2.00 DRILL CIRC PROD 06:00 - 08:00 2.00 DRILL WIPR PROD 08:00 - 08:30 0.50 DRILL CIRC PROD 08:30 - 16:00 7.50 DRILL DRLG PROD 16:00 - 18:30 2.50 DRILL CIRC PROD 18:30 - 00:00 5.50 DRILL TRIP PROD 1/8/2002 00:00 - 02:30 2.50 DRILL PULD PROD 02:30 - 05:30 3.00 CEMEN PLUG PROD 05:30 - 06:30 1.00 CEMEN TRIP PROD 06:30 - 07:30 1.00 RIGMNT RSRV PROD 07:30 - 08:30 1.00 CEMEN TRIP PROD 08:30 - 09:30 1.00 CEMEN OTHR PROD 09:30 - 10:00 0.50 CEMEN TRIP PROD 10:00 - 10:30 0.50 CEMEN CIRC PROD 10:30 - 11 :30 1.00 CEMEN PLUG PROD 11 :30 - 12:30 1.00 CEMEN TRIP PROD 12:30 - 13:30 1.00 CEMEN CIRC PROD 13:30 -14:30 1.00 CEMEN TRIP PROD 14:30 - 17:00 2.50 CEMEN PULD PROD 17:00 - 17:30 0.50 WELCT 17:30 - 21 :00 3.50 WELCT 21 :00 - 21:30 21 :30 - 00:00 0.50 WELCT BOPE PROD 2.50 DRILL PULD PROD Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations VD) ART 9.1 hrs , AST 1.1 hrs Circu Hole clean pryor to drilling Bermuda p er well plan - Clean hole ECD 10.6 Dir Drlg & Slide 7574' to 8115' MD (5169' T VD) ART 6.8 hrs , AST 1.5 hrs Max BU Gas 206 units Dir Drlg & Slide (Control ROP 80' FPH Max) 8115' to 8330' MD (5279' TVD) Pump Hi Vis Sweep - Circu hole clean Wiper Trip to 6425' - No excess drag - No s wab Pump Hi Vis Sweep - Circu hole - Logs show ed no Bermada sands- Dicission was made b y Engineers to drill 200' TVD more hole to c heck for sands. Dir Drlg & Slide 8330' to 8663' MD ( 5458' T VD) ART 4.0 hrs , AST 1.9 hrs ** Note**Stop ped early - Engineer ( Steve Moothart)called and said they had seen enough - Stop drilli ng - Will plug back for Side Track ........ Pump Hi Vis Sweep - Circu Hole clean - Pum p Dry job - Monitor well TOH - LID BHA Con't LID BHA -PJSM - Remove RA scources - LID HOS & MWD - SIB Motor and MWD P/U CMT Stinger - P/U Mule shoe & 20 jts 2 7/8H EUE 8rd Tbg & 2 XOs TIH wI Tbg CMT stinger on 4" DP to 2940' Cut drill line TIH to 4800' Spot 10 ppg Gel pill from 4800' to 4400' TOH to 4400' Circu BU Cement - Lay balanced CMT Plug from 4400' to 3800' - Pump 10 bbl H2o ,30.7 bbl 17.0p pg CMT , 2.9 H2o - Displace with Rig 343 st ks 9.6ppg mud.- Pressures while pumping @ 13.5 bbls ,20spm ,2730 psi @ 25.3 bbls 5 spm, 3100 psi ,@ 34.6 bbl , 40spm ,870 P si TOH -Slowly pulling out of CMT to 3300' (5 00' above calcu TOC) Circu and clear drill string - Saw contaminat ed Mud - No CMT TOH - SIB 4" DP R/U Tbg tools - LID 2 7/8" Tbg CMT stinger &' mule shoe Pull wear bushing - Install test plug Test BOPs & Choke Manifold - test 250 130 OOpsi - Chart for 5min/5min - AOGCC John S paulding waived witness test Pull test plug - Install wear bushing P/U BHA #7 Printed: 1/21/2002 10:27:43 AM l Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 2P-448 2P-448 ROT - DRILLING Doyon Doyon 141 Page 9 of 12 Spud Date: 12/22/2001 End: 1/3/2002 Group: Start: 12/21/2001 Rig Release: 1/16/2002 Rig Number: 141 Description of Operations Date Sub From - To Hours Code Code Phase 1/9/2002 00:00 - 02:30 02:30 - 04:00 04:00 - 04:30 04:30 - 05:30 05:30 - 06:30 06:30 - 08:30 08:30 - 10:00 10:00 - 11 :00 11 :00 - 12:00 12:00 - 19:30 19:30 - 21:00 21 :00 - 22:00 22:00 - 00:00 1/10/2002 00:00 - 04:30 04:30 - 05:30 05:30 - 12:00 12:00 - 13:30 13:30 - 15:00 15:00 - 19:00 19:00 - 19:30 19:30 - 20:00 20:00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 2.50 DRILL 1.50 DRILL 0.50 DRILL 1.00 DRILL 1.00 DRILL 2.00 DRILL 1.50 DRILL 1.00 DRILL 1.00 DRILL 7.50 DRILL 1.50 DRILL 1.00 DRILL 2.00 DRILL 4.50 DRILL 1.00 DRILL 6.50 DRILL 1.50 DRILL 1.50 DRILL 4.00 DRILL 0.50 DRILL 0.50 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 0.50 DRILL DRLG PROD TRIP PROD CIRC PROD TRIP PROD CIRC PROD CI RC PROD CI RC PROD DRLG PROD DRLG PROD DRLG PROD CIRC PROD WIPR PROD DRLG PROD DRLG PROD CI RC PROD DRLG PROD DRLG PROD CIRC PROD TRIP PROD TRI P PROD SFTY PROD PULD PROD PULD PROD TRIP PROD PULD PROD P/U BHA # 7- PJSM RA sources - Initialize MWD (repair CIM connection) Install RA sco urces -P/U Std NM DCs TIH to 2996' Fill Pipe - Break Circu - Pulse Test MWD TIH to 3590' M/U TD - Circu slowly - Wash to 3910' (CMT stringers & Soft CMT @ 3870' ) Circu hole clean - Preform PWD baseline Te st - Clean Hole ECD = 10.4+ Waiting on State to approve PTD - Rotate & Pump at a reduced rate ( 20 RPMs & 1.5 BP M) recip DP Drlg CMT 3910' - 4000' Time Drlg Side Track well @ 4000' to 4051' ( Departure point 4000') Dir Drlg & Slide 4051' to 4406' ( 3240' TVD) ECDs = 10.8 Pump sweep - Circu hole clean WiperTrip back thru KO point - Work KG poi nt clean Dir Drlg & Slide 4406' to 4480' ( 3290' TVD) ECDs = 11.0 Dir Drlg & Slide 4480' to 4712' ART 2.0 hrs . AST 0.5 hrs - Control drlg fl ECDs + LWD logs - ROP 120 fph High ECDs 11.17 - Circu & Condition hole t 0 lower ECDs - Recip & Rotate 120 RPMs to maximize hole cleaning - Start wi 11.22 - Fi na110.8 Dir Drlg & Slide 4712'to 4982' MD (3657' T VD) ART 4.5 hrs , AST 1.0 hrs Control drlg FI ECDs @ 75 fph - ECDs = 10.9 Dir Drlg & Slide 4982' - 5030' MD ( 3694' TV D) ART 0.9 hrs . AST 0.0 hrs Tool failure - No signal from pulsor - 650 extra SPP (pos sible plugged jet) Pump Sweep - Circu Hole clean TOH - No Swab - No Tight hole Broke connection on Top of Pulsor sub - Ha d a large amount of CMT debris setting on t op of pulsor from inside DP - Large pieces some 2"X4" & 3/8" thick. PJSM - Discuss plan to LID and clean Cmt fr om tools LID MWD & PWD - Brk Bit,guage and clean ( 1 plugged jèt) - SIB remaining BHA in derric k Move HWDP from Right to Left side of derric k TIH open ended with CMT affected 4" DP - 2 5 stds total (75 its) TOH LID CMT affected 4" DP Printed: 1/21/2002 10:27:43 AM ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ( Re: Distribution of Survey Data for Well 2P-448 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 754.53' MD 847.95' MD 0 . 00' M D (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) cl'õ¡~~i39' 30-Jan-02 RECEIVED Frp 0 1 I"'\nO2 _U ~ Cow ' Alaska, Oil & Gas Cons, Gormnission ,Anchorage -. 1'\ DEFINITIVE '. " a "~ Kuparuk River Unit North Slope, Alaska Kuparuk 2P, Slot 2P-448 2P-448 Job No. AKMM11214, Surveyed: 7 January, 2002 ( SURVEY REPORT 28 January, 2002 Your Ref: API 501032039600 Surface Coordinates: 5868858.45 N, 443542.95 E (70° 03' 08.4766" N, 1500 27' 06.4661" W) , Kelly Bushing: 252.50ft above Mean Sea Level ( ',- Survey Ref: svy9826 A Halliburton Company Sper1y-Sun Drilling Services . ~ Survey Report for 2P-448 Your Ref: AP/501032039600 Job No. AKMM11214, Surveyed: 7 January, 2002 , .. North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ( 754.53 8.910 248.210 500.53 753.03 8.13 S 29.15 W 5868850.53 N 443513.74 E 29.57 Tie On Point 847.95 8.900 253.240 592.82 845.32 12.90 S 42.79 W 5868845.86 N 443500.07 E 0.833 43.86 Window Point ~ 940.03 9.490 253.540 683.72 936.22 17.11 S 56.89 W 5868841.76 N 443485.94 E 0.643 58.29 "-' 1031.05 11.610 252.470 773.19 1025.69 21.99 S 72.82 W 5868837.00 N 443469.97 E 2.339 74.66 1128.76 13.640 253.720 868.54 1121.04 28.18 S 93.25 W 5868830.96 N 443449.49 E 2.096 95.63 1225.99 16.970 249.670 962.31 1214.81 36.33 S 117.57W 5868822.99 N 443425.11 E 3.595 120.93 1319.69 19.830 245.650 1051.21 1303.71 47.64 S 144.88 W 5868811.89 N 443397.72 E 3.338 150.36 1415.89 23.860 244.590 1140.49 1392.99 62.72 S 177.33 W 5868797.05 N 443365.16 E 4.209 186.10 1512.58 26.460 242.170 1228.00 1480.50 81.17S 214.05 W 5868778.87 N 443328.30 E 2.891 227.19 1609.22 29.990 240.680 1313.13 1565.63 103.068 254.17 W 5868757.28 N 443288.03 E 3.725 272.88 1705.65 32.750 240.150 1395.46 1647.96 127.858 297.81 W 5868732.81 N 443244.20 E 2.876 323.05 1801.23 36.350 239.880 1474.17 1726.67 154.94 S 344.75 W 5868706.07 N 443197.06 E 3.770 377.21 1898.66 40.340 240.270 1550.57 1803.07 185.088 397.13 W 5868676.32 N 443144.46 E 4.103 437.60 1992.45 43.480 240.100 1620.36 1872.86 216.22 S 451.48 W 5868645.58 N 443089.88 E 3.350 500.20 2088.66 47.740 240.610 1687.64 1940.14 250.21 S 511.22W 5868612.03 N 443029.89 E 4.444 568.90 2183.84 49.870 241.680 1750.33 2002.83 284.768 573.95 W 5868577.95 N 442966.91 E 2.392 640.51 ( 2280.71 52.930 241.800 1810.76 2063.26 320.60 8 640.62 W 5868542.60 N 442899.97 E 3.160 716.20 2375.32 56.540 240.740 1865.37 2117.87 357.748 708.34 W 5868505.97 N 442831.97 E 3.924 793.43 2473.44 55.370 240.650 1920.30 2172.80 397.53 8 779.24 W 5868466.70 N 442760.79 E 1.195 874.70 2568.31 58.060 241.210 1972.37 2224.87 436.06 8 848.55 W 5868428.69 N 442691.19 E 2.878 953.98 ........' 2663.56 58.830 240.690 2022.21 2274.71 475.478 919.51 W 5868389.81 N 442619.95 E 0.933 1035.13 2759.1 b 58.240 240.940 2072.08 2324.58 515.21 8 990.65 W 5868350.60 N 442548.51 E 0.657 1116.59 2856.40 57.810 240,020 2123.61 2376.11 555.88 8 1062.47 W 5868310.46 N 442476.39 E 0.916 1199.09 2933.34 57.680 240.380 2164.67 2417.17 588.21 8 1118.94 W 5868278.55 N 442419.69 E 0.430 1264.12 2996.56 57.550 238.660 2198.53 2451.03 615.29 S 1164.94 W 5868251.81 N 442373.48 E 2.307 1317.45 3093.16 57.210 238.490 2250.60 2503.10 657.71 8 1234.37 W 5868209.91 N 442303.74 E 0.382 1398.65 3188.79 58.140 239.780 2301.74 2554.24 699.168 1303.74 W 5868168.97 N 442234.07 E 1.498 1479.35 3284.76 58.790 242.230 2351.94 2604.44 738.80 8 1375.28 W 5868129.86 N 442162.24 E 2.279 1561.12 3380.69 59.900 243.230 2400.85 2653.35 776.61 8 1448.63 W 5868092.60 N 442088.61 E 1.464 1643.63 3475.36 58.960 243.100 2449.00 2701.50 813.40 S 1521.36 W 5868056.35 N 442015.60 E 1.000 1725.13 -.. """"""""""",,"""""""'-""------ --".--"..__.....",..,-,... ,.... " 28 January, 2002 ~ 15:02 Page 2 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for 2P-448 Your Ref: AP/501032039600 Job No. AKMM11214, Surveyed: 7 January, 2002 \ North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ( 3572.36 59.470 243.210 2498.65 2751.15 851.03 S 1595.71 W 5868019.27 N 441940.97 E 0.535 1808.45 3668.45 56.630 243.130 2549.49 2801.99 887.83 S 1668.46 W 5867983.01 N 441867.95 E 2.956 1889.96 ',-,". 3765.04 56.630 242.940 2602.62 2855.12 924.41 S 1740.36 W 5867946.97 N 441795.79 E 0.164 1970.62 3861.34 56.430 242.150 2655.73 2908.23 961.44 S 1811.64W 5867910.46 N 441724.23 E 0.715 2050.95 3957.19 57.330 242.540 2708.10 2960.60 998.70 S 1882.75 W 5867873.73 N 441652.85 E 0.999 2131.22 4053.01 57.600 242.490 2759.63 3012.13 1035.98 S 1954.41 W 5867836.98 N 441580.92 E 0.285 2212.00 4148.24 57.830 242.500 2810.50 3063.00 1073.16 S 2025.82 W 5867800.33 N 441509.23 E 0.242 2292.51 4244.63 57.890 242.690 2861.78 3114.28 1110.73 S 2098.28 W 5867763.30 N 441436.50 E 0.178 2374.13 4339.05 56.950 241.800 2912.62 3165.12 1147.78 S 2168.68 W 5867726.78 N 441365.82 E 1.274 2453.69 4432.90 56.270 242.540 2964.27 3216.77 1184.36 S 2237.98 W 5867690.71 N 441296.25 E 0.979 2532.05 4530.97 57.180 241.920 3018.08 3270.58 1222.56 S 2310.52 W 5867653.04 N 441223.43 E 1.068 2614.03 4626.06 55.980 241.410 3070.45 3322.95 1260.23 S 2380.38 W 5867615.90 N 441153.29 E 1.339 2693.40 4722.30 56.920 240.780 3123.64 3376.14 1299.00 S 2450.59 W 5867577.65 N 441082.80 E 1.119 2773.59 4817.66 58.010 240.710 3174.92 3427.42 1338.29 S 2520.73 W 5867538.88 N 441012.37 E 1.145 2853.96 4913.61 59.160 240.180 3224.93 3477.43 1378.68 S 2591.96 W 5867499.02 N 440940.84 E 1.288 2935.80 5009.69 58.970 239.820 3274.33 3526.83 1419.89S 2663.33 W 5867458.34 N 440869.17 E 0.377 3018.16 ( 5105.44 58.120 239.790 3324.29 3576.79 1460.97 S 2733.93 W 5867417.79 N 440798.27 E 0.888 3099.77 5201.56 57.660 241.690 3375.39 3627.89 1500.76 S 2804.95 W 5867378.52 N 440726.95 E 1.741 3181.15 5297.00 58.160 243.070 3426.09 3678.59 1538.24 S 2876.59 W 5867341.57 N 440655.04 E 1.332 3262.00 5393.01 57.820 243.440 3476.98 3729.48 1574.88 S 2949.29 W 5867305.4 7 N 440582.06 E 0.482 3343.40 '--' 5489.35 58.340 241.830 3527.92 3780.42 1612.47 S 3021.91 W 5867268.42 N 440509.17 E 1.518 3425.17 5584.28 58.190 242.550 3577.85 3830.35 1650.14 S 3093.32 W 5867231.29 N 440437.48 E 0.664 3505.90 5680.34 57.980 242.150 3628.64 3881.14 1687.98 S 3165.55 W 5867193.98 N 440364.98 E 0.416 3587.44 5777.21 57.620 241.990 3680.26 3932.76 1726.37 S 3237.97 W 5867156.13 N 440292.27 E 0.397 3669.41 5873.53 58.130 242.700 3731.48 3983.98 1764.23 S 3310.22 W 5867118.80 N 440219.74 E 0.819 3750.98 5969.03 57.180 242.100 3782.57 4035.07 1801.61 S 3381.72 W 5867081.96 N 440147.96 E 1.128 3831.66 6064.58 58.280 242.300 3833.59 4086.09 1839.29 S 3453.19 W 5867044.81 N 440076.22 E 1.165 3912.45 6160.47 58.710 242.810 3883.70 4136.20 1876.97 S 3525.74 W 5867007.67 N 440003.39 E 0.638 3994.21 6256.23 58.210 243.190 3933.79 4186.29 1914.02 S 3598.46 W 5866971.16 N 439930.40 E 0.622 4075.81 6352.95 57,570 242.800 3985.20 4237.70 1951.22 S 3671.45 W 5866934.50 N 439857.13 E 0.745 4157.73 ......,....,..... ",.. ""..,. ..' ",."-.,,,'- ."",-,"'" "-""",-",-"""",,,""""'--'-'--'-'--""---"'---- -------..,---,-,......,..'..-...." .,... ",. 28 January, 2002 .. 15:02 Page 3 of 5 DrillQuest 2.00.08.005 Sper1y-Sun Drilling Services . Survey Report for 2P-448 Your Ref: AP/501032039600 Job No. AKMM11214, Surveyed: 7 January, 2002 , , North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) .(ft) (0/100ft) ( 6448.56 58.050 243.370 4036.13 4288.63 1987.84 S 3743.60 W 5866898.41 N 439784.72 E 0.712 4238.63 6545.29 57.660 243.700 4087.60 4340.10 2024.34 S 3816.92 W 5866862.46 N 439711.13 E 0.496 4320.51 ~ 6640.81 59.360 243.300 4137.49 4389.99 2060.69 S 3889.81 W 5866826.65 N 439637.97 E 1.815 4401.93 6736.99 60.120 243.570 4185.96 4438.46 2097.84 S 3964.12W 5866790.05 N 439563.39 E 0.827 4484.99 6833.61 59.330 242.560 4234.67 4487.17 2135.63 S 4038.51 W 5866752.81 N 439488.72 E 1.218 4568.42 6929.48 59.740 243.260 4283.28 4535.78 2173.26 S 4112.07W 5866715.73 N 439414.88 E 0.761 4651.04 7025.94 57.910 241.930 4333.21 4585.71 2211.24 S 4185.34 W 5866678.30 N 439341.33 E 2.234 4733.57 7121.75 58.050 242.500 4384.01 4636.51 2249.10 S 4257.21 W 5866640.96 N 439269.19 E 0.525 4814.80 7217.98 58.320 242.200 4434.74 4687.24 2287.05 S 4329.64 W 5866603.55 N 439196.47 E 0.386 4896.57 7314.55 58.570 242.440 4485.28 4737.78 2325.28 S 4402.52 W 5866565.87 N 439123.32 E 0.334 4978.86 7410.48 57.350 242.070 4536.17 4788.67 2363.13 S 4474.48 W 5866528.55 N 439051.07 E 1.313 5060.18 7506.86 57.640 241.510 4587.96 4840.46 2401.56 S 4546.11 W 5866490.66 N 438979.16 E 0.575 5141.46 7602.59 56.780 240.860 4639.81 4892.31 2440.34 S 4616.62 W 5866452.40 N 438908.37 E 1.064 5221.92 7698.90 57.280 240.820 4692.22 4944.72 2479.71 S 4687.18 W 5866413.55 N 438837.52 E 0.520 5302.70 7794.75 57.680 241.370 4743.75 4996.25 2518.77 S 4757.93 W 5866375.01 N 438766.48 E 0.639 5383.50 7891.19 58.150 241.430 4794.97 5047.47 2557.89 S 4829.67 W 5866336.43 N 438694.45 E 0.490 5465.21 ( 7987.15 57.450 241.450 4846.11 5098.61 2596.71 S 4900.99 W 5866298.14 N 438622.85 E 0.730 5546.40 8082.87 57.970 241.420 4897.24 5149.74 2635.40 S 4972.06 W 5866259.98 N 438551.49 E 0.544 5627.31 8179.02 58.280 241.720 4948.01 5200.51 2674.27 S 5043.86 W 5866221.64 N 438479.40 E 0.417 5708.96 8260.50 58.860 242.220 4990.50 5243.00 2706.94 S 5105.23 W 5866189.42 N 438417.79 E 0.884 5778.48 ",-.. 8349.41 58.060 241.290 5037.01 5289.51 2742.80 S 5171.99 W 5866154.06 N 438350.78 E 1.267 5854.25 8370.65 58.090 241.640 5048.24 5300.74 2751.41 S 5187.82 W 5866145.57 N 438334.88 E 1.406 5872.28 8461.95 56.950 243.030 5097.27 5349.77 2787.17 S 5256.03 W 5866110.31 N 438266.40 E 1.791 5949.29 8564.03 57.460 242.640 5152.56 5405.06 2826.35 S 5332.37 W 5866071.70 N 438189.77 E 0.594 6035.10 8595.62 57.600 243.220 5169.52 5422.02 2838.48 S 5356.11 W 5866059.75 N 438165.95 E 1.611 6061.74 8663.00 57.600 243.220 5205.63 5458.13 2864.11 S 5406.89 W 5866034.49 N 438114.97 E 0.000 6118.63 Projected Survey ,."" .,.,....."""",.""", "....- "'..,..- -........... - -., ..--.....-- ,. -----..--..-.,.",.... 28 January, 2002 - 15:02 Page 4 of 5 DrillQuest 2.00.08.005 . Kuparuk River Unit , Sperry-Sun Drilling Services Survey Report for 2P-448 Your Ref: AP/501032039600 Job No. AKMM11214, Surveyed: 7 January, 2002 '. All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.3210 (28-Jan-02) l-,- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 242.1700 (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8663.00ft., The Bottom Hole Displacement is 6118.63ft., in the Direction of 242.089° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 754.53 847.95 8663.00 753.03 845.32 5458.13 8.13 S 12.90 S 2864.11 S "-- - - Survey tool program for 2P-448 From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 ...,..,0'" " 28 January, 2002 - 15:02 To Measured Vertical Depth Depth (ft) (ft) 8663.00 5458.13 29.15 W 42.79W 5406.89 W Tie On Point Window Point Projected Survey Survey Tool Description MWD Magnetic (2P-448PB1) , ,.",..-....-....",.--..-..-........._._m.."__.._'-'-- Page 5 of 5 . ' . North Slope, Alaska Kuparuk 2P i \ ( ..__.,-.." ...._'.... DrillQuest 2.00.08.005 { AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ,I' \( Re: Distribution of Survey Data for Well 2P-448PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~.,v, , '! "IJJN'.ÌfI" ~(11"~:1~~""" ~~,:~' -', ":Ir:"c¡"~'" "r'" "',':",'¡~,',',',""'I"',',,,,",l,-,' \""", ì',','I'II',< ""," '_"" ,',;+,-",::"" ,~I_:,:- ' , - 30-Jan-02 RECEIVED FFB 0 1 2002 A!aska Oil 8: Gas Cons, Commission Anchorage " r' ._, " . ~ " DEFINITIVE '~"'- Kuparuk River Unit North Slope, Alaska Kuparuk 2P, Slot 2P-448 2P-448PB 1 Job No. AKMM11214, Surveyed: 23 December, 2001 f SURVEY REPORT 28 January, 2002 Your Ref: AP/501032039670 Surface Coordinates: 5868858.45 N, 443542.95 E (70003' 08.47668 N, 150027' 06.46618 W) Kelly Bushing: 252.50ft above Mean Sea Level ( .......",. 5pe""""y-sul! tJFUL..LINd SERVices A Halliburton Company SLlrvey Ref: svy9825 ,," . Sperry-Sun Drilling Services Survey Report for 2P-448PB1 ! Your Ref: AP/501032039670 . Job No. AKMM11214, Surveyed: 23 December, 2001 '. North Slope, Alaska Kuparuk River Unit Kuparuk 2P Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) ( 0.00 0.000 0.000 -252.50 0.00 0.00 N 0.00 E 5868858.45 N 443542.95 E 0.00 MWD Magnetic 206.12 0.340 265.000 -46.38 206.12 0.05S 0.61 W 5868858.40 N 443542.34 E 0.165 0.56 .....- 293.05 0.440 307.090 40.55 293.05 0.13 N 1.13W 5868858.58 N 443541.82 E 0.340 0.94 383.61 0.650 290.100 131.10 383.60 0.51 N 1.89W 5868858.98 N 443541.06 E 0.290 1.43 476.73 1.810 268.800 224.20 476.70 0.66 N 3.86W 5868859.14 N 443539.10 E 1.318 3.10 569.81 4.570 254.050 317.13 569.63 0.39 S 8.89W 5868858.13 N 443534.05 E 3.069 8.05 661.88 6.750 247.960 408.74 661.24 3.43 S 17.44 W 5868855.15 N 443525.49 E 2.453 17.02 754.53 8.910 248.210 500.53 753.03 8.13 S 29.15 W 5868850.53 N 443513.74 E 2.332 29.57 847.98 10.560 247.910 592.63 845.13 14.04 S 43.80 W 5868844.73 N 443499.04 E 1.766 45.29 939.70 13.640 244.420 682.30 934.80 21.87 S 61.35 W 5868837.03 N 443481.44 E 3.450 64.47 1032.70 15.930 243.160 772.21 1024.71 32.37 S 82.63 W 5868826.69 N 443460.08 E 2.486 88.19 1124.50 18.410 245.340 859.92 1112.42 44.11 S 107.05 W 5868815.14 N 443435.58 E 2.791 115.26 1217.27 20.600 240.150 947.36 1199.86 58.35 S 134.52 W 5868801.10 N 443408.00 E 3.008 146.20 1313.32 22.410 241.340 1036.72 1289.22 75.54 S 165.25 W 5868784.14 N 443377.15 E 1.938 181.40 1408.92 25.520 242.160 1124.07 1376.57 93.90 S 199.46 W 5868766.03 N 443342.80 E 3.272 220.22 1504.09 28.290 244.240 1208.94 1461.44 113.28 S 237.90 W 5868746.94 N 443304.21 E 3.074 263.27 ( 1601.56 31.250 243.860 1293.53 1546.03 134.46 S 281.41 W 5868726.08 N 443260.55 E 3.043 311.64 1696.60 33.280 243.210 1373.89 1626.39 157.08 S 326.82 W 5868703.80 N 443214.97 E 2.167 362.35 1792.83 35.640 239.730 1453.24 1705.74 183.12 S 374.62 W 5868678.11 N 443166.99 E 3.193 416.78 1889.32 38.130 240.590 1530.41 1782.91 211.92 S 424.86 W 5868649.68 N 443116.54 E 2.635 474.65 '-.' 1985.05 40.550 242.410 1604.44 1856.94 240.85 S 478.19 W 5868621.15 N 443062.99 E 2.800 535.32 2040.00 40.550 242.410 1646.20 1898.70 257.40 S 509.85 W 5868604.84 N 443031.21 E 0.000 571.04 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 25.352° (23-Dec-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 242.170° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 2040.00ft., ..,.. '" "', .. ,--, ",-"-,--,,,--'----------'--"'-""--' ",---,-,............_--",."",. 28 January, 2002 - 15: 11 Page 2 of 3 Dril/Qup.st 2.00.08.005 I Sperry-Sun Drilling Services Survey Report for 2P-448PB1 Your Ref: API 501032039670 Job No. AKMM11214, Surveyed: 23 December, 2001 . .. ! '. Kuparuk River Unit North Slope, Alaska Kuparuk 2P The Bottom Hole Displacement is 571.14ft., in the Direction of 243.2130 (True). Comments ( \..- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 2040.00 1898.70 257.40 S 509.85 W Projected Survey Survey tool program for 2P-448PB1 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 0.00 2040.00 1898.70 MWD Magnetic ( 'I' '"-" -......." """...-..---......--..,--, ,-_._-,.._, --.. ... 28 January, 2002 - 15:11 Page 3 of 3 DrillQues t 2.00.08.005 (" -,j \ WC¡A, ì'~{OL- I)V:J a I jJô(ú è PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage,AJaska 9951~60 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 January 8, 2002 Ms. Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 2P-448 Application for Sundry Approval (APD 201-229) Dear Commissioner: Phillips Alaska, Inc. hereby files this Application for Sundry Approval to P&A the current Meltwater well 2P-448. If you have any questions regarding this matter, please contact Pat Reilly at 265-6048. Sin~ely, C ~~jJ~ C. R. Mall~ - () Drilling Engineering Supervisor P AI Drilling CRM/skad RECEIVED JAN 0 9 2002 Alaska Oil & Gas Cons '. AnChorage CommIssIon ORIGINAL ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS J't't (.-t Iiol D Z" ð)}j oJ/laiC) 'è A- \/,,-cn 1. Type of request: Abandon _X Suspend- Alter casing - Repair well- Change approved program - 2. Name of Operator Philli s Alaska, Inc. 3. Address P. O. Box 100360 Anchora e, AK 99510-0360 4. Location of well at surface 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 1715' FSL, 1576' FWL, Sec. 18, T8N, R7E, UM At effective depth At total depth 1531' FSL, 1230' FWL, Sec. 18, T8N, R7E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 120' 2946' Casing Conductor Surface Production Perforation depth: measured true vertical Tubing {size, grade, and measured depth Packers & SSSV (type & measured depth) 8663 5458 8663 5458 Size 16" 7.625" No Perforations No Perforations No Tubing Run No Packers or SSSV"s 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation January 8, 2002 16. If proposal was verbally approved Operational shutdown - Plugging! Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (asp's: 443543, 5868858) (as proposed) feet feet Plugs (measured) feet feet Cemented Junk (measured) 9 cu. Yds High Early 391 sx AS Lite, 202 sx LiteCrete Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 254 feet AMSL 7. Unit or Property name Other - Kuparuk River Unit 8. Well number 2P-448 9. Permit number / approval number 201-229 10. API number 50-103-20396-00 11. Field / Pool Kuparuk River Field/Meltwater Oil Pool Measured Depth 120' 2976' True vertical Depth 120' 2440' RECEIVED JAN 0 9 2002 Alaska Oil & Gas Cons. Commission Anchorage Detailed operations program - 15. Status of well classification as: Oil- Name of approver Date approved Service - 17. I hereby certify that the foregoing i rue and correct to the best of my knowledge. Signed C ~ C.Malla FOR COMMISSION USE ONLY Conditions of approval: Notify Comm sion so representative may witness . Plug integrity - BOP Test - Location clearance - I I "1 Mechanical Integrity Test - Subsequent form required 10- ....,. 0 . Approved by order of the Commission Form 1 0-403 Rev 06/15/88 . Title: Drilling Engineering Supervisor ORIGINAL Schematic - Gas- Suspended - Questions? Call Pat Reilly 265-6048 g ~ :2<;;02 Commissioner SUBMIT IN TRIPLICATE ( ( Calculations Charj Subject "'^ 111 f"l, í W~12. File 2 {J- 4 t.{ c¡ FLU 6r ßA vI<- By Sheet number I of I Date ( mD TVD 38001 TOP i (000' 1< \ c... K ðF~ PLUG, (-< 0 (P L/ 0& 0 I '-/1 tj ö'ô ' ßO;.TOM.", l' ¥ 00 100', ~'. H ",I, ~f+ \It> Pt L L. ( ( ( fD ~rolo ~ 5/i 59 I O-L. PRINTING (907) 563-4743 159.5881 (' ( 2P-448 Plug Back Procedure (balanced plug) Calculations assume 7.25" hole 1. Contact inspector to witness job. 2. PU 636' of 2 7/8" tubing to use as cement stinger. 3. RIH with stinger and DP to planned bottom of high vis pill 4800'. 4. CBU Pump High Vis Pill 5. Pump 5 bbl fresh water spacer. 6. Pump 20.4 bbl (400') high vis pill. (fresh water aqua gel 25 Ib/bbl weighted to 10 ppg) 7. Pump 0.64 bbl fresh water to balance plug. Plug # 1 (Kick Off Plug) 8. POOH to planned bottom of plug #1 (kick off plug) 4400'. 9. Pump 10 bbl fresh water spacer. ./ 10. Pump plug # 1,30.7 bbl cement as per design below. 11. Pump 2.9 bbls fresh water to balance plug. 12. Pull stinger and DP out of plug to 500' above planned top of plug 3300' no faster than 1 stand I 3 minutes while pulling out of cement. 13. Circulate up spacers and contaminated mudlcement. 14. POOH to PU side track BHA. 15. CONFIRM COMPRESSIVE STRENGTH DEVELOPMENT WITH lAB BEFORE DRilliNG ON PLUG. 16. IF PLUG IS NOT FIRM AFTER DRilLING 200', STOP DRilliNG, PUll UP AND CIRCULATE. CAll DRilLING ENGINEER. Meltwater 2P-448 Plug Back Requirements Cement Plug #1 (Kick-Off Plug) : 3800' MD to 4400' MD = 600'. Cement with Class G + additives @ 17 ppg. Assume 150/0 excess on open hole volume. 2P-448 Plug Back Verbal approval ( { Subject: 2P-448 Plug Back Verbal approval Date: Mon, 7 Jan 2002 18:34:09 -0900 From: "Patrick Reilly" <preilly@ppco.com> To: winton_Aubert@admin.state.ak.us CC: tom - maunder@admin.state.ak.us, Jane - williamson@admin.state.ak.us Winton, Thank you for Per our phone kick off plug hydrocarbons. plug. Thanks, Pat Reilly Phillips Alaska (907) 265-6048 (907) 244-5558 (907) 265-1535 preilly@ppco.com 1 of 1 the verbal approval to proceed with the 2P-448 plug back. conversation, we will plug back the original 2P-448 with a for a sidetrack. 2P-448 had no log indications of I will fax a sketch of the planned plug back and kick off Drilling & Wells WORK CELLULAR FAX 1/9/2002 10:36 AM ( ~ 2P-448 Plug Back Procedure (balanced plug) Calculations assume 7.25" hole 1. Contact inspector to witness job. 2. PU 636' of 2 7/8" tubing to use as cement stinger. 3. RIH with stinger and DP to planned bottom of high vis pill 4800'. 4. CBU Pump High Vis Pill 5. Pump 5 bbl fresh water spacer. 6. Pump 20.4 bbl (400') high vis pill. (fresh water aqua gel 25 Ib/bbl weighted to 10 ppg) 7. Pump 0.64 bbl fresh water to balance plug. Plug # 1 (Kick Off Plug) 8. POOH to planned bottom of plug #1 (kick off plug) 4400'. 9. Pump 10 bbl fresh water spacer. 10. Pump plug # 1, 30.7 bbl cement as per design below. 11. Pump 2.9 bbls fresh water to balance plug. 12. Pull stinger and DP out of plug to 500' above planned top of plug 3300' no faster than 1 stand I 3 minutes while pulling out of cement. 13. Circulate up spacers and contaminated mudlcement. 14. POOH to PU side track BHA. 15. CONFIRM COMPRESSIVE STRENGTH DEVELOPMENT WITH lAB BEFORE DRilLING ON PLUG. 16. IF PLUG IS NOT FIRM AFTER DRilLING 200', STOP DRilLING, PUll UP AND CIRCULATE. CAll DRilLING ENGINEER. Meltwater 2P-448 Plug Back Requirements Cement Plug #1 (Kick-Off Plug) : 3800' MD to 4400' MD = 600'. Cement with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. ~DI-~a '1 2P-448 Plug Back and Sidetrack ( ( Subject: 2P-448 Plug Back and Sidetrack Date: Thu, 27 Dec 2001 11 :47:16 -0900 From: "Thomas A Brockway" <tbrockw@ppco.com> To: winton - aubert@admin.state.ale us CC: "Charles R Mallary" <crmalla@ppco.com>, "Patrick Reilly" <preilly@ppco.com> Winton, As per our conversation of 12/27/01, this e-mail is to notify you of upcoming sidetrack of the surface hole on well 2P-448 in the Kuparuk (KRU). This sidetrack was required after losing the drilling BRA in hole at 1646' MD. Approximately 3 days were spent unsuccessfully attempting to retrieve the fish. This fish does not contain radioactive sources. Current plans call for laying two balanced cement plugs above the fish, kicking off of the plug using a steerable motor assembly, and drilling to surface casing TD as outlined in the original approved permit to drill (APD #201-229). No changes from the original permit are planed in regards to surface casing point of well target. the River the Attached is a plug setting procedure and schematic. If you have any questions or require further information, please contact feel free to contact myself or Chuck Mallary, KRU Drilling Engineering Supervisor. Tom Brockway Lead Drilling Engineer Phillips Alaska, Inc. Ph: (907) 263-4135 Cell: (907) 244-5956 Fax: (907) 265-1535 (See attached file: 2P-448 Well Plan Addendum #2 (Plug and ST) 12-26-01.doc) ~ ' ~ ~ ~ w - :..... -::::::=::::::-- ~ - - - - - w - ~ - - ' - ~ ; :::: =- :::: ::::;;:::=-. ,,;:::::- .:: ::: :: = == .::. -:: .::::.::: ::::::; \',",WM_W Name: 2P-448 Well Plan Addendum #2 (Plug and j!32P-448 Well Plan Addendum #2 (Plug and ST) 12-26-01.doc¡ Type: ~{,}~¿;f/F~~C ; (applicationlmsword) , Encoding: base64 10fl 12/27/01 12:27 PM ' PHILLIPS Å__ska, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY ¡,'I; Drill and C~...plete Addendum #2 Meltwater 2P-448 3-1/2" Slim Hole Producer AFC: #AKO215 Prepared By: Drilling Engineer Thomas A. Brockway Approved By: Drilling Engineering Supervisor Chuck Mallary Approved By: Drilling Team Leader Randy Thomas nistr¡b, Iti().,: Well File Doyon 141 Drilling Foremen Morrison / Overstreet Tom Brockway Pat Reilly Randy Thomas Chuck Mallary Lamont Frazer Steve Moothart Ryan Stramp Aras Worthington Brad Gathman Ronda Wenger Dan Therry Tom Jones Stuart Sutherland Owen Hnatiuk Keith Lynch . Currier/Koosman Brian Duwe Baker Kevin Tanner Dowell Kevin Hite FMC Corporation Dave Higbie Baroid Satellite Prod. Engr. 1 copies + fax 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy 1 copy Baker Inteq Baker Inteq Baker Inteq Date Date Date Original NSK-33/ 3163 NSK -12 ATO-1586 ATO-1502 ATO-1576 ATO-1596 ATO-1154 ATO-1292 E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail E-mail PHILLIPS A 3ka, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY Df ~nd Complete Addendum #2 Meltwater #2P-448 3-1/2" Slim Hole Producer AFC: #AKO215 ** The following changes should be incorporated into the approved wellplan for Meltwater 2P-448 * * Procedure for Surface Hole Plug Back and Sidetrack 1. RIH with clean out BHA to just above top of fish. Circulate and condition hole until mud properties return to the ranges specified in the 2P-448 well plan. POOH. 2. RIH with 5" DP with a 300' 4" HT38 stinger to +/- 1234' MD (top of fish at 1264' MD). Circulate and condition hole. 3. Lay 250' balanced cement plug from 1260' MD to +/- 1010' MD. 4. POOH 3 stands to +/- 740' MD. Circulate out excess cement and contaminated mud. Wait +/- 2 hrs for plug to set up. Ease slowly back into hole and tag top of plug. Determine amount of excess needed for second plug based on calculated vs actual TOC. Circulate and condition for second plug. 5. Lay 250' balanced cement plug from +/- 1010' MD to +/- 760' MD. 6. POOH 3 stands to +/- 490' MD. Circulate out excess cement and contaminated mud. 7. Finish POOH and stand back 5" DP 8. PU kickoff BHA, RIH, tag cement, and dress plug to +/- 790'. . Note: an estimated minimum of hours of WOC time (actual WOC time to be determined based on results of Dowell lab testing) will be required before dressing the plug in order for the cement to obtain sufficient compressive strength. . Rabbit and rattle pipe before running back in hole to help minimize the possibility of cement falling into the MWD and motor. Run Drill pipe screens if available. . 6-3/4" jars will be used in this hole section. 9. Kick off as per revised Inteq directional plan. Time drill as necessary to get off of plug. . Pre-treat mud system as necessary to help minimize any cement contamination effects. . Run gyro surveys as needed until magnetic interference from the fish is no longer seen on MWD survey tools 10. Drill to TD, case and cement as per 2P-248 well plan. 1. TAB 2P-448 Well Plan Addendum #2 12/26/01 Page 2 of 3 PHILLIPS Ai: 3ka, Inc. A Subsidiary of PHilLIPS PETROLEUM COMPANY l Dt ~nd Complete Addendum #2 Meltwater #2P-448 3-1/2" Slim Hole Producer AFC: #AKO215 16" 62.6# @ +/-120' MD Depths are based on Doyon 141 RKB 9-7/8" Open Hole Meltwater 2P-448 Proposed Sidetrack Plug 250' Balanced Plug 1010' - 760' MD 106 bbls 17.0 ppg Class G 250' Balanced Plug 1260' - 1010' MD 106 bbls 17.0 ppg Class G Top of Fish - 1264' MD 9.6 ppg Drilling Mud Base of Fish - 1646' MD Original Hole TD @ 2041' MD /1898' TVD TAB Page 3 of 3 2P-448 Well Plan Addendum #2 12/26/01 I ~~!Æ1fŒ ffi)~ !Æ~~~[(!Æ / ~ TONY KNOWLES, GOVERNOR ALAS IiA 0 IL Alft) GAS CONSERVATI ON COMMISSION 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Chuck Mallary Drilling Engineering Supervisor . Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Kuparuk River Unit 2P-448 Phillips Alaska, Inc. Pennit No: 201-229 Sur Loc: 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM Btmhole Loc. 1531' FSL, 1230' FWL, Sec. 18, T8N, R7E, UM Dear Mr. Mallary: Enclosed is the approved application for pennit to drill the above referenced well. The pennit 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. Annular disposal has not been requested as part of the Pennit to Drill application for Kuparuk River Unit 2P-448. 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 Kuparuk River Unit 2P must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, & rf),..LoL: ~ C~echsli Taylor Chair BY ORDER OF THE COMMISSION DATED this 4th day of December, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work: Drill b!.J Redrill U Re-entry 0 Deepen 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. location of well at surface 1022' FNL, 1583' FWL, Sec. 17, T8N, R7E, UM At top of productive interval 1715' FSL, 1576' FWL, Sec. 18, T8N, R7E, UM At total depth 1531' FSL, 1230' FWL, Sec. 18, T8N, R7E, UM 12. Distance to nearest property line 13. Distance to nearest well 1230' @ TD feet 2P-438 198' @ 487.5 16. To be completed for deviated wells Kickoff depth: 400 MD 18. Casing program size Hole 42" CaslnQ 16" 9.625" 7.625" 6.75" 5.5" 3.5" 6.75" 1b. Type of well. Exploratory U Stratigraphic Test U Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB = 254 feet AMSL 6. Property Designation ADL 373112 ALK 4998 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 2P-448 #59-52-180 9. Approximate spud date Amount December 4, 2001 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8324' MD / 5291 ' TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 1814 psig At total depth (TVD) 2385 psig Setting Depth ( STATE OF ALASKA ~- ALASKA Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 feet Maximum hole angle 58 WelQht 62.5# 29.7# 15.5# 9.3# SpecUications Grade CouplinQ H-40 Weld L-80 BTCM L-80 BTCM L-80 EUE 8rd M Top Bottom TVD 110' 2452' 4991' 5291' lençrth 80' 2970' 7731' 563' MD 30' 30' 30' 7761' TVD 30' 30' 30' 4991' MD 110' 3000' 7761' 8324' Total Depth: 19. To be completed for Redrili, Re-entry, and Deepen Operations. Present well condition summary Plugs (measured) Effective Depth: Casing Conductor Surface 0 Perforation depth: measured true vertical feet feet pi tf ¡ "lAIA IV! Development Oil b!.J Multiple Zone 0 10. Field and Pool Kuparuk River Field Meltwater Oil Pool Quantity of Cement (include staQe data) 9 cu yds High Early 330 sx AS III L & 210 sx LiteCRETE 220 sx Class G see above True Vertical depth Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 0 Drilling program 0 0 Time vs depth plot DRefraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 egoing is true;;dyrJct to the best of my kn.owledge QuestIons? Call Pat ;e¡~Jy/~~6!1 -vvV~..", ./ Title: Drilling Engineering SupeNisor Date I' 0/ 7/ C1 ~ - hv" AII.C:/ln-Dr::Jla:. /' I Commission Use Onl\ permitNUmb~/j"~"r \,~.I- 'Ji.,,'_'2C-1i APlntfnbJr, '?""",-;::lCJ/, he APP,_rOVé)Is!..atÞJil ~ ~ / 50-V/D3-L.C~.J-",L:--,-£.....1) . I~J,/OJ Conditions of approval Samples required 0 Yes ŒI No Mud log required Hydrogen sulfide measures 0 Yes ~ No Directional survey required 1&1 Yes Required working pressure for BOPE D2M; 0 3M; 1[1 5M; 0 10M; 0 0 Other: 20. Attachments Drilling fluid program 21, I hereby COVal the Signed C. Mallary Approved by measured true vertical Junk (measured) feet feet length Cemented Measured depth Size IR,tGEI\/E[) ," ~ ':') 2.001 measured 1¡~,.I~~("~n", flH §I, Gas Cf.ms, Cûmrniss¡on ..¡ ,,\...,.\.(;1 '. iI ...... l\nchorage true vertical Original Signed By - -, ,. by order of the commission Commissioner Form 10-401 Rev. 12/1/85' . ~ ".'" r r ~~ I' I ~~ I ~ 1-11. See cover letter for other requirements 0 Yes I8J No 0 No Date I d /4/ t) I . I . Submit in triplicate ,.,.- ( APPI( - ';on for Permit to Drill, Well 2P-448 . Saved: 4-Dec-O1 Permit It' Meltwater 2P- 448 Application for Permit to Drill Document MoximizE Well VahlE Table of Contents 1. Well Name............. ......... ............ ... .............. ........... ........ .............. ..... ........................3 Requirements of 20 AAC 25.005 (f)........................................................................................................3 2. Location Su m mary ........... ....... ...... ...... ............... ......................... ............ .................3 Requirements of 20 AAC 25.005(c)(2) ...................................................................................................3 Requirements of 20 AAC 25.050(b)........................................................................................................3 3. Blowout Prevention Equipment Information ......................................................... 4 Requirements of 20 AAC 25.005(c)(3) ..,................................................................................................4 4. Dri II i ng Hazards Information.. ........ ...... ................... ................................................4 Requirements of 20 AAC 25.005 (c)(4) .................................................................................................. 4 5. Procedure for Conducting Formation Integrity Tests ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) ""......".""""""........."..........."........................""....".........."'" 4 6. Casing and Cementing Program ............................................................ .................4 Requirements of 20 AAC 25.005(c)(6) .""".".""""""""""'.."""""""""."""""'.""."."."""""""""'.'" 4 7. Diverter System Information.. ........ ......... ........ .................. ........ ... ....... ....................5 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 5 8. Dri II i ng FI u id Program..... ... ...... ... ........... .................................... ...................... ... ..... 5 Requirements of 20 AAC 25. 005(c)(B) .... ........."................ ..."............................................................... 5 9. Abnormally Pressured Formation Information ......................................................6 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 6 10. Seism ic Analysis................ ......... ............................................... ................ ......... ..... 6 Requirements of 20 AAC 25.005 (c)(1 0) ................................................................................................ 6 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 6 12. Evidence of Bond i ng ....................... ............................................ ................ ....... ..... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................6 ORIGINAL 2P-448 PERM/T /T 11-29-01.doc Page 1 of 7 Printed: 4-Dec-O1 ( APpr +ion for Permit to Drill, Well 2P-448 Saved: 4-Dec-O1 13. Proposed Dri II i ng Program... ..... ............. ...... ...... ..... ....... ........ ... .............. ... .......... ... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attachments. .......... ...... ........ ................................................... ..................... ............ 7 Attachment 1 AOGCC Form 10-401 (Front of permit package) ............................................................7 Attachment 2 Directional Plan ...............................................................................................................7 Attachment 3 Drilling Hazards Summary...............................................................................................7 Attachment 4 Well Schematic....... ................................................................................................ ......... 7 Attachment 5 Cement Details ........................................................................................... ..................... 7 ORIGINAL 2P-448 PERMIT IT 11-29-01.doc Page 2 of 7 Printed: 4-Dec-O1 ( AP~;: tion for Permit to Drill, We1l2P-448 Saved: 4-Dec-O1 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique APJnumber assigned by the comml:5sion under 20 AAC 25.040(b). For a well with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 2P-448. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a PermIt to Drill must be accompanied by each of tl7e following Jtem.~ except fvr an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property'!> owners and s170wing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective f'Ormation and at total depth referenced to governmental section lines. (B) the coordinates of the proposed 10(;'atiol7 of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth ot the well at the top of each objective formation and at total depth; Location at Suñace I 1022' FNL, 1583' FWL, Sec 17, T8N, R7E, UM NGS Coordinates RKB Elevation: 254.0 ft AMSL Northings: 5868858.49 Eastings: 443542.95 Pad Elevation: 224.0 ft AMSL Location at Top of Productive Interval Bermuda Formation NGS Coordinates Northings: 5866352.21 1715' FSL, 1576' FWL, Sec 18, T8N, R7E, UM Eastings: 438706.55 7861' 4792' 5044' Location at Total De th NGS Coordinates Northmg~ 5866171 Easäng~ 438359 and (D) other lì7fo/mation required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well it; to be intentionally deviate4 the application for a Permit to Drill (Form .10-4D.1) must (1) inäude a plat, drawn tv a suitable 8cô/e, showing the path of the proposed wellbore, including all adjacent wellbores witt7in 200 feet of any portiof} of the propœ;ed well; Please see Attachment 2: Directional Plan and (2) for all wells wIthin 200 fiDet of the proposed wellbore (A) /íst the names of the operators of those well~ to th(:; extent that those names are known or discoverable in publIc record9, and show that each named operator has been fumi.:;hed a copy of the applit.:è-1tion by certified mai~' or (8) state that the applicant l'i the only alfected owner. The Applicant is the only affected owner. ORIGINAL 2P-448 PERMIT IT 11-29-01,doc Page 3 of 7 Printed: 4-Dec-O1 ( APP( -ion for Permit to Drill, Well 2P-448 Saved: 4-Dec-O1 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a PermIt to 01711 must be accompanied by each of the following Item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25. 03~ 20 AAC 25. 03~ or 20 AAC 25. 037., as applicable; Please refer to Doyon Rig 141 BOP Schematic currently on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to Onll must be accompanied by each of the following Item~ except for an Item already on file with the commission and identIfied in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encounterect criteria used to determlÌ7e it; and maximum potential surt~1Ce pressure based on a methane gradient; The expected reservoir pressures in the Bermuda sands in the 2P pad area vary from 0.44 to 0.46 psijft, or 8.5 to 8.9 ppg EMW (equivalent mud weight). These are pressures obtained from drilling and testing operations on the nearby exploration wells, Meltwater North #1 and Meltwater North #2/2A. The maximum potential surface pressure (MPSP) based on the the above maximum pressure gradient, a methane gradient (0.11) and the vertical depth of the expected base of the Bermuda formation is: MPSP =(5184 ft)(0.46 - 0.11 psi/ft) =1814 psi Assuming a leak off of 15.9 ppg (0.83 psijft) based on open hole LOT results from offset Meltwater exploration wells, formation breakdown at the surface casing shoe (2452' TVD) can be expected to occur at 2035 psi. Therefore, the MPSP may be based on the maximum pressure gradient as calculated above. (8) data on potential gas zones; No potential gas zones have been identified along the planned well path. and (C) data Gvnceming potential causes of hole problems such a!-i abnormally geo-pres..,,"ured stratal lo!-it circulation zones~ and zones that have a propensity ('Or differential stìc:'king; Please see Attachment 3: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commi.';sion and identified in the application: (5) a description of the procedure for conduclli7g ('Ormation intcYJnty test:'i¡ as required under 20 AAC 25,030(f); A formation integrity test will be performed after drilling out below surface in accordance with the Phillips Alaska LOT / FIT procedure, currently on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An appkcation for a PermIt to Dlill must be accompanied by each of'the following Itern'i¡ except for an item already on tlle with the commission and identified in the application: (6) a complete proposed casli7g and cementli7g program as required by 20 AAC 25,03°1 and a description of any slotted lliìer, pre.. perforated liner, or screen to be ¡¡7stalled; ORIGINAL 2P-448 PERMIT IT 11-29-01.doc Page 4 of 7 Printed: 4-Dec-O1 ( AP~'; -tion for Permit to Drill, Well 2P-448 Saved: 4-Dec-O1 Casing and Cementing Program Hole Top Btm CsglTbg Size Weight Length MD/TVD MD/TVD 00 (in) (in) (lb/ft) Grade Connection (ft) (ft) (ft) Cement Pro,qram 30 X 16 42 62.5 H-40 Welded 80 30 / 30 110/ 110 9 cy High Insulated Early 7-5/8 9-7/8 29.7 L-80 BTC,AB 2970 30 / 30 3000 / 2452 330 sx 10.7 Modified ppg AS3 Lead, 210 sx 12.0 ppg LiteCrete Tail Planned Top of Cement: Surface 51/2 6-3/4 15.5 L-80 BTC,AB 7731 30 / 30 7761/4991 220 sx 15.8 Modified ppg Class 'G' 3-1/2 6-3/4 9.3 L-80 EUE, 8rd 563 7761/4991 8324/5291 Planned Top of Mod Cement: 7261' MD 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dnll must be accompanied by each of me following item~ exœpt for an item already on file with the commis..c,io(1 and identified in the application: (7) a diagram and de!iCTiption of the diverter system as required by 20 AAC 25", 035; unle::,-s this requirement is waived by the commis.."io(1 under 20 AAC .15,035(11)(2),' Please refer Doyon Rig 141 Diverter Schematic currently on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An tJpplication tor a Permit to Drill must be accompanied by each of the following item~ exœpt for an item already on tìle with the commi.t;:;,"Í()n and Identified Ii? the application: (8) a drilling flllId program, including a diagram and description of the dnl/ing flUId !:'ystern as required by 20 MC 25, 03~' Water based drilling fluid systems will be utilized to drill this well from spud to TD. These systems will be built and maintained to the following specifications: 1 vJ6A \2-,~lo ( Spud to ;-5/8" Drill Out to Top Bermuda Surface CasinQ Too Bermuda To Well TD Initial Value Final Value Initial Value Final Value Initial Value Final Value Density (ppg) 9.6 9.8 9.4 9.8 9.8 9.8 Funnel Viscosity 80 100 50 65 50 65 (seconds) Yield Point 35 45 10 25 20 30 (cP) Plastic Viscostiy 13 21 6 14 6 14 (lb/100 sf) 10 second Gel 10 15 2 6 4 7 Strength (lb/100 sf) 10 minute Gel 15 40 4 8 4 8 Strength (lb/100 sf) pH 9.5-10 9.5-10 9.0-9.5 9.0-9.5 7.5-8.5 7.5-8.5 API Filtrate(cc) <15 <15 <6 <6 8-10 8-10 ORIGINAL 2P-448 PERMIT IT 11-29-01.doc Page 5 of 7 Printed: 4-Dec-01 ( AP~" 'tion for Permit to Drill, Well 2P-448 Saved: 4-Dec-O1 Please refer to Doyon Rig 141 Fluid System Components currently on file with the Commission. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a PermIt to Dnll must be accompanied by each of the following Items¡ except for an Item already 0/7 file with the comm~,;sion and identified in the application: (9) for an exploratory or stratigraphic test we/~ a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f),' Not applicable: Application is not for an exploratory of stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a PermIt to Dnll must be accompanied by each of the following items¡ exctyJt for an item already on file with the comm~,;sion and identified in the application: (10) for an exploratory or stratigraphic test wel¿ a ::.-eismic refraction or reflection analy.ti~'; as required by 20 AAC 25. 061 (a),' Not applicable: Application is not for an exploratory of stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application fvr a Permit tv Drill must be accompanied by each of the following liem5~ except for an item already on file with the commission and identIfied in the application: (.l1) for a well drilled tram an offshore pfatform/ mob/Je bottom-founded structure/ jack-up 119/ or floating drilling vesse¿ an analysis of seabed condItions as required by 20 MC 25,O61(b)/' Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fvr a Permit tv Dnll must be accompanied by each of ti7e following liems~ exŒpt' tÓr an item already on file with the commis.."ion and identitìed in the application: (12) evidence S770Wli7g that the requirements ot20 AAC 25. 025 {Bonding}have been mel~' Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application (or a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 4: Well Schematic: 1. Excavate cellar, install cellar box, set and cement 16" x 30" insulated conductor to +1- 110' RKB. Weld landing ring on conductor. 2. Move in I rig up Doyon 141. Install diverter & function~ test sFJme. q - '1/g¡u J ~q,\ I2..NIO' 3. Spud and directionally drill ~' hole to ~-5/8" surface casing point (+1- 3000 MD') according to directional plan. Run MWD I LWD logging tools in drill string for directional monitoring and formation data gathering. , {)~/b,;e-C..hr..~"¿:.1 .Á ð .1 1-Cf.í wGt\ u./tJfó( 4. Run and cement .,-5/8" -~ L-80 BTCM casing to surface using ArcticSet 3 lead slurry and LiteCrete tail to assure cement returns to the surface. Adequate tail cement will be pumped to ensure cement reaches the surface. Displace cement with mud. 00 'v---iGA ldq/o( 5. Nipple down diverter and install wellhead. Nipple up BOPE and test to~ ps~ Record results. 6. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes. Record results. ORIGINAL 2P-448 PERMIT IT 11-29-01.doc Page 6 of 7 Printed: 4-Dec-O1 (" APPt ";on for Permit to Drill, Well 2P-448 Saved: 4-Dec-O1 7. Drill out cement and 20' minimum to SO' maximum of new hole. Perform formation integrity test not to exceed 16.0 PP9~M . &-~"¡" 8. Directionally drill.8r hole to well total depth (+/- 83241 MD) according to directional plan. Run MWD / LWD logging tools in drill string for directional monitoring and formation data gathering. Circulate and condition hole. POOH. ð~/R~~/2:>..?_;Ý/IÍt!~<-/ ~t"'e..c..h,,~',{ 9. Run open hole e-line or drill pipe conveyed logs qS needed. 'V.J" ~C'k' s~.-",L ///)Z;;7-jA?/r'Pk.~s..Y<:"E '5-I¡-1." )( ~_I[t.1C w61\ \1-(4Ioi "/ /"" 10. Run and cement 7" 26.0# L 80 DTCM x 1 1/2 12.6# L 00 DTCM tapered production casing string with Baker casing seal recept,acle cros$oyer (CSR). Place CSR +/- 100' above the planned top perforation. "5 - '/t. It wtJA ¡2-£l1t 0 t 11. Run and land 1::*' tubing. Displace well to completion brine. 12. Pull landing joint. Install BPV. Nipple down BOP stack, and nipple up production tree. Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. 13. Freeze protect well. Set BPV. Release rig and turn well over to production. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. /~J> 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for i:1 Permit to Drill ml1stc be accompanied by each of the lollowlng item~ except for an Item already on file wIth the commis::.,70n and Identified In the appllcFltion: (14) a general des1.yiption of I70W the operator plans tv dispose of drIlling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25": ()S{) for an annular disposal operation in tfle well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 2P pad or hauled to a Class II disposal well. All cuttings to be disposed of will be either disposed of down the annulus or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for disposal down an approved disposal well. At the end of drilling operations, a request will be submitted for this well to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 2P pad. 15. Attachments Attachment 1 AOGCC Form 10-401 (Front of permit package) Attachment 2 Directional Plan Attachment 3 Drilling Hazards Summary Attachment 4 Well Schematic Attachment 5 Cement Details ORIGINAL 2P-448 PERMIT IT 11-29-01.doc Page 7 of 7 Printed: 4-Dec-O1 0 ::a c-> :.....- :J::-. r- 1) llilli ~p s ..u.. Creolerl oy Omichoel For: P Heilly Dele plo:led : I ¡; I\ev ;>0111 ~;Ol Reference i, 2P- ~ ~ 8 Vers;on# I. Coord;role" 0'" i" reel rele,"nce s'o\ 1/~~8, Structure: Drill Site 2P Field: Meltwater Alaska, Well: 448 X 11 C 0 {PHilLIPS i ~ Location: North Slope, Alaska Truc Verlicol Dep:"s ore reference RKG (Doyon 1 ~ 1), w;¡:¡;:¡ I!.IIJ[S!! _I> I NT"') 6300 6000 5700 5~00 TO LOCATION: 1531' FSL, 1230' FWL Sl:.:C, 18, TBN, rUE:: -,.-.---..--------------..------.----,---- . <- West (feet) 5100 ~800 ~500 ~:)QO 3900 3600 ,3300 24-2.1 7 AZIMUTH 5559' (TO TARGET) ***I:Jlane of ['roposal*** ~ ~ !;I\\:); 3000 /700 7~00 7100 1800 1500 1700 900 600 300 L-.-----_._---~-_._--_...--'- , -'1 SURFACE. LOCATION: 1'>1> 1022' FNL, 1583' F-WL ~b,b, sec. 17, T8N, R7E, Begin Build/Turn KOP --------~----- Bose Permafrost ~ (f / 5/8 Casing 1'[ C--80 TRUE ~1> \. \) C-:57 ~~~. TARGrT LOCATION: 1663' FSI_, 1-178' FWL Sr:C. 18, T8N, R7[ TOP BERMUDA I.OCATION: 1715' r-SL, 15ï'6' FWL SEC. 18, T8N, R7E -'-...---..-.....-....,-------------.,-........ ....------.., Casing X-Over T3(Top Bermuda) I arget -- Bermuda Midf-'l ~ - T2(Base Bermuda) (f C:55 rD - Casing I't 0 300 SOD 0 ( - 300 600 900 1700 U) 0 C -+- .1500 ::J ~ --¡., CD 1800 CD -+- '--" I 2100 V 2400 2700 :SOOO ,)-100 3600 ( 400 - 800 1;J00 ,........., -1- 1600 Q) <::) Q) '1- '----" 2000 :x:. ....c +- 0... - - Q) t;:) 0 2400 - - 0 :c:: 0 2800. +- !.... ::t:. Q) > r- 3200- Q) :J !.... f- 3600 I V ~OOO 4400 - 0 I RKB Elevation: 252' Phillips Alasll{a, Inc. KOI) 2.00 ~ .00 6.00 8.00 Begin Build/l urn 13.00 16.00 19.00 DLS: 3.00 deg per 100 It /2.00 25.00 28.00 Bose Permafrost 31.00 3:5,99 DLS: 2.00 deg per 100 It 3999 . ßase WSak ~5.99 :'.>1.99 EOC 7 5/8 CCJsing c-so TANGENT ANGLE 57.78 DEG 4800 ~200 Structure: Drill Site 2P Well: 448 Field: Meltwater Location: North Slope. Alaska 212. 1 7 AZIMUTH 5559' (TO TARGET) ***I:Jlanc of f)roposol*** C-50 C-40 C-3! üUI" i IPS . . I I..... ( i~j;) Creoled by bm;chael For: P [~eilly Dole plo\:ed : 16-Nov-;>OOI Plol Reterence ;s 2P-4~8 Versian# 1. Coordinates are in teel reference <lot #448. True Verticol Depths ore reference RKB (Doyon 141 !:""-í:e :!J'_oa::: _fi. 'NT>:!) ( ( CCJ(sing X-Over ) 13 Top Bermuda Torget --- Bermuda Midl"t T2(Base Bermuda) é35 ~ TD - Casing PI 5600--- --. l--- -"'-T """"1'-'---I"'-----l"--'--I"---"-- r---'-r""--"-I.'-"--I-"'-----1"-'--1"-"-----T-------l-m ..- '1'--"--¡--"'-"'--[----"1"--""r-'.---1-- ---1"----1'----- -,--"-T-"-,""-----r'-.---T"----"--'--,'----'--,--¡ a ~oo 800 1200 1600 ;:>000 ;:>400 2800 3;:>00 3600 ~ 000 HOO 4800 5;:>00 5600 6000 Vert i c a I Sect ion (f e e t) - > Azimuth 242.17 with reference 0.00 N, 0.00 E from slot #448 C :x:J - - s:;-) - - ~ r-- C,eo'"" by bry';choel For: P Reilly Do:c plol:cd : :G-~ov-200' °101 RoI.,""o. ;5 7P-448 V.",:on#'. Co",c;natc^ 0"0 ;0 ~ool 'c'o,onoo "ot H<48. T,uc yc,';o,,' DeclO' orc ,dc'once RKB (Doyon ~ 41)- ¡¡-~j;¡¡:¡ BA"~ HU<""_S INTI"J) Phi Jll fl P S A I a s )k a, I Dl C ø Structure: Drill Site 2P Field: Meltwater ~~~~ PRO F ~ t-, E --------- I)oinl -.. -- -- .... --- MD 400.00 KOP 13egin F3uilcJ/Turn Base Permafrost 900.00 1488.18 Base WSak 197/.72 2492.87 EOC 7 S/8 Casing l:Jt C-80 2999.72 3112.25 C-50 C ~D 4050.0~ 4725.7-4 C-37 5081.60 7761.20 Casing X Over T3(Top Bermudo) 7861.20 1992.47 Targel -- Bermuda Mid' V> ¡T2(Base Bermuda) 8123.78 I !c35 8180.04 I IIQ......=...Ç,q.?i.lJ.g..Pl................................................ .......$..~2.~.] 8 Inc 0.00 1 O. DO 27.61\ 42.33 57.78 57.78 51. 78 57.78 5/./8 57.78 57.78 57.78 57.78 Well: 448 Location: North Slope, Alaska COMMENT 244.00 ?44.0D 2"12.58 242.28 242.10 742.10 242.10 242.10 24/..10 242.10 242.10 242..10 242.10 Dir TVD 400.00 Norlh 0.00 ---19.08 ~104.97 -234.63 -- 418.38 ---619.00 -663.54 -1034.75 ..-1302.01 -1443.07 --2503.73 -2543.31 -..2595.27 DATA -<59.12 -207.46 -455.53 --803.76 1182.73 -1266.87 -1968.0<'1 24/2.89 -2739.34 -47"12.86 -4817.63 --4915.78 lasl 0.00 <PH Ili. iPS) ({~~ ~~~~ V. Sect 0.00 4:5.50 232.47 512.38 906.11 1~S~34.91 1430.11 2223.48 2794.71 3096.19 5363.15 5447.75 5558.81 Oeg/100' 0.00 /..00 ( 897.47 1452.00 1852.00 2181.77 2452..00 2512.00 3012.00 ,SS!2.00 3562.00 4990.69 5044.00 5113.99 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 ( 0.001 0.00 0.00 i 57.78 242.10 5184.00 -2647.24 -5013.96 5669.89 0.001 57.78 247.10 521"1.00-.2669.52 ---5056.03 5/17.50 o.Oo! I I I 57.78 242.10 5290.64 -2726.41 -5163.50 5839.10 0.001 """""""""""""""""'" """"""""................................................................................""""""""""""""""""""""""""""'.....................................,. """""""""""""""""""""""""""""""""""""""""" """""""""""""""""""""""" ..............................1 ( I~' \l ]P]hil]liJ)S Alaska, ][rlC. .-.-';""----~"' :.:: :::;:':1: : IP~ ~ -~! ! i! '!..!.~ ! ~!! " . . . " . " . i ,'%' ,"" :'~~' ,. ':;;:::::: ~ ~ " . " ... '""-,-,.-,,..,,',..,"'-"'-,....'u- .- ~..::...-'~ .. ..,........,............,.._..........,.. C'oo,"" by b..:,,"", For: P Reilly Structure: Drill Site 2P Well: 448 Dolo 010""0; 16-~0,-2DOI 1'10: .,1","," i, 2P-"8 V",ion#1. Field: Meltwater Location: North Slope, Alaska COO'"I,o:., 0'. In 1.., ..Ieo.", ,101 ~4'8, c,., V,~iool O'D'"' 0'. rel.-.,o, RK6 (Doyon ",),- ~ "'TE'" ill TRUE NORTH ~ L-:-::::J 350 0 10 f?\ l~J ~ W 340 20 330 210 30 ø 3l0 50 320 40 300 60 290 70 280 270 90 260 100 250 l l 0 240 ~ 120 230 130 220 140 210 150 190 180 'ê1 70 1 60 m ~ \& 200 Normal Plane Travelling Cylinder - Feet All depths shown are MeCJsurcd depths on Reference Well ORIGINAL Crootod oy omichool For: P Hei lIy Da:e plotted: 16-Nav-?ODI 1'101 ""Ierooeo is ?P- ^~8 Versianl!1. Coordinates arc in ~ect reference slot 1I~~8, True Verkel Dcplns are re~erenc. RKG (Doyon I Z=;ii\!: .u",.., -5' INn:Q 1000 960 920 880 8~0 800 760 2000 2100 8 0 :x:J - c-> 4300 , :æ: 4400 , :r:::.. 4500 . .- 4600 . .. 4700 ~ 1700 .. . ~200 ,2600 cØ> @> .. 2300 , 2/00 @> Pllilli P s Structure: Drill Site 2P Alaska9 720 1900 - -~'100 Field: Meltwater Well: 448 I 11 C . ~\ Ie.::::'~'~"::::::":":":'::::,:.:::: ~........,.......,..,_.._...._.. ............ -.... .".. ..-........ -- -- -, ....--,-.. ":~~,-"~~~;-;~":~~,,,-;;;': 680 6~0 <- West (feet) 520 4100 , 4200 .. 1600 .. .. 2500 cØ> Location: North Slope. Alaska 600 1800 . 2000 . 2400 , :/000 560 . 1700 .5900 . 4000 .. 1500 .. .- - - 1900 , 7:500 ~80 ~~O ~OO 360 320 280 2~0 200 160 120 ~O 8 :5400 , ( 3500 80 .. 110,~ '1400 .5600 , 3800 . 3700 1200, "'(500 170 .. . 1600 ,- ø 1300, 1600 ' 1100 160 . 1 ~OO .... .. 1800 1700 , 1900 , 1500 700 1400 .. - '1800 .. 2000 ø 240 (J) ,¡.~ 0 , 1600 ,- C -+- - 280 ::J" r--.... - CD . 1700 - 320 CD -+- "--" (J; I i - :560 V "~Oo (!7 ,,1600 ¡ 440 ( .. 1600 , 2100 , 1/00 . 2200 .. 1800 .. 1800 .. 1900 " 1900 â cY .. 2000 460 . 1700 (!; ;: 520 (jJ (!; (!; ¡ -560 <::::) ::0 - c-> - :æ: )::::... r-- Crea:'d by bMicnoel For: P Reilly Dcte 1"01 led : 15-~av-~OO1 1'10' I¡c~crcncc is ~p-~~8 Vcrs;anHI. Coordinates are i,o leel reference slot 1/~~8, True Vertiool Depths arc reference RKiJ (Dayon ~5.-¡:¡ W\K DO !!UGŒ!i "">:<1 5200 5000 ~~oo ~800 ~600 3600 , .. ;800 @ C-)~I~O [iliJ ~200 ~ooo 5400 Ed 3:500 . , . ~t)00 4500 ø lP l~illi P s Alaslka, Structure: Drill Site 2P Well: 448 Location: North Slope, Alaska Field: Meltwater 3800 3600 5100 . d800 3000 , .' ~'200 IJ~_(j] . 4200 <- West (feet) 3~00 3200 3000 2800 s 2700 , " 3600 , 4800 " ,3900 ,5100 .. 5400 . 3600 . 3900 Inc. 2600 2~00 2200 2400 . , ~ ,DOD , ~200 , ~t)oo * 3300 ø 2000 , ,,3000 . 3900 .. 3600 , 3000 1800 , 3300 ø 1000 1200 (j) ..2/00 0 1400 C (!; -I- ::J r--. 1600 -h , 2.400 CD (!; CD -I- ~ "--'" 1800 I V !JJ 2000 ( ~ 2()O ¡ ~lllPS 1600 HOO 1200 1000 r;;f;\ .. 5'10~ . 5700 ~ . 240D , .5000 2100 . ,'270Q 3300 , )400 .3600 . 2700 .. 3000 . 3000 . 2700 noo . ~500 2400 ,4800 2600 Ib \!I . 3300 .. 5100 (!J (}l 800 ~OO /S\ 600 ~ ( 800 2800 PJhiJllips AlasJka, ~HllUPS W+.i;i7'~'-:;+J""':;~':' .....,.. """" ..,........ ......... ....... ......... "'." ....... .,. "..'" ......... ...... ...... ..........-"" ....... ,... .... ""'..""'" ....- .,_. ---- -- "'-""- ..,.... ..... ...... .,., .........'" ........- -.... .., ..-..----_.. ...... ....... ............ . ..."""...."...",;;.".".:..,........." l .L n c . Croaled by b,.,ichael For: P Reilly ~c:" Dlo::ed , 16-Nov-?OO 1 Structure: Drill Site 2P Well: 448 Field: Meltwater Location: North Slope, Alaska Pia: '~ecrenco is 7P "8 Version/II. Coordinole" arc in Ice: re~erence 510: 1/448. Irue Ve.:ieo! DepUls are ,e'ere"ce '~KS (Doyo" 1 æ!õi!!.1E !!AI(m nüGiE5 INTLQ <- West (feet) 190 180 I/O 160 1 ~)O HO 150 1:>0 110 100 90 SO /0 60 bO ~O ~SO :>0 10 0 10 :>0 .50 30 20 10 6300 @ 1><1>< ,8300 . 500 0 C .$300 , '" '600 ,,800 ."", " 500 ," íoo ,,600 ::0 10 600 *500 -$-300 - .-SOO ,900 - - 700 .. * 600 800 . 700 c-> 900 - .. 900 . 20 1000 .. 3100 - - ' 700 . 1000 S 1100 E3 ,;. -1000 800* (!; 30 ¡ ..800 ,,:5200 r-- - 1100;. - '-1100 40 * 900 . 900 - - ;. 1000 50 - . 1200 "3300 ' "1200 60 ,1000 g * 1000 - ' . 1300 ""/0 .. .. "'1300 ;. 1100 (!J 80 . 1100 ø * 1400 90 ø' i 400 ø ø ø (!J .l - 100 ( (j) 0 C -t- ::J ,,--.., -h CD CD -+- '---" I V (" f ( Phillips Alaska, Inc. Drill Site 2P 448 slot #448 Meltwater North Slope, Alaska PRO PO S A L LIS TIN G by Baker Hughes INTEQ Your ref: 2P-448 Version#l Our ref: prop4858 License: Date printed: l6-Nov-2001 Date created: 10-Sep-2001 Last revised: 16-Nov-2001 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 8.477,w150 27 6.466 Slot Grid coordinates are N 5868858.493, E 443542.954 Slot local coordinates are 1021.01 S 1586.70 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( ( Phillips Alaska, Inc. PROPOSAL LISTING Page 1 Drill Site 2P,448 Your ref : 2P-448 VersionU Meltwater,North Slope, Alaska Last revised : 16-Nov-2001 Measured Inclin. Azimuth True Vert R E C TAN G U LA R Dogleg Vert Depth Degrees Degrees Depth COO R DIN A T E S Deg/l00ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 244.00 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 244.00 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 244.00 300.00 0.00 N 0.00 E 0.00 0.00 400.00 0.00 244.00 400.00 0.00 N 0.00 E 0.00 0.00 KOP 500.00 2.00 244.00 499.98 0.77 S 1.57 W 2.00 1. 74 600.00 4.00 244.00 599.84 3.06 S 6.27 W 2.00 6.97 700.00 6.00 244.00 699.45 6.88 S 14.11 W 2.00 15.69 800.00 8.00 244.00 798.70 12.22 S 25.06 W 2.00 27.87 900.00 10.00 244.00 897.47 19.08 S 39.12 W 2.00 43.50 Begin Build/Turn 1000.00 13 .00 243.50 995.45 27.91 S 56.99 W 3.00 63.43 1100.00 16.00 243.18 1092.25 39.14 S 79.36 W 3.00 88.45 1200.00 19.00 242.96 1187.61 52.76 S 106.16 W 3.00 118.51 1300.00 22.00 242.80 1281.27 68.73 S 137.32 W 3.00 153.52 1400.00 25.00 242.67 1372.97 86.99 S 172.75 W 3.00 193.38 1488.18 27.64 242.58 1452.00 104.97 S 207.46 W 3.00 232.47 Base Permafrost 1500.00 28.00 242.57 1462 .46 107.51 S 212.36 W 3.00 237.99 1600.00 31.00 242.49 1549.49 130.21 S 256.04 W 3.00 287.22 1700.00 33.99 242.42 1633.82 155.05 S 303.67 W 3.00 340.93 1800.00 36.99 242.37 1715.23 181.96 S 355.11 W 3.00 398.99 1900.00 39.99 242.31 1793.49 210.85 S 410.24 W 3.00 461.22 1977.72 42.33 242.28 1852.00 234.63 S 455.53 W 3.00 512.38 Base WSak 2000.00 42.99 242.27 1868.38 241.65 S 468.89 W 3.00 527.47 2100.00 45.99 242.23 1939.70 274.28 S 530.90 W 3.00 597.55 2200.00 48.99 242.19 2007.26 308.65 S 596.12 W 3.00 671.26 2300.00 51.99 242.16 2070.87 344.66 S 664.34 W 3.00 748.41 2400.00 54.99 242.13 2130.36 382.21 S 735.40 W 3.00 828.78 2492.87 57.78 242.10 2181.77 418.38 S 803.76 W 3.00 906.11 EOC 2500.00 57.78 242.10 2185.56 421.20 S 809.09 W 0.00 912.14 2999.72 57.78 242.10 2452.00 619.00 S 1182.73W 0.00 1334.91 7 5/8" Casing pt 3000.00 57.78 242.10 2452.15 619.11 S 1182.94 W 0.00 1335.14 3112.25 57.78 242.10 2512.00 663.54 S 1266.87 W 0.00 1430.11 C-80 3500.00 57.78 242.10 2718.74 817.03 S 1556.78 W 0.00 1758.15 4000.00 57.78 242.10 2985.32 1014.94 S 1930.63 W 0.00 2181.15 4050.04 57.78 242.10 3012.00 1034.75 S 1968.04 W 0.00 2223.48 C-50 4500.00 57.78 242.10 3251.91 1212.85 S 2304.48 W 0.00 2604.15 4725.24 57.78 242.10 3372.00 1302.01 S 2472.89 W 0.00 2794.71 C-40 5000.00 57.78 242.10 3518.49 1410.77 S 2678.33 W 0.00 3027.16 5081.60 57.78 242.10 3562.00 1443.07 S 2739.34 W 0.00 3096.19 C-37 5500.00 57.78 242.10 3785.08 1608.68 S 3052.17 W 0.00 3450.16 6000.00 57.78 242.10 4051.66 1806.59 S 3426.02 W 0.00 3873.16 6500.00 57.78 242.10 4318.25 2004.51 S 3799.87 W 0.00 4296.17 7000.00 57.78 242.10 4584.84 2202.42 S 4173.72 W 0.00 4719.17 7500.00 57.78 242.10 4851.42 2400.34 S 4547.56 W 0.00 5142.17 7761.20 57.78 242.10 4990.69 2503.73 S 4742.86 W 0.00 5363.15 Casing X-Over 7861.20 57.78 242.10 5044.00 2543.31 S 4817.63 W 0.00 5447.75 T3 (Top Bermuda) 7992.47 57.78 242.10 5113.99 2595.27 S 4915.78 W 0.00 5558.81 Target - Bermuda MidPt 7992.49 57.78 242.10 5114.00 2595.28 S 4915.79 W 0.00 5558.82 MW(A) Rvsd 24 May 01 8000.00 57.78 242.10 5118.01 2598.25 S 4921. 41 W 0.00 5565.18 8123.78 57.78 242.10 5184.00 2647.24 S 5013.96 W 0.00 5669.89 T2(Base Bermuda) All data is in feet unless otherwise stated. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Total Dogleg for wel1path is 57.79 degrees. Vertical section is from wellhead on azimuth 242.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL ( ( Phillips Alaska, Inc. Drill Site 2P,448 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-448 Version#1 Last revised: 16-Nov-2001 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C TAN G U LA R COO R DIN ATE S Dogleg Deg!lOOft Vert Sect 8180.04 8323.78 57.78 57.78 242.10 242.10 5214.00 5290.64 2669.52 S 2726.41 S 5056.03 W 5163.50 W 0.00 0.00 5717.50 C35 5839.10 TD - Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Total Dogleg for we11path is 57.79 degrees. Vertical section is from wellhead on azimuth 242.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL ,I'" t, ( Phillips Alaska, Inc. Drill Site 2P,448 Meltwater,North Slope, Alaska PROPOSAL LI5TING Page 3 Your ref: 2P-448 Version#l Last revised: 16-Nov-2001 Comments in we11path -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 400.00 400.00 0.00 N 0.00 E KOP 900.00 897.47 19.08 5 39.12 W Begin Build/Turn 1488.18 1452.00 104.97 5 207.46 W Base Permafrost 1977.72 1852.00 234.63 5 455.53 W Base W5ak 2492.87 2181.77 418.38 5 803.76 W EOC 2999.72 2452.00 619.00 5 1182.73W 7 5/8" Casing pt 3112.25 2512.00 663.54 5 1266.87 W C-80 4050.04 3012.00 1034.75 S 1968.04 W C-50 4725.24 3372.00 1302.01 5 2472.89 W C-40 5081.60 3562.00 1443.07 5 2739.34 W C-37 7761.20 4990.69 2503.73 5 4742.86 W Casing X-Over 7861.20 5044.00 2543.31 5 4817.63 W T3(Top Bermuda) 7992.47 5113.99 2595.27 5 4915.78 W Target - Bermuda MidPt 7992.49 5114.00 2595.28 S 4915.79 W MW(A) Rvsd 24 May 01 8123.78 5184.00 2647.24 5 5013.96 W T2(Base Bermuda) 8180.04 5214.00 2669.52 5 5056.03 W C35 8323.78 5290.64 2726.41 5 5163.50 W TD - Casing pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 8323.78 2999.72 5290.64 2452.00 2726.415 619.005 5163.50W 1182.73W 3 1/2" Liner 7 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5114.00 2595.285 4915.79W 22-Feb-2001 ORIGINAL ( (" Phillips Alaska, Inc. Drill Site 2P 448 slot #448 Meltwater North Slope, Alaska PRO PO S A L LIS TIN G by Baker Hughes INTEQ Your ref: 2P-448 Version#l Our ref: prop4858 License: Date printed: 16-Nov-2001 Date created: 10-Sep-2001 Last revised: 16-Nov-2001 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 8.477,w150 27 6.466 Slot Grid coordinates are N 5868858.493, E 443542.954 Slot local coordinates are 1021.01 S 1586.70 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( (' Phillips Alaska, Inc. PROPO5AL LI5TING Page 1 Drill 5ite 2P,448 Your ref : 2P-448 Version#l Meltwater,North 5lope, Alaska Last revised : l6-Nov-2001 Measured Inclin Azimuth True Vert R E C TAN G U LA R G R I D COO R D 5 G E 0 G R A PHI C Depth Degrees Degrees Depth COO R DIN A T E 5 Easting Northing COO R D I N ATE 5 0.00 0.00 0.00 0.00 O.OON O.OOE 443542.95 5868858.49 n70 3 08.48 w150 27 06.47 100.00 0.00 244.00 100.00 O.OON O.OOE 443542.95 5868858.49 n70 3 08.48 w150 27 06.47 200.00 0.00 244.00 200.00 O.OON O.OOE 443542.95 5868858.49 n70 3 08.48 w150 27 06.47 300.00 0.00 244.00 300.00 O.OON O.OOE 443542.95 5868858.49 n70 3 08.48 w150 27 06.47 400.00 0.00 244.00 400.00 O.OON O.OOE 443542.95 5868858.49 n70 3 08.48 w150 27 06.47 500.00 2.00 244.00 499.98 0.775 1.57W 443541.38 5868857.74 n70 3 08.47 w150 27 06.51 600.00 4.00 244.00 599.84 3.065 6.27W 443536.66 5868855.48 n70 3 08.45 w150 27 06.65 700.00 6.00 244,00 699.45 6.885 14.11W 443528.80 5868851.72 n70 3 08.41 w150 27 06.87 800.00 8.00 244.00 798.70 12.225 25.06W 443517.81 5868846.46 n70 3 08.36 w150 27 07.19 900.00 10.00 244.00 897.47 19.085 39.12W 443503.70 5868839.71 n70 3 08.29 w150 27 07.59 1000.00 13.00 243.50 995.45 27.915 56.99W 443485.76 5868831.03 n70 3 08.20 w150 27 08.11 1100.00 16.00 243.18 1092 .25 39.145 79.36W 443463.31 5868819.96 n70 3 08.09 w150 27 08.75 1200.00 19.00 242.96 1187.61 52.765 106.16W 443436.41 5868806.54 n70 3 07. 96 w150 27 09.52 1300.00 22.00 242.80 1281.27 68.735 137.32W 443405.13 5868790.82 n70 3 07.80 w150 27 10.42 1400.00 25.00 242.67 1372.97 86.995 172.7 5W 443369.56 5868772.83 n70 3 07.62 w150 27 11.44 1488.18 27.64 242.58 1452.00 104.975 207.46W 443334.72 5868755.12 n70 3 07.45 w150 27 12.44 1500.00 28,00 242.57 1462.46 107.515 212.36W 443329.80 5868752.62 n70 3 07.42 w150 27 12.58 1600.00 31.00 242.49 1549.49 130.215 256.04W 443285.96 5868730.25 n70 3 07.20 w150 27 13.84 1700.00 33.99 242.42 1633.82 155.055 303.67W 443238.14 5868705.77 n70 3 06.95 w150 27 15.21 1800.00 36.99 242.37 1715.23 181.965 355.11W 443186.50 5868679.27 n70 3 06.69 w150 27 16.70 1900.00 39.99 242.31 1793.49 210.855 410.24W 443131.16 5868650.80 n70 3 06.40 w150 27 18.28 1977.72 42.33 242.28 1852.00 234.635 455.53W 443085.70 5868627.36 n70 3 06.17 w150 27 19.59 2000.00 42.99 242.27 1868.38 241.655 468.89W 443072.28 5868620.44 n70 3 06.10 w150 27 19.97 2100.00 45.99 242.23 1939.70 274.285 530.90W 443010.03 5868588.29 n70 3 05.78 w150 27 21.76 2200.00 48.99 242.19 2007.26 308.655 596.12W 442944.56 5868554.43 n70 3 05.44 w150 27 23.64 2300.00 51.99 242.16 2070.87 344.665 664.34W 442876.07 5868518.94 n70 3 05.09 w150 27 25.60 2400.00 54.99 242.13 2130.36 382.215 735.40W 442804.73 5868481.94 n70 3 04.72 w150 27 27.65 2492.87 57.78 242.10 2181.77 418.385 803.76W 442736.11 5868446.29 n70 3 04.36 w150 27 29.62 2500.00 57.78 242.10 2185.56 421.205 809.09W 442730.76 5868443.51 n70 3 04.34 w150 27 29.77 2999.72 57.78 242.10 2452.00 619.005 1182. 73W 442355.66 5868248.58 n70 3 02.39 w150 27 40.54 3000.00 57.78 242.10 2452.15 619.115 1182. 94W 442355.45 5868248.47 n70 3 02.39 w150 27 40.54 3112.25 57.78 242.10 2512.00 663.545 1266.87W 442271.19 5868204.69 n70 3 01. 95 w150 27 42.96 3500.00 57.78 242.10 2718.74 817.035 1556.78W 441980.14 5868053.43 n70 3 00.44 w150 27 51.31 4000.00 57.78 242.10 2985.32 1014.945 1930.63W 441604.83 5867858.39 n70 2 58.50 w150 28 02.08 4050.04 57.78 242.10 3012.00 1034.755 1968.04W 441567.27 5867838.87 n70 2 58.30 w150 28 03.16 4500.00 57.78 242.10 3251.91 1212.855 2304.48W 441229.52 5867663.35 n70 2 56.55 w150 28 12.85 4725.24 57.78 242.10 3372.00 1302.015 2472.89W 441060.45 5867575.49 n70 2 55.67 w150 28 17.70 5000.00 57.78 242.10 3518.49 1410.775 2678. 33W 440854.21 5867468.31 n70 2 54.60 w150 28 23.61 5081.60 57.78 242.10 3562.00 1443.075 2739.34W 440792.96 5867436.48 n70 2 54.28 w150 28 25.37 5500.00 57.78 242.10 3785.08 1608.685 3052.17W 440478.90 5867273.27 n70 2 52.66 w150 28 34.38 6000.00 57.78 242.10 4051. 66 1806.595 3426.02W 440103.60 5867078.23 n70 2 50.71 w150 28 45.14 6500.00 57.78 242.10 4318.25 2004.515 3799.87W 439728.29 5866883.19 n70 2 48.76 w150 28 55.91 7000.00 57.78 242.10 4584.84 2202.425 4173. 72W 439352.98 5866688.15 n70 2 46.81 w150 29 06.67 7500.00 57.78 242.10 4851.42 2400.345 4547.56W 438977.67 5866493.11 n70 2 44.87 w150 29 17.44 7761.20 57.78 242.10 4990.69 2503.735 4742.86W 438781.61 5866391.22 n70 2 43.85 w150 29 23.06 7861.20 57.78 242.10 5044.00 2543.315 4817.63W 438706.55 5866352.21 n70 2 43.46 w150 29 25.21 7992.47 57.78 242.10 5113.99 2595.275 4915.78W 438608.01 5866301.01 n70 2 42.95 w150 29 28.04 7992.49 57.78 242.10 5114.00 2595.285 4915.79W 438608.00 5866301.00 n70 2 42.95 w150 29 28.04 8000.00 57.78 242.10 5118.01 2598.255 4921.41W 438602.36 5866298.07 n70 2 42.92 w150 29 28.20 8123.78 57.78 242.10 5184.00 2647.245 5013.96W 438509.45 5866249.79 n70 2 42.43 w150 29 30.86 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Total Dogleg for we1lpath is 57.79 degrees. Vertical section is from wellhead on azimuth 242.17 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL (' (' Phillips Alaska, Inc. Drill Site 2P,448 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-448 Version#l Last revised: 16-Nov-2001 Measured Inclin Depth Degrees Azimuth Degrees True Vert Depth R E C TAN G U LA R COO R DIN ATE S 8180.04 8323.78 57.78 57.78 242.10 242.10 5214.00 5290.64 2669.52S 2726.41S 5056.03w 5163.50W G R I D COO R D S G E 0 G R A PHI C Easting Northing COO R D I N ATE S 438467.22 5866227.84 n70 2 42.22 w150 29 32.07 438359.32 5866171.77 n70 2 41.66 w150 29 35.17 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea level). Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Total Dogleg for wellpath is 57.79 degrees. Vertical section is from wellhead on azimuth 242.17 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ORIGINAL ~. ( Phillips Alaska, Inc. Drill Site 2P,448 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref: 2P-448 Version#l Last revised: 16-Nov-200l Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 400.00 400.00 O.OON O.OOE KOP 900.00 897.47 19.08S 39.12W Begin Build/Turn 1488.18 1452.00 104.97S 207.46W Base Permafrost 1977.72 1852.00 234.63S 455.53W Base WSak 2492.87 2181.77 418.38S 803.76W EOC 2999.72 2452.00 619.00S 1182. 73W 7 5/8" Casing pt 3112.25 2512.00 663.54S 1266.87W C-80 4050.04 3012.00 1034.75S 1968.04W C-50 4725.24 3372.00 1302.01S 2472.89W C-40 5081. 60 3562.00 1443.07S 2739.34W C-37 7761.20 4990.69 2503.735 4742.86W Casing X-Over 7861.20 5044.00 2543.31S 4817.63W T3 (Top Bermuda) 7992.47 5113.99 2595.27S 4915.78w Target - Bermuda MidPt 7992.49 5114.00 2595.28S 4915.79W MW(A) Rvsd 24 May 01 8123.78 5184.00 2647.24S 5013. 96W T2(Base Bermuda) 8180.04 5214.00 2669.52S 5056.03W C35 8323.78 5290.64 2726.41S 5163.50W TO - Casing pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 8323.78 2999.72 5290.64 2452.00 2726.41S 619.00S 5163.50W 1182.73W 3 1/2" Liner 7 5/8" Casing Targets associated with this we11path ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5114.00 2595.28S 4915.79W 22-Feb-2001 ORIGINAL """"'.""""""...............,...... I;\TEQ Measured Svy# Depth Tie-In 0.00 1 100.00 2 200.00 3 300.00, 4 '400.00 5 500.00 6600.00 7 700.00 8 800;00 9909.00 10 iooo.oo 11 ", tiooX)() 12 J2aó.()O 13 ,,1~;øo 14.,' ' 0 15 ' 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 ~.'" ~. Riì8 ..... , Angle Azimuth" ' TVD-RKB deg deg It 0.00 ,", 0.00 0.00 0.00244:00 100.00 0.00 '244.00 200.00 0.00244,00 300.00 0.00 ',244.00 400.00 2.00 ,244.00 499.98 4.00 '244,aO 599.84 6.00,244.()O 699,45 8.00' ,244:00 798.70 10.00" 244:00 897.47 13.00 '243:50 995.45 16.00 ,243:18 1092.25 19.00~42:96 1187.61 22.00' '242:$0 1281.27 25.00 1372.97 27.64 1452.00 28.00 1462.46 31.00 1549,49 33.99 1633.82 36.99 1715.23 39.99 1793.49 42.33 1852.00 42.99 1868.38 45.99 1939.70 48.99 2007.26 51.99 2070.87 54.99 2130.36 57.78 2181.77 57.78 2185.56 57.78 2452.00 57.78 2'::52.15 57.78 2512.00 57.78 2718.74 57.78 2985.32 57.78 3012.00 57.78 3251.91 57.78 3372.00 57.78 3518.49 57.78 3562.00 57.78 3785.08 57.78 4051.66 57.78 4318.25 57.78 4584.84 57.78 (.851'<:.2 57.78 4990.69 57.78 5044.00 57.78 5113.99 57.78 5114.00 57.78 5118.01 5~~ 518~00 57.78 5214.00 57.78 5290.64 Alaska Slete Plane Coordinates 1YD X Subsea 11, ' ft -252.00 443542.955868858A9 -152,00 443542.955868858.49 -52.00 443542.95 5868858.49 48.00 443542.95 5868858 49 148.00 443542.95 5868858.49 247.98 443541.38 5868857.74 347.84 443536.66 5868855.48 447.45 443528.80 5868851.72 546.70 '::43517.81 5868846.46 645.47 443503.70 5868839.71 743.45 443485.76 5868831.03 840.25 443463.31 5868819.96 935.61 443436.41 5868806.54 1029.27443405.13 5868790.82 1120.97 443369.56 5868772.83 1200.00 443334.72 5868755.12 1210,46 443329.80 5868752.62 1297.49 443285.96 5868730.25 1381.82 443238.1':: 5868705.77 1463.23 443186.50 5868679.27 1541.49 443131.16 5868650.80 1600.00 443085.70 5868627.36 1616.38 443072.28 5868620.44 1687.70 443010.03 5868588.29 1755.26 442944.56 5868554.43 1818.87 ':'::2876.07 5868518.94 1878.36 442804.73 5868481.94 1929.77 '::42736.11 5868446.29 1933.56 '::42730.76 5868443.51 2200.00 '::42355.66 5868248.58 2200.15 442355.45 5868248.47 2260.00 '::42271.19 5868204.69 2466.74 441980.14 5868053.43 2733.32 441604.83 5867858.39 2760,00 44156727 5867838.87 2999.91 441229.52 5867663.35 3120.00 441060.45 5867575.49 3266.49 440854.21 5867468.31 3310.00 440792.96 586743648 3533.08 440478.90 5867273.27 3799.66 440103.60 5867078.23 4066.25 439728.29 5866883.19 4332.84 439352.98 5866688.15 4599.'::2 438977.67 5866493.11 4738.69 438781.61 5866391.22 4792.00 438706.55 5866352.21 4861.99 438608.01 5866301.01 4862.00 438608.00 5866301.00 '::866.D1 438602.36 5866298.07 4932.00 438509.45 5866249.79 4962.00 438467.22 5866227.84 5038.64 438359.32 5866171.77 NJ-S 11: 0.00 0.00 0.00 0.00 0.00 -0.77 ' -3.06 > -6.88 -12.22 -19,08 -27.91 . -39.14~ -52.76> -68.73 ... -86.99 ' -104.97 -107.51 -130.21 -155.05 -181.96 -210.85: -234.63 -241.65 -274.28' -308.65 ' -344.66 -382.21 -418.38 -421.20 -619.00 -619.11 -663.54 -817.03 -1014.94 -1034.75 -1212.85 -1302.01 -1410.77 -1443.07 -1608.68 -1806.59 -2004.51 -2202.42 -2400.34 -2503.73 -2543.31 -2595.27 -2595.28 -2598.25 -2647.24 -2669.52 -2726.41 e/"w DLS 11: degl100 11: 0.00 0.00 0;00 0.00 0.00 0.00 0.00 0.00, " 0.00 0.00 -1.57 2.00 , "6.27 2.00 ' "14,11 2.00 ~25~06 2.00 ' ".39;12 2.00 -5a~99 3.00 ~~;36 3.00 ,106;16 3.00 ~1;37:32 3.00" 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 , Vert. See 11: 0.00 0.00 0.00 , 0.00 0.00 , 1.74 " 6.97 15.69 27.87 , 43:50 63.43 : 88;45 1151 ORIGINAL l { { Phillips Alaska, Inc. Drill Site 2P 448 slot #448 Meltwater North Slope, Alaska SUM MAR Y C LEA RAN C E R E PO R T by Baker Hughes INTEQ Your ref: 2P-448 Version#l Our ref: prop4858 License: Date printed: 16-Nov-2001 Date created: 10-Sep-2001 Last revised: 16-Nov-2001 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 8.477,w150 27 6.466 Slot Grid coordinates are N 5868858.493, E 443542.954 Slot local coordinates are 1021.01 S 1586.70 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Obj ect wellpath Closest approach with 3-D Last revised Distance 4-Jun-2001 197.9 25-May-2001 619.7 30-0ct-2001 559.9 16-Nov-2001 659.5 26-Feb-2001 4291.3 26-Feb-2001 4071.9 26-Feb-2001 5955.7 6-Mar-2001 44889.9 Minimum Distance method M.D. Diverging from M.D. 487.5 487.5 0.0 0.0 100.0 100.0 200.0 200.0 400.0 400.0 2055.6 2055.6 4760.0 4760.0 8323.8 8323.8 MWD <0-9224'>,,438,Dril1 Site 2P MWD <0 - 6008'>,,417,Drill Site 2P MWD <0-6860'>,,420,Drill Site 2P MWD <3660 - ???'>,,415,Drill Site 2P PMSS <0-6300'>"MWN#2,Meltwater North #2 PMSS <2212-7349'>"MWN#2A,Meltwater North #2 PMSS <0-6122'>"MWN#1,Meltwater North #1 PMSS <0-8935'>"MWSouth1,Meltwater South #1 ORIGINAL t .~: Phillips Alaska, Inc. Drill Site 2P 448 slot #448 Meltwater North Slope, Alaska PRO PO S ALL 1ST I N G INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: 2P-448 Version#l Our ref: prop4858 License; Date printed; 16-Nov-2001 Date created: 10-Sep-2001 Last revised: 16-Nov-2001 Field is centred on 441964.235,5869891.466,999.00000,N Structure is centred on 441964.235,5869891.466,999.00000,N Slot location is n70 3 8.477,w150 27 6.466 Slot Grid coordinates are N 5868858.493, E 443542.954 Slot local coordinates are 1021.01 S 1586.70 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ORIGINAL ( f Phillips Alaska, Inc, PROPOSAL LISTING Page 1 Drill Site 2P,448 Your ref : 2P-448 Version#l Meltwater,North Slope, Alaska Last revised : 16-Nov-2001 Measured Inclin. Azimuth True Vert R E C T A N G U LA R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth COO R DIN ATE S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0,00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 244.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 244.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 244.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 0.00 244.00 400.00 0.00 N 0.00 E 0.00 1. 04 1. 04 0.60 N/A 500.00 2.00 244.00 499.98 0.77 S 1.57 W 1. 74 1. 31 1. 31 0.75 N/A 600.00 4.00 244.00 599.84 3.06 S 6.27 W 6.97 1. 61 1. 57 0.90 64.00 700.00 6.00 244.00 699.45 6.88 S 14.11 W 15.69 1. 97 1. 84 1. 05 64.00 800.00 8.00 244.00 798.70 12.22 S 25.06 W 27.87 2.43 2.12 1. 20 64.00 900.00 10.00 244.00 897.47 19.08 S 39.12 W 43.50 3.02 2.41 1. 36 64.00 1000.00 13.00 243.50 995.45 27.91 S 56.99 W 63.43 3.80 2.72 1. 52 63.84 1100.00 16.00 243.18 1092.25 39.14 S 79.36 W 88.45 4.82 3.05 1. 68 63.65 1200.00 19.00 242.96 1187.61 52.76 S 106.16 W 118.51 6.11 3.41 1. 86 63.46 1300.00 22.00 242.80 1281.27 68.73 S 137.32 W 153.52 7.70 3.80 2.05 63.30 1400.00 25.00 242.67 1372.97 86.99 S 172.75 W 193.38 9.62 4.22 2.27 63.15 1488.18 27.64 242.58 1452.00 104.97 S 207.46 W 232.47 11.61 4.61 2.48 63.04 1500.00 28.00 242.57 1462.46 107.51 S 212.36 W 237.99 11.87 4.66 2.51 63.03 1600.00 31.00 242.49 1549.49 130.21 S 256.04 W 287.22 14.49 5.13 2.79 62.92 1700.00 33.99 242.42 1633.82 155.05 S 303.67 W 340.93 17.49 5.62 3.11 62.83 1800.00 36.99 242.37 1715.23 181. 96 S 355.11 W 398.99 20.88 6.13 3,47 62,75 1900.00 39.99 242.31 1793.49 210.85 S 410.24 W 461.22 24.68 6.65 3.88 62.67 1977.72 42.33 242.28 1852.00 234.63 S 455.53 W 512.38 27.95 7.07 4.25 62.62 2000.00 42.99 242.27 1868.38 241. 65 S 468.89 W 527.47 28.88 7.19 4.35 62.61 2100.00 45.99 242.23 1939.70 274.28 S 530.90 W 597.55 33.49 7.72 4.88 62.55 2200.00 48.99 242.19 2007.26 308.65 S 596.12 W 671.26 38.52 8.26 5.46 62.50 2300.00 51. 99 242.16 2070.87 344.66 S 664.34 W 748.41 43.94 8.79 6.10 62.46 2400.00 54.99 242.13 2130.36 382.21 S 735.40 W 828.78 49.75 9.31 6.79 62.42 2492.87 57.78 242.10 2181.77 418.38 S 803.76 W 906.11 55.48 9.78 7.48 62.38 2500.00 57.78 242.10 2185.56 421.20 S 809.09 W 912.14 55.92 9.81 7.54 62.38 2999.72 57.78 242.10 2452.00 619.00 S 1182.73 W 1334.91 86.94 12.33 11.36 62.28 3000.00 57.78 242.10 2452.15 619.11 S 1182.94 W 1335.14 86.96 12.33 11.36 62.28 3112.25 57.78 242.10 2512.00 663.54 S 1266.87 W 1430.11 93.96 12.90 12.23 62.27 3500.00 57.78 242.10 2718.74 817 . 03 S 1556.78 W 1758.15 118.15 14.86 15.23 62.23 4000.00 57.78 242.10 2985.32 1014.94 S 1930.63 W 2181.15 149.40 17.39 19.13 62.20 4050.04 57.78 242.10 3012.00 1034.75 S 1968.04 W 2223.48 152.53 17.65 19.52 62.20 4500.00 57.78 242.10 3251.91 1212.85 S 2304.48 W 2604.15 180.67 19.93 23.04 62.19 4725.24 57.78 242.10 3372.00 1302.01 S 2472.89 W 2794.71 194.77 21.07 24.80 62.18 5000.00 57.78 242.10 3518.49 1410.77 S 2678.33 W 3027.16 211.96 22.46 26.95 62.17 5081.60 57.78 242.10 3562.00 1443.07 S 2739.34 W 3096.19 217.07 22.88 27.59 62.17 5500.00 57.78 242.10 3785.08 1608.68 S 3052.17 W 3450.16 243.27 25.00 30.87 62.16 6000.00 57.78 242.10 4051.66 1806.59 S 3426.02 W 3873.16 274.57 27.54 34.78 62.16 6500.00 57.78 242.10 4318.25 2004.51 S 3799.87 W 4296.17 305.88 30.08 38.70 62.15 7000.00 57.78 242.10 4584.84 2202.42 S 4173.72 W 4719.17 337.20 32.62 42.62 62.15 7500.00 57.78 242.10 4851.42 2400.34 S 4547.56 W 5142.17 368.51 35.16 46.55 62.14 7761. 20 57.78 242.10 4990.69 2503.73 S 4742.86 W 5363.15 384.87 36.48 48.60 62.14 7861.20 57.78 242.10 5044.00 2543.31 S 4817.63 W 5447.75 391.14 36.99 49.38 62.14 7992.47 57.78 242.10 5113.99 2595.27 S 4915.78 W 5558.81 399.36 37.66 50.41 62.14 7992.49 57.78 242.10 5114.00 2595.28 S 4915.79 W 5558.82 399.36 37.66 50.41 62.14 8000.00 57.78 242.10 5118.01 2598.25 S 4921.41 W 5565.18 399.83 37.70 50.47 62.14 8123.78 57.78 242.10 5184.00 2647.24 S 5013.96 W 5669.89 407.58 38.33 51.44 62.14 All data is in feet unless otherwise stated. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Vertical section is from wellhead on azimuth 242.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL (,- i . '(, Phillips Alaska, Inc. Drill Site 2P,448 Meltwater,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref: 2P-448 Version#l Last revised: 16-Nov-2001 Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth R E C TAN G U LA R COO R DIN ATE S Vert Sect Ellipse Semi Axes Major Minor Vert. Minor Azi. 8180.04 8323.78 57.78 57.78 242.10 242.10 5214.00 5290.64 2669.52 S 2726.41 S 5056.03 W 5163.50 W 5717.50 5839.10 411.11 420.11 38.61 39.34 51.88 53.01 62.14 62.14 POSITION UNCERTAINTY SUMMARY ============================== Depth From To Survey Tool Error Model Position Uncertainty Major Minor Vert. ---------------------------------------------------------------------------------------------------- 0 8324 ARCO (H.A) Mag) User specified 420.11 39.34 53.01 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. other. All data is in feet unless otherwise stated. Coordinates from slot #448 and TVD from RKB (Doyon 141) (252.00 Ft above mean sea Bottom hole distance is 5839.10 on azimuth 242.17 degrees from wellhead. Vertical section is from wellhead on azimuth 242.17 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ level) . ORIGINAL t- ~. Phillips Alaska, Inc. Drill 5ite 2P,448 Meltwater,North 5lope, Alaska PROPO5AL LI5TING Page 3 Your ref: 2P-448 Version#l Last revised: 16-Nov-2001 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 400.00 400.00 0.00 N 0.00 E KOP 900.00 897.47 19.08 5 39.12 W Begin Build/Turn 1488.18 1452.00 104.97 5 207.46 W Base Permafrost 1977.72 1852.00 234.63 5 455.53 W Base W5ak 2492.87 2181.77 418.38 5 803.76 W EOC 2999.72 2452.00 619.00 5 1182.73W 7 5/8" Casing Pt 3112.25 2512.00 663.54 5 1266.87 W C-80 4050.04 3012.00 1034.75 5 1968.04 W C-50 4725.24 3372.00 1302.01 5 2472.89W C-40 5081. 60 3562.00 1443.07 5 2739.34 W C-37 7761.20 4990.69 2503.73 5 4742.86 W Casing X-Over 7861.20 5044.00 2543.31 5 4817.63 W T3(Top Bermuda) 7992.47 5113.99 2595.27 5 4915.78W Target - Bermuda MidPt 7992.49 5114.00 2595.28 5 4915.79 W MW(A) Rvsd 24 May 01 8123.78 5184.00 2647.24 5 5013.96W T2(Base Bermuda) 8180.04 5214.00 2669.52 5 5056.03 W C35 8323.78 5290.64 2726.41 5 5163.50 W TO - Casing pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE O.OOE 8323.78 2999.72 5290.64 2452.00 2726.415 619.005 5163.50W 1182.73W 3 1/2" Liner 7 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- MW(A) Rvsd 24 May 01 438608.000,5866301.000,999.00 5114.00 2595.285 4915.79W 22-Feb-2001 ORIGINAL , { { 2P-448 Drillinq Hazards Summar'l (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan for further discussion of these risks) Surface CasinQ Interval Event Risk Level Conductor Broach Low Well Collision Low G ravel and sand Low slou hin Shaker/Trough Cuttings Low S stem Overflow Permafrost Hydrates Low Shoe Fracture/Lost Returns during cement .ob Low Interval Risks Miti ation Strate Monitor cellar continuousl durin interval. Careful well planning and surveying, adherence to anti-collision olic Elevated mud viscosity from spud; Hi dens swee s. Controlled ROP Controlled drilling, reduced pump rates, higher mud weights, cold mix water and mud, lower viscosities, and lecithin add itions as needed Reduced pump rates, and lightweight tail cement Event Risk Level Mitigation Strategy Lost Circulation in High Good drilling practices. LCM as needed. Bermuda interval Stay within ECD Hardline of 11.1. High ECD and Low Pumping and rotating out on all trips to swabbing if higher reduce swab and barite sag potential. MW is required Hole stability during e- Moderate Emphasis on maintaining mud properties. line runs Clean out runs as needed. Good drilling practices ORIGINAL 2P-448 Drilling Hazards Summary. doc prepared by Pat Reilly 12/04/01 Page 1 of 1 Meltwater 2P-4( J Proposed Completion Schematic Slimhole Base Case - 3-1/2" Completion String 16" 62.6# @ +1- 120' MD Depths are based on Doyon 141 RKB Surface csg. 7-5/8" 29.7# L-80 BTCM +1- 3000' MD I 2452' TVD 121 Pup (Critical) Intermediate csg. 5-1/2" 15.5# L-80 BTCM run CSR to surface +1- 7761' MD 14991 1VD Future Perforations Production csg 3-1/2" 9.3# L-80 EUE8RD TD to CSR +/- 8324' MD I 5291' 1VD ( PHilLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 3-1/2" FMC Gen 5 Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple wI 2.875" No-Go Profile. 3-1/2" x 6' L-80 handling pups installed above and below, EUE8RD set at +1- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple 3-1/2" X 1" Camco 'KBUG-2-9' Mandrels wI DV's and RK latch's (Max. OD 4.725", ID 2.90"), IBT box x box, 3-1/2" X 6' L-80 EUE8RO box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below. Spaced out wI 3-1/2" 9.3# L-80 EUE8RD tubing as follows: GLM# 1VD-RKB MO-RKB GLM Numbers and Spacing To Be Determined 3-1/2" x 1 II Cameo 'KBG-2-9' mandrel wI DCK-3 shear valve and bottom latch (Max. OD 4.725",102.90"), IBT box x box, pinned for 3000 psi shear (casing to tubing differential), 3-1/2" x 6' L-80 EUE8RD box x IBT pin handling pup installed above, 3-1/2" x 6' L-80 IBT pin x EUE8RD pin handling pup installed below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 'CMU' sliding sleeve wI 2.813" Camco No-Go profile, EUE8RD box x pin. 3-1/2" x 6' L-80 EUE8RD handling pups installed above 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 3-1/2" x 12' L-80 EUE8RO handling pup installed above. 3-1/2" x 6' L-80 EUE8RD handling pup below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Baker 80-40 GBH-22 casing seal assembly wI 15' stroke, 3-1/2" L-80 EUE8RD box up, 3-1/2" X 6' L-80 EUE8RD handling pup installed on top Baker Casing Seal Receptacle, 80-40, 5-1/2"BTCM x 3-1/2" EUE8RD Baker 5" OD x 4" ID 17' Seal Bore Extension CSR set at +1- 100' MD above the top of the Bermuda (OR 100' MD ABOVE THE TOP OF THE CAIRN IF THE CAIRN IS PRESENT) ORIGINAL PJR, 11129/01 Schlumbe rger Cem\JADE Preliminary Job Design 7 5/8' Su rface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 12/4/2001 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 350% excess in the permafrost and 45% excess below the permafrost. Top of tail slurry is designed to be 20' below base of permafrost.) Lead Slurry (minimum pump time 177 min.) ASLite @ 10.7 pp~, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%079' 4.44 ft /sk < TOC at Surface Pre\Aous Csg. < 16",62.6#, H-40 grade Welded Connection at 120 ft. MD < Base of Permafrost at 1,488 ft. MD < Top of Tail at 1,508 ft. MD < 7 5/8", 29.7#, L-80 grade BTC, AB Modified in 9 7/8" OH 1D at 3,000 ft. MD (2,452 ft. TVD) . Mark of Schlumberger 0.9513 fe/ft x (120') x 1.00 (no excess) = 0.2148 ft3/ft x (1488" 120') x 4.50 (350% excess) = 0.2148 fe/ft x (1508" 1488') x 1.45 (45% excess) = 114.2 fe + 1322.3 fe+ 6.2 fe = 1442.7 fe /4.44 fe/sk = Round up to 330 sks 114.2 fe 1322.3 fe 6.2 fe 1442.7 fe 324.9 sks Have 220 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry (minimum pump time 134 min.) LiteCRETE @ 12.0 ppg' 2.40 ft3/sk 0.2148 fe/ft x (3000" 1508') x 1.45 (45% excess) = 0.2578 fe/ft x 80' (Shoe Joint) = 464.7 fe + 20.6 fe = 485.3 ft3/ 2.40 fe/sk = Round up to 210 sks 464.7 fe 20.6 fe 485.3 fe 202.2 sks BHST = 58°F, Estimated BHCT = 74°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 100 6 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 40 6.7 16.4 Lead Slurry 6 261 43.5 59.9 Tail Slurry 6 90 15.0 74.9 Drop Top Plug 3.0 77.9 Displacement 6 114 19.0 96.9 Bump Plug 3 20 6.7 103.6 MUD REMOVAL Recommended Mud Properties: 9.7 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 z 17-20, T y z 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL Schlumberger CemvADE Preliminary Job Design 5 1/2' x3 1/2' Production Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: Kuparuk (Meltwater) Client: Phillips Alaska, Inc. Revision Date: 12/4/2001 Prepared by: Kevin Tanner Location: Anchorage, AK Phone: (907) 265-6205 Mobile: (907) 230-6628 email: ktanner@slb.com Volume Calculations and Cement Systems (Volumes are based on 75% excess. Top of tail slurry is designed to be 500' above casing X-over. Tail Slurry (minimum thickening time 136 min.) GasBLOK wI Class G + 053, 0600, 0135, 0800, 0047, 0065, per lab testing @ 15.8 ppg, 1.2 fe/sk Pre\i1ous Csg. < 7 5/8", 29.7#, L-80 grade BTC, AB Modified at 3,000 ft. MD < 51/2", 15.5#, L-80 grade BTC, AB Modified in 63/4" OH < Top of Tail at 7,261 ft. MD < X-o>ver at 7,761 ft. MD < Top of Bermuda Fm. at 7,861 ft. MD < 31/2", 9.3#, L-80 grade EUE, 8re1 Modified in 6 3/4" OH TO at 8,324 ft. MD (5,291 ft. lVD) . Mark of Schlumberger 0.0835 fe/ft x 500' x 1.75 (75% excess) = 0.1817 fe/ft x (8324" 7761 ') x 1.75 (75% excess) = 0.0488 fe/ft x 90' (Shoe Joint) = 73.1 fe + 179 fe + 4.4 fe = 256.5 ft31 1.2 fe/sk = Round up to 220 sks 73.1 fe 179fe 4.4 fe 256.5 fe 213.8 sks BHST = 132°F, Estimated BHCT = 118°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 40 6.7 6.7 Drop Bottom Plug 3.0 9.7 MudPUSH XL 6 40 6.7 16.4 Tail Slurry 6 47 7.8 24.2 Drop Top Plug 3.0 27.2 Displacement 6 169 28.2 55.4 Bump Plug 3 20 6.7 62.1 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: 12.0 ppg MudPUSH* XL, Pv z 19-22, T y z 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ORIGINAL ,// I ./ , ./ " ~ , { ,,\ """ ' , ..( -' . . . . ,'. " , "",,:,:' Phillips Alaska, Inc. P. O. Box 102776 Anchorage, AK 99510-2776 ,", ":",: '" " ",'" ,::;:>:,:,:,::,:,~::~:,\:,'::,,': ,,:,,::, ,,::',,: ,:'::::,:\, :'::,:, '," ':, "" ,', " , ' , , : :', "'" ..," bNE~RÊ):),DOL!J\.R9 "':ÅMÞ" ~NÒ :ÇE~t$. ',..'" ,'" ",'..' , " .'è)f'öXli"ß'4:6 ' .. 12-04-01 * ****-.\,* ****** *100 "DO* To ,the order of: Date Amount STATE OF ALASKA AOGCC 333W, 7TH AVENUE, ANCHORAGE Vaid after 90 days SUITE 1.00 AK ~~') J)./111\() <;!ld..uJ.4Ll "J,:""~~:¡;;';':"':~'! ',:,,!,\" fOf amounts ,over $25;000,0(1. OP,~,åt~: ANI¡:,'R:1Y~ P,"~i'..Cl'<ÌN,,:,~~!'~TS ",~,o:';.;:;"i!i:,¡" "O:."',~: ~:";,:~,, "',": ':'~, III 0 00 0 .0 . :i ~ b II' 1:08 j gO L. 2 b 21: Og gOOD 011' PHILLIP' -J Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY It Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 December 3, 2001 Ms. Cammy Oechsli Taylor Commissioner Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 2P-448 Surface Location: Target Location: Bottom Hole Location: 1022'FNL,1583'FWL,Sec.17,T8N,R7E 1715' FSL, 1576' FWL, Sec. 18,T8N, R7E 1531' FSL, 1230' FWL, Sec. 18,T8N,R7E Dear Commissioner: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 2P-448. This well is using the same bottomhole location as 2P-447 but from a different surface location. The permit to drill for 2P-447 has been approved earlier in the year. A copy is attached. The well will be drilled and completed using Doyon 141. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2P, or hauled to an approved Prudhoe or GKA Class" disposal well. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon Allsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Steve Moothart, Geologist 265-6965 If you have any questions or require further information, please contact Pat Reilly at (907) 265-6048. Sincerely, Chuck Mallary Drilling Engineering Supervisor CL ORIGINAL f .( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERIP ARAGRAPHS TO BE INCLUDED IN TRANSNßTTALLETTER 2 -P~ . ¿( Y<S WELL NAME t:/ì/i' CHECK 1 ST ANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) tI' DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNULAR }HSPOSAL ~NO INJECTION WELL ANNULAR DISPOSAL L-) YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new well bore segment of existing well . Permit No, . API No. . . Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. .. . ANNULUS c . / ~YES+ SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 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. I<Æ ¿i_- WELL PERMIT CHECKLIST COMPANY WELL NAME2¡:? if "PROGRAM: exp - dev --L redrll FIELD & POOL C..", INIT CLASS ~L-" I C/ L GEOL AREA 51L) ADMINISTRATION 1. Pennìt fee attached. . . . . . . . . . . . . . . . . . . . . . . Y No.' 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . / N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . ' N 5. Well located proper distance from drilling unit boundary. .. . / N 6. Well located proper distance from other wells.. . . . . . . . . ' N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . ~' N. 8. If deviated, is wellbóre plat induded.. . . . . . . . . . . . . . ", N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . of N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ." N 11. Permit can be issued without conservation order. . . . . . . . '.: N 12. Permit can.be issued without administrative approval.. . . . " N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N 14. Conductor string provided . . . . . . . . '. . . . . . . . . . N 15. Surface casing proteds all known USDWs. . . . . . . . N 16. CMT vol adequate to drculate on condudor & surf csg. . . . . N 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . . . N 18. CMT will cover all known productive horizons. . . . . '. . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . ' N 20. Adequate tankage or reserve pit.. . . . . . . . .' . . . . . . . N 21. If a re-drill, has a 10-403 for abandonment been approved. . . N Nth 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required. does it meet regula,tions . . . . . . . . . . , N 24. Drilling ,fluid program schematic & equip list adequate. . ~ . 'å... ~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . v-fG" ~ N APPR I Pt:!J~ J ,26. BOPE press rating appropriate; test to !i(}"'C!ëJ 3500 Dsig. , N l/~A ~ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdbwn. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ 30. Permit can be issued w/o hydrogen sulfide measures. . . . ,.'& N 31. Data presented ön potential overpressure zones. . . . . . . ~'t-N/ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . J>d A 'Y N APPR DAr¡=: 33. Seabed condition survey (if off-shore). . . . . . . . . . . ~r Y N ,)0 /2 ,i. ,L"' ( 34. Contact name/phone for weekly progress reports [~eJ9Rrtory only) Y N ANNULAR DISPOSAL35. With proper cementing records. this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface;" , ' (C) will not impair mechanical integrity pf 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 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annuiar COMMISSION: ~Þ8 I~/ ii ~:~A ¡li~/o( '9~s ¿ serv wellbore seg _ann. disposal para req- UNIT# 0/ / I¿,ó ON/OFF SHORE éJ? , L./ I'¿)' ~ - "';, ct" -"') .2...f-~~ V-' '7 j¿, ö~--h~,- ~~ ~")";-)1... 4~,':J-~~' ,(\-'~ ~4:/.,h~?t.~ .ð.IÍ/1 2¡;:;~,r:f?qG z.s. CIS- ( CL "C,l ) ,,1 A ~ ~ . AP~,R ~, A TY-, - /:>l {'I " ENGINEERING c 0 Z 0 -t ~ ::0 ( - -I m - Z -I ,J: GEOLOGY - APPR DATE Y N Y N en :Þ ::0 m » ( Com ments/lnstructions: ¡zJoz D. c:\msoffice\wordian\diana\checklist (rev. 11/01/100) i( ~ Well H ¡story File APPENDIX Infonnation 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 chrono'ogicaHy organize this category of information. ( I:~I i, aOI-~~ OJ 10 7 lo'-! Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 18 09:24:20 2002 Reel Header Service name............ .LISTPE Date.....................02/04/18 Origin...................STS Reel Name................UNKNOWN Continuation Number..... .01 Previous Reel Name.... ...UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date.....................02/04/18 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 2P-448 501032039600 Phillips Alaska, Inc. Sperry-Sun Drilling Services 18-APR-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MWD RUN 2 MWD RUN 4 AK-MM-1l214 AK-MM-1l214 AK-MM-1l214 J. STRAHAN J. PANTER B. ZIEMKE D. PRESNELL D. PRESNELL D. GLADDEN 17 8N 7E 1022 1583 MSL 0) 252.50 225.00 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 110.0 6.750 7.625 2976.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 AND 2 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP, ( ( UTILIZING SCINTILLATION DETECTORS). 4. REAL-TIME SGRD AND SROP DATA ARE PRESENTED FOR RUN 1 (52' - 848'), DUE TO THE FACT THAT THE BHA BECAME STUCK AT ABOUT 2000', AND WAS NOT RETRIEVED. 848' IS THE PLUG-BACK TD. THE COMPLETE RUN 1 DATA SET IS PRESENTED SEPARATELY AS 2P-448 PB1. 5. MWD RUN 3 WAS ABORTED DUE TO A FAILED CASING TEST. 6. MWD RUN 4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR, UTILIZING GEIGER- MUELLER TUBE DETECTORS), ELECTROMAGNETIC WAVE RESISTIVITY - PHASE 4 (EWR4), STABILIZED LITHO-DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN) . 7. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ (PHILLIPS ALASKA) TO R. KALISH (SSDS) DATED 2/18/02, QUOTING AUTHORIZATION FROM GKA GROUP. 8. MWD RUNS 1, 2, AND 4 REPRESENT WELL 2P-448 WITH API# 50-103-20396-00. THIS WELL REACHED A TOTAL DEPTH OF 8663'MD / 5458'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) . CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS ADJUSTED FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN PROCESSING POROSITY LOGS: FIXED HOLE SIZE: MUD WEIGHT: MUD SALINITY: CHLORIDES FORMATION WATER FLUID DENSITY: MATRIX: MATRIX DENSITY: 6.75" 9.6 - 9.65 PPG 26,000 - 32,000 PPM SALINITY: 22,727 PPM CHLORIDES 1.0 G/CM3 SANDSTONE 2.65 G/CM3 $ File Header Service name............ .STSLIB.001 { Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP NCNT FCNT NPHI FET RPD RPM RPS RPX PEF DRHO RHOB $ 1 { clipped curves; all bit runs merged. .5000 START DEPTH 52.0 110.0 2950.5 2950.5 2950.5 2965.0 2965.0 2965.0 2965.0 2965.0 2972.5 2972 . 5 2972.5 STOP DEPTH 8608.0 8663.0 8570.5 8571.5 8570.5 8615.0 8615.0 8615.0 8615.0 8615.0 8586.5 8586.5 8586.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO 1 2 4 # REMARKS: MERGED MAIN PASS. $ MERGE TOP 52.0 848.0 2990.5 MERGE BASE 847.5 2990.5 8663.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 j 11 ~: First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 52 8663 4357.5 17223 52 8663 ROP MWD FT/H 2.34 1812.93 90.9821 17107 110 8663 GR MWD API 27.55 290.42 125.033 17076 52 8608 RPX MWD OHMM 0.76 1395.98 4.83972 11301 2965 8615 RPS MWD OHMM 0.96 593.6 5.20368 11301 2965 8615 RPM MWD OHMM 0.21 1432.52 5.9002 11301 2965 8615 RPD MWD OHMM 0.17 2000 6.51433 11301 2965 8615 FET MWD HOUR 0.38 102.18 1. 50875 11301 2965 8615 NPHI MWD PU-S 11.01 58.29 33.6535 11241 2950.5 8570.5 FCNT MWD CNTS 108.53 968.13 269.796 11243 2950.5 8571.5 NCNT MWD CNTS 13931.9 32402.6 19926.1 11241 2950.5 8570.5 RHOB MWD G/CM 1.897 3.472 2.38046 11229 2972 . 5 8586.5 DRHO MWD G/CM -0.068 1.039 0.0457911 11229 2972 .5 8586.5 PEF MWD BARN 1. 77 7.05 2.47943 11229 2972.5 8586.5 First Reading For Entire File......... .52 Last Reading For Entire File.......... .8663 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 52.0 110.0 STOP DEPTH 847.5 847.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 23-DEC-01 Insite 66.16 Real-Time 848.0 110.0 848.0 .0 40.5 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE TOOL NUMBER PB02375HAW4 ,if ( $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: EZ-Mud 9.60 68.0 8.9 26000 3.8 .000 .000 .000 .000 .0 95.3 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........ ..........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point... .......... .Undefined Frame Spacing.....................60 .lIN Max frames per record............ .Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 52 847.5 449.75 1592 52 847.5 ROP MWD010 FT/H 2.34 435.84 137.311 1476 110 847.5 GR MWD010 API 27.55 275.52 79.6024 1555 52 847.5 First Reading For Entire File......... .52 Last Reading For Entire File.......... .847.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... (' Version Number.......... .1.0.0 Date of Generation..... ..02/04/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP GR $ 3 " i{ header data for each bit run in separate files. 2 .5000 START DEPTH 848.0 848.0 STOP DEPTH 2990.5 2927.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value......................-999 29-DEC-01 Insite 66.16 Memory 2990.0 848.0 2990.0 8.9 58.8 TOOL NUMBER PB02375HAW4 9.875 EZ-Mud 9.60 56.0 9.0 27000 5.0 .000 .000 .000 .000 .0 95.3 .0 .0 ( ( Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 848 2990.5 1919.25 4286 848 2990.5 ROP MWD020 FT/H 6.75 1812.93 116.769 4286 848 2990.5 GR MWD020 API 42.06 290.42 104.545 4159 848 2927 First Reading For Entire File......... .848 Last Reading For Entire File.......... .2990.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR NCNT FCNT NPHI FET RPD RPM RPS RPX DRHO RHOB PEF ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 2927.5 2950.5 2950.5 2950.5 2965.0 2965.0 2965.0 2965.0 2965.0 2972.5 2972.5 2972.5 2991. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): STOP DEPTH 8608.0 8570.5 8571.5 8570.5 8615.0 8615.0 8615.0 8615.0 8615.0 8586.5 8586.5 8586.5 8663.0 07-JAN-02 Insite 66.16 Memory 8663.0 2990.0 { BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 SLD CTN $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 STABILIZED LITHO DEN COMP THERMAL NEUTRON # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O ( 8663.0 56.0 60.1 TOOL NUMBER PB02375HAW4 PB02375HAW4 PB02375HAW4 PB02375HAW4 6.750 2976.0 EZ-Mud 9.60 46.0 9.4 32000 4.8 .130 .081 .070 .240 70.0 116.6 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 Name Service Unit DEPT FT ROP MWD040 FT/H Min 2927.5 3.36 Max 8663 209.76 Mean Nsam 5795.25 11472 75.2126 11345 First Reading 2927.5 2991 Last Reading 8663 8663 ( { GR MWD040 API 60.65 258.48 138.75 113 62 2927.5 8608 RPX MWD040 OHMM 0.76 1395.98 4.83972 11301 2965 8615 RPS MWD040 OHMM 0.96 593.6 5.20368 11301 2965 8615 RPM MWD040 OHMM 0.21 1432.52 5.9002 11301 2965 8615 RPD MWD040 OHMM 0.17 2000 6.51433 11301 2965 8615 FET MWD040 HOUR 0.38 102.18 1. 50874 11301 2965 8615 NPHI MWD040 PU-S 11.01 58.29 33.6535 11241 2950.5 8570.5 FCNT MWD040 CNTS 108.53 968.13 269.796 11243 2950.5 8571.5 NCNT MWD040 CNTS 13931.9 32402.6 19926.1 11241 2950.5 8570.5 RHOB MWD040 G/CM 1. 897 3.472 2.38046 11229 2972.5 8586.5 DRHO MWD040 G/CM -0.068 1.039 0.0457911 11229 2972.5 8586.5 PEF MWD040 BARN 1. 77 7.05 2.47943 11229 2972.5 8586.5 First Reading For Entire File......... .2927.5 Last Reading For Entire File.......... .8663 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/04/18 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date.....................02/04/18 Origin...................STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.....................02/04/18 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File