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Home My WebLink About203-134 Image ~ject Well History File c!er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. J 03 - ~ 3 LJ- Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: b I (Count does ;nclude CO/Shee,) Page Count Matches Number in Scannirg pr?taration: V YES BY: ( Maria) Date: I d- 13 os- I If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided 11111111111" 111111 RESCAN -I Color Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, NolType: o Poor Quality Originals: D Other: NOTES: BY: ~ Maria ) Date: J d- 13 fJ :5' Project Proofing BY: ~ Maria) Date: ~ 1-3 ()S' , :J.- x 30 = J 09 + Date: lJ-, J.3 /os- Scanning Preparation BY: ~ Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 11111111I111111I11I OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: vwP 1111111111111111111 mP 151 151 = TOTAL PAGES 00 (Count does not include cover slÍeet)1I\A. P 151 , n 1111111111111111111 151 NO Y\1P YES NO 151 1111111111111111111 1111111111111111111 151 Quality Checked 11111111111I1111111 10/6/2005 Well History File Cover Page. doc • ,..~~-~ MICROFILMED 43/01 /2008 DO NOT PLACE ~,~} y.. Ye fi:. ~~ - ~" ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc q Ò~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031340 Well Name/No. KUPARUK RIV U WSAK 1B-101L1 Operator CONOCOPHILLlPS ALASKA INC >(J~ 31 ~~r API No. 50-029-23173-60-00 MD 12197 / TVD 3659 "'" Completion Date 9/9/2003"--- Completion Status 1-01L REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: GR/Res Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No ~ D Las 12198 I nd uction/Resistivity ~D D Pdf 12198 Induction/Resistivity ~ 12198 I nd uction/Resistivity ~ Directional Survey ¡V/t> ~ rv.b Blu Well Cores/Samples Information: Name Interval Start Stop Received Sent ADDITIONAL INFORM~ON Well Cored? Y W Chips Received? ~ Analysis ~ Received? Daily History Received? Formation Tops _._._--~.~- Comments: -~ ...J-o -~ Compliance Reviewed By: Current Status 1-01L UIC N Directional s~ Yes ~ _ (data taken from Logs Portion of Master Well Data Maint Interval OH/ . Start Stop CH Received Comments 3090 12197 Open 10/2/2003 Multiple Propagation Resistivity - Gamma Ray 3090 12197 Open 1 0/2/2003 Multiple Propagation Resistivity - Gamma Ray 3090 12197 Open 10/2/2003 Multiple Propagation Resistivity - Gamma Ray 6846 12197 11/20/2003 Sample Set Number Comments '(ÐN (j)N . ._---~ Date: ~_-]). - ~ ~_)- -- .. Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells Conoc;pJ,illips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 December 5, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 I Subject: Well Completion Report for 1 B-1 01 I 1 B-1 01 L 1 (APD # 203-133/203-134) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 B-1 01 and 1 B-1 01 L 1. If you have any questions regarding this matter, please contact me at 265-6830 or Steve McKeever at 265-6826. Sincerely, ~\~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT Iskad RECEIVED DEC 11 Z003 Alaska 0;1 & Gas Cons. Commission Anchorage ü~~\G'NAL . STATE OF ALASKA _ ALA OIL AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged 0 Abandoned 0 Suspended 0 WAG 0 20AAC 25.105 20AAC 25.110 Gas U 1a. Well Status: Oil [2] 1b. Well Class: Development [2] Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: GINJ 0 2. Operator Name: o WDSPL 0 WINJ No. of Completions _ Other 5. Date Comp., Susp., or Aband.: September 9, 2003 6. Date Spudded: August 31,2003 7. Date TD Reached: September 3, 2003 8. KB Elevation (It): RKB 28' I 88' AMSL 9. Plug Back Depth (MD + TVD): 12197' MD I 3659' TVD 10. Total Depth (MD + TVD): , 12197' MD 13659' TVD f 203-1341 13. API Number: 50-029-23173-60 14. Well Name and Number: 1B-101L1 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 502' FNL, 210' FEL, Sec. 9, T11N, R10E, UM At Top Productive Horizon: 227' FNL, 953' FEL, Sec. 10, T11N, R10E, UM Total Depth: 251' FNL, 1900' FEL, Sec. 3, T11 N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x - 550229 y- TPI: x- 554764 y- Total Depth: x- 553771 y- 18. Directional Survey: Yes [2] No 0 16. Property Designation: ADL 25648 5969647 5969953 5975202 Zone- 4 Zone-4 Zone-4 11. Depth where SSSV set: SSSV @ 2665' 17. Land Use Permit: ALK 466 19. Water Depth, if Offshore: NIA feet MSL 20. Thickness of Permafrost: 1668' 21. Logs Run: GRlRes 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 148' Surface 3080' Surface 6849' 6847' 12173' CASING SIZE WT. PER FT. 62.5# 45.5# 1 40.5# 29.7# 12.6# GRADE H-40 L-80 I J-55 L-80 L-80 HOLE SIZE 24" 13.5" 9.875" 6.75" CEMENTING RECORD AMOUNT PULLED 16" 132 sx ArcticCrete 10.75" 7.625" 675 sx AS III Lite, 285 sx Class G 755 sx Class G 4.5" slotted liner 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): TUBING RECORD DEPTH SET (MD) 6830' 24. SIZE PACKER SET (MD) 6172' 4.5" slotted liner 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NIA NIA 26. Date First Production November 21, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Flowing - shares production with 1 B-1 01 Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 1992 455 0 31% 252 OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 2583 651 not available CORE DATA 11/27/2003 Flow Tubing press. 246 psi 27. 18 hours Casing Pressure 1002 Test Period --> Calculated 24-Hour Rate -> Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RECEIVED DEC 11 2003 Alaska Oil & Gas Cons. Commission Anchorage r('\,:'1,:~:;'t:~~~~.". . 1 ,..;:,.;\:.;' '..ë:- I;...;." ~ L~h'n: . j .J¡c¿;¿..Q3: ¡ ~,jC'':¡:::~1' , '~__._ ~~...._~__.._~~_,. î :".>.-.-.-:", ....._..,-''''.~'......--'''',-~..<. NONE fØIIS BfLœeU,it& ~ f.pJ 'S¡.: 'r' Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE OR1Gll~I-\L 28. GEOLOGIC MARKERS. 29. . FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1B-101L1 West Sak D West Sak D 6848' 8787' 3656' 3662' NIA RECEIVED DEC 11 2003 Alaska Oil & Gas Cons. Commission Anchorage 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve McKeever @ 265-6826 Printed N~ "'- . 1~.ThO~ Signature '- ~ \ ~. Title: ~hone Kuparuk Drillina Team Leader Z-bS- 6~ 3û Date t ~J s Ið ~ 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 OqfG'~jAL . Page 1 of 10 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 B-1 01 Common Well Name: 1 B-1 01 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date FT' H . Cd: Sub ¡ Phase rom - o! ours ¡ 0 e : Code! ....-.... . - -..." 8/15/2003 02:00 - 02:30 0.50 MOVE MOVE MOVE 02:30 - 03:30 1.00 MOVE MOVE MOVE 03:30 - 06:30 3.00 MOVE MOVE MOVE 06:30 - 07:30 1.00 MOVE MOVE MOVE 07:30 - 08:30 1.00 MOVE MOVE MOVE 08:30 - 09:30 1.00 MOVE MOVE RIGUP 09:30 - 10:30 1.00 MOVE OTHR RIGUP 10:30 - 12:30 2.00 WELCTL NUND RIGUP 12:30 - 14:00 1.50 RIGMNT RSRV RIGUP 14:00 - 15:30 1.50 RIGMNT RSRV RIGUP 15:30 - 16:00 0.50 RIGMNT RSRV RIGUP 16:00 - 17:30 1.50 DRILL PULD SURFAC 17:30 - 18:00 0.50 DRILL PULD SURFAC 18:00 - 20:00 2.00 DRILL PULD SURFAC 20:00 - 20:30 0.50 DRILL OTHR SURFAC 20:30 - 21 :00 0.50 DRILL DRLG SURFAC 21 :00 - 22:45 1.75 DRILL DRLG SURFAC 22:45 - 23:15 0.50 DRILL SURV SURFAC 23:15 - 00:00 0.75 DRILL DRLG SURFAC 8/16/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC 12:00 - 00:00 12.00 DRILL DRLG SURFAC 8/17/2003 00:00 - 06:00 6.00 DRILL DRLG SURFAC 06:00 - 07:00 1.00 DRILL CIRC SURFAC 07:00 - 08:30 1.50 DRILL REAM SURFAC 08:30 - 09:00 0.50 DRILL REAM SURFAC 09:00 - 09:15 0.25 DRI LL REAM SURFAC 09:15 - 09:30 0.25 DRILL REAM SURFAC 09:30 - 10:45 1.25 DRILL REAM SURFAC 10:45 - 11 :00 0.25 DRILL OBSV SURFAC 11 :00 - 12:00 1.00 DRILL REAM SURFAC 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 13:30 1.00 DRILL PULD SURFAC 13:30 - 13:45 0.25 DRILL PULD SURFAC 13:45 - 14:30 0.75 DRILL TRIP SURFAC 14:30 - 15:45 1.25 DRILL REAM SURFAC 15:45 - 17:00 1.25 DRILL TRIP SURFAC 17:00 - 18:15 1.25 DRILL PULD SURFAC 18:15-19:00 0.75 DRILL TRIP SURFAC 19:00-19:15 0.25 DRILL SURV SURFAC Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations .. .-.. .-.,..--.... . . Move pipe shed and rock washer. Move Modules and sub off of well 1 B-1 02. Prep gravel pad and NU 21 1/4" annular preventer. Spot sub over well1B-101. Spot pits, motors, boiler modules. (RIG ACCEPTED @ 0830 HRS 8/15/03) Spot pipe shed and rock washer. Complete rig acceptance checklist and mix spud mud. NU knife valve and cement flange and riser. Cut drlg. line, adjust and inspect brakes. Change out saver sub. Service top drive, fix service loop D-rings. PU 5" HWDP, jar, DC's, Stand back in derrick. PU surface rotary tools. MU BHA 1, Bit, motor, pony sub,mwd, xo, ubho. Orient. Flood conductor, check f/leaks. RU slickline for gyro. Drill ice from 122-148. 2115 hrs. Drill Surface from 148 to 257. Gyro survey and connection. Drill from 257 to 300. TVD 300. ADT 0.0 AST 0.3. Drilled from 300 to 1258. ART 1.0, AST 5.2, ADT 6.2. PU 56-90, SO 56-88. PU and SO values were consistent with TO and Drag model. Pump pressure 820 - 1550 psi. Mud pump #1 down for 1.5 hr. The BHA had difficulty holding angle. Drilled from 1258 to 2557. ART 2.3, AST 5.3, ADT 7.6. PU 90-100, SO 56-88. PU and SO values were consistent with TO and Drag model. Pump pressure 1550 - 1800 psi. Drilled from 255 - 3090. 2208 TVD. AST 1.2 ADT 4.0. PU 98-102, SO 79-84. PU and SO values were consistent with TO and Drag model. Pump pressure 1575 - 1825 psi. Pump sweep surface to surface. 600 gpm, 1550 psi. Backream to 1760 @ 30'/min. 140 spm, 80 rpm. At 1760 hole unloading. Continue to backream to 1700 at reduced speed of 10'/min while cleaning hole-2000 strokes. Turned off pumps and rotary. Slacked off from 1700 - 1755, hole took weight. PU, brought on pumps and rotary, attempted to ream through (bridge?) Worked down to 1785. Bridge did not appear to go away. Oriented toolface, wash and work down to 1817. Hole still taking weight and stalling motor. Plan forward-TOOH, PU hole opener. Backream out to BHA @ 1075 @ 30'/min. Flow check, POOH two stands, 15k overpull. Backream BHA out 215. Stand back HWDP, jars, DC's. LD BHA 1. MU BHA 2 (Hole opener) RIH to 1817. tag and set down 30k. Ream from 1817 to 1820. 140 spm, 140 rpm, 1150 psi, 3k TO, 95 PU, 84 SO. Unable to go further. Plan forward-TOOH, PU BHA 3 - motor assembly. TOOH, LD BHA 2 - hole opener. MU BHA 3, bit, motor, pony, MWD, 3 DC's. RIH to 1820. Survey & orient Hi side to attempt lost hole re-entry. New survey was Printed: 10/10/2003 1 :22:00 PM -- Page 2 of 10 ConocoPhillips Alaska Operations Summary Report 0.25 DRILL SURV SURFAC taken @ 1754 (Inc = 47.03, Azimuth = 103.82). The closest original hole survey was taken @ 1759 (Inc = 50.16, Azimuth = 103.96). The drilling assembly is now 3 degrees below the original hole at approximately the same MD. Drilled from 1820 to 2363. 1915 TVD. ART 1.4 AST 1.1 ADT 2.5. Drill fl 2363' to 3090' TVD 2203' AST = 1.3 hrs, ART = 4.2 hrs, ADT = 5.5 hrs, UP 103K, DN 78K, ROT 87K, WOB 15/20K, RPM 90, TO 6K onl 5K off, GPM 680 @ 2250 PSI Pump Hi-vis weighted sweep around, Stand back 1 stand every 45 min. to 2831', Pump 2nd sweep around due to high cuttings load on shakers. Back ream out to 1890' wi 595 GPM @ 1700 psi, 80 RPM Pump out to HWDP due to swabbing, POOH to BHA @ 191' Lay down BHA, Jars, 3- DC's, MWD, Motor, Clear & clean rig floor Rig to run 10-3/4' casing, PJSM with all personal. Run 10-3/4' csg. to 2105' pipe stopped, Wash csg f/2105' to 2192' w/3 bpm @ 300 psi, Run csg to 2244', Wash csg. f/2244' to 2290', Casing circulating good wi full returns, UP 120K, DN 70K Ran 103/4' csg from 2,290' to 3,040' PU Landing Jt & Hanger and Est Circ, Pull master bushing and cont circ hole at 6 bpm at 300 psi (Circ 400 bbls) LD Landing it & hanger, damaged pin end on pup jt below hanger, LD Jt # 71 due to damaged box, Replaced with new jt of csg, LD Franks Fill Up tool, sent hanger to Baker to replace pup it on hanger Circ & cond mud for cementing, lowered YP from 34 to 12 and Mw from 9.2 ppg to 9.1 ppg, circ & reciprocated csg at 6 bpm at 200 psi, Pu wt 130K, Dn wt 100K LD Jt used to circ hole, PU Landing JT & Hanger & landed csg, MU Cement Head, Ran a total of 56 Jts 2,414.37' of 10 3/4', 40.5# L-80 BTC csg with float equip followed by 15 its, 633.24' of 103/4' 45.5# L-80 BTC csg (71 Jts total), Landed csg with float shoe at 3,079' and float collar at 2,990'. 1.00 CEMENTCIRC SURFAC Cont to circ & cond mud for cementing, held PJSM with Dowell, APC vac truck drivers & rig crew on cementing csg, circ & reciprocated pipe at 6 bpm at 200 psi 2.00 CEMENT PUMP SURFAC Switch over to Dowell, Pump 5 bbls CW100, Test cement lines to 3000 psi. Pump 45 bbls CW100, 50 bbls Mudpush XL @ 10.5ppg. Drop bottom plug. Pump 513.5 bbls Lead cement, AS Lite III (675sx, yield 4.28) @ 10.7 ppg. Pump 60 bbls (285 sx, yield 1.16) Tail cement, class 'G' @ 15.8 ppg. Shut down 1.00 CEMENT DISP SURFAC Drop top plug, Pump 20 bbls H20. Switch to rig & displace cement with rig pumps @ 6 PBM. Slowed displacement rate to 3 PBM last 20 bbls of displacement. Bump plug with 269.7 bbls of 9.1 ppg mud (FCP 500 psi @ 3 bpm.) Pressure up to 1100 psi, bleed off pressure & check floats, Ck Ok. Had 150 bbls of 10.7 ppg cmt back at surface, CIP @ 1300 hrs 08/19/2003. Note; lost returns when cement went out the shoe for approximately 10 bbls then regained full returns. Reciprocated casing until 450 bbls Lead cement pumped. Reciprocation was 15' stroke @ 20 fpm. 0.50 CASE DEOT SURFAC Tested 103/4" csg to 2,500 psi for 15 min, pressure dropped 200 psi in 10 min, no test 1.00 CASE RURD SURFAC LD Landing Jt, RD Doyon's Csg equipment & cleared rig floor 2.00 WELCTL NUND SURFAC Flushed out divertor & ND same 1.00 WELCTL NUND SURFAC NU Vetco Gray 11" 5M Gen 1 Horizontal wellhead, tested seals to Legal Well Name: 18-101 Common Well Name: 18-101 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To ! Hours COde! îo~e! Phase . -...,.--.,..,..- .. . ..... ..._ ....____ - _.. _,_,__u . . 8/17/2003 19:00 - 19:15 19:15 - 00:00 4.75 DRILL DRLG SURFAC 8/18/2003 00:00 - 08:45 8.75 DRILL DRLG SURFAC 08:45 - 12:00 3.25 DRILL CIRC SURFAC 12:00 - 13:30 1.50 DRILL TRIP SURFAC 13:30 - 15:15 1.75 DRILL TRIP SURFAC 15:15 - 17:30 2.25 DRILL PULD SURFAC 17:30 - 19:00 1.50 CASE RURD SURFAC 19:00 - 00:00 5.00 CASE RUNC SURFAC 8/19/2003 00:00 - 01 :00 1.00 CASE RUNC SURFAC 01 :00 - 03:00 2.00 CASE CIRC SURFAC 03:00 - 05:00 2.00 CASE RURD SURFAC 05:00 - 08:00 3.00 CASE CIRC SURFAC 08:00 - 09:00 1.00 CASE RURD SURFAC 09:00 - 10:00 10:00 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 16:30 16:30 - 17:30 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations _. .. .......__... __. ....u.... __.. _., n____.. -... ---.--- ...--..-.........-.-. -.. . - -. Printed: 10/10/2003 1 :22:00 PM . . Page 3 of 10 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/19/2003 8/20/2003 8/21/2003 8/22/2003 8/23/2003 18-101 18-101 ROT - DRILLING Start: 8/15/2003 n1334@ppco.com Rig Release: 9/9/2003 Doyon 141 Rig Number: . .... '. .,.,. > .. ...., "SUb'· ".' ..'., . . . ·Hóllr~:,~~Code?ib()d~~1 ijlfhase' '. . 5,000 psi for 10 min NU 135/8" BOP stack Installed test plug & RU to test BOP's Testing rams, manifold and valves to 250 psi low and 5,000 psi high. NOTE: John Crisp with AOGCC waived witnessing of BOP test Fin testing BOP's, tested blind rams to 250 psi low & 5,000 psi high, tested annular to 250 psi low & 3,500 psi high, performed accumulator test, pulled test plug & installed wear bushing Installed riser, elevator bales and PU 5" handling tools PU & RIH with 30 jts of 5" DP, POOH & stood back PU 97/8" Bit #3 & MU BHA #4 with 6 3/4" Autotrak and TIH to 1,100'. Had to pull wear bushing to run BHA, installed wear bushing after MU ghost reamer, tested Autotrak tool at 1,100' & Ck Ok TIH with BHA #4 from 1,100' to 2,837' PU 5" DP from pipe shed Est Circ washed down & took Ck shot survey at 2,916', RIH & tagged up at 2,985', (FC @ 2,990') Fin circ 1 complete hole volume, 8.8 ppg mw in & out, rot wt 87K, pu wt 105K, dn wt 72K, circ at 500 gpm at 500 psi and 60 rpm's RU & tested 103/4" csg to 2,500 psi for 30 min, good test Drilled out float collar at 2,990', drilled firm cmt in shoe, drilled float shoe at 3,079' and cleaned out to TD at 3,090', drilled fit equip with 80 rpm's, 3-5K wob, 510 gpm at 1,000 psi Drilled 20' of new formation from 3,090' to 3,110', ADT .10 hrs, started displacing hole with clean 9.1 ppg mud Fin circ 9.1 ppg mud in & out Performed FIT to 13.9 ppg EMW with 9.1 ppg mud at 2,200' TVD and 550 psi. Downlinked and initialized Autotrak tool Drilled 9 7/8" hole from 3,110' to 3,670' MD/2,449' TVD (560'), ADT 3.6 hrs, 5-10K wob, 100 rpm's, 142 spm, 600 gpm, 1,850 psi, off btm torque 4K ft-Ibs, on btm 6K ft-Ibs, rot wt 93K, pu wt 128K, dn wt 73K, 12.00 DRILL DRLG INTRM1 Drilled 9 7/8" hole per directional plan from 3,670' to 4,783' MD/2,909' TVD (1,113'), ADT 7.4 hrs, 2-10K wob, 110-130 rpm's, 150 spm, 640 gpm, 2,100 psi, off btm torque 10K ft-Ibs, on btm 12K ft-Ibs, rot wt 103K, up wt 170K, dn wt 73K, 9.1 ppg mwand 86 vis, pumped wt'd hi vis sweep 2#'s over mw and had 30% increase in cuttings back 12.00 DRILL DRLG INTRM1 Drilled from 4,783' to 5,619' MD/3,265' TVD (836'), ADT 8.5 hrs, 5-10K wob, 130 rpm's, 153 spm, 653 gpm, 2,300 psi, off btm torque 12K ft-Ibs, on btm 14K ft-Ibs, rot wt 107K, up wt 182K, dn wt 73K, 9.1 ppg mw and 83 vis, began adding 5 sxslhr Mix IIlcm while drlg Ugnu and pumped wt'd hi vis sweeps with 0-20% increase in cuttings 12.00 DRILL DRLG INTRM1 Drilled 9 7/8' hole per directional plan from 5,619' to 6,511' MD/3,591' TVD (892'), ADT 7.9 hrs, 2-10K wob, 130 rpm's, 150 spm, 634 gpm, 2,400 psi, off btm torque 12.5K ft-Ibs, on btm 14K ft-Ibs, rot wt 114K, up wt 155K, dn wt 83K, raised mw from 9.1 to 9.6 ppg per plan, Est top of K-13 6,401' MD/3,557' TVD 12.00 DRILL DRLG INTRM1 Drilled from 6,511' to 7,291' MD/3,750' TVD (780'), ADT 7.4 hrs, 5-10K wob, 140 rpm's, 155 spm, 657 gpm, 2,725 psi, off btm torque 14K ft-Ibs, on btm 15K ft-Ibs, rot wt 113K, up wt 159K, dn wt 83K, pumped wt'd hi vis sweeps with 30-40% increase in cuttings, est top of West Sak "D' at 6,848' MD/3,682' TVD 1.50 DRILL DRLG INTRM1 Drilled from 7,291' to 7,395' MD/3,761, TVD (104'), ADT 0.9 hrs, 5-10K wob, 150 rpm's, 155 spm, 657 gpm, 2,800 psi, off btm torque 14K ft-Ibs, . . .. .. . ... .......... . "-: -< .. ~ ... :":-::.:..::'. , "fromiitfo . '" 16:30 -17:30 1.00 WELCTL NUND SURFAC 17:30 - 20:30 3.00 WELCTL NUND SURFAC 20:30 - 21 :00 0.50 WELCTL OTHR SURFAC 21 :00 - 00:00 3.00 WELCTL BOPE SURFAC 00:00-01:15 1.25 WELCTL BOPE SURFAC 01:15 - 02:00 0.75 DRILL OTHR SURFAC 02:00 - 03:00 1.00 DRILL PULD SURFAC 03:00 - 07:30 4.50 DRILL TRIP SURFAC 07:30 - 10:30 3.00 DRILL TRIP SURFAC 10:30 - 11 :30 1.00 DRILL REAM SURFAC 11 :30 - 12:00 0.50 DRILL CIRC SURFAC 12:00 - 13:00 1.00 DRILL DEOT SURFAC 13:00 - 16:00 3.00 CEMENT DSHO SURFAC 16:00 - 16:15 0.25 DRILL DRLG SURFAC 16:15 - 16:45 0.50 DRILL CIRC SURFAC 16:45 - 17:30 0.75 DRILL FIT SURFAC 17:30 - 18:00 0.50 DRILL DEOT INTRM1 18:00 - 00:00 6.00 DRILL DRLG INTRM1 00:00 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 01 :30 Spud Date: 8/15/2003 End: Group: ':i::\:;,I:::r>/gescription of.OperatiOhS ......:::.';;;.-..: Printed: 10/10/2003 1 :22:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To - -. . ...-.- .. . 8/23/2003 00:00 - 01 :30 01 :30 - 03:00 03:00 - 04:15 04:15 - 04:45 04:45 - 07:00 . . Page 4 of 10 ConocoPhillips Alaska Operations Summary Report 18-101 1 8-1 01 ROT - DRILLING n1334@ppco.com Doyon 141 . ! Sub i Hours Code! Code I Phase : .... --...- .... . Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations . ............. ..--- ..........-.-- ---..... -. . . ..-.. -.--..-. .-- 1.50 DRILL DRLG INTRM1 on btm 15K ft-Ibs, rot wt 114K, up wt 170K, dn wt 80K, 9.7 ppg mw, Est top of West Sak "B" at 7,315' MD/3,756' TVD 1.50 DRILL CIRC INTRM1 Pumped wt'd hi vis sweep (2# over mw) and circ a total of 2 btms up, 10% increase in cuttings from sweep, circ at 654 gpm at 2,825 psi and 150 rpm's 1.25 DRILL WIPR INTRM1 Monitored well-static, POOH 10 stds from 7,395' to 6,480', ave 25K drag, hole did not take calc fill, no other problems POOH 0.50 DRILL WIPR INTRM1 TIH from 6,480' to 7,325', washed 70' to btm with no problems 2.25 DRILL CIRC INTRM1 Circ Btms up after wiper trip, had large amount of cuttings back at btms up, no increase in chlorides, pumped wt'd hi vis sweep and saw no increase in cuttings, circ at 654 gpm, 2,850 psi 150 rpm's and 14K ft-Ibs torque, up wt 170K, dn 80K Monitored well - static, backreamed out 15 stds from 7,395' to 5,990' with no problems, circ a 634 gpm, 2,700 psi and 130 rpm's, Circ btms up from 5,990' after backreaming out, had a large amount of cuttings back at btms up, circ a total of 2.5 btms up Monitored well-static, POOH wet 10 stds, hole took calc fill, pumped dry job and POOH to 3,020', (csg shoe) with no problems Monitored well at shoe-static, POOH LD 63 jts 5" DP, POOH to BHA at 1,073' Pulled wear bushing, LD ghost reamer, HWDP, jars, flex dc's, downloaded Autotrak tool & fin LD BHA #4 Changed out top set of rams to 7 5/8" csg rams Tested door seals to 250 psi low and 3,500 psi, good test RU doyon's 7 5/8" 350 ton csg equipment, changed out elevator bales and MU Franks fill up tool Held PJSM with casing operator & rig crew on running 7 5/8" csg MU 7 5/8" float shoe, 2 jts-7 5/8" 29.7#, L-80 BTC-Mod csg and 7 5/8" float collar, thread locked conn below fit collar and pumped thru fit equip & ck ok, cont PU & RIH with 75/8" csg to 3,018', Ran a total of 25 centralizers & stop rings per well program Circ 1 csg cap at 3,018', inside 103/4" csg shoe, circ at 5 bpm at 280 psi, up wt 98K, dn wt 65K RIH with add 59 jts of 7 5/8" 29.7#, L-80, BTC-Mod csg to 5,535' (130 jts total) Circ 1 annulus cap from 5,535' at 5 bpm at 700 psi, up wt 145K, dn wt 65K Fin RIH with 7 5/8" csg, MU landing jt and hanger & landed csg, no problems RIH, landed 7 5/8" csg at 7,389' MD/3,761, TVD with fit collar at 7,299', Ran a total of 172 jts and 2-pup jts of 7 5/8", 29.7#, L-80, BTC-Mod csg (7,361.79') 0.50 CASE RURD INTRM1 RD Franks fill up tool & MU Dowell's cement head 3.25 CEMENT CIRC INTRM1 Circ & cond mud for cementing, lowered YP to 15 and YP to 13 with 9.6 ppg mud, staged pumps up to 6 bpm at 475 psi, reciprocated pipe, up wt 21 OK, dn wt 65K, held PJSM with Dowell, APC and rig crew on cementing csg 1.50 CEMENT PUMP INTRM1 Switch over to Dowell, Pump 5 bbls CW100, Test cement lines to 3500 psi. Pump 45 bbls CW100, 50 bbls Mudpush XL @ 10.5ppg. Drop bottom plug. Pump 165.8 bbls, 756 sxs Tail cement, class 'G' @ 15.8 ppg and 1.17 yield with add. Ave 6 bpm at 250 psi 1.25 CEMENT DISP INTRM1 Drop top plug, Pump 20 bbls H20. Switch to rig & displace cement with rig pumps @ 6 BPM. Slowed displacement rate to 3 PBM last 20 bbls of displacement. Bump plug with 308.2 bbls of 9.6 ppg mud (3,092 07:00 - 09:15 2.25 DRILL REAM INTRM1 09:15 - 10:30 1.25 DRILL CIRC INTRM1 10:30 - 12:45 2.25 DRILL TRIP INTRM1 12:45 - 14:00 1.25 DRILL PULD INTRM1 14:00 - 17:15 3.25 DRILL PULD INTRM1 17:15 - 18:15 1.00 WELCTL EORP INTRM1 18:15 - 18:45 0.50 WELCTL BOPE INTRM1 18:45 - 19:30 0.75 CASE RURD INTRM1 19:30 - 19:45 0.25 CASE SFTY INTRM1 19:45 - 00:00 4.25 CASE RUNC INTRM1 8/24/2003 00:00 - 00:30 0.50 CASE CIRC INTRM1 00:30 - 02:45 2.25 CASE RUNC INTRM1 02:45 - 03:30 0.75 CASE CIRC INTRM1 03:30 - 05:15 1.75 CASE RUNC INTRM1 05:15 - 05:45 05:45 - 09:00 09:00 - 10:30 10:30 - 11 :45 Printed: 10/10/2003 1 :22:00 PM -~. - - ConocoPhillips Alaska Operations Summary Report 1.25 CEMENTDISP INTRM1 strokes) (FCP 610 psi @ 3 bpm.) Pressure up to 1100 psi for 5 minutes, bleed off pressure & check floats- Ok. CIP @ 1133 hrs 08/24/2003. Est T.O.C. 4,500' Note; lost returns when MUDPUSH went out the shoe for approximately 5 bbls then regained full retums. Reciprocated casing throughout cement job. Reciprocation was 20' stroke @ 20 fpm, decreasing to 5' stroke length. RU & tested 7 5/8" csg to 3,000 psi for 30 min, good test Closed annular preventer and pumped 10 bbls of 9.6 ppg mud down 7 5/8" x 103/4" annulus to clear csg shoe, pumped at 1/2 bpm at 510 psi RD cement head, Doyon's cag equipment, LD landing jt, RU 5" elevator & bales Set 7 5/8" pack-off, RILDS, energized & tested to 5,000 psi for 15 min, ckok Changed out btm set of 5" rams to 4" and changed top set of 7 5/8" csg rams over to 3 1/2' x 6" VBR's Changed over top drive saver sub, grabbers, stabbing guide and pipe handler to 4" DP, PU 4" handling tools and set test plug RU & began testing BOP rams, valves & choke manifold to 250 psi low and 5,000 psi high, while testing choke manifold, 11' 5M flange between csg head & 11" x 13 5/8' 5M DSA leaked, made several attempts to tighten with no success Drained stack, LD test jt & ND stack, removed ring gasket and emery clothed ring groove on btm of DSA, (had some pitting) Changed out ring gasket on 11" 5M flange between csg head & DSA, NU Stack Fin testing BOP's, Rams, valves & choke manifold to 250 psi low & 5,000 psi high, annular to 250 psi low & 3,500 psi high, Jeff Jones with AOGCC witnessed test, pulled test plug & installed wear bushing Installed riser, turnbuckles and mousehole LD 47 stds (141 jts) of 5' DP from derrick in mousehole PU 54 stds 4' 14# XT 39 DP (162 jts) & RIH, MU 4' LoTads, 1/std (54 total), while RIH POOH & stood back 54 stds 4" DP MU 6 3/4" BHA #5 on bit #4, orient & program MWD, RIH to 251' and surface test MWD TIH with BHA #5 PU 4" DP, TIH to 4,457' Cont TIH with BHA #5 PU 4' DP to 6,793' Cut & Slip 60' of Drlg Line, Serviced top drive and drawworks TIH from 6,793' to 7,260', washed down from 7,260' and tagged float collar at 7,299' Drilled plugs, float collar at 7,299', med-firm cement in shoe track, drilled float shoe at 7,389', cleaned out to TD at 7,395', drilled 20' of new formation to 7,415', ART 0.1 hrs, 5-10K wob, 60 rpm's, 260 gpm at 1,650 psi, rot wt 83K, up wt 130K, dn wt 63K Changed over 9.6 mud in hole to new 9.6 ppg Flo Pro mud Performed F.I.T. to 13.0 ppg EMW with 9.6 ppg mw at 3,761' TVD at 675 psi Performed base line PWD test Drill, slide & survey 6 3/4" hole from 7,415 to 7,620' MD/3,767' TVD, (205') ART 2.3 hrs, AST 0.2 hrs, 2-10K wob, 110 rpm's, 66 spm, 280 gpm's, 1,700 psi, off btm torque 7K ft-Ibs, on btm 7.5K ft-Ibs, rot wt 84K, up wt 135K, dn wt 55K, 9.6 ppg mw, ave ECD 11.0 ppg Legal Well Name: 18-101 Common Well Name: 18-101 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 i .' i Sub ¡ Date ! From - To : Hours. Code Code ¡ Phase . ---.--...... 8/24/2003 10:30 - 11 :45 11 :45 - 12:30 0.75 CASE DEOT INTRM1 12:30 - 13:00 0.50 CASE OTHR INTRM1 13:00 - 14:30 1.50 CASE RURD INTRM1 14:30 - 16:00 1.50 CASE OTHR INTRM1 16:00·18:00 2.00 WELCTL EORP INTRM1 18:00 - 20:00 2.00 DRILL RIRD INTRM1 20:00 - 22:30 2.50 WELCTL BOPE INTRM1 22:30 - 00:00 1.50 RIGMNT RGRP INTRM1 8/25/2003 00:00 - 01 :30 1.50 RIGMNT RGRP INTRM1 01 :30 - 04:30 3.00 WELCTL BOPE INTRM1 04:30 - 05:30 1.00 DRILL RIRD INTRM1 05:30 - 09:30 4.00 DRILL PULD INTRM1 09:30·15:45 6.25 DRILL PULD INTRM1 15:45 -18:30 2.75 DRILL TRIP INTRM1 18:30 - 20:30 2.00 DRILL PULD INTRM1 20:30 - 00:00 3.50 DRILL TRIP INTRM1 8/26/2003 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 03:00 1.50 RIGMNT RSRV INTRM1 03:00 - 03:30 0.50 DRILL TRIP INTRM1 03:30 - 05:30 2.00 CEMENT DSHO INTRM1 05:30 - 07:00 1.50 DRILL CIRC INTRM1 07:00 - 07:45 0.75 DRILL FIT INTRM1 07:45 - 08:15 0.50 DRILL CIRC PROD 08:15 - 12:00 3.75 DRILL DRLG PROD Page 5 of 10 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations .....--...-..... ... .._,...._..._._..__._.___ _n... _.. Printed: 10/10/2003 1 :22:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . Page 6 of 10 ConocoPhillips Alaska Operations Summary Report 1B-101 1 B-1 01 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Date .": .:..". . -:~:... S b :'From '~To HoutS l'òb.dß .~ b¿ad~·' Phase Description of Operations 8/26/2003 12:00 - 00:00 8/27/2003 00:00 - 12:00 12:00 - 00:00 8/28/2003 00:00 - 09:00 09:00 - 09:30 09:30 - 17:15 17:15 - 18:30 18:30 - 20:45 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 9.00 DRILL DRLG PROD 0.50 RIGMNT RGRP PROD 7.75 DRILL DRLG PROD 1.25 DRILL TRIP PROD 2.25 DRILL DRLG PROD 20:45 - 21 :30 0.75 DRILL CIRC PROD 21 :30 - 21 :45 0.25 DRILL OSSV PROD 21 :45 - 00:00 2.25 DRILL REAM PROD 8/29/2003 00:00 - 03:45 3.75 DRILL REAM PROD 03:45 - 04:30 0.75 DRILL CIRC PROD 04:30 - 04:45 0.25 DRILL OSSV PROD 04:45 - 05:15 0.50 DRILL TRIP PROD 05:15 - 09:45 4.50 DRILL TRIP PROD 09:45 - 12:00 2.25 DRILL TRIP PROD Drill, slide & survey 6 3/4" hole from 7,620' to 8,628' MD/3,760' TVD, (1,008') ART 4.7 hrs, AST 1.18 hrs, 2-5K wob, 115 rpm's, 66 spm, 280 gpm's, 1,850 psi, off btm torque 8K ft-Ibs, on btm 8K ft-Ibs, rot wt 84K, up wt 130K, dn wt 52K, 9.6 ppg mw, ave ECD 11.2 ppg Drill, slide & survey 6 3/4" hole from 8,628' to 9,596' MD/3,755' TVD (968') ART 6.6 hrs, AST 1.2 hrs, 3-5K wob, 115 rpm's, 66 spm, 280 gpm, 2,000 psi, off btm torque 8.5K ft-Ibs, on btm 8.5K ft-Ibs, rot wt 85K, up wt 128K, dn wt 53K, 9.6 ppg mw, ave ECD 11.4 ppg with 2% Lubricants Drill, slide & survey 6 3/4' hole from 9,596' to 10,563' MD/3,742' TVD (967') ART 5.4 hrs, AST 1.5 hrs, 2-10K wob, 115 rpm's, 71 spm, 300 gpm, 2,250 psi, off btm torque 7K ft-Ibs, on btm 7K ft-Ibs, rot wt 84K, up wt 125K, dn wt 58 K, 9.6 ppg mw, ave ECD 11.4 ppg with 3% Lubricants Drilled 6 3/4" Hole from 10,563 to 11,288' MD, (725') ART 4.3 hrs, AST 1.2 hrs, 2-15K wob, 115 rpm's, 71 spm, 300 gpm, off btm press 2,350 psi, on btm 2,500 psi, off btm torque 8.5K ft-Ibs, on btm 8.5K ft-Ibs, rot wt 86K, up wt 126K, dn wt 55K Replaced ring gasket in mudline unibolt flange. Derrickman did great job in catching leak possibly preventing a spill! Drilled from 11,288' to 12,013', (725') ART 4 hrs, AST 0.5 hrs, 2-6K wob, 115 rpm's, 300 gpm, off btm press 2,375 psi, on btm 2,500 psi, on & off btm torque 9K ft-Ibs, rot wt 84K, up wt 133K, dn wt 43K, 9.6 ppg mw, ave ECD 11.6 ppg, ave bgg 35 units Sackreamed out 3 stds to 11,726', MU 3 stds of 4' WT pipe to TD well & TIH NOTE: Corrected TVD's per new survey data, EST Top of West Sak "D" 6,848' MD/3,655' TVD West Sak 'S", 7,310' MD/3,726' TVD Drilled from 12,013' to 12,230' MD/3,713' TVD, Lower Lateral T.D., (217') ART 1.0 hrs, AST 0.4 hrs, 2-6K wob, 115 rpm's, 71 spm, 300 gpm, off btm press 2,500 psi, on btm 2,675 psi, on & off btm torque 9K ft-Ibs, rot wt 89K, up wt 140K, dn wt 48K, mw 9.6 ppg, MST's 4.5, ave ECD 11.5 ppg, ave bgg 36 units Circ btms up at 300 gpm, 2,600 psi, off btm torque 8.5K Monitored well-static Sackreaming out from 12,230' to 10,663' to run 4.5" liner, backreaming out at 300 gpm, 2,500 psi, 115 rpm's Sackreamed out from 10,663' to 7,398' (75/8" csg shoe) circ at 300 gpm at 1,850 psi, 115 rpm's with 4K ft-Ibs torque, no problems backreaming Circ 2 btms up and clean at shakers, circ at 300 gpm at 1,900 psi and 100 rpm's, no increase in cuttings at btms up Monitored well 15 min-static POOH 4 stds and hole didn't take calc fill, swabbing inside of csg. Pumped out of hole to 6,014', monitored well-static, worked pipe and still wanting to swab, cant to pump out of hole to 3,878', monitored well at 5,110' and 4,600' and still swabbing, monitored well at 5,110 & 4,600' and well-static POOH on elevators, hole taking calc fill, pumped slug at 2,000', POOH to SHA Printed: 10/10/2003 1 :22:00 PM -- ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1 B-1 01 1 B-1 01 ROT - DRILLING n1334@ppco.com Doyon 141 ¡ . Sub I From - To : Hours Code. Code! Phase . ....... .. ... . ...._.......... I . ...... .. 12:00 -13:15 1.25 DRILL PULD PROD 8/29/2003 13:15 - 15:00 15:00 - 15:30 15:30 - 20:30 1.75 DRILL 0.50 CASE 5.00 CASE PULD PROD RURD CMPL TN PULR CMPL TN 20:30 - 22:15 1.75 CASE RUNL CMPL TN 22: 15 - 22:30 0.25 CASE CIRC CMPL TN 22:30 - 00:00 1.50 CASE RUNL CMPL TN 8/30/2003 00:00 - 02:00 2.00 CASE RUNL CMPL TN 02:00 - 03:45 1.75 CASE RUNL CMPL TN 03:45 - 05:00 1.25 CASE CIRC CMPL TN 05:00 - 05:30 0.50 CASE RUNL CMPL TN 05:30 - 07:30 2.00 CASE CIRC CMPL TN 07:30 - 09:30 2.00 CASE RUNL CMPL TN 09:30 - 12:30 3.00 CASE RUNL CMPL TN 12:30 - 14:30 2.00 WINDOWPULD CMPL TN 14:30 - 15:00 0.50 WINDOWOTHR CMPL TN 15:00 - 17:00 2.00 WINDOWTRIP CMPL TN 17:00 - 20:00 3.00 WINDOWTRIP CMPL TN 20:00 - 20:30 0.50 WINDOWOTHR CMPL TN 20:30 - 21 :00 0.50 WINDOWTRIP CMPL TN 21 :00 - 21 :45 0.75 WINDOWSETW CMPL TN 21 :45 - 00:00 2.25 WINDOWSTWP CMPL TN 8/31/2003 00:00 - 02:30 2.50 WINDOWSTWP CMPL TN 02:30 - 03:15 0.75 WINDOWCIRC CMPL TN Page 7 of 10 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations .__u ._,..... __.__ .... ... ...__.__... Stood back std of flex dc's, download MWD, LD MWD, muud motor & bit PU 6 stds of 4' hwdp & stood back RU Doyon's 4 1/2' handling tools and held PJSM on running liner PU & ran 173 jts of 41/2' 12.6# L-80 NSCT liner, ran 77 jts of slotted and 96 jts of blank liner, MU Baker 4 1/2' x 7 5/8' SC-1 R Packer Assembly. Overall liner & packer length 5,348.7', used 171 41/2' x 6 1/4' spiral guide centralizers RIH with liner & packer on 20 stds of 4' DP to 7,295' Circ 1 DP volume at csg shoe, circ at 3 bpm at 400 psi, up wt 90K, dn wt 72K, rotated at 10 rpm's with 3K ft-Ibs torque and 78K rot wt RIH with add 23 stds of 4' DP (43 total) with liner & packer to 9,513' with no problems and good retums, up wt 100K, dn wt 66K, Note: 1st 54 stds 4" DP to have LoTads Fin RIH with 41/2' liner on 4' DP from 9,513', tagged btm at 12,230', no problems RIH with liner, string wt up 112K, dn wt 65K Dropped 29/32" ball and pumped down, ball on seat after 62 bbls, staged pressure up to 3,100 psi to set SC-1 R pkr, slacked off, PU & closed annular and tested pkr to 1,000 psi, ck ok, press up to 2,000 and released setting tool, press up on DP to 4,600 psi with test pump and blew ball seat, set SC-1 R pkr at 6,882' with liner set to 12,230'. Note: After dropping ball and after 35 bbls pumped, bgg increased to 200 units and 9.6 ppg mud was gas cut to 8.2 ppg, with ball on seat bgg down to 130 units. Circ 1 complete hole volume at 6 bpm at 975 psi, initial bgg 130 units, 9.6 mud initially gas cut to 9.1, after btms up bgg down to 15 units and had 9.6 in & out. Monitored well, weeped slightly then static after 15 min, POOH 3 stds to 6,530' and didn't take proper fill Circ & raised MW from 9.6 ppg to 9.8 ppg, with 9.8 ppg mud in & out, circ at 8 bpm at 1,200 psi, monitored well-static Pumped out of hole from 6,530' to 5,590' due to well wanting to swab, pumped at 4 bpm at 550 psi. Monitored well-static. Blow down mud line POOH & LD packer setting tool, Note Changed out shock hose and Unibolt flange on mud line on trip out of hole. PU & MU Baker's 7 5/8' btm trip whipstock on BHA #6 with MWD and oriented whipstock Retrieved rabbit from stand of HWDP TIH with whipstock and 9 stds of HWDP to 946', pressure tested mudline to 3,500 psi and pulse tested MWD. TIH slow with whipstock from 946' to 6,280' Log down with MWD from 6,230' to 6,260' and correlated well TIH to 6,823', est circ at 6 bpm at 1,750 psi, up wt 102K, dn wt 77K Oriented whipstock with MWD, set whipstock at 6,882' at 30 deg left with 76 deg angle. Milled window from 6,849' MD/3,756' TVD to 6,852', 2-4K wom, 100 rpm's, 300 gpm at 2,000 psi, off btm torque 3K ft-Ibs, on btm 4K ft-Ibs, rot wt 85K, up wt 103K, dn wt 76K. Top of window at 6,849', planned btm of window at 6,861' (12') Milled window in 7 5/8" Csg from 6,852' to 6,874', Top of window at 6,849', btm of window at 6,861', worked thru window several times with pumps off & ck ok Pumped wt'd hi vis sweep and circ hole clean at 300 gpm at 2,000 psi, Printed: 10/10/2003 1:22:00 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 8/31/2003 02:30 - 03: 15 03:15 - 05:45 05:45 - 08:00 08:00 - 08:45 08:45 - 13:30 . . ConocoPhillips Alaska Operations Summary Report 18-101 18-101 ROT - DRILLING n1334@ppco.com Doyon 141 ¡ ¡Sub Hours ! Code : Code Phase : . _n. ..... ...__.."'. .., 0.75 WINDOWCIRC CMPL TN 2.50 WINDOWTRIP CMPL TN 2.25 WINDOWPULD CMPL TN 0.75 WINDOWOTHR CMPLTN 4.75 WELCTL BOPE PROD 13:30 - 15:30 2.00 DRILL PULD PROD 15:30 - 18:15 2.75 DRILL TRIP PROD 18:15 - 20:30 2.25 RIGMNT RSRV PROD 20:30 - 20:45 0.25 DRILL OTHR PROD 20:45 - 00:00 3.25 DRILL DRLG PROD 9/1/2003 00:00 - 12:00 12:00 - 00:00 9/2/2003 00:00· 12:00 12:00 - 00:00 9/3/2003 00:00 - 14:00 14:00 - 16:00 16:00 - 21 :30 21 :30 - 21 :45 21 :45 - 00:00 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 12.00 DRILL DRLG PROD 14.00 DRILL DRLG PROD 2.00 DRILL 5.50 DRILL 0.25 DRILL 2.25 DRILL CIRC REAM OBSV CIRC PROD PROD PROD PROD Page 8 of 10 Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations .....-.. ..-.." .. .-..-....,-."". ... .--.-... had 10% increase in cutting from sweep Monitored well-static, pumped dry job & POOH to BHA at 912' Stood back HWDP and LD whipstock mills, top watermelon mill in gauge, RU & Flushed out BOP stack, cleared rig floor, pulled wear bushing & installed test plug RU & tested rams, valves and choke manifold to 250 psi low and 5,000 psi high, tested annular to 250 psi low and 3,500 psi high, good test, pulled test plug & installed wear bushing. Note Chuck Scheve with AOGCC waived witnessing of test MU 63/4" BHA #7 with bit #4RR1, PU MWD & changed out battery and oriented tool. TIH from 251' to 6,742' Cut & Slip 65' of drlg line, serviced top drive, drawworks and changed out swivel packing Oriented BHA to 30 deg left, RIH thru window with no problems Drill, slide & survey 6 3/4" hole from 6,874' to 6,988' MD/3,672' TVD, ART -0-, AST 2 hrs, 2-10K wob, -0- rpm's, 60 spm, 255 gpm, 1,400 psi, up wt 108K, dn wt 72K, max gas while drlg 425 units, 9.6 ppg mud gas cut to 9.3 ppg Drill, slide & survey 6 3/4" hole per geologist from 6,988' to 7,630' MDI 3,676' TVD, (642'), ART 4.7 hrs, AST 3 hrs, 2-15K wob, 110 rpm's, 70 spm, 295 gpm, off btm press 1,650 psi, on btm 1,800 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 11 OK, dn wt 65K, 9.6 ppg MW, ave ECD 11.1 ppg, Ave BGG 200-250 units, max gas 600 units, 9.6 MW, ave gas cut.2 to.3 ppg, displaced hole with new 9.6 ppg Flo Pro mud at 7,126' Drill, slide & survey 6 3/4" hole per geologist from 7,630' to 8,673' MDI 3,661' TVD, (1,043'), ART 5.5 hrs, AST 2.3 hrs, 5-15K wob, 100-105 rpm's, 70 spm, 295 gpm, off btm press 1,750 psi, on btm 1,900 psi, off btm torque 6K ft-Ibs, on btm 6K ft-Ibs, rot wt 85K, up wt 113K, dn wt 62K, 9.6 ppg MW, ave ECD 11.1 ppg, Ave BGG 150- 200 units, max gas 350 units, 9.6 MW, ave gas cut.1 to.2 ppg Drilled from 8673 - 9450. ART 4.5 AST 2.6. 295 gpm 2050 psi. PU(112-122) SO(60-46) ROT(85-83) TO and Drag values are corresponding to the following model friction factors: (15% casing) (30% open hole). The PU and SO values deteriorated 5-10k Ibs between 9200 and 9600 MD. Lubricant concentration was increased from 2-3 % and the values retumed to the original trend line. Drilled from 9450-10704. ART 6.8 AST 1.0. 295 gpm 2400 psi. PU(122-128) SO(46-53) ROT(84-80) TO and Drag values are corresponding to the following model friction factors: (15% casing) (30% open hole). Drilled from 10704 - 12197. ART 7.7 AST 0.5. 295 gpm PP on BTM (2400-2800) PP off BTM (2250-2700). RPM 100. PU(126-145) 50(41-54) ROT(81-95) TO off BTM (7.5-9) TO on BTM (8-9.5) ECD(11.8-12.4) WOB (2-5). TO and Drag values are corresponding to the following model friction factors: (0.15 casing) (0.30 open hole). Circulate sweep, 70 spm, 2800 psi, 115 RPM. Flow check - static. Backream out to 6935, 100 rpm, 70 spm. Flow check - static. POOH across window to 6742. Circ/cond. Rotate/Recip while wt up from 9.6 to 9.8 ppg. 70 spm, 1800 psi, 110 rpm. Printed: 10/10/2003 1:22:00 PM - Page 9 of 10 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 1 B-1 01 1B-101 ROT - DRILLING n1334@ppco.com Doyon 141 Hours ! Code ! 5~Je: Phase I .....,--"._.".... . . ..,..-......... . 9/4/2003 00:00 - 00:30 00:30 - 05:15 05:15 - 07:00 07:00 - 08:00 08:00 - 10:00 10:00 - 10:30 0.50 DRILL CIRC PROD 4.75 DRILL OBSV PROD 1.75 DRILL PULD PROD 1.00 CMPL TN RURD CMPL TN 2.00 CMPLTNTRIP CMPLTN 0.50 CMPL TN OTHR CMPL TN 10:30 - 11 :15 11:15 - 12:00 12:00 - 13:30 0.75 CMPLTN CIRC CMPLTN 0.75 CMPL TN OBSV CMPL TN 1.50 CMPLTNTRIP CMPLTN 13:30 - 14:00 14:00 - 14:45 0.50 CMPLTNTRIP CMPLTN 0.75 CMPLTN CIRC CMPLTN 14:45 - 15:30 0.75 CMPLTN CIRC CMPL TN 15:30 - 16:00 0.50 CMPL TN TRIP CMPL TN 16:00 - 18:00 2.00 CMPL TN TRIP CMPL TN 18:00 - 19:00 1.00 CMPL TN OBSV CMPL TN 19:00 - 19:30 0.50 CMPL TN TRIP CMPL TN 19:30 - 20:30 1.00 CMPL TN CIRC CMPL TN 20:30 - 22:30 2.00 CMPL TN CIRC CMPL TN 22:30 - 00:00 1.50 CMPL TN CMPL TN 9/5/2003 00:00 . 02:30 2.50 CMPL TN TRIP CMPL TN 02:30 - 03:15 0.75 CMPL TN OTHR CMPL TN 03:15 - 04:45 1.50 FISH PULD CMPL TN 04:45 - 05:45 1.00 FISH TRIP CMPL TN 05:45 - 06:30 0.75 FISH CIRC CMPL TN 06:30 - 07:30 1.00 FISH TRIP CMPL TN 07:30 - 09:15 1.75 WELCTL OBSV CMPL TN 09:15 - 13:00 3.75 WELCTL CI RC CMPL TN 13:00 - 13:15 0.25 WELCTL OBSV CMPL TN 13:15 - 15:30 2.25 FISH CIRC CMPL TN 15:30 - 16:30 1.00 FISH CIRC CMPL TN 16:30 - 17:00 0.50 FISH OTHR CMPL TN 17:00 - 18:30 1.50 FISH FISH CMPL TN 18:30 - 21:00 2.50 FISH TRIP CMPL TN 21 :00 - 23:00 2.00 FISH TRIP CMPL TN 23:00 - 00:00 1.00 FISH FISH CMPL TN 9/6/2003 00:00 - 03:30 3.50 CMPL TN TRIP CMPL TN 03:30 - 05:30 2.00 CMPL TN RURD CMPL TN Start: 8/15/2003 Rig Release: 9/9/2003 Rig Number: Spud Date: 8/15/2003 End: Group: Description of Operations . . ...--........ ..--.-- --...... . ... Spot lube pill. Observe well - TOH to 4176 - Pump dry job - TOH to BHA (251' MD). LD drilling BHA. PU whipstock retrieval BHA. TIH to 6854. Hook anchorlseal assy. Observe well. Pulled anchor loose with 77k overpull. Observe well. Circulate BU 6 bpm, 1450 psi. Observe well - TOH to 6660. Continue TOOH to 5710. 10-30 ftImin. Gained 11.5 bbl total - mild swabbing. TIH to 6250, 20 ftImin. CBU, 60 spm, 1475 psi. Very thick gas cut mud to surface @ 1100 stks. (BU strokes, 1870) Continue to circulate. Mud gas cut to 7.4 ppg @ BU. Continue to circulate and condition mud to 9.8 ppg in and out. TIH to 6815. 20 ftImin. Circulate and condition. Stage up to 70 spm, 2000 psi, 3 BU. No very thick mud this time. Flow check, POOH 5 stands to 6350. Gained 4 bbls. TIH to 6815. Circulate and condition. Stage up to 85 spm, 2900 psi. Reciprocate pipe 60' @ 30 ftImin. On bottoms up, mud cut to 7.4 ppg. Circulate and condition @ 60 spm, 1600 psi. Reciprocate pipe 70 ftImin. Condition mud from Yp 34, vis 60, to Yp 28, vis 50. Flow check. POOH 20 ftImin. Work pipe to insure proper hole fill. Continue TOH to 4742. Pump dry job, TOH to BHA (873'). Stand back HWDP, LD hook. (Whip stocK not retrieved) MU box tap over$hot, flex DC's, float sub, 9 stands HWDP. RIH to 3771. Fill pipe, circ and condition @ 6 bpm, 1050 psi. TIH to 6811. Circ and condition @ 7 BPM, 1700 psi. Lost 20 bbls in 5 minutes. Slow pump to 3 bpm. Lost 150 bbl total. Shut down, observe well 30 min. Well breathing. Record slow pump rates. Flow increased. 8 bbl gain. Shut in, monitor pressure, start to circulate out influx through choke @ 30 spm until 9.8 ppg mud all around. Check pressure, open annular, monitor well - static. Circulate and condition, rotate and recip., stage up to 60 spm, 1200 psi, 100 rpm, 3000 ft-Ib torque. Clean anElload pit 5 with 9.8 ppg brine. Pump 20 bbl high vis spacer and displace with 9.8 ppg brine, 75 spm, 1350 psi, 120 rpm, 2500 ft Ib torque. Monitor well - static. Check TQ and drag. Wash down tag top whipstock. Attempt to work box tap over - no success. CBU 75 spm @ 1200 psi. Trip to surface and LD box tap. MU hook, TIH to fish, tag @6856, PU 106, SO 80. Engage fish. Extra 2,000 Ibs on pick up weight. Pump out of hole to 6473. Observe well, continue TOOH on elevators to 873. LD whipstock and BHA. Clear floor in preparation for liner running equipment. Printed: 10/10/2003 1 :22:00 PM . . Page 10 of 10 ConocoPhillips Alaska Operations Summary Report Legal Well Name: 18-101 Common Well Name: 18-101 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 D t I F T· H : C d : Sub ¡ a e ¡rom - 0: ours; 0 e ; Code: Phase 9/6/2003 05:30 - 05:45 0.25 CMPL TN RURD CMPL TN 05:45 - 06:15 0.50 CMPL TN SFTY CMPL TN 06:15-11:15 5.00 CMPL TN RUNT CMPL TN 11:15 -12:00 0.75 CMPLTN RURD CMPL TN 12:00 - 16:45 4.75 CMPLTN RUNT CMPL TN 16:45 - 17:45 1.00 CMPL TN RUNT CMPL TN 17:45 - 19:00 1.25 CMPL TN RUNT CMPL TN 19:00 - 20:30 1.50 CMPLTN CIRC CMPL TN 20:30 - 23:00 2.50 CMPL TN RUNT CMPL TN 23:00 - 00:00 1.00 CMPL TN RUNT CMPL TN 9/7/2003 00:00 - 02:30 2.50 CMPL TN RUNT CMPL TN 02:30 - 03:00 0.50 RIGMNT RSRV CMPL TN 03:00 - 10:30 7.50 CMPL TN TRIP CMPL TN 10:30 - 11 :00 0.50 CMPL TN OTHR CMPL TN 11:00 - 16:00 5.00 CMPL TN TRIP CMPL TN 9/8/2003 16:00 - 16:30 0.50 CMPL TN RURD CMPL TN 16:30 - 18:30 2.00 CMPL TN OTHR CMPL TN 18:30 - 19:30 1.00 RIGMNT RSRV CMPL TN 19:30 - 00:00 4.50 CMPL TN TRIP CMPL TN 00:00 - 00:30 0.50 CMPL TN RURD CMPL TN 00:30 - 02:00 1.50 CMPL TN RURD CMPL TN 02:00 - 12:30 10.50 CMPLTN RUNT CMPL TN 12:30 - 13:15 0.75 CMPL TN RUNT CMPL TN 13:15 - 14:00 0.75 CMPL TN RUNT CMPL TN 14:00 - 14:30 0.50 CMPL TN RUNT CMPL TN 14:30 - 15:00 0.50 CMPL TN RUNT CMPL TN 15:00 - 16:00 1.00 CMPL TN RUNT CMPL TN 16:00 - 17:30 1.50 CMPL TN DEOT CMPL TN 17:30 - 20:00 2.50 CMPL TN DEOT CMPL TN 20:00 - 21 :00 1.00 CMPL TN NUND CMPL TN 21 :00 - 21 :30 0.50 CMPL TN DEOT CMPL TN 21 :30 - 22:00 0.50 CMPL TN DEOT CMPL TN 22:00 - 23:00 1.00 CMPL TN DEOT CMPL TN 23:00 - 00:00 1.00 CMPL TN FRZP CMPL TN 00:00 - 02:30 2.50 CMPL TN FRZP CMPL TN 02:30 - 03:30 1.00 CMPL TN RURD CMPL TN 03:30 - 04:00 0.50 CMPL TN OTHR CMPL TN 9/9/2003 Start: Rig Release: Rig Number: 8/15/2003 9/9/2003 Spud Date: 8/15/2003 End: Group: Description of Operations . - -..,..-.... . ... . ....-- ... ......,.......... ..,.... ......... RU to run 4.5' slotted upper lateral liner. PJSM wi co reps, toolpushers, and rig crew. Run 4.5' liner to 5295. (170 joints) RU to run 2 7/8' inner wash string. Run 2 7/8' inner wash string. Space out work string and MU liner hook hanger assembly. Run liner on DP to 6780. CBU 40 spm, 700 psi. Gas at surface, circulate an additional 1000 stks for a total of 3100 strokes. Flow check, continue running liner. Break circulation 10 stands outside of window. Continue running liner to setting depth of 12,172. Work and rotate string to line up hook hanger per on site Baker representative. Drop setting ball. Weights just above setting depth: (PU 130) (SO 71). Continue to pump ball down. Ball on seat @ 640 stks. Pressure up to 2600 psi, release from HR running tool. Pressure up to 3200, blow ball seat. Circulate 1 BU @ 6 bpm, 2275 psi clean brine. Observe well, pump dry job. Service top drive and blocks. TOOH, LD 27 joints HWDP, 186 DP, 55 LoTads. Service running tool. LD inner string swivel and XO. RU to LD 2 7/8' wash string. LD inner wash string. Note: Performed injectivity test on 10.75' x 7.625" annulus with 750 psi 9.6 ppg mud. 2200' TVD = 16.2 EMW. Flushed annulus w/260 bbl fresh water and freeze protected with 130 bbl diesel. RD 2 7/8" equipment and clear floor tools. TIH with 61 stands DP from derrick. Slip and cut drilling line. LD 4" DP. Pull Wear ring and LD same. RU to run 4.5 tubing. PJSM. Run 4.5" 12.6# L-80 IBT mod tubing. Tail at 6830. Pressure tubing V2500 to set packer @ 6172. Hole for 10 min. Unsting and circ clean 9.8 ppg brine. 100 SPM @ 1000 psi. Space out, MU hanger and landing joint. RU TEC and SSSV hanger control lines to hanger. Test lines to 5000 psi. Land tubing. RILDS. Test hanger seals to 5000 for 15 min. Pressure test annulus to 1500, bleeding oft 100 every 10 min. Install TWC. ND BOP. Test annulus to 1500 - No sjJccess. NU tree. Pressure test tubing to 3500 psi to set packer - hold for 10 min. tubing test. Hold 2000 on tubing. Pressure test annulus to 3000 for 10 min. Good test. Bleed tubing to shear RP valve. Install TWC. Test tree to 5000. Pull TWC. Freeze protect with 115 bbls diesel. U-Tube the diesel. Install BPV. NU actuator valve on tree. Secure well. RIG RELEASED 09/09/2003 0400 HRS. Printed: 10/10/2003 1 :22:00 PM · l ~.' = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. Page of 2 .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT IIV.&Q Well Name & No. PAD 1 B/101 PB1/101/101 L1 Survey Section Name Definitive Survey BHI Rep. C MILCHAK I D BALLOU WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO ssO Target Description Target Coord. E/W Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) IS(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F1) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT e- 15-AUG-03 GSS 148.00 0.00 0.00 148.00 148.00 0.00 0.00 0.00 0.00 0.00 15-AUG-03 GSS 168.00 0.50 265.00 20.00 168.00 0.01 -0.01 -0.09 2.50 2.50 15-AUG-03 GSS 258.00 0.30 138.00 90.00 258.00 -0.16 -0.22 -0.32 0.80 -0.22 16-AUG-03 GSS 349.00 1.00 117.00 91.00 348.99 -0.84 -0.75 0.55 0.80 0.77 16-AUG-03 GSS 440.00 2.35 112.00 91.00 439.95 -2.32 -1.81 2.98 1.49 1.48 16-AUG-03 GSS 563.39 6.85 119.66 123.39 562.91 -8.40 -6.41 11.73 3.67 3.65 6.21 MWD SURVEY 16-AUG-03 GSS 621.00 10.00 108.00 57.61 619.90 -12.98 -9.65 19.47 6.19 5.47 -20.24 16-AUG-03 GSS 712.00 11.00 121.00 91.00 709.39 -22.47 -16.57 34.43 2.82 1.10 14.29 16-AUG-03 MWD 837.57 13.12 131.49 125.57 832.19 -41.58 -32.18 55.38 2.42 1.69 8.35 16-AUG-03 MWD 925.27 15.31 127.51 87.70 917.20 -57.99 -45.83 72.02 2.73 2.50 -4.54 16-AUG-03 MWD 1016.16 15.45 126.76 90.89 1004.84 -75.75 -60.38 91.24 0.27 0.15 -0.83 16-AUG-03 MWD 1107.80 18.46 126.46 91.64 1092.49 -95.26 -76.31 112.69 3.29 3.28 -0.33 16-AUG-03 MWD 1201 .39 23.44 119.78 93.59 1179.87 -118.07 -94.37 140.79 5.89 5.32 -7.14 -= 16-AUG-03 MWD 1294.27 26.13 113.42 92.88 1264.21 -141.34 -111.69 175.60 4.07 2.90 -6.85 16-AUG-03 MWD 1387.43 30.33 108.76 93.16 1346.28 -164.18 -127.41 216.72 5.09 4.51 -5.00 16-AUG-03 MWD 1482.04 35.74 106.11 94.61 1425.57 -188.11 -142.77 265.93 5.92 5.72 -2.80 16-AUG-03 MWD 1572.07 40.47 106.48 90.03 1496.39 -213.00 -158.37 319.24 5.26 5.25 0.41 16-AUG-03 MWD 1665.65 44.78 104.97 93.58 1565.23 -240.78 -175.51 380.23 4.73 4.61 -1.61 16-AUG-03 MWD 1759.13 50.16 103.96 93.48 1628.40 -269.63 -192.68 446.91 5.81 5.76 -1.08 16-AUG-03 MWD 1852.25 56.45 103.71 93.12 1684.02 -300.16 -210.52 519.38 6.76 6.75 -0.27 16-AUG-03 MWD 1943.90 62.40 104.00 91.65 1730.61 -332.46 -229.41 595.95 6.50 6.49 0.32 16-AUG-03 MWD 2036.74 67.03 103.29 92.84 1770.26 -366.54 -249.20 677.51 5.03 4.99 -0.76 16-AUG-03 MWD 2128.73 64.06 105.29 91.99 1808.34 -401 .39 -269.85 758.64 3.79 -3.23 2.17 ..-- .L-.... ~ JL--' -----., II--) i...---J L-J -L--J L . . .. = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. Page 2 of 2 - . I . Company CONOCOPHILUPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT INrEQ. Well Name & No. PAD 1B/101PB1/101/101L1 Survey Section Name Definitive Survey BHI Rep. C MILCHAK I D BALLOU WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLD ssD Target Description Target Coord. EJW Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 16-AUG-03 MWD 2221.73 65.24 104.16 93.00 1848.16 -436.97 -291 .21 839.93 1.68 1.27 -1.22 16-AUG-03 MWD 2314.82 65.03 104.75 93.09 1887.30 -472.36 -312.29 921.71 0.62 -0.23 0.63 -= 16-AUG-03 MWD 2407.31 67.35 104.33 92.49 1924.64 -507.93 -333.53 1003.62 2.54 2.51 -0.45 16-AUG-03 MWD 2500.51 66.03 102.82 93.20 1961.52 -542.60 -353.62 1086.81 2.05 -1.42 -1.62 17-AUG-03 MWD 2593.98 64.42 104.13 93.47 2000.69 -576.83 -373.39 1169.34 2.14 -1.72 1.40 17 -AUG-03 MWD 2685.77 66.61 105.27 91.79 2038.73 -612.17 -394.59 1250.13 2.64 2.39 1.24 17-AUG-03 MWD 2779.01 67.08 102.24 93.24 2075.40 -647.13 -414.97 1333.39 3.03 0.50 -3.25 17-AUG-03 MWD 2872.58 64.99 103.46 93.57 2113.40 -680.76 -433.98 1416.75 2.53 -2.23 1.30 17-AUG-03 MWD 2965.21 64.45 103.42 92.63 2152.96 -714.51 -453.45 1498.21 0.58 -0.58 -0.04 17·AUG-03 MWD 3035.64 64.75 104.23 70.43 2183.17 -740.53 -468.65 1559.99 1.12 0.43 1.15 17-AUG-03 MWD 3090.00 64.75 104.23 54.36 2206.36 -760.96 -480.74 1607.65 0.00 0.00 0.00 Projected Data - NO SURVEY -e- - L--I L.J L.J LJ L-.I l....--J --------- ---I ------- ----\11 ----= ~ ~-¡¡¡ ......-~ I ~.J;i¡ I '- ___Ii ~.iI. _ì Q SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 1 of 5 - .. . Company CONOCOPHILLlPS ALASKA. INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT 'IV. à:Q Well Name & No. PAD lBll0l PBl 1101 1101Ll Survey Section Name 1 B-l01 MWD BHI Rep. C MILCHAK I D BALLOU WELL DATA Target 1VD (F1) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLD SSD Target Description Target Coord. EIW Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DD) Builcl\Walk\DL per: 10Oft~ 30mD lOmD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Inc!. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 1VD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (F1) (DD) (DD) (F1) (FT) (F1) (F1) (Per 100 F1) Drop (-) Left (-) MWD 1665.65 44.78 104.97 1565.23 -241.09 -175.51 380.23 TIE IN POINT e- 17-AUG-03 MWD 1754.06 47.03 105.17 88.41 1626.75 -268.Q1 -192.02 441.54 2.55 2.54 0.23 17-AUG-03 MWD 1847.26 50.32 105.02 93.20 1688.28 -298.05 -210.24 509.10 3.53 3.53 -0.16 17 -AUG-03 MWD 1940.41 60.71 105.20 93.15 1740.95 -330.98 -230.24 583.13 11.16 11.15 0.19 17-AUG-03 MWD 2033.97 64.01 105.01 93.56 1784.35 -366.55 -251.83 663.14 3.53 3.53 -0.20 17 -AUG-03 MWD 2126.17 68.86 104.62 92.20 1821 .20 -402.43 -273.43 744.81 5.27 5.26 -0.42 17-AUG-03 MWD 2219.38 67.11 105.09 93.21 1856.13 -439.19 -295.58 82.ß.34 1.93 -1.88 0.50 17 -AUG-03 MWD 2310.95 65.81 105.52 91.57 1892.71 -475.50 -317.74 909.31 1.48 -1.42 0.47 18-AUG-03 MWD 2404.74 68.27 103.21 93.79 1929.29 -511.54 -339.14 992.96 3.47 2.62 -2.46 18-AUG-03 MWD 2497.75 66.63 103.84 93.01 1964.96 -546.26 -359.23 1076.47 1.87 -1.76 0.68 18-AUG-03 MWD 2590.79 66.30 102.99 93.04 2002.1 1 -580.60 -379.02 1159.44 0.91 -0.35 -0.91 18-AUG-03 MWD 2683.61 66.99 103.64 92.82 2038.91 -614.76 -398.65 1242.37 0.98 0.74 0.70 18-AUG-03 MWD 2776.37 66.60 103.57 92.76 2075.46 -649.34 -418.70 1325.23 0.43 -0.42 -0.08 18-AUG-03 MWD 2869.85 66.25 103.76 93.48 2112.85 -684.16 -438.94 1408.48 0.42 -0.37 0.20 .- 18-AUG-03 MWD 2962.17 65.25 104.36 92.32 2150.76 -718.91 -459.39 1490.13 1.23 -1.08 0.65 18-AUG-03 MWD 3031.87 65.67 105.65 69.70 2179.71 -746.03 -475.80 1551.37 1.79 0.60 1.85 2O-AUG-03 MWD 3157.37 65.42 102.02 125.50 2231 .68 -792.77 -503.12 1662.27 2.64 -0.20 -2.89 20-AUG-03 MWD 3250.88 65.26 103.03 93.51 2270.70 -825.76 -521 .55 1745.23 1.00 -0.17 1.08 2O-AUG-03 MWD 3343.91 65.26 103.35 93.03 2309.63 -859.47 -540.83 1827.49 0.31 0.00 0.34 2O-AUG-03 MWD 3436.84 65.38 103.71 92.93 2348.43 -893.61 -560.58 1909.59 0.37 0.13 0.39 20-AUG-03 MWD 3529.84 65.28 103.50 93.00 2387.25 -927.88 -580.46 1991.73 0.23 -0.11 -0.23 2O-AUG-03 MWD 3622.71 65.65 102.50 92.87 2425.82 -961.33 -599.47 2074.05 1.06 0.40 -1.08 21-AUG-03 MWD 3715.15 67.63 101.12 92.44 2462.47 -993.29 -616.82 2157.11 2.54 2.14 -1.49 21-AUG-03 MWD 3807.83 68.92 97.53 92.68 2496.78 -1022.21 -630.76 2242.05 3.86 1.39 -3.87 . " & ß I R ~ l ¡ L , ; I l , LJ L-.J L...J L-.J L--A L---A, ~ t !' ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 2 of 5 - - - . I . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT INja:Q Well Name & No. PAD 1B/101PB1 1101 1101L1 Survey Section Name 18-101 MWD BHI Rep. C MILcHAK I D BALLOU WELL DATA Target rvD (F1) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL 0 ssO Target Description Target Coord. EIW Slot Coord. EIW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 10Oft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (per 100 FT) Drop (-) Left (-) 21-AUG-03 MWD 3901.55 70.07 95.89 93.72 2529.62 -1047.92 -641 .01 2329.23 2.05 1.23 -1.75 -- 21-AUG-03 MWD 4011.56 69.24 93.36 t 1 0.01 2567.87 -1074.52 -649.33 2432.03 2.28 -0.75 -2.30 21-AUG-03 MWD 4087.41 66.47 91.60 75.85 2596.46 -1090.09 -652.38 2502.21 4.24 -3.65 -2.32 21-AUG-03 MWD 4179.85 64.95 91.81 92.44 2634.48 -1107.65 -654.89 2586.42 1.66 -1.64 0.23 21-AUG-03 MWD 4272.29 63.82 91.03 92.44 2674.45 -1124.61 -656.96 2669.75 1.44 -1.22 -0.84 21-AUG-03 MWD 4365.85 63.85 90.92 93.56 2715.70 -1141.06 -658.39 2753.71 0.11 0.03 -0.12 21-AUG-03 MWD 4458.58 63.70 91.04 92.73 2756.68 -1157.35 -659.81 2836.88 0.20 -0.16 0.13 21-AUG-03 MWD 4551.52 63.79 91.54 92.94 2797.79 -1174.13 -661.69 2920.21 0.49 0.10 0.54 21-AUG-03 MWD 4644.14 63.72 90.51 92.62 2838.75 -1190.47 -663.17 3003.27 1.00 -0.08 -1.11 21-AUG-03 MWD 4736.00 65.36 90.53 91.86 2878.24 -1206.07 -663.93 3086.20 1.79 1.79 0.02 21-AUG-03 MWD 4829.07 65.26 91.37 93.07 2917.12 -1222.59 -665.33 3170.75 0.83 -0.11 0.90 21-AUG-03 MWD 4922.07 65.33 90.29 93.00 2955.99 -1238.93 -666.55 3255.23 1.06 0.08 ·1.16 21-AUG-03 MWD 5015.20 65.18 89.87 93.13 2994.97 -1254.20 -666.67 3339.81 0.44 -0.16 -0.45 e- 21-AUG-03 MWD 5108.07 65.13 91.21 92.87 3033.99 -1270.08 -667.46 3424.08 1.31 -0.05 1.44 21-AUG-03 MWD 5200.58 65.20 90.17 92.51 3072.85 -1286.11 -668.47 3508.02 1.02 0.08 -1.12 21-AUG-03 MWD 5293.56 65.18 84.99 92.98 3111 .88 -1297.71 -664.91 3592.31 5.06 -0.02 -5.57 21-AUG-03 MWD 5386.89 65.35 79.79 93.33 3150.96 -1301.71 -653.69 3676.29 5.06 0.18 -5.57 21-AUG-03 MWD 5479.69 65.36 74.68 92.80 3189.68 -1298.11 -635.06 3758.51 5.00 0.01 -5.51 21·AUG-03 MWD 5572.67 65.30 69.89 92.98 3228.50 -1287.24 -609.36 3838.97 4.68 -0.06 -5.15 22·AUG-03 MWD 5665.76 65.29 65.20 93.09 3267.43 -1269.47 -577.07 3917.10 4.58 -0.01 -5.04 22-AUG-03 MWD 5758.28 65.23 63.02 92.52 3306.15 -1246.92 -540.38 3992.69 2.14 -0.06 -2.36 22-AUG-03 MWD 5852.25 66.83 59.47 93.97 3344.34 -1219.76 -499.07 4067.94 3.85 1.70 -3.78 22-AUG-03 MWD 5944.37 67.86 53.89 92.12 3379.84 -1186.54 -452.39 4138.93 5.70 1.12 -6.06 22·AUG-03 MWD 6037.15 68.93 46.66 92.78 3414.04 -1144.21 -397.29 4205.21 7.34 1.15 -7.79 -----.J L...J I L--.J L.J L.J L.....J L.....J ~ ~ ~. ~ ER SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page~ of ~ ~ Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1 B/101 PB1/101/101 L1 Survey Section Name 1 B-1 01 MWD BHI Rep. C MILCHAK I D BALLOU '1\ Ere: WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. E/W Slot Coord. E/W -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Build\Walk\DL per: 100ft~ 30mO 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DO) (DO) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 22-AUG-03 MWD 6130.11 68.71 42.45 92.96 3447.64 -1094.35 -335.54 4266.00 4.23 -0.24 -4.53 . 22-AUG-03 MWD 6223.24 69.77 38.65 93.13 3480.66 -1039.40 -269.38 4322.60 3.98 1.14 -4.08 22-AUG-03 MWD 6316.17 72.38 36.02 92.93 3510.81 -980.19 -199.49 4375.89 3.88 2.81 -2.83 22-AUG-03 MWD 6408.78 73.01 31.38 92.61 3538.37 -916.62 -125.95 4424.92 4.83 0.68 -5.01 22-AUG-03 MWD 6501.72 74.14 25.66 92.94 3564.67 -847.21 -47.65 4467.46 6.03 1.22 -6.15 22-AUG-03 MWD 6594.39 74.86 18.00 92.67 3589.47 -771.67 35.17 4500.62 8.00 0.78 -8.27 22-AUG-Q3 MWD 6687.40 74.67 10.49 93.01 3613.94 -690.11 122.08 4522.69 7.79 -0.20 -8.07 22-AUG-03 MWD 6780.53 74.97 3.28 93.13 3638.36 -604.32 211 .25 4533.45 7.48 0.32 -7.74 22-AUG-03 MWD 6846.60 75.52 2.67 66.07 3655.18 -542.14 275.06 4536.77 1.22 0.83 -0.92 22-AUG-03 MWD 6873.19 75.66 2.52 26.59 3661 .80 -517.04 300.78 4537.94 0.76 0.53 -0.56 22-AUG-03 MWD 6965.66 75.89 1.63 92.47 3684.52 -429.50 390.36 4541.18 0.97 0.25 -0.96 22-AUG-03 MWD 7059.15 80.64 358.95 93.49 3703.54 -339.56 481 .86 4541.63 5.80 5.08 -2.87 22-AUG-03 MWD 7151.73 84.61 355.82 92.58 3715.42 -248.60 573.54 4537.43 5.44 4.29 -3.38 22-AUG-03 MWD 7244.69 86.83 351.96 92.96 3722.36 -156.17 665.69 4527.56 4.78 2.39 -4.15 .- 23-AUG-03 MWD 7337.24 86.74 347.23 92.55 3727.55 -63.79 756.55 4510.87 5.10 -0.10 -5.11 26-AUG-03 MWD 7415.39 87.46 351.42 78.15 3731.51 14.24 833.24 4496.42 5.43 0.92 5.36 26-AUG-03 MWD 7510.61 87.45 349.68 95.22 3735.74 109.35 927.07 4480.80 1.83 -0.01 -1.83 26-AUG-03 MWD 7608.73 90.06 348.80 98.12 3737.87 207.43 1023.43 4462.49 2.81 2.66 -0.90 26-AUG-03 MWD 7705.93 91.81 350.10 97.20 3736.28 304.61 1118.97 4444.70 2.24 1.80 1.34 26-AUG-03 MWD 7803.29 92.86 349.45 97.36 3732.32 401.89 1214.70 4427.43 - 1.27 1.08 -0.67 26-AUG-03 MWD 7852.43 91.63 349.00 49.14 3730.39 450.99 1262.94 4418.25 2.67 -2.50 -0.92 26-AUG-03 MWD 7898.79 92.83 349.23 46.36 3728.59 497.31 1308.43 4409.50 2.64 2.59 0.50 26-AUG-03 MWD 7950.79 91.01 350.10 52.00 3726.85 549.28 1359.55 4400.18 3.88 -3.50 .67 26-AUG-03 MWD 7995.95 90.98 350.59 45.16 3726.06 594.43 404.06 4392.60 .09 -0.07 .09 ~ L...- L..- Page~ of ~ Field KUPARUK RIVER UNIT BHI Rep. C MILCHAK I D BALLOU ~ Sidetrack No. LJ L-I 0450-00173 ~ Job No. Rig: #141 MWD L",-Í L..J L..J L..J 1...-1 . L-J . L-I SURVEY CALCULATION AND FIELD WORKSHEET Rig Contractor & No. Doyon Drilling Co. Survey Section Name 1 B-1 01 L~j Company CONOCOPHILLlPS ALASKA, INC. Well Name & No. PAD 1 B/1 01 PB1 01 01 L1 .J t- , Depths Measured From: RKB ~ MSLO SSO Calculation Method MINIMUM CURVATURE Map North to: OTHER 0.000 25.130 25.130 Grid Correction Declination to Map Corr. Magn. Magn. -501.00 -210.00 349.68 WELL DATA Slot Coord. NIS Slot Coord. E/W Vert. Sec. Azim. NIS E/W Build\Walk\DL per Coord. Coord. Target Target (F1) Target TVD Target Description Target Dir-ection 10mO OOft~ 30mO (DO) Comment Walk Rate Right (+) Left (-) -0.42 Build Rate Build (+) Drop (-) -0.84 DL (Per 100 FT) 0.94 Coordinate E(+) IW(-, (FT) 4383.55 SURVEY DATA Total N(+) I S(-) (FT) 1458.04 Vertical Section TVD (FT) 3725.34 Course Length (FT) 54.74 Hole Direction (DO) Inc!. Angle (DO) 90.52 90.77 Survey Depth (F1) 8050.69 8110.33 Survey Tool Type MWD Date . 6 649.1 350.36 350.79 0.72 0.42 0.83 4373.78 516.88 708.79 3724.67 59.64 -1.27 o .1 -1 .68 4365.99 1583.39 755.94 3724.25 47.16 350.19 90.25 8157.49 -0.89 -0.80 19 4360.56 1594.34 787.37 3724.19 31.43 349.91 90.00 8188.92 26-AUG-03 MWD 26-AUG-03 MWD 26-AUG-03 MWD MWD 26-AUG-03 -0.54 0.06 0.54 4343.20 1689.39 883.99 3724.13 96.62 349.39 90.06 8285.54 26-AUG-03 -0.31 -1.51 .54 4325.07 784.78 981.09 3725.28 97.11 349.09 88.59 8382.65 MWD 26-AUG-03 -2.08 12 2.36 4305.40 1878.12 076.43 3726.74 95.40 347.11 89.66 8478.05 26-AUG-03 MWD 26-AUG-03 MWD 27-AUG-03 MWD 4.85 .00 -1 4.96 4287.50 1974.68 1174.64 3728.16 98.25 351.88 88.68 8576.30 2.03 -0.15 2.03 4275.44 2070.98 271.55 3730.52 97.09 353.85 88.53 8673.39 0.73 12 .33 4265.76 2166.26 1367.02 3732.09 95.78 354.55 89.60 8769.17 -2.67 0.26 2.68 4254.32 2262.98 1464.22 3732.55 97.40 351.95 89.85 -2.63 0.24 -0.80 .72 2.75 .74 4238.83 4221.06 2357.44 2453.81 1559.93 657.93 3733.45 3733.58 95.74 98.00 349.43 349.67 349.59 89.08 90.77 8866.57 8962.31 9060.31 9156.90 27-AUG-03 MWD 27-AUG-03 MWD 27-AUG-03 MWD 27-AUG-03 MWD MWD 27 -AUG-03 -e- -0.08 0.00 0.08 4203.67 2548.82 754.51 3732.28 96.59 90.77 -0.13 -0.10 0.17 4185.98 2644.51 851.82 .06 3731 97.32 349.46 90.67 9254.22 MWD 27 -AUG-03 27 -AUG-03 -0.73 0.23 0.76 4167.60 2740.00 1949.07 3729.73 97.26 348.75 349.0 90.89 9351.48 MWD 0.27 0.26 0.37 4149.03 2834.47 2045.33 3728.03 96.29 91.14 9447.77 MWD 27-AUG-03 -0.38 0.40 0.56 4130.31 2929.25 2141.93 3725.77 96.64 348.64 91.53 9544.41 27-AUG-03 MWD 27-AUG-03 MWD 0.12 -1.01 .02 4111 .31 3024.33 2238.87 3724.01 96.97 348.76 90.55 9641.38 -1.02 0.33 .07 4092.01 3117.29 2333.79 3722.85 94.95 347.79 90.86 9736.33 MWD 27-AUG-03 -0.84 -0.36 -0.56 2.08 -0.76 -0.05 .04 .07 .13 10 .21 2.08 4070.68 4048.53 4008.31 4027.65 3212.57 3306.99 3402.21 3496.29 2431.35 2625.63 2721.65 2528.21 3722.01 3720.95 3716.40 3719.07 97.65 96.99 97.50 96.09 346.97 346.62 348.65 348.11 90.12 3 91.08 92.11 .1 91 9833.98 9930.97 0028.47 10124.56 MWD 27-AUG-03 MWD 27-AUG-03 MWD 27-AUG-03 MWD 27 -AUG-03 LJ LJ Lj, LJ. I r L_.I i I i ~ ~ ---., ~ =¡ a, ...;. I---...J '--",1 I:.........JI ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 1 Page 5 of 5 .. . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT IN.~ Well Name & No. PAD 1B/101PB1/101/101L1 Survey Section Name 1 B-1 01 MWD BHI Rep. C MILCHAK I D BALLOU WELL DATA Target TVD (FT) Target Coord. NIS Slot Coord. NIS -501 .00 Grid Correction 0.000 Depths Measured From: RKB g¡ MSLD SSD Target Description Target Coord. EJW Slot Coord. EJW -210.00 Magn. Declination 25.130 Calculation Method MINIMUM CURVATURE Target Direction (DO) Builcl\Walk\DL per: 10Oft~ 30mD 10mD Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.130 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 27 -AUG-03 MWD 10221.29 91.35 349.91 96.73 3713.48 2818.33 3591.20 3989.87 2.02 -0.79 1.86 27 -AUG-03 MWD 10317.86 90.40 348.57 96.57 3712.00 2914.88 3686.06 3971 .85 1.70 -0.98 -1.39 .- 27 -AUG-03 MWD 10414.50 89.54 349.16 96.64 3712.05 3011 .51 3780.87 3953.19 1.08 -0.89 0.61 27-AUG-03 MWD 10511.39 90.15 349.16 96.89 3712.32 3108.39 3876.03 3934.96 0.63 0.63 0.00 28-AUG-03 MWD 10609.17 90.03 350.51 97.78 3712.16 3206.17 3972.28 3917.71 1.39 -0.12 1.38 28-AUG-03 MWD 10705.21 89.63 350.55 96.04 3712.45 3302.20 4067.01 3901.91 0.42 -0.42 0.04 28-AUG-03 MWD 10801.37 88.62 351.45 96.16 3713.92 3398.32 4161.97 3886.86 1.41 -1.05 0.94 28-AUG-03 MWD 10897.48 88.43 351.31 96.11 3716.39 3494.36 4256.96 3872.46 0.25 -0.20 -0.15 28-AUG-03 MWD 10995.81 90.12 351.25 98.33 3717.63 3592.64 4354.15 3857.56 1.72 1.72 -0.06 28-AUG-03 MWD 11091.08 91.17 351.17 95.27 3716.56 3687.87 4448.29 3843.00 1.11 1.10 -0.08 28-AUG-03 MWD 11188.88 90.25 351.80 97.80' 3715.35 3785.61 4545.00 3828.52 1.14 -0.94 0.64 28-AUG-03 MWD 11284.98 90.55 352.83 96.10 3714.68 3881.60 4640.24 3815.67 1.12 0.31 1.07 28-AUG-03 MWD 11379.55 91.69 351.43 94.57 3712.83 3976.06 4733.89 3802.72 1.91 1.21 -1.48 28-AUG-03 MWD 11477.60 90.86 351.01 98.05 3710.65 4074.05 4830.77 3787.76 0.95 -0.85 -0.43 -= 28-AUG-03 MWD 11574.66 90.21 350.67 97.06 3709.74 4171.09 4926.59 3772.31 0.76 -0.67 -0.35 28-AUG-03 MWD 11670.79 89.79 350.63 96.13 3709.74 4267.20 5021.44 3756.69 0.44 -0.44 -0.04 28-AUG-03 MWD 11767.94 89.75 349.92 97.15 3710.13 4364.35 5117.19 3740.28 0.73 -0.04 -0.73 28-AUG-03 MWD 11864.35 88.74 349.45 96.41 3711.40 4460.75 5212.03 3723.02 1.16 -1.05 -0.49 28-AUG-03 MWD 11959.92 87.73 348.65 95.57 3714.35 4556.27 5305.82 3704.88 1.35 -1.06 -0.84 28-AUG-03 MWD 12037.99 89.51 349.50 78.07 3716.23 4634.31 5382.45 3690.09 2.53 2.28 1.09 28-AUG-03 MWD 12135.38 91.32 350.08 97.39 3715.52 4731 .69 5478.29 3672.82 1.95 1.86 0.60 28-AUG-03 MWD 12176.49 91.66 350.62 41.11 3714.45 4772.78 5518.80 3665.94 1.55 0.83 1.31 28-AUG-03 MWD 12230.00 91.66 350.62 53.51 3712.90 4826.26 5571.57 3657.22 0.00 0.00 0.00 Projected Data - NO SURVEY LJ LJ LJ LJ L..J I I I L I L....-I I i LJ i ~ II i iì 11 ¡¡¡¡ l = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 2 Page 1 of 3 - . I . Company CONOCOPHILLlPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD1B/101PB1 1101 1101L1 Survey Section Name 1 B-1 01 L1 MWD BHI Rep. C MILCHAK I D BALLOU INI Æ:Q WELL DATA Target TVD (Fl) Target Coord. NIS Slot Coord. NIS -501.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO SSO Target Description Target Coord. EJW Slot Coord. EJW -210.00 Magn. Declination 25.126 Calculation Method MINIMUM CURVATURE Target Direction (CD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.126 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) I S(-) E(+) I W(-) DL Build (+) Right (+) Comment Type (Fl) (DD) (DD) (Fl) (Fl) (Fl) (Fl) (Per 100 Fl) Drop (-) Left (-) MWD 6846.60 75.52 2.67 3655.18 -541.19 275.06 4536.77 TIE IN POINT 01-SEP-03 MWD 6927.88 84.16 358.79 81.28 3669.51 -463.70 354.97 4537.75 11.62 10.63 -4.77 -= 01-SEP-03 MWD 6977.05 89.82 358.88 49.17 3672.09 -415.24 404.04 4536.75 11.51 11.51 0.18 01-SEP-Q3 MWD 7074.21 90.34 356.03 97.16 3671.95 -318.99 501 .09 4532.44 2.98 0.54 -2.93 01-SEP-03 MWD 7170.88 88.37 352.97 96.67 3673.04 -222.68 597.30 4523.18 3.76 -2.04 -3.17 01-SEP-03 MWD 7225.46 87.54 352.16 54.58 3674.99 -168.20 651.38 4516.12 2.12 -1.52 -1.48 01-SEP-03 MWD 7267.71 88.07 350.09 42.25 3676.61 -126.00 693.09 4509.61 5.05 1.25 -4.90 01-SEP-03 MWD 7364.58 89.17 349.60 96.87 3678.94 -29.16 788.42 4492.53 1.24 1.14 -0.51 01-SEP-Q3 MWD 7395.84 89.23 350.03 31.26 3679.38 2.10 819.18 4487.00 1.39 0.19 1.38 01-SEP-Q3 MWD 7460.76 91.61 351.71 64.92 3678.90 66.99 883.27 4476.70 4.49 3.67 2.59 01-SEP-03 MWD 7557.97 90.98 351.18 97.21 3676.71 164.13 979.37 4462.25 0.85 -0.65 -0.55 01-SEP-03 MWD 7653.91 92.58 350.97 95.94 3673.73 259.99 1074.10 4447.37 1.68 1.67 -0.22 01-SEP-Q3 MWD 7750.89 92.16 352.29 96.98 3669.72 356.83 1169.96 4433.27 1.43 -0.43 1.36 01-SEP-03 MWD 7847.97 91.78 349.91 97.08 3666.38 453.82 1265.81 4418.26 2.48 -0.39 -2.45 -- 01-SEP-03 MWD 7945.34 89.66 347.32 97.37 3665.15 551.15 1361.24 4399.04 3.44 -2.18 -2.66 01-SEP-Q3 MWD 8041.29 90.89 344.57 95.95 3664.69 646.88 1454.31 4375.74 3.14 1.28 -2.87 01-SEP-03 MWD 8137.33 89.45 345.44 96.04 3664.41 742.60 1547.08 4350.89 1.75 -1.50 0.91 01-SEP-03 MWD 8234.86 90.95 347.67 97.53 3884.07 839.98 1641.92 4328.22 2.76 1.54 2.29 01-SEP-03 MWD 8331.59 87.49 347.19 96.73 3665.38 936.61 1736.31 4307.17 3.61 -3.58 -0.50 01-SEP-03 MWD 8428.98 91.01 346.95 97.39 3666.66 1033.87 1831.21 4285.38 3.62 3.61 -0.25 01-SEP-03 MWD 8525.40 91.41 346.84 96.42 3664.62 1130.16 1925.10 4263.53 0.43 0.41 -0.11 01-SEP-03 MWD 8621 .27 91.29 347.17 95.87 3662.36 1225.89 2018.49 4241.98 0.37 -0.13 0.34 02-SEP-03 MWD 8717.85 90.06 350.11 96.58 3661 .23 1322.44 2113.15 4222.96 3.30 -1.27 3.04 02-SEP-03 MWD 8815.00 89.20 351.64 97.15 3661 .85 1419.56 2209.07 4207.55 1.81 -0.89 1.57 . - ~ - - L.J L.J L..J. L..J. L-i --à -i ¡¡ i .i ' ~ :"1 .~.,.. ÌiÌ Ïi1. >1\. ,", ¡o¡ ~ = SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-00173 Sidetrack No. 2 Page 2 of 3 - . I . Company CONOCOPHILUPS ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Field KUPARUK RIVER UNIT Well Name & No. PAD 1B/101PB1 1101 1101L1 Survey Section Name 1 B-101 L1 MWD BHI Rep. C MILCHAK I D BALLOU 'NJ'J3Q WELL DATA Target rvD (F]) Target Coord. NIS Slot Coord. NIS -501 .00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLO ssO Target Description Target Coord. ENI Slot Coord. ENI -210.00 Magn. Declination 25.126 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mO 10mO Vert. Sec. Azim. 349.68 Magn. to Map Corr. 25.126 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length rvD Section N(+) I S(-) E(+) IW(-) DL Build (+) Right (+) Comment Type (F]) (DD) (DD) (Fl) (F]) (F]) (F]) (per 100 F]) Drop (-) Left (-) 02-SEP-03 MWD 8911 .97 91.29 352.02 96.97 3661 .44 1516.46 2305.05 4193.77 2.19 2.16 0.39 . 02-SEP-03 MWD 9008.15 87.69 350.48 96.18 3662.30 1612.58 2400.09 4179.14 4.07 -3.74 -1.60 02-SEP-03 MWD 9105.31 88.25 348.44 97.16 3665.74 1709.67 2495.54 4161.38 2.18 0.58 -2.10 02-SEP-03 MWD 9202.17 89.14 349.17 96.86 3667.94 1806.50 2590.53 4142.58 1.19 0.92 0.75 02-SEP-03 MWD 9298.72 90.61 349.09 96.55 3668.15 1903.04 2685.35 4124.37 1.52 1.52 -0.08 02-SEP-03 MWD 9395.42 91.44 348.57 96.70 3666.42 1999.71 2780.20 4105.65 1.01 0.86 -0.54 02-SEP-03 MWD 9492.96 92.28 349.01 97.54 3663.26 2097.19 2875.83 4086.69 0.97 0.86 0.45 02-SEP-03 MWD 9588.27 91.01 348.83 95.31 3660.52 2192.45 2969.32 4068.38 1.35 -1.33 -0.19 02-SEP-03 MWD 9685.63 90.98 348.33 97.36 3658.83 2289.77 3064.74 4049.11 0.51 -0.03 -0.51 02-SEP-03 MWD 9782.45 90.55 348.77 96.82 3657.54 2386.57 3159.62 4029.89 0.64 -0.44 0.45 02-SEP-03 MWD 9877.30 90.15 348.11 94.85 3656.96 2481.39 3252.55 4010.88 0.81 -0.42 -0.70 02-SEP-03 MWD 9975.45 90.18 348.18 98.15 3656.68 2579.50 3348.60 3990.72 0.08 0.03 0.07 02-SEP-03 MWD 10072.57 90.77 349.47 97.12 3655.87 2676.61 3443.88 3971.90 1.46 0.61 1.33 e- 02-SEP-03 MWD 10169.17 89.85 349.55 96.60 3655.35 2773.21 3538.86 3954.31 0.96 -0.95 0.08 02-SEP-03 MWD 10264.50 90.12 350.41 95.33 3655.37 2868.53 3632.73 3937.73 0.95 0.28 0.90 02-SEP-03 MWD 10361.42 90.49 348.86 96.92 3654.86 2965.45 3728.07 3920.29 1.64 0.38 -1.60 02-SEP-03 MWD 10459.27 90.40 347.55 97.85 3654.10 3063.26 3823.85 3900.29 1.34 -0.09 -1.34 02-SEP-03 MWD 10555.62 90.18 349.38 96.35 3653.61 3159.58 3918.24 3881.02 1.91 -0.23 1.90 02-SEP-03 MWD 10651.90 90.52 350.52 96.28 3653.02 3255.86 4013.04 3864.22 1.24 0.35 1.18 03-SEP-03 MWD 10748.84 90.25 348.93 96.94 3652.37 3352.79 4108.42 3846.93 1.66 -0.28 -1.64 03-SEP-03 MWD 10842.45 90.34 349.30 93.61 3651.89 3446.40 4200.35 3829.25 0.41 0.10 0.40 03-SEP-03 MWD 10935.67 90.77 348.38 93.22 3650.99 3539.60 4291.80 3811.21 1.09 0.46 -0.99 03-SEP-03 MWD 11028.85 90.28 351.10 93.18 3650.13 3632.77 4383.48 3794.62 2.97 -0.53 2.92 03-SEP-03 MWD 11122.20 89.66 350.03 93.35 3650.18 3726.11 4475.56 3779.32 1.32 -0.66 -1.15 · - L...J L-J ( 1lAV'RS& ì ~ IN,B;I Target TVD Target Description Target Direction Date Survey Tool Type MWD MWD 03-SEP-03 03-SEP-03 - - l - - - - - l l I. l' l' LI I I i L SURVEY CALCULATION AND FIELD WORKSHEET Company CONOCOPHILLlPS ALASKA, INC. Well Name & No. PAD 1 B/101 PB1/101/101 L1 (FT) (DD) Survey Depth (FT) 11215.60 11308.36 Incl. Angle (DD) 90.21 90.09 03-SEP-03 MWD 11401.06 90.25 03-SEP-03 MWD 11493.47 90.12 03-SEP-03 MWD 11583.52 89.94 03-SEP-03 MWD 11673.37 89.79 03-SEP-03 MWD 11764.40 89.78 03-SEP-03 MWD 11854.96 89.66 03-SEP-03 MWD 11945.44 89.32 03-SEP-03 MWD 12034.13 88.71 03-SEP-03 MWD 12124.42 87.64 03-SEP-03 MWD 12144.62 87.20 _ 03-SEP-03 MWD 12197.00 87.20 i L j 11 Job No. 0450-00173 Rig Contractor & No. Doyon Drilling Co. - Rig: #141 Survey Section Name 1B-101L1 MWD Target Coord. NIS Target Coord. E/W Build\Walk\DL per: 100ft~ 3OmO 10mO Hole Direction (DD) 349.89 350.21 350.67 349.73 349.53 349.53 348.91 349.20 348.41 347.81 347.96 347.26 347.26 Course Length (FT) 93.40 92.76 92.70 92.41 90.05 TVD (FT) 3650.29 3650.04 3649.77 3649.47 3649.42 89.85 3649.63 91.03 3649.98 90.56 90.48 88.69 90.29 20.20 52.38 3650.42 3651.22 3652.75 3655.62 3656.53 3659.09 WELL DATA Slot Coord. N/S Slot Coord. E/W Vert. Sec. Azim. SURVEY DATA Vertical Section 3819.50 3912.26 4004.95 4097.36 4187.41 4277.26 4368.28 4458.84 4549.30 4637.94 4728.14 4748.31 4800.58 -501.00 -210.00 349.68 Total Coordinate N(+) I S(-) (FT) 4567.53 4658.90 4750.31 4841.37 4929.95 5018.30 5107.72 5196.63 5285.39 5372.16 5460.40 5480.10 5531.13 E(+) IW(-) (FT) 3763.03 3747.00 3731.61 3715.88 3699.67 3683.34 3666.32 3649.12 3631.56 3613.29 3594.35 3590.02 3578.48 Grid Correction Magn. Declination Magn. to Map Corr. DL (Per 100 FT) 0.61 0.37 0.53 1.03 0.30 0.17 0.68 0.35 0.95 0.96 1.20 4.09 0.00 Build Rate Build (+) Drop (-) 0.59 -0.13 0.17 -0.14 -0.20 -0.17 -0.Q1 -0.13 -0.38 -0.69 -1.19 -2.18 0.00 j, j i à Sidetrack No. 2 Page ~ of 3 Field KUPARUK RIVER UNIT BHI Rep. C MILCHAK I D BALLOU 0.000 25.126 25.126 Depths Measured From: RKB ~ MSLO SSO Calculation Method MINIMUM CURVATURE Map North to: OTHER Walk Rate Right (+) Left (-) -0.15 0.34 0.50 -1.02 -0.22 0.00 -0.68 0.32 -0.87 -0.68 0.17 -3.47 0.00 Projected Data - NO SURVEY Comment -- e- coooc¡)Á1mips ConocoPhillips AI .,Slot #101 Pad 18, Kuparuk River Unit, North Slope, Alaska SURVEY U Page 1 Weilbore: 101 l1 Weilpath: MWD w/lFR <6921 - 12197'> Date Printed: 11-Nov-2003 Name 101 L 1 I Created 14-0ct-2003 I Last Revised 14-0ct-2003 Name 101 I Govefl1[T1efl~ ID I L?!$t Revi,sed ~2-Jul-2003 Name Slot #101 I Grid Northinq 5!;J6(1647.3610 I Grid Easting 550228.3510 I Latitude N7Q 1$ 40.2457 I Longitude W14$ 35 33.5484 I North 501.00S lEast 210.00W N<\IT)e Pad 1B I Nç¡rthina I Coord $~tem N~me INOrth AliQnfl1efl~ 550434.958 5970149.712 AK-4 on NORTH AMERICAN DATUM 1927 datum True N¡¡me Kvoarvk River Vr¡jt I !;:?!$tina INQrthina 4~77!;i4.Q21¡ I Coon;! System Nç¡[T1e INQrth Alianment 5(:¡4e985.821 AK-4 01;1 NORTH AMERiCAN DATUM 1947 qatu[T1 True All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.00 Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6587.79 Feet on azimuth 32.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated sea level) CooocJ"'Phillips ConocoPhillips Ala c., Slot #101 Pad 18, Kuparuk River Unit,North Slope, Alaska SURVEY LI Page 2 Wellbore: 101 l1 Well path: MWD wllfR <6927 - 12197'> Date Printed: 11-Nov-2003 6846.6( 75.5;2; ;?67 3955.1t 275.061\ 4(536.77E 0.00 -542.r: 554762.7~ !?9699(52. It 6f;J27.8t 84.16 358.7~ 3669.5' 354.9(1'- 4537.75E'- 11.62 -463,6S 55476~.1~ 5970Q3;2,6l 6977.0t 89.82 358.81: 3672.0~ 404.04t\ 4536.75E 11.51 -415.2£ 554761.81 5970081.7: 7074,2' 90.34 356.0~ 3f;ì71.9( 501,091\ 4;532.44E'- 2.9e- ·~18.f;JE 5547;56.81. 5~70178.7; 7170.81. 1;38.37' ~';2.97 3673.0t 597.29t\ 4523,17E. 3.76- -222.67 554746.91. 597Q274.8l 7225.4( 87.54 352.1E 3674.9~ 651.38t\ 4516.12E 2.12 -168.2C 554739.5f 5970328.8! 7267.7' 1;38.Q7 350.Q~ 3676.9' 693.091\ 4;50$.60E. 5.05 -1;26.0C 554n2.7; 5970370.51 7364.5!. 89.17 349.f;ìC. 3678.9E. 788.41 t\ 4492,'3E. 1.24 -29.1e '~715.0t 5!;ì7Q465.71 7395.8.: 89.23 350.0~ 3679.31. 819.18t\ 4487.00E 1.39" 2,10 554709.3: 5970496.41 7460.7f. 91.61 351.71 3678.9' 883.2,?1'- 4476.701:. 4.49 67·0C 554698.f;ìL 5970560.4f 7557.$7 $0.$8 351.1é: 3676·7' 979.371\ 4462.241:. 0.85 164.1< 554683·5t 5$?0f;ìQ6.41 7653.9' 92.58 350.97 3673.7~ 1074.101' 4447.37E 1.68 260.0C 554667,9! 5970751.1{ 7750.8~ 92.16 352.2S 3669.7~ 1169.$6/1 4433.26E'- 1.4~ 356.8£ 554653.2' 597Q846.8{ 7a47.f;J7 91.78 ~9·91 3f;ìf;ì6.3~ 1265.81/1 4418.25E. 2.48 453.84 5~f;ì37.6( 5970942.5! 7945.3< 89.66 347.3:: 3665.H 1361.24/1 4399.04E 3.44 551.1E 554617.7~ 5971037,8! 1;3041.2~ 90.89 344.57 3664.7( 1454.31 I' 4375,74E. 3.14 646.8~ 554p93.8~ 5971130.71. 8137,3~ 89.45. 345.4è 36&4,4' 1(547.08/1 4350.I;J9E 1.75 74;2.f;ìC 554568.3t 5971223,3~ 8234.8€ 90,95 347.67 3664.Oi 1641.921' 4328.22E 2.76 839.91: 554545.0~ 5971318.0t 8331 ,5~ 87.49 347..1~ ~f;ìf;ì(5.3~ 1736.311' 4307.17E, 3.61 936.6' 554!?23,3' 597141;2.2! 8428.f;J( 91,01 34f;ì.9f 36f;ìf;ì,6f 11;331.21~ 4285.38E. 3.62 103M~ 5Q4500.9l 5971;:;07,0; 8525.4( 91.41 346,& 3664.6~ 1925.10/1 4263.53E 0.43 1130.1E 554478.4" 5971600.7{ e6;21.2ï. 91.29 347.17 3662,3Î 2018,48/1 4241.97E. 0.37 1225.9( 55445f;ì.3( Q971694,Ol 8717,8~ 90.06 350.1 ' 3Q61.2~ 2113.1,/1 42;22.9!?E 3,30 132;2.4': 554436.6~ 5971788,5; 8815.0C 89.20 351.6£ 3661,8f 220R07\ 4207.55E 1.81 1419.5ï 554420,6{ 5971884.3: 1;3911.9"t 91.29 352.0::' 3661.4.: 230(5·Q51'- 4W3.77E. 2.19 151Ç}.4( !?54406.11. 5971980.2( 9008.1~ 87·fi9 350.4f 3662.3( 240Q.09/1 4179.14E. 4.07 1612.5!. 554390.9: ;5972075.1: 9105.3' 88.25 348.4.1.. 3665.7¿ 2495.54/1 4161.38E 2.18 1709.61. 554372,5: 5972170.4{ 9202,1; 8f;J.14 349.17 39Q7.9t 2590.53/1 4142·(58E 1.11) 18Q6.5t 554353.0l 5~722Q;5.3' 9298·7~ 90.61 349.Q~ 3668,1( 2685·35/1 4124.37E 1.52. 1903.0.: 554334.2t 9! 9395.4; 91.44 348.57 3666.4::" 2780.20/1 4105.64E 1.01 1999.7' 554314.8! 7' 94!;12,9f 92.28. 349.Q'· 3663.2f 2875,e31' 4086.6!;1E 0.97 ;2097.H 5542\19,~<' 5~725qO,1! 958ª.2"( !;I1.01 348.8~ :$660.5:: 2~69,32~ 4068.3e~ 1.35 2192.4~ 55427Q.3t 9685.6:: 90.9& 348.32- 3658.& 3064.74/1 4049.11f 0.51 2289.7f 554256.41 978~.4f 90.55 348,77 36q7.5L 3159.62/1 40;29.89f Q.Q4 238l5.15i 554;236.6( ~877,3( 90,1 Q. 348.1' 3Q5ç.f;J( ~252.;55/1 4010.1;38E. Q.81 ;2481.4( 554?1l5.~1 9975.4~ 90.18 348.1E 3656.6f 3348.60f\. 3990.72E 0.08 2579.5^ 554196.1' 10072.5~ 90.77 34!¡J.4"( 36;;;l.er 344~.e71' 3971,9Q1;. 1,46 ~676,6' 554176.7' :;>97~117.4{ 10199.1: 89.e;:;- 349.5E. 3655.:$f 3(5:$Mfi/l 39E;i4.31E 0.9fi ?773.2 , 554158.4l 9$7~2.12.2¡ 10264.5( 90.12 350.4' 3655.3f 3632.73/1 3937.73E 0.95 2868.5· 554141.21 5973306.0' 10361.4: 90.49 348·8E: 3654·l;3f 372e·07l\ 3920.29E' 1.64 29q5.4~ 554123.2' 59734Q1.2: 10459.2,~ f;J0.40 347.E;if 3Q54.1( 3823.84/1 3900,29Ç. 1.34 30f)3.2;' 554102.5', 59734~6.8! 10555.6: 90.1& 349.3E 3653.6' 3918.24t- 3881.02E 1.91 3159.5~ 554082.6~ 5973591.1' 10651.9t 90·5f. 350·5¡ ~65~.0~ 4Q13.04f\ 3894.?2E. 1.24. 32:;>5.8~ 554Q65.2' ,71 10748.8' 90.25- 348.9:;" 3652.3; 4108·42/1 384Q.93E. 1.66 3352.8( 554047·3' .0.- 10842.41 90.34 349.3C 3651.8~ 4200.35/1 3829.25E 0.41 3446.4( 554029.0: 5973872.8; 10935.6~ 9Q'77 348.3E 3Q50.9~ 4291.80/1 3811.211;. 1.09 3539.6' 554010·3' 5973964. it 11028.e~ 90.2~ 3;51.1 ç 3f)50.1¿ 4383.48/1 3794.62E. 2.97 3632.7;' 553$$3.1 : 5974055.7' 11122.2l 89.66 350.0:'. 3650. H 4475.561'- 3779.32E 1.32 3726.1' 553977.21 5974147.61 11,21 Q.6( 90.;21 34$.8~ 3650,Zf 4567.531'- ;3763.03E' 0.61 381$.:;>' 5539f)0.3! 59742,3!;1.5: 11308.3l 90.09 350.21 36qO,Qf 4f):;>e.$01\ 3(47.01E 0.37 39t2.2"f 553943.7' T 11401.0! 90.25 350.67 3649.7;' 4750,31f\. 3731.61& 0.5:> 4004.9f. 553927.7' All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6587.79 Feet on azimuth 32.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocJÂ1i11ips ConocoPhillips Alas c.,Slot #101 Pad 1 S, Kuparuk River Unit, North Slope, Alaska SURVEY L Page 3 Wellbore: 101 L 1 Wellpath: MWD w/lFR <6927 -12197'> Date Printed: 11-Nov-2003 114$~Æ 90.12 34$).n ~64\ì.4ï 4$41.37[\ ~715.88E 1.03 4097.3f p$~911.~· $974913.0' 11 (i?3.$~ 89,94 ~49.5~ 3649.4~ 4$29.9;;1' 369\ì.67E O.~O 4187.4' 553694.5" 5974f?01Æ 11673.3~ 89.79 349.5~ 3649.6¿ 5018.301' 3683.34E 0.17 4277.2f 553877.6l 5974689.7' 11764.4t 8\ì.78- 348.$1 3649.$f 5107.721' ;3,6?Q.3;2f 0.68. 4368.2( 5;;38QO,0~ 9$74779.0' 11854.9l 89.66- 34\ì.2C 3650.4¡ 5196,63J'.. 3649.12E 0.35 4458.8¿ 553;342.2~ 597481?7,7! 11945.4' 89.32. 348.41 3651.2~ 5285.391'- 3631.56E 0.95 4549.3' 553824.0! 5974956.4: 12034.1~ ;38.71 347.81 3952,7f 5:?72.11?I' 3613.29E 0.96 4637 .\ì~ 5$3805.2' $\ì7$Q4;3.Q€ 12124.4~ 87.64 347.9E. 3655·9::' 5460.401' 3594.35E 1.20 4728.11:. 553765.7' 5975131.1! 12144.6: 87.2C. 347.2E 3656.5· 5480.101' 3590.02E 4.09 4748.3' 553781.21 5975150K 12197.0t 87.2C ;347.2E 365$.1C 5531.131' 3!?78.48E 0.00 4800.5f 553769·'r 5975201.71 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 69.Oft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6587.79 Feet on azimuth 32.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Conoc~mips ConocoPhillips Alask Pad 18, Kuparuk River Unit, North Slope, Alaska SURVEY Page 4 Well bore: 101 L 1 Well path: MWD w/IFR <6921- 12191'> Date Printed: 11-Nov-2003 MDrftl ~TVD{ftJ 563.3 562. 1665.6 1565.2 ~Comment 11.73 MWD Survey 3\30.23 Tie-in to 1EHQ1 P!31 131/Ä 1;3 1/¡ 97/8 0.0c. 182Q.O( 3090.0( 0.00 1670·7( 2203.7~ 0,001\ 204.83~ 489.33S Q.OOI; 488.98E 1602.55E ~9!?Q.Oí 3090.0( 7395.0C 2íZQç¡,3f 2203.7~ 3730.5ï 48\J,~;3~ 489.33~ 818.35t\ 1QQ2.5!;>E 101Pl31 1602.55E. 101 4487.15E 101 16" Conductor 103/4" C?l9ina 7 5/&" cai?inQ 0.00 0·00 O,OÇ. O.OC 0.00 0.00 O.OON 0.001\. Q.QOt\ O.OOE O.OQE O.OOE 148.0C 30aO.0( 7389.0C 148.0C 2199.5~ 3730.2f 0.001\ 4&7.11E, 807,221\ O.OOE 101PB1 1593.72E 101 4500.f;¡7E 101 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 89.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 349.68 degrees Bottom hole distance is 6587.79 Feet on azimuth 32.90 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Transmittal Form INTEQ Anchorage GEOScience Center PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1B-101Ll Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 523077 Sent By: Glen Borel Received By: Date: Oct 1, 2003 Date: . . ~ \ ruJ ~- FRANK H. MURKOWSKI, GOVERNOR AI#ASIiA. OIL AM) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Field 1B-101L1 ConocoPhillips Alaska, Inc. Permit No: 203-134 Surface Location: 501' FNL, 211' PEL, SEe. 9, T11N, RlOE, UM Bottomhole Location: 244' FNL, 1882' FEL, SEC. 3, T11N, RlOE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1B-101, Permit No 203-133, API 50-029-23173-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely" , in. / ) (7 _ ~~~~ §;::~ <)v Chair BY ORDER OF THE COMMISSION DATED tbis---1L day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o ene!. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION PERM IT TO DRILL 20 AAC 25.005 1a. Type of Work: Dríl0 RE7entry(] 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: RedrílU 1b. Current Well Class: Stratigraphic Test 0 ExploratorU ServicD 5. Bond: U Blanket U 59-52-180 6. Proposed Depth: Development cI.:!J M~íìiple Ze{] Development GO Single Z0 Single Wel 11. Well Name and Number: 1B-101L1 12. Field/Pool(s): Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 4a. Lecation of Well (Governmental Section): l' Top of Productive Horizon: 7. Property Designation: ALK 25648 8. Land Use Permit: " West Sak Pool 13. Approximate Spud Date: 8/7/2003 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 244' @ TD 4b. Location of Well (State Base Plane Coordinates): Surface: x- 16. Deviated wells: 10. KB Elevation 15. Distance to Nearest Well Within Pool: 1D-103 @ 1033' /" (Height above GL): 88' AMSL 17. Anticipated Pressure (see 20 MC 25.035) Kickoff depth: ft. Maximum Hole Angle: 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Length MD TVD MD TVD Quantity of Cement c. f. or sacks (including stage data) Setting Depth Top Bottom 19 Total Depth MD (ft): 5594' PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Plugs (measured) no cement (To be completed for Redrill and RE7Entry Operations) Effective Depth MD (ft): Effective DepthTVD (ft): Junk (measured) Casing length Cement Volume MD TVD Liner Perforation Depth MD (ft): ,20. Attachments: Fíling Fee 0 Property Plat 0 BOP SketG Diverter Sket<C] Drilling progrfd Seabed RepO Time v. Depth 0 Drilling Fluid ProgrG!] Date: Shallow Hazard AnalO 20 MC 25.050 requirem0 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature R. Thomas Contact Title Kuparuk Drilling Team Leader Permit to Drill Number: I API Number: 50- Samples required Hydrogen sulfide measures Commission Use Only Permit Approval I Date: 2fltø /O?;;; Mud log required Directional survey required I See cover letter for . Conditions of approval: Other: BY ORDER OF COMMISSION ~/ Approved by: /,,/ Form 10-401 Re ~ 03/2003 · APp.n for Permit to Drill, We1l1B-101 L 1 Revision No.O Saved: 23-Jul-03 Permit It - West Sak Well #1 B-101 L 1 Application for Permit to Drill Document Moxir'l'liz~ Well Volu~ Table of Contents 1. Well Name... .......... ... ........ ................. ................ ............. ......... ............... ................... 2 Requirements of 20 AAC 25.005 (f)...................... ................. ..... ...................................... .... ..................2 2. Location Sum mary .... ............. ............... ................. ........... ............ ................. .......... 2 Requirements of 20 AAC 25.005(e)(2) ..... .............. .......... ...... ...... ............................. .......... ........ ...........2 Requirements of 20 AAC 25. 050(b)..... ................... ...................... ..................... ...... ...... .... .... ....... .......... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(e)(3) .......... .......... .............. ............................... .......... ......... ...... ......... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (e)(4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests........................................... 3 Requirements of 20 AAC 25.005 (e)(5) .................................................................................................. 3 6. Casing and Cementing Program............................................................................. 4 Requirements of 20 AAC 25.005(e)(6) ..................... ..... ....... ......... ................................ ....... ......... ......... 4 7. Diverter System Information ...................................................................................4 Requirements of 20 AAC 25. 005( e)(7) ........... .............. ............... .............. ....... ............. .... ..................... 4 8. Dri II i ng FI u id Program ....... ................ .................... ........... ............. ............. ..... ........ 5 Requirements of 20 AAC 25.005(e)(B) ... ............. ........ .............. ....... ....... .................. ............ ............ ..... 5 Upper Lateral Mud Program (6% KCf BARADRILn).............................Error! Bookmark not defined. 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (e)(9) ..................................................................................................5 10. Seismic Analysis ..... ..... ........ .... .......................... .............. ........ .................... ..... ....... 5 Requirements of 20 AAC 25.005 (e)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................5 Requirements of 20 AAC 25.005 (e)(11) ................................................................................................ 5 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (e)(12) ................................................................................................6 18-101 L1 PERMIT IT. doc Page 10(7 Printed: 23-Jul-03 · APpan for Permit to Drill, We1l1B-101 L1 Revision No.O Saved: 23-Jul-03 13. Proposed Drilling Program ......................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments .......... ........... ........... ........... ............ ........ .......... ............. ......... .............. 7 Attachment 1 Directional Plan (4 pages) ................................................................................................ 7 Attachment 2 Drilling Hazards Summary (1 Page)................................................................................. 7 Attachment 3 Well Schematic (2 pages) ................................................................................................ 7 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 API number assigned by the commission under 20 MC 25.040(b). For a well with multiple well branches, each branch must similady 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 18-101 L1. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation and at total depth; referenced to governmental section lines. (8) the coordinates of the proposed location of the well at the surfac~ referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administratk)n;" (C) the proposed depth of the well at the top of each objective formation and at total depth/ Location at Surface 501' FNL, 2U' FEL, Section 9, TUN, Rl0E, UM .,/ NGS Coordinates I RKB Elevation I 88.4' AMSL Northings: 5,969,647 ./ Eastings: 550,228 ./ Pad Elevation 60.4' AMSL Location at Top of Productive Interval (West Sak "D" Sand) NGS Coordinates Northings: 5,969,710 470' FNL, 1006' FEL, Section 10, TUN, Rl0E, UM .,/ Eastings: 554,713 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 6,603 3,625 3,536 Location at Total Depth NGS Coordinates Northings: 5,975,209 Eastings: 553,788 244' FNL, 1882' FEL, Section 3, TUN, Rl0E, UM .....- Measured Depth, RKB: 12,197 ./ Total Vertical Depth, RKB: 3,663 ,/ Total Vertical Depth, 55: 3,574 and (D) other information required by 20 MC 25.0S0(b)/ 18-101 L1 PERMIT IT. doc Page 2 of 7 Printed: 23-Jul-03 · APpan for Permit to Drill, We1l1B-101 L1 Revision No.O Saved: 23-Jul-03 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviatect the application for a Permit to Drill (Form 10-401) must (1) include a plat, drawn to a suitable sca/~ showing the path of the proposed wellbor~ including all adjacent wellbores witllin 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed well bore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, 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. 035, 20 AAC 25.03~ or 20 AAC 25.037, as applicable/ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1B-101 L1. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a PermIt to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that may be encounterect criteria used to determine it and maximum potential surface pressure based on a methane gradient,· The expected reservoir pressures in the West Sak sands in the 1B-101 L1 vary from 0.50 to 0.52 psi/ft, or -- 9.6 to 9.8 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1513 psi, calculated thusly: MPSP =(3691 ft)(0.52 - 0.11 psi/ft) - =1513 psv (B) data on potential gas zone~· The well bore is not expected to penetrate any gas zones. ,/ and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost drculation zones, and zones that have a propensity for differential sticking/ Please see Attachment 2: 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 Items, except for an Item already on file with the commission and identified in the application: (5) a description of the procedure for conducting fonnation integrity tests, as required under 20 AAC 25. 030{f}/ 18-101 L1 PERMIT IT. doc Page 3 of 7 Printed: 23-Jul-03 · APpen for Permit to Drill, Well 1 B-1 01 L 1 Revision No.O Saved: 23-Jul-03 / 1B-101 will be completed with 7-5/8" surface casing landed in the West Sak B-Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that Phillips Alaska placed on file with the Commission. The formation integrity of the West Sak D sand is expected to be the same as that of the B sand, so no formation integrity test is planned during 1B-101 L1 operations ,- 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) 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 commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 MC 25: 030, and a description of any slotted liner; pre- perforated liner; or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Size (in) 24 Csg/Tbg 00 (in) 16 Weight (Ib/ft) 62.5 Top MO/TVO (ft) 28 / 28 Btm MO/TVO (ft) 148/ 148 Connection Length (ft) 110 Grade H-40 Welded 10-3/4 13-1/2 45.5 L-80 BTC 872 28 / 28 900 /895 10-3/4 13-1/2 40 J-55 BTC 2182 900 /895 3082 / 2200 7-5/8 9-7/8 29.7 L-80 BTCM 7075 28 / 28 7103 / 3700 6-3/4" Lower Lateral (lB-101) 6-3/4" Upper Lateral (lB-101 L1) 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) 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 commission and identified in the application: (7) a diagram and description ofthe diverter system as required by 20 MC 25.035; unless this requirement is waived by the commission under 20 MC 25.035(h)(2J" 4-1/2 slotted 4-1/2 slotted 12.6 L-80 6630/ 3630 12210 / 3722 NScr 5580 12.6 L-80 NScr 6603/ 3625 12197 / 3663 5594 No diverter system will be utilized during 1B-101 L1 operations. Cement Program Cemented to surface with 260d ArcticCRETE Cemented to Surface with 730 sx ASLite Lead, 680 sx Class G Tail Cement Top planned @ 4500' MD / 2800' TVD. Cemented w/ 663 sx Class G Slotted- no cement Slotted- no cement , 1B-101 L1 PERMIT IT. doc Page 4 of 7 Printed: 23-Jul-03 · APpen for Permit to Drill, We1l1B-101 L 1 Revision No.O Saved: 23-Jul-03 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Pem7it to Drill must be accompanied by each of the following items, except for an item already on file with the commi.'iSion and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI FlowPro NT) BID sand laterals Initial Value Final Value 9.8 9.8 45-60 45-60 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) Tau 0 Chlorides (mgll) pH API filtrate (cc 130 min) **HTHP filtrate (cc I 30 min) MBT (Ib I gal) ***Solíds (% Vol) / 22-30 22-30 8-12 8-12 4-7 4-7 100-110K 100-110K 8-9.5 8-9.5 <6 <6 <10 <10 <5 <5 <6 <6 .. HTHP to be run at 80° F'" The drílled LGS Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An applicaäon for a Permit to Drill must be accompanied by each of the following Items, except for an Item already on file with the commission and identified in the application: (9) for an exploratory or straägraphic 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 hot for an exploratory or stratigraphic test well. ./ 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the applicaäon: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 MC 25.061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and Idenäfled in the application: 18-101 L 1 PERMIT IT.doc Page 5 of 7 Printed: 23-Jul-03 · APpen for Permit to Drill, Well1B-101 L1 Revision No.O Saved: 23-Jul-03 (II) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floatli7g drilling vesse¿ an analysis of seabed conditions as required by 20 MC 25.061 (b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pem1it to Drill must be accompanied by each of the following items, except for an item already on flle with the commis.."ion and identified in the application: (12) evidence showing that the requirements of 20 MC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already 0/1 file with the commission and identified in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematics. This procedure will begin upon completion of the lower lateral, 1B-101 1. Run and set Baker WindowMaster whipstock system, at window point of 6603' MD / 3625'1VD, just into the top of the D sand. 2. Mill window. POOH. 3. Pick up 6-3/4" drilling assembly with LWD and MWD. RIH. 4. Change over to clean FloPro NT drilling mud. 5. Drill to TD of D sand lateral at 12,197' MD / 3,663'1VD, as per directional plan. 6. POOH, back reaming out of lateral. POOH. 7. RIH with whipstock retrieval tool. Retrieve whipstock and POOH 8. PU and run 4-1/2" slotted Liner. 9. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 10. Release hanger running tool. POOH, laying down drill pipe as required. 11. Make up tubing tail and completion equipment as required and RIH to depth. 12. Drop RHC plug and pump down to nipple below packer. Pressure tubing and set packer. Shear seal assembly from PBR, space out and land tubing in well head 13. Install BPV, nipple down stack, nipple up and test tree to 5,000 psi. Pull BPV. Test tubing to 3,500 psi for 10 minutes, recording results. Holding 1000 psi pressure on tubing, pressure test annulus to 3000 psi for 10 minutes, recording results. Continue to pressure annulus up and shear RP shear valve in top gas lift mandrel. Freeze protect well with diesel by pumping into annulus, taking returns from tubing and allowing to equalize. 14. Set BPV and move rig off. 15. Rig up wire line unit. Pull BPV. Set dummy valve in place of RP shear valve in top mandrel. Perform MIT pressure tests of tubing and annulus (Tubing and annulus to 3500 psi). 16. Pull RHC plug from nipple below packer. Open CMU sliding sleeve. Set Weatherford jet pump in CMU profile. Set sub-surface safety valve. Rig down wire line unit. 17. Initiate production and clean up well to tanks. Freeze protect well and turn well over to production. LtJD: 9 Æ - ïe&5 ð.....c...r r-'v~ tA,,~v.e ~ 7" 3D.o..J 18-101 L1 PERMIT IT. doc Page 6 of 7 Printed: 23-Jul-03 · APPlen for Permit to Drill, Well 1 B-1 01 L 1 Revision No.O Saved: 23-Jul-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items; except for an item already on tile with the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator Intends to request authorization under 20 MC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on lC Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on lC Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska does not intend to request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1: Directional Plan (3 pages) Attachment 2: Drillíng Hazards Summary (1 Page) Attachment 3: Well Schematic (2 pages) /0/0 nf II 5'""..." !ì:.' ~¡ 18-101 L1 PERMIT IT. doc Page 7 of 7 Printed: 23-Jul-03 · Page 1 of 3 D Lateral Grid Lat Long Report e ConocoPhil1ips Alaska, Inc. Pad IB 101 slot n01 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 18-101 VS D-LAT VEUO.E propS487 Date printed Date created Last revised 17-Jul-2003 2-Jul-2003 ll-Jul-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n7Q 19 45.173,w149 35 27.418 Slot location is n70 19 40.246,w149 35 33.548 Slot Grid coordinates are N 5969647.361,'É 550228.351 Slot local coordinates are 501.00 S 210.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North '1 · e Page 2 of 3 D Lateral Grid Lat Long Report ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1B,101 Your ref 1B-101 V5 D-LAT VER#O.E Kuparuk River Uni t, North Slope, Alaska Last revised : 11-Jul-2003 Measured Inclin Azimuth True Vert R E C TANGULAR G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth C 0 0 R DIN ATE S Easting Northing C 0 0 RDINA T E S r 6603.35 76.40 18.28 3625.00 32.37N 4485.08E 554712.68 5969709.88 n70 19 40.55 w149 33 22.62 6615.35 78.05 17.31 3627.65 43.51N 4488.66E 554716.18 5969721.04 n70 19 40.66 w149 33 22.51 r 6633.35 78.05 17.31 3631.38 60.33N 4493.89E 554721.30 5969737.89 n70 19 40.83 w149 33 22.36 6700.00 81. 24 11.35 3643.37 123.82N 4510.09E 554737.07 5969801. 48 n70 19 41. 45 w149 33 21. 89 6800.00 86.17 2.60 3654.35 222.35N 4522.11E 554748.43 5969900.09 n70 19 42.42 w149 33 21.53 6876.24 90.00 356.00 3656.90 298.49N 4521.17E 554746.98 5969976.20 n70 19 43.17 w149 33 21.56 6900.00 91. 12 353.90 3656.67 322.15N 4519.08E 554744.73 5969999.85 n70 19 43.40 w149 33 21. 62 6940.20 93.00 350.35 3655.22 361. 95N 4513.58E 554738.96 5970039.60 n70 19 43.79 w149 33 21. 78 7000.00 93.00 350.35 3652.09 420.81N 4503.57E 554728.55 5970098.40 n70 19 44.37 w149 33 22.07 7030.00 93.00 350.35 3650.52 450.35N 4498.55E 554723.33 5970127.90 n70 19 44.66 w149 33 22.22 7100.00 90.90 350.35 3648.14 519.31N 4486.82E 554711.14 5970196.77 n70 19 45.34 w149 33 22.56 7155.75 89.23 350.35 3648.08 574.28N 4477 .47E 554701. 42 5970251.67 n70 19 45.88 w149 33 22.83 7500.00 89.23 350.35 3652.72 913.62N 4419.75E 554641.43 5970590.58 n70 19 49.22 w149 33 24.51 8000.00 89.23 350.35 3659.46 1406.49N 4335.91E 554554.29 5971082.83 n70 19 54.07 w149 33 26.95 8484.66 89.23 350.35 3666.00 1884.25N 4254.65E 554469.83 5971559.99 n70 19 58.77 w149 33 29.31 8500.00 89.59 350.07 3666.16 1899.36N 4252.04E 554467.12 5971575.08 n70 19 58.92 w149 33 29.39 8501.77 89.63 350.03 3666.17 1901.11N 4251. 73E 554466.80 5971576.82 n70 19 58.93 w149 33 29.40 9000.00 89.63 350.03 3669.36 2391.81N 4165.50E 554377.28 5972066.88 n70 20 03.76 w149 33 31. 91 9500.00 89.63 350.03 3672.55 2884.25N 4078.96E 554287.44 5972558.68 n70 20 08.60 w149 33 34.43 9726.03 89.63 350.03 3674.00 3106.86N 4039.84E 554246.82 5972781. 00 n70 20 10.79 w149 33 35.57 9749.96 90.26 349.68 3674.02 3130.42N 4035.62E 554242.45 5972804.54 n70 20 11. 02 w149 33 35.69 10000.00 90.26 349.68 3672.90 3376.41N 3990.82E 554196.00 5973050.19 n70 20 13.44 w149 33 37.00 10500.00 90.26 349.68 3670.64 3868.31N 3901. 24E 554103.12 5973541.44 n70 20 18.28 w149 33 39.61 11000.00 90.26 349.68 3668.39 4360.22N 3811.65E 554010.24 5974032.68 n70 20 23.12 w149 33 42.22 11500.00 90.26 349.68 3666.14 4852.12N 3722.06E 553917.35 5974523.92 n70 20 27.96 w149 33 44.83 12000.00 90.26 349.68 3663.89 5344.02N 3632.48E 553824.47 5975015.16 n70 20 32.80 w149 33 47.44 " 12197.16 90.26 349.68 3663.00 ,,- 5537.99N 3597.15E 553787.84 5975208.87 n70 20 34.70 w149 33 48.47 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #101 and TVD from Est. RKB=89, (89.00 Ft above mean sea level). Bottom hole distance is 6603.70 on azimuth 33.01 degrees from wellhead. Total Dogleg for wellpath is 37.60 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 350.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ i: Page 3 of 3 D Lateral Grid Lat Long Report . e ConocoPhillips Alaska, Inc. Pad 1B,101 Kuparuk River Uni t, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref 1B-101 V5 D-LAT VERiO.E Last revised : Il-Jul-2003 Comments in wel1path -------------------- -------------------- MD TVD Rectangular Coords. Comment - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - -- - -- - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - -- 6603.35 3625.00 32.37N 4485.08E Top Whipstock Face 6615.35 3627.65 43.51N 4488.66E Base Whipstock Face 6633.35 3631.38 60.33N 4493.89E KOP - End Milled Hole / 6940.20 3655.22 361.95N 4513.58E End 10/100 BId/Turn 7030.00 3650.52 450.35N 4498.55E Drop 3/100 7155.75 3648.08 574.28N 4477.47E EOC 8484.66 3666.00 1884.25N 4254.65E WS V5 D QTR TGT RLOC' D 9JULO 3 8501.77 3666.17 1901.11N 4251. 73E EOC 9726.03 3674.00 3106.86N 4039.84E WS V5 D MIDPT RLOC'D RVSD8JUL3 9749.96 3674.02 3130.42N 4035.62E EOC 12197.16 3663.00 5537.99N 3597.15E WS V5 D-TOE RLOC'D RVSD08JUL03 Targets associated with this wel1path ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- -- - - - - - - - -- -- - - - - -- - -- - - - - - - -- - -- ---- WS V5 D QTR TGT RLOC WS V5 D MIDPT RLOC'D WS V5 D-TOE RLOC'D R 3666.00 3674.00 3663.00 1884.25N 3106.86N 5537.99N 4254.65E 4039.84E 3597.15E 10-Jul-2003 10-Jun-2003 10-Apr-2002 taker Hughes Incorporat! Anticollision Report Ir-"(::~~~~;~;-" .. ·······..ë~~~~~phiiïi~s Alaska, Inc. Held: Kuparuk River Unit ! Reference Site: Pad 18 ; Reference Well: 101 Reference Wellpath: 18-101 D-Lat VersOe -.--.".-----.. . ..... 7/28/2003 Time: 08: 19:40 J)l\te: I'age: Co-ordinate(:'lil!.) Refereuce: Vertical (TV))) Reference: Well: 101, True North Wellhead(89') 89.0 Db: Oracle ..- ...-------.-... . ..--...----- . . . ._.__ ... n_.. .... .. -... .."....,.......... ...---....---..----.-..-.-........ ....._,...... ---.. -.. .---.. -. . -. . .--.---..... . NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 20.00 ft Depth Range: 6600.00 to 12197.15 ft Maximum Radius: 1500.00 ft Reference: Error Model: Scan Method: Error Surface: Survey Program for Definitive Wellpath Date: 7/17/2003 Validated: No Planned From To Survey ft ft 0.00 6603.35 Planned: 18-101 8-Lat VersO.E 6603.35 12197.15 Planned: 18-101 D-LatVersOeV Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Casing Points ...-.. ........-...-.......... ,----...---".. . ...........-.--,.- .... ...-".'-.-'-'--. ,. . ... .. ..--..-"..---. . .............. :\11) ft 12197.15 ~aDle 1"\'1) ft 3663.00 Diameter in Hole Size in 6.750 51/2" 5.500 Summary . . ._._.......n . .------_._,'. .--.-----., .-"..' <---------------- Offset Wellpath ------------------> Site Well WellJath Offset MD ft Ctr-Or ~o-Go I)istallce Area ft ft nererence !\1D ft Pad 18 10 18-10GI VO Pad 18 102 18-102 Version#1 V6 PI 6821.45 6240.00 497.63 106.29 Pad 18 11 1B-11GI V1 Pad 18 1 18-01 VO Pad 18 12 18-12 VO Pad 18 13 18-13 VO Pad 18 14 18-14 VO Pad 18 15 18-15 VO Pad 18 16 18-16 VO Pad 18 17 18-17 V2 Pad 1 B 18 18-18 VO Pad 18 19 18-19 VO Pad 18 20 18-20 V5 Pad 18 2 18-02 VO Pad 18 3 18-03 VO Pad 1 8 4 18-04 VO Pad 18 5 1 8-05 VO Pad 18 6 18-06 VO Pad 18 7 18-07 VO Pad 18 8 18-08 VO Pad 18 8 1 8-08A VO Pad 18 9 1 8-09GI VO Pad 18 CPF-1A CPF-1A VO Pad 18 WS-10 WS-10 VO Pad 18 WS-11 WS-11 VO Pad 18 WS-1 WS-01 VO Pad 18 WS-2 WS-2 VO Pad 18 WS-3 WS-03 VO Pad 18 WS-4 WS-04 VO Pad 18 WS-5 WS-05 VO Pad 18 WS~6 WS-06 VO Pad 18 WS-7 WS-7 VO Pad 18 WS-8 WS-08 VO Pad 18 WS-9 WS-09 VO Pad 1C 01 1C-01 V2 Pad 1 C 02 1C-02 VO Pad 1 C 03 1C-03 VO Pad 1C 04 1 C-04 VO Pad 1C 05 1 C-05 VO Pad 1 C 06 1C-06 VO Pad 1C 07 1 C-07 VO Pad 1C 08 1 C-08 VO Pad 1 C 09 1C-09 VO Pad 1 C 10 1C-10 VO o 1 .~. Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Allowable J)e,'iation ft . ·-1 I \\'arnin¡: Out of range 397.38 Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range . e Baker Hughes Incorporated Anticollision Report .._.___..". '..... .. __. ... .._ _._._ __ ... _._._n__.__.__._,._.____..__. ... .. ......_ ...~ Cumpany: Held: Reference Site: Reference Well: Reference Wellp;lth: --.. ... -..... ... . ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1B 101 1 B-1 01 D-Lat VersOe Co-ordinate(NJo:) I{cferencc: Vertical (TV) Rcfcrencc: Well: 101, True North Wellhead(89') 89.0 Date: 7/28/2003 Time: 08:19:40 -............ . . .... ....-.-....--...... ....--.. ---.-.. ...... ....--...-..,..-.......-........ . ....... ........ ... ....__..____..__.___.___..___.__ .n ..__...__._.___.__...... Warnin2 Summary '. .. ...........---.....----. - <-------------------- Offset Wellpath --------------.> Site Wl'Il Wellpath .................-----. .. Reference )1\) ft Offset MI.) ft Ctr-Ctr ~u-Go I>istance Area ft ft Alluwahle Ucyiatiun ft -..".,.,..-.. .....-. --.--..... ..-.-----. "----. ~- -. I'age: 2 Db: Oracle ...-.-.-.".-..----....-.-. - ........ .. -...... . .....-..- . .....-.. -"........ . Pad 1C 102 Pad 1C 102 Pad 1C 104 Pad 1C 104 Pad 1C 104 Pad 1C 109 Pad 1C 109 Pad 1 C 111 Pad1C 11 Pad 1C 113 Pad 1C 117 Pad 1C 119 Pad 1C 121 Pad 1C 12 Pad 1C 123 Pad 1C 125 Pad 1C 127 Pad 1C 131 Pad 1C 13 Pad 1C 133 Pad 1C 135 Pad 1C 14 Pad 1C 15 Pad 1C 15 Pad 1C 16 Pad 1C 170 Pad 1C 170 Pad 1C 17 Pad 1C 172 Pad 1C 174 Pad 1C 178 Pad 1C 178 Pad 1C 178 Pad 1C 178 Pad 1C 18 Pad 1C 184 Pad 1C 190 Pad 1C 19 Pad 1C 22 Pad 1C 23 Pad 1C 23 Pad 1C 24 Pad 1C 25 Pad 1C 26 Pad 1C 27 Pad 1C SWPT1 Pad 1C WS-1 Pad 1C WS-24 Pad 1D(lncomplete) 103 1C-102 V6 1C-102L 1 V3 1C-104 VO 1C-104L 1 V1 1C-104PB1 VO 1C-109 VO 1C-109L 1 VO 1C-111 VO 1C-11 VO 1C-113 VO Plan: 1C-113 1C-117VO 1C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 V1 1C-15 V2 Plan: 1C-15L 1 1C-15L 1 VO 1C-16 VO 1C-170 VO 1C-170PB1 V14 1C-17VO 1C-172 V14 1C-174 V24 1C-178 V13 1C-178L1 V1 1C-178PB1 V1 1C-178PB2 V2 1C-18 VO 1C-184 V10 1C-190 V8 1C-19 V6 1C-22 V3 1 C-23A V2 1 C-23PB 1 V1 1 C-24 VO 1C-25 VO 1C-26 V2 1C-27 V1 WSSWPT1 V4 WS1 V1 WS-24 VO 10-103 V1 6850.00 13360.00 1033.10 349.96 683.06 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk . . 18-101 Ll Drillina Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Hazard Abnormal Reservoir Pressure Stuck Pipe Risk Level Low Lost Circulation Hole Swabbing on Trips Low Moderate 18-101 L1 Drilling Hazards Summary. doc prepared by Steve McKeever 7/21/20033:00 PM R1mning Order: (1) Guide shoe (no float), Ray Oil Tools Silver Bullet with eccentric nose, 3-1/2 in, 9.2#, IBT box, OD=4.250" (PES!) (1) Bent Pup Joint, 18.5 ft length, 3-1/2 in. 9.2#, L-80, IBT. (CPAI) (1) Crossover, 4-'12" 12.6# NSCT Box x 3-1/2 in, 9.2#, IBT pin (CPAI). (1) Blank joint liner, 4- W' 12.6# L80 NSCT (CPA!) (1) Pack off Bushing Sub, 4-W' 12.6# NSCT Box x Pin (Baker) (x) Joints slotted liner, 4-1/2 in, 12.6#, L-80, NSCT, with sixteen 0.25 in x 2.5 in slots per foot. (CPAI). alternating every other joint with (x) Joints blank liner, 4-1/2 in, 12.6#, L-80, NSCT. (CPAI) C) as required to reach: (2) Joints blank liner, 4-1/2 in, 12.6#, L-80, NSCT. (CPAI) (1) Crossover, 4-1/2 in, 11.6#, BTC Box x 4-1/2 in, 12.6#, NSCT Pin (CPAI) (1) Swivel Sub, Baker, 4-1/2 in, 11.6#, Casing BTC Box x Pin (CPAI component of 1063-7668) (1) Liner Hanger, (1063-7668) Baker Flanged Hook Hanger, Model B, Size 7-5/8 in x 4-1/2 in, 4-1/2 in 11.6#, BTC Pin Down (BOT) (1) Liner Running Tool Assembly, Baker with 3-V2 IF Box up Top of Window at +/- 6603' MD, Centralization: 3625' TVD Run (1) 4-1/2 in x 6-1/4 in Weatherford SpiraGlider per joint above the packoff bushing, with NO stop collars. ------- 4 ~~~~ ------ ------ ------ I D ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ ------ 6-3/4" Open Hole TD: Production Casing _ +/-12,197' MD /3,663' TVD 7-5/8" 29.7# L-80 BTC Mod ~ SM@710;~:~~~~:~:=========1 See Sheet 2 ------------- for Lower ------------- ------------- Lower Liner Top Set @ Lateral Liner +/. 6630' MD / 3630' TVD Details 6' :s o 8 \)~ :T -. - - -. i ~"tJ CD- CD I» -~ ~~C:: 08.~ ....OUl U1 - " 0 (J) c31» 'tS"2.;II;" 'tSCD~ CD :::!: CD .,0- r~= 5' (J) [D CD (') I .,::r~ CCDO CD3~ S'~ ;;;' ë)' ... t¡o ... c ... ~ ~ C/) ~ 9- (1) (1) t(ß"t) ~ ~ ~.g I~ .... '" ~ '" ~~Q.:I' 8~~~ .... - "- I ubing Hanger, Vet co Gray Gen la, 4-112", wI 4.909" ~A Top Connection; 4-112", 12.6#, L-80 IBT-Mod box down, drilled for Tree Assy, TEC wire & two SSSV control lines. , Vetco Gray "Producer" Casing I Tubing Head Assy Vetco Gray, 11" API 5M flange up. J 10-3/4", 45.5#, L-80 x 40.5#. J-55. BTC Casing Shoe @ +1- 3,082' MD 12.200' TVD 9-718" Hole Sail Angle: 65 degrees Tubing String: 4-1/2", 12.6 #, L-80, IST,AS Modiifed (1054-2463) Control Line / TEC wire for / Gaurdian Gauges, held in place with ~ Canon Clamps on every coupling (x) Joints Tubing (1) Nipple (1061-9229) for Sub Surface Safety Valve, Schlumberger (Cameo) Model BP-6i, with 3.813" Camco 'DB' profile (3.813" ID Packing bore), IBT-Mod, set at +1- 2700' MD I l2000'TVD. Run with isolation sleeve (x.xxx" ID) installed, and 10' pups top and bottom. with (1) Cameo Model WRDP-2 valve installed after rig release (x) Joints Tubing (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-112" x 1" Model KBG-2 with DCK shear valve installed, pinned to shear when annular pressure is 2500 psi greater than tubing pressure, 4-112" IBT Pin x Pin, with 6 foot 4-112" XO Pups, top and bottom, set at +1- 2400 ft TVD, (+1- 3530' MD) (x) Joints Tubing (1) Gas Lift Mandrel, (1062-2035) CAMCO 4-112" x 1" Model KBG-2 with BK-2 dummy valve installed, 4-112" IBT Pin x Pin, with 6 foot 4-112" XO Pups, top and bottom. (1) Joint Tubing (1) Handling pup, 10ft long (1) Profile Nipple, Camco DB, 3.75" Packing Bore (1) Relief Groove Sub, Baker with (1) Jet Pump installed after rig release, (1) Sliding Sleeve, 3.S13 CMU Wealhefford, x" Reverse Circulation #xx Nozzle, #XX (1) Relief Groove Sub, Baker Throat, wilh lop XO to CAMCO 3.75 Lock. (1) Polished Bore Sub, 3.750"ID polished bore, 24 inshes long. (1) Handling pup, 10 ft long (1) Joint Tubing (1) Pressure Gauge, Internal Tubing, Baker Gaurdian (2) Joints Tubing (1) PBR with Seal Assembly, 17 ft Baker Model 80-47, 4-11 2" L-80 IBT- Mod, 6 ft handling pups installed on top & bottom. (1) Packer / Millout Assembly, Baker Model 7-518 x 4- 112" 'S3', (ID 3.875), 4-1/2" IBTM, 6 ft handling pup installed on top. (1) Profile Nipple, 4-% Camco DB, 3.687" ID packing bore, 4-112" L-80 IBT-Mod Box, set at 70 deg maximum inclination. With RHC Plug installed for use with ball and rod. With 10 ft handling pups. Top @ 6200' MD / 350S' TVD (x) Joints Tubing and tubing pups (1) Wire line Entry Guide, 4-112" L-80 IBT-Mod Box, to be spaced out +1- 15' above hook hanger Hook Hanger, Baker Model ~ B, 7-5/S" x 4-%", __________ Main Bore Drift = 5.315" Lateral Bore Drift = 3.S75" Window @ 6603' MD / 3625' TVD Conoc6Phillips ~. ~------I! - ~...:--~ - -- ------ ------- ------ ------- ~ Lower Liner Top Set @ +1-6,630' MD I 3.630' TVD I;;;==~I j tE:--~r Intermediate Casing 7-518" 29.7# L-80 BTC Mod Set @ 7,103' MD 13,700' TVD West Sak Production Well 1 B-1 01 Planned Completion Schematic Sheet 5 015: Tubing Details prepared by Steve McKeever 18-101 Permit Schematic_s5.vsd Monday, July 21, 2003 . . TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME fft( jE-/D/ L / PTD# 2-D 3 - /3tj CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing weD ~ /8 -/D / Permit No,lÞ5"¡.35API No. SZJ-oz!J-.2:S173-~ Production should continue to be reported as a function' of the original API number stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance witb 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Pr{ Date: ~/b(5 Public Commissioner ~~ Geologic Commissioner: Engineering Commissioner: Date Date 35 36 Date 37 7/30/2003 38 39 CQnta_ct namelphonefOO\leß~ly progress reports [explorç¡tory _onlYl Seismic_analysis Qf shaJlow gas_zoo~s_ Seç¡bed conditioo survey (if oft-shore) Yes Yes NA NA NA Appr SFD Geology Appr Date &¡ 8/6/2003 'þt'1--¥- ~h.( 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 Permit cao be issued wlo hydrogen sulfide meas.ures D_ata_presßoted On pote_ntial overpres_surß _zones MechaniCÇIlcoodJtion of w~lIs within .-6.0B verified (For_s_ervice wßIJ onJy) Js presence_ Qf H2S gas_ prob_ablß J~st to J _C_hokemanifold cQmpJies w/APlRF'-53. "YO. WQrk will occ.ur withoutoperç¡tion _shutdown psig in t"ay 84) BOPEs,_do _B_OPE_press ratiog appropriate; comments)_ DrilJiog flujd prQ9Jam SGhemç¡tic& equip Casiog desi9ns adequate for C,T~ B&_permafrost _Adequate tankage_oJ re_serve pit _ Jfare-drilt has_a_ 10-403 fQr abandonme_nt _Adequate well bore separ¡;¡tjon proposed Itdjvßrter req.uired, dQesit they meßt reguJaJion meßt rßguJaJions istadequ¡;¡te beeo ¡;¡pprQvßd CMT vol adßQuate_ to CMT will coyer all kOQwn _prQductiYe hQri~on_s _C9nductor strin! _S_urface _cç¡sing_ r"-' ",,,1'<........' CMT vol adßQu_ate_ to circulate_on _cond_uctor & surt C59 tie-in IQng _string to_surf csg_ Yes NA Yes No No_ Yes Yes NA Yes NA Yes Yes Yes Yes Yes No NA Stßve_ MGKee\ler, _CPA, 3-25-03: no H2S known in WSak QiI: rig eq.uipped withsensorslalarms, scayengßr av¡;¡ilaÞl M.-6.SP estirnated at 1513 psi. 3500 psi appropriate, PPCQ likely to test to_ 5000 psi BOp wi BHP expected beJweeo 9._6JQ 9.8 ppg EMW, PlanoedMW fQr WS 9.8 minimum. _already be oippled_up, F'roximit~ analysis perfoOTJed Big js_ e_quiped_ with steel pits. Close apprQaches identified. Tr¡;¡veJiog Gylindßr plQt jn~luded, No reserve pit pJanned. Waste_ to ao ¡;¡pprQvßd annulus or_dJsposaJ well, Set fQr "mother bore" _1 6-_101 M aq.uifeJs exempted 40 em :14 7.102(b )(3)_ Set fQr drilljngthe "m9thß( bore" 1 B-1 01 SettQr ddllin9 the_ "mothßr bore_" 16-_101 Slotte_d ioer _completioo plaoned._ Cement hejght meets regulatioos. Engineering Appr . 7/30/2003 Date . PTD#: 2031340 Administration "b,...II, ml Unique well Company CONOCOPHILLlPS ALASKA PeOTJit fee attached KUPARUK RIVER, WEST SAK OIL - 490150 12 13 14 15 16 17 2 3 4 5 6 7 8 9 10 11 n'^·ð~.~ ~'Lknown_ USDWs ACMP_ Finding 9f Consistency_has been issued_ for_ this prolect AJI wßlJswithln _1l4_mile_area_of reyißw ideotified (For servjce well only) Pre-produ_ced injßctor; .dur¡;¡tjQn_of prß-j)ro.dUGtion less than 3 months_ (For_sßrvlce well Qnly) Permit can be issued withQut PeOTJit can be issued wjthQut C_ao permjt Þe ¡;¡pprovßd before Well _1 JQCÇlted within area and_strata authorized by lojectioo Order ## (put 5-day waJt 10# incommeotsUFQr inclu.ded _Opßr_ator onl~ affectßd party _ _ _Opß(ator has_appropriate_ bond in Joroo conserva_tion order ad_minist(ati\le_approvaJ Well Well Well _S_utficient Kdeviated, js_ weJlbQre plç¡t acreageayailable in_driIJiog unit IQCÇlted in_adefine_dppol IQCÇlted proper _distance_ from drilling unit IQCÇlted proper _distance_ from Qther wells b_oundary _ LeasenUl)1ber _appropri¡;¡te name and oumb_er Field & Pool NC Initial ClasslType NA Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA NA NA drilljn9_the_ Multi-lateral well. DEV Well Name: KUPARUK RIV U WSAK PEND GeoArea 890 Multi-lateral;_$100 fee wç¡iyed, SFD B-101L 1 Unit 11160 Program DEV On/Off Shore On Well Annular Disposal bore seg ~ o WE,[.L f8RMIT ÇHECf(JI$T Field & Pool KUPARUK RIVER, WEST SAK OIL - 490150 PTD#:2031340 Company CONOCOPHILLlPS ALASKA INC Initial ClasslType Administration 1 Permit fee attached _ _ _ _ _ _ _ _ NA _ _ 2 Lease_number_appropriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ___Yes 3 _Unique wellname_aod oumb_er _ _ Yes _ 4 WeJIJQcated in_a_d_efioed-pooL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 5 WE!JIJQcated prpper _distaoÇE!Jrom dri)liog uoitb_ouodalY_ _ _ _ Yes _ 6 WeUJQcatedprpper_distaOÇE!JromQtheJW!3lJs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 7 _S_utficieot acr!3age_ayailable indrilJiog unit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 8 Jfdeviated, js weJlbQre platJocJuded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ 9 _O-P!3r_ator OOly affect!3d party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes 10 _Qp!3(ator has_approprlateJ~ond inJQrce _ Yes _ _ _ _ _ _ _ _ _ _ 11 Permit ca(1 Þe issued wjthQut conserva_tioo order _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ 12 Permit cao Þe issued withQut admioistrative_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ 7/30/2003 13C_ao permiLbe apprQv!3d before 15-day_ wait _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 14 WeJIJQcated wtthio area and_strata authQrized byJ(1jectipo Order # (puUOtt in_C9mmeotsUFor_ NA _ _ _ _ _ _ 15AJI W!3lJswithi!1JI4mile_are_a_of (eyi!3W ideotified (For servjceweU POly) _ _ _ _ _ _ _ _ NA _ 16 Pre-produ_ced i(1j!3ctor; duratio_n_of pr!3-productipo less_ than_ 3 months (fors!3r:vice welt QnJy) _ _ NA 17 ACMPFïnding9f CQn~i~te(1cy_has beenjssuedJorthis prplect _ _ _ NA _ Appr . Engineering Appr . Date 8/6/2003 Geology Appr SFD Date 7/30/2003 Geologic Commissioner: 18 _Cpodu_ctor string_PJQvid!3d _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ SettQr drilUngJhe_ "m_oth!3r bore_" _1 B-_101 19 _S_urface _casingpJQtects allkoown_ USQWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ ,6.11 aquifeJs exempted 40 cm :l47_.102(b)(3L _ _ _ _ _ _ _ _ _ _ _ 20CMT vol ad!3Qu_ate_ to circulate_o!1conductor & surfcsg _ _ _ Yes _ _ Set fQr d(illjngthe "moth!3( bore" 1 B-1 01 21 .CMTyolad!3Qu_atetotie-inJQng_striogto_sur:fçsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ _ _SettQrdrilljngJhe_"mpth!3(bore"1B-JOLCeme!1theightmeetsregulatipos._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. 22CMTwiIJ coyer_aJl koown-Pfo_ductiye bQrizons _ _ _ No_ _ SloUedJioercompletioo plaoned._ 23 _Casiog desi.Qos ad_equate fo( C,T~ B&permafrpst _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 24 AdequateJankageoJ reserye pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Rig isequiped with_steel pits._ 1\10 reserve pitpJa_noed_. Waste_ tp a(1 apPJQv!3d aonulus or_disposaJ welt _ _ _ _ _ _ _ 25 Jfare-drilt has_a_ 10-403 fQr aba_ndonme!1t bee(1 apPJQv!3d _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 26 Adequatewellboreseparationproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _Proximityanalysisperfprme_d. CloseapprQache_sid_eotified.TraveJirmcylind!3(pIQtjn_cLuded, _ _ _ _ _ _ _ _ _ _ __ 27 Jtdivecter required, dQes it me!3tr!3guJatioos _ _ _ NA _ BOP wiJl_alJeady be oippledup. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 28 _DriUi(1g f!ujdprogram sch!3matic_& eq_uiplistadequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Bt-IP eX-P!3cted betwee(1 9._6_tQ 9.8 ppg EMW. Plaooe_d_MW fQr WS 9.8 minjmum._ 29 BOPEs.dp they me!3t r!3gulatioo _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 30 _BOPE-Pfe_ssrati(1g appropriate; testto(pu_t psig i!1_commeotsL _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP estim_ated at 15_13 psi._ 3500 psLappropriate, PPCQ likely to testto 5000 psi. 31 _C_hoke_manjfold ÇQmpJies w/APIRF'-53 (May 84) _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 32 WQrk wi!1 pccur withputoperationshutdown_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 33 Js preseoce_ of H2S gas_ prob_aþl!3 _ _ _ _ No_ 34 Meçhanicalcpoditioopt wells withio ,6.0R yeriJied (Fors_ervice W!311 only) _ _ _ NA Date 35 Permit cao Þe issued wlo hydr_ogen sulfide measures _ 36 Datapres!3oted on potential pverpres_surezones _ _ 37Sei~mica!1alysis_ of sbaJlow gaszpoes 38 _Seabedcoodjtipo survey (if Qff-sho(e) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes_ _ ____ _ NA _ _ _______NA - - - - - - - - Date: Engineering Commissioner: Public Commissioner Date Date Well Name: KUPARUK RIV U WSAK 1B-101L 1 DEV I PEND GeoArea 890 Unit 11160 _ _ Multi-lateral;$10Q fee waived,SFD _ _ _ _ _ _ _ _ _ _ _ _ _ ~ D Program DEV On/Off Shore On WeU borE! seg Annular Disposal - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - ~ - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - ~ - - - - - - ~ - - - - - - - - - - - - - - - - - - ~ - - - - ~ - - - - - - - - - - - - - - - - - - - - -- - - - - - -- ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - . _ _ . Multi-lateral W!3ll. . - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _ . _ _ St!3ve_ Mc;K_eever, _CPA, 3-25-03: no H2S kooW!1 in WSak QiI; rig equipped withsenso(slalarms. scayeng!3( availaÞt - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Commissioner: . . 39 Date: CQntact l1ameLphol1eJor_weßlsly progress reports [explQratory 9nlYt Engineering Commissioner: Date Public Commissioner Date NA e e Well History File APPENDIX Information of detailed nature that is not particularly gennane 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 infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . . ð[)3-~3~ # AWS 01 ¡1-\C{'8 **** REEL HEADER **** LDWG 03/10/01 **** TAPE HEADER **** LDWG 03/10/01 01 *** LIS COMMENT RECORD *** !!!!!!!!!!!! !!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1B-10lL1 500292317360 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 01-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 3 C. MEYER F. HERBERT MWD RUN 6 6 C. MEYER D. LOWE MWD RUN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 9 llN 10E 88.40 60.40 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 10.750 3080.0 9.875 7.625 6890.0 STRING 6.750 12197.0 # REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 40.246" LONG: W149 DEG 35' 33.548" ~~~Y)\~ LeEASURED FROM D.F. AT 88.4 FT. ~ PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Directional Only service from 148 - 3090 feet MD (148 - 2206' TVD). (2) Baker Hughes INTEQ run 3 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity & Gamma Ray services from 3090 - 7395 feet MD (3) Baker Hughes INTEQ run 4 utilized a Multiple Propagation Resistivity (MPR) service along with a Navi II Annular Pressure sub in the interval covered by the lower lateral (lB-101, 7395 - 12230 feet MD, 3731 - 3713' TVD) . (4) Baker hughes INTEQ run 5 was a window milling run for this lateral. No data is presented from this run. (5) Baker Hughes INTEQ run 6 utilized a Multiple Propagation Resistivity (MPR) service along with a Navi II Annular Pressure sub from 6874 - 12197 feet MD (3661 - 3659' TVD). (6) Per ConocoPhillips Alaska instructions, the Gamma Ray curve from this log is the depth reference for this well. As such, no depth shifts have been applied. REMARKS: (1) The interval from 148 - 3090 feet MD (148 - 2206' TVD) was drilled with directional tools. No formation evaluation logging was done in this interval. (2) Depth of 10 3/4" Casing Shoe-Logger: 3080 feet MD (2200' TVD) Depth of 10 3/4" Casing Shoe-Driller: 3080 feet MD (2200' TVD) (3) Depth of 7 5/8" Casing Window-Logger: 6890 feet MD (3664' TVD) * Please note that due to the change in resistivity tools at the 7 5/8" casing window, from RNT to MPR, that the presentation goes from 2 phase resistivity curves to 4 phase resistivity curves. (4) The interval from 12166 to 12197 feet MD (3657 - 3659' TVD) was not logged due to sensor-bit offset at TD. $ Tape Subfile: 1 92 records... Minimum record length: Maximum record length: 8 bytes 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! ! ! ! !! !!!! ! !!!!!!!!!!!! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ LDWG File Version 1.000 Extract File: FILE001.HED 1 and clipped curves; all bit runs merged. .5000 START DEPTH 3030.0 STOP DEPTH 12197.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DA~EASURED DEPTH) 4IIÞ --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ BIT RUN NO 3 6 MERGE TOP 3030.0 6890.0 MERGE BASE 6890.0 12197.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. Please note that due to the change in resistivity tool type at the 7 5/8" casing window, the presentation goes from 2 resistivity curves (RPD, RPS) to 4 resistivity curves (RPD, RPM. RPS, RPX). RPM & RPX data above 6890' contains null values. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT Ib-l0lLl 5.xtf 150 ConocoPhillips Alaska, Inc. IB-I0lLl Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 , 5 RPX MWD . 1 OHMM 4 4 . 6 ROP MWD 68 1 FPHR 4 4 7 FET MWD 68 1 HR 4 4 8 MTEM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 655 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3030.000000 12197.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 703 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** ! !!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate files. 3 .2500 START DEPTH 3030.0 STOP DEPTH 6890.0 # 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: 23-AUG-03 MSB 18704 6.75 ATK MEMORY 7395.0 3030.0 6890.0 o 63.3 86.4 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL TOOL NUMBER SHE 17834 RNT 20099 RNT 20099 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3080.0 # BOREHOLE CONDITIONS J 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # L. 9.40 .0 .0 150 .0 .000 .000 .000 .000 118.0 .0 .0 .0 .00 .000 .0 o BIT RUN 3 (MWD Run 3) . GR/RNT. This wellbore, 1B-101L1, was sidetracked at a point along this bit run drilled for 1B-101 (6890' MD). CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT splice.xtf 150 ConocoPhillips Alaska, I 1B-10lL1 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] 4 Number of frames per~ord is: One depth per frame (value= 0) Datum Specification Block Sub-type 28 is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 552 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 3030.000000 6890.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 644 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 3 . log header data for each bit run in separate files. 6 .2500 START DEPTH 6890.0 STOP DEPTH 12197.0 # 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): 03-SEP-03 MSB 18704 4.75 MPR MEMORY 12197.0 6890.0 " BOTTOM LOG ItllbVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL MULT. PROP. GAMMA RAY RES IS. # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 12..0 o 75.5 92.6 TOOL NUMBER SDS 13 63 MPR 54694 SRIG 58019 6.750 6890.0 Flo-Pro 9.60 .0 .0 79000 .0 .000 .000 .000 .000 96.0 .0 .0 .0 .00 .000 .0 o BIT RUN 4R (MWD Run 6). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT splice.xtf 150 ConocoPhillips Alaska, I IB-I0lLl Kuparuk River North Slope Alaska . *** INFORMATION TAB. CIFO MNEM CHAN DIMT CNAM . ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1118 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6890.000000 12197.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 4 1217 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/10/01 01 ~ , . **** REEL TRAILER **** LDWG 03/10/01 AWS 01 Tape Sub file: 5 Minimum record length: Maximum record length: . 2 records... 132 bytes 132 bytes