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Home My WebLink About201-231Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221128-1 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# CLU 13 50133206460000 214171 11/12/2022 Halliburton PERF CLU 05RD2 50133204740200 222092 11/11/2022 Halliburton PPROF KBU 22-06 50133205500000 205054 2/26/2022 Halliburton RMX KBU 22-06 50133205500000 205054 2/26/2022 Halliburton TMD3D KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton RMX KBU 33-06X 50133205290000 203183 2/28/2022 Halliburton TMD3D KDU 4 50133201760000 169012 11/7/2022 Halliburton EPX KDU 4 50133201760000 169012 11/7/2022 Halliburton MFC24 KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton EPX KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton MFC24 Please include current contact information if different from above. By Meredith Guhl at 10:05 am, Nov 29, 2022 T37319 T37313 T37320 T37320 T37321 T37321 T37322 T37322 T37323 T37323 KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton EPX KU 43-6RD 50133100910100 201231 11/8/2022 Halliburton MFC24 Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.11.29 11:15:51 -09'00' • Seth Nolan Hilcorp Alaska, LLC GeoTech II 3800 Centerpoint Drive Anchorage, AK 99503 Tele: 907 Hik rp RECEIVED Fax: 907 777-85010 E-mail: snolan@hilcorp.com AUG 2 9 2017 AOGCC 9A 5 011 DATE 08/28/2017 M.K.BENDER To: Alaska Oil & Gas Conservation Commission Meredith Guhl Petroleum Geology Assistant II 333 W 7th Ave Ste 100 Anchorage, AK 195-055 28556 201-144 28558 99501 - 205-117 28557 201-231 28550 ----- DATA 8559DATA TRANSMITTA PEARL STRATIGRAPHIC TESTS Log digital raster data CD: 1 Electric logs aro KBU 31-07RD_induction.pdf 9/19/2013 4:27 PM PDF Document 15,577 KB L_I KBU 31-07RD_inducti on.of 9/18/2013 9:34 AM TIF File 797 KB KBU_31-07RD_mudlog.pdf 8/14/2017 8:54 AM PDF Document 1,129 KB KBU_31-07RD_mudlog.tif 8/14/2017 8:47 AM TIF File 3,362 KB tai,KTU43-6XRD2_ML MD.pdf 9/1/2005 10:31 AM PDF Document 2,026 KB u KTU43-6XRD2_ML_MD.tif 8/14/2017 8:53 AM TIF File 3,701 KB �a KU24-05RD_mudlog,pdf 8/14/2017 8:54 AM PDF Document 561 KB u KU 24-05RD mudlog.tif 8/14/2017 8:45 AM TIF File 2,677 KB KU_43-06RD mudlog.pdf11 8/14/2017 8:54 AM PDF Document 1,022 KB I K1J 43-06RD mudlog.tif 8/14/2017 8:46 AM TIF File 3,362 KB Please include current contact information if different from above. O SEP 1 22017, Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Ot4 Date: (X)A412-420020....i<17) . . MEMO WELLS PRODUCING IN KENAI, STERLING POOL 6 AS NATIVE & STORAGE GAS WELLS Reference letter in file dated October 25, 2006 about wells producing from the Kenai, Sterling 6 Pool (pool code 448568) and the Kenai Pool 6 Gas Storage (pool code 448809). Storage Injection Order 7 A has a report, 2007 Annual Gas Storage Performance Evaluation dated March 2, 2007 which has a statement with an official start date of May 8, 2006 where storage started in the pool. There was no formal paperwork submitted about this change so this letter is for the official well status date change for the well status or date it was accomplished by AOGCC. The following is a list of wells that is reported with both pool codes 448568 and 448809: APD No. 201-097 201-231 159-013 165-007 178-055 168-071 181-092 181-154 182-015 182-085 184-109 185-181 200-148 Well No. 21-6RD 43-6RD 34-31 33-32L 44- 3 OL DU5-L 14X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X 17 h?- ?'fl. ,.. 0 ~ o ~\~~ sCANNED JUL 2 7 2007 e e Alaska Asset Team United States Production Operations (. M.') Marathon MARATHON Oil Company P.O. Box 3128 Houston, TX 77253 Telephone 713-296-3597 Fax 713-235-6322 July 2, 2007 FEDERAL EXPRESS 5CANNED JUL 05 2007 Alaska Oil & Gas Conservation Commission Attn: Howard Okland 333 W. 7th Avenue, Suite 100 Anchorage,AJ( 99501 RE: Marathon KU #43-06RD - API 50-133-10091-01 I ") CONFIDENTIAL - ~ \0. f'.. Dear Mr. Okland: f} I ) Enclosed is one CD containing confidential digital well data for the above referenced well, as described on the attached CD Contents document. Please indicate your receipt of this data by signing below and returning one copy to my attention at the letterhead address or fax to 713-235-6322. Thank you, Courtney McElmoyl Received by: 1JJfJIlJ Date: > Enclosures JUL 0 3 Z007 Alaska Oil & Gas Cons. Commission Anchorage 10\ - ~)L e Directional Data: rlª ' · !1cJ.J_ 43-6rd_dir _sur. dat ¡ .........................................................- Mudlog Data: roP..~.~..~~~~.J !ôMorning Reports ~KU43-6RD FINAL WELL REPORT. doc ~ KU43-6RD.las ŒJ REMARKS. TXT e KU 43-06RD API 50-133-10091-01 CD CONTENTS Confidential .." .. . Alaska .eam Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/565·3076 October 25,2006 Alaska Oil and Gas Conservation Commission Attn: Steve McMains 333 W. 7th Street, Suite 100 Anchorage, AK 99501 , 'Mj>,\rt'l ti\;~1tJ!' t.t:.t.+ ~ C RE: Wells Completed in Pool Codes 568 and 448809 Dear Steve, " Per your request, this letter is being provided to the AOGCC to identify wells completed in the Kenai Sterling Pool 6 (Pool Code 568) and the Kenai Pool 6 Gas Storage (Pool Code 448809). As you are aware, the above pool codes refer to the same geologic reservoir, a partially depleted gas reservoir which is being used for gas storage operations. Subsequent to the initiation of storage operations in May 2006, all future production from this reservoir is allocated between the remaining native gas and the injected/stored volumes, per written agreements between Marathon Oil Company and both the ADNR and the BLM. Therefore, any production from the wells completed in Pool 6 will be reported monthly on Form 10-405 under both pool codes. The wells appearing on Form 10-405 will appear the same for both pool codes. Per your request, the following is a list of wells which will be reported on Form 10-405, for both Pool Code 568 and 448809: Well No. 21-6RD 43-6RD 34-31 33-32L 44-30L DU5-L l4X-6AN 34-32L 14-32L 13-6L 23X-6SAN 33-7S 3 1- 7X API No. 5011331009001 5011331009101 5011331009700 5011331009800 5011332013900 5011332031900 5011332034200 5011332034800 5011332035100 5011332035600 5011332037100 5011332038000 5011332049500 APD No. 201097 201231 159013 165007 178055 168071 181092 181154 182015 182085 184104 185181 200148 ¡/ > '. . . Please advise if you have any questions or need any additional information. I can be reached at 907.565.3041 or lcibele@marathonoil.com. yndon Ibele, PE Production Coordinator Cc Randy Jindra, IBM, Tulsa Ken Walsh, MOC, Kenai Marathon Houston Central Piles Brian Havelock, ADNR, Anchorage Greg Noble, BLM, Anchorage . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marlœr.doc yz,,;l' - l,'A- ~t(t... ^(o t'Jr~ ~I<L ~. )(~ Permit to Drill 2012310 MD 5740 r TVD 4787 .- - REQUIRED INFORMATION - DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type MedlFrmt Number Name Well Cores/Samples Information: Name L__._- Cuttings ADDITIONAL INFORMATION Well Cored? Y I Ú Chips Received? . Y I N - Analysis Received? ~ Comments: --- Compliance Reviewed By: )() ,1.~)¡C~~ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 S'p « ¿ l t>¡ J vv---, ~ 0 i:\ -", API No. 50-133-10091-01-00 Well NamelNo. KENAI UNIT 43-06RD Operator MARATHON OIL CO Completion Date 311112002 Completion Status 1-GAS Current Status 1-GAS UIC N Mud Log No Samples No Directional Survey Yes ¡;1 ~ ~- (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No ) Interval Start Stop OHI CH Received Comments Interval Start Stop 4174 5740 Sample Set Number Comments 1112 --- Sent Received Daily History Received? ÒN &/N Formation Tops c ~ ,"- [ !~ L.--v~ 1Zu.. "'- yZ~~ ) Date: - [~ f:l¡~ AA'-1J '--{ , ~, .-... Alaska ,Jess Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 September 20, 2002 V r Þ ~ 0 1- ;ìv1 ¡ S~~ \\\~ Alaska Oil & Gas Conservation Commission Attn: Howard Oakland 333 W. ih Avenue, Suite 100 Anchorage, AK 99501 VIA COURIER RE: Marathon Kenai Unit #43-6RD - CONFIDENTIAL Accompanying this letter are two (2) boxes of CONFIDENTIAL well samples for the above referenced well, as described below Box # 1 2 Depth 4174 5500 To Depth 5500 5740 Please review the enclosed data, sign and return one copy of this transmittal. Thank you, ~~~)'Nì,,- Kaynell Zeman' Technical Assistant Attached (2 boxes) Received by: Date: ~~ Environmentally aware for the long run. WtJA 1-; l~ ~ STATE OF ALASKA ---- ALAbt'\.A OIL AND GAS CONSERVATION COMr-v,.,310N WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well olLD GAS[R] SUSPENDEDD ABANDONEDD 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 205' FNL, 4231' FWL, Sec. 7, T4N, R11W, S.M. At top of Producing Interval SERVICED ~- r. ~ ',ji ~ ß.. .~~! i"CÔMPLf:(íòU, ! ~,,:~,,~i At Total Depth ! Á-Þ i 2548' FSL, 3448' FWL, Sec. 6, T 4N, R11 W, SM ',,:,:;:;:"~~.:::::::~ 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. 21.00' DF-GL A-028142 Classification of Service Well 7. Permit Number 201-231 8. API Number 50-133-10091-01 9. Unit or Lease Name Kenai Beluga Unit 10. Well Number KU 43-6rd 11. Field and Pool Sterling Pool 6 Kenai Gas Field 12. Date Spudded 1/19/2002 17. Total Depth (MD+TVD) 5740' MD, 4787' TVD 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/11/2002 N/A feetMSL one 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 5651' MD, 4720' TVD YeS~No D N/A feet MD N/A 13. Date T.D. Reached 1/21/2002 22. Type Electric or Other Logs Run RST-GR-CCL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED CASING SIZE WT. PER FT. GRADE 20" 78.6 K-55 0 52 10-3/4" 32.75 H-40 0 1297 7-518" 26.4 J-55 0 4174 4-172" 12.6 L-80 3984 5740 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) Sterling Pool 6 5304' - 5420' MD, 4461' - 4548' TVD 6 spf, 3-318" TCP guns Driven 17-1/2" 9-7/8" 6-1/8" 25. SIZE 3-1/2" & 2-7/8" (tapered) Driven 1450 sks 700 sks 190 sks TUBING RECORD DEPTH SET (MD) PACKER SET (MD) 5283' NIA NIA NIA NIA NIA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED NIA 27. Date First Production 12-Mar-02 Date of Test 4/4/2002 Flow Tubing Pres. 150 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) flowing PRODUCTION FOR OIL-BBL GAS-MCF TEST PERIOD --.. 0 3205 CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE--" 0 3205 Hours Tested 24 Casing Pressure 0 WATER-BBL CHOKE SIZE I GAS-OIL RATIO 0 NIA WATER-BBL OIL GRAVITY-API (corr) 0 NIA 28. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Interbedded sandstone, siltstone, shale, and coal ru'~ #"" r~ n f .- 0' ~%'.' t~ i ~=, u !- . ~ \. \."" b ~ fa ¡¡.~. . , . . (', ,.., Iì f\ C, ') f,.;1'I.V l,'/ /1' I ;1,-,: ; '- L..lie;<- (ì .,' , . Alaska Oil & Gas Cons. CommissIOn Anchorage Form 10-407 Rev. 7-1-80 N: \drlg \kgf\wells\KBU 33- 6\AOGCO MP L. xis CONTINUED ON REVERSE SliB OMS B F I Submit in Triplicate MAY' 52m2 -.., /'""\ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME MEAS. DEPTH TRUE VERT. DEPTH Top Sterling 4177 3596 Top Beluga 5625 4701 Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. NIA ,". t ~-P!!""n ! "" ~ ~, .. ~", ", ~ ) L Ii ;," Ù.. ,f' ~ "'OAf) ¡ i -/ ')1 i,it" U -- '"' l '.' '""' Alaska OJ! & Gas CeilS. L;Omm¡SSiOf: AnchoraQe 31. LIST OF ATTACHMENTS Daily operations summary, wellbore schematic, directional survey 32. I hereby carti that the foregoing is \rue and correct to the best of my knowledge , ~~ Gary Eller Title Production Engineer Date 5/1/2002 Signed INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.) Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other- explain. Item 28: If no cores taken, indicate "none". Form 10-407 N: \drlglsterl inglsu32-9\A 00 COM P L. xis r~¡ "-/ (~) DF-GL: 21.00' DF-THF: 18.78' API:50-133-10091-01 AOGCC: 201-231 205' FNL, 4231' FWL Sec. 7, T4N, R11W, S.M. Tree cxn: 6.5" Otis Tree drawinq "-, Tubino (tapered string) 0' - 3919', 3-1/2", 9.3 ppf, L-80, EUE 8rd 3919' - 5272', 2-718", 6.4 ppf, L-80, ST-L (flush) includes 1 jnt of slotted 2-7/8" tbg, 5237' - 5268' 5272' - 5283', 2-3/8", 4.6 ppf, L-80, EUE 8rd XN nipple @ 5232' ID::: 2.313", no-go::: 2.205' Re-entry Guide @ 5283' ID::: 1,995" Tubing detail Directional Max hole angle 41.9 deg Directional survey Well Name & Number: County or Parish: Perforations: (MD) Date Completed: Prepared By: . KU 43-6rd .. t~:' I Iii:; %\:: l}: :Wf' Ililifl ,..,. fU :~ if~1 t 'ad ::.. ¡I'll ::-~ ~ ! ~~:~ ! r ; ~ m ~ ~ ~ Ifci:< i.a iß I PBTD: 5651' I TD: 5740' KU 43-6rd I StatelProv. Pool 6, 5304' - 5420' MD 031111021 Gary Eller ..-, ~ I Drive Pipe: 20",78.6 ppf @ 52' . Surface Casino: 10-3/4",32.75 ppf, H-40, STC @ 1297' Cmt w/1450 sks Liner Top: Baker ZXP liner-top packer @ 3965' 4-1/2",12.6 ppf, L-80, BTC linertop @ 3984' Production Casino: 7-5/8",26.4 ppf, J-55, LTC @ 4174' (sidetrack window) Cmtw/700 sks (Originally run to 5601', June 1965) RA Taos: 2-7/8" tubing @ 5006' 4-1/2" casing @ 5102' Pool 6 Perfs 5304' - 5420', 3-318" TCP guns, 6 spf, 60-deg phase with auto-release system IFiSh: 3-318' gun assembly, 5513' - 5651' Production Liner: 4-1/2", 12.6 ppf, L-80, BTC @ 3984' - 5740' Gmt w/190 sks Lease I Alaska (TVD) I Last Revision Date: Country: I 4461' - 4548' TVD I DF-GL: 1-May-02 I 21. 00 USA ;-.., ,~. WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS RiQ down riQ. 24 HR FORECAST Continue rig down rig. FIELD NAME Kenai ST KB GL 01 87.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 24HRSPROG ITMD TVD DFS IREPTNO. ¡DATE 1 119/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 5,713 9208002 735,000 I MOC WI INRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%) 36,250.00 36,250.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST ¡NEXT CASING LEAKOFF PPG 0 (in) @ 0 (ft) Move rig to KU43-6. 1 STATEIPROV I COUNTY/OTHER ¡LAST CASING Alaska Kenai Borough @ OP COMMENTS: Rig released from maintenance @ 12:00hrs 1108/2001. RID rig and prepare to move rig to 43-6 location. 12:00 06:00 18.00 AF RDMO Release rig from maintenance @ 12:00hrs 1108/2001. Remove carrier tarps. derrick guide wires. Back wind walls. Pull electric wires to to rig floor and pits. Blow down service lines and brakes. Spot blocks and and scope down top derrick section. Rig down rig floor wind walls. Remove doghouse and choke house. Pump off 1480 gallons excess fuel. Remove fuel tank. Top all day tanks wlfuel. Level 43-6 location. Begin to set rig mats on 43-6. Inlet Drilling Alaska Weaver Brothers R&K Industrial 18 5 1 216.00 Veco Alaska 60.00 Alaska Petroleum Contrac 12.00 1 4 12.00 48.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: Printed: 1/11/2002 6:44:48 PM ,-.... '-", WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS Move and RlU rig. 24 HR FORECAST Complete rig down rig. FIElDNAME Kenai ST KB IGL 01 87.00 66,00 RIG NAME & NO. GLACIER DRILLING 1 24HRSPROG ITMD TVD DFS REPTNO. ¡DATE 1 2 1110/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 5,713 9208002 735,000 I MOC WI INRI DAILY WELL COST CUM WELL COST 100.00 (%j 92.20 (%) 16,370.00 52,620.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST I NEXT CASING lEAKOFF PPG 0 (in) @ 0 (ft) Move rig to KU43-6. I STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough @ OP COMMENTS: Complete RID of rig. Cont. RlU rig on 43-6. 06:00 06:00 24.00 AF MIRU Finish set rig mats on 43-6. Lay derrick over on carrier. RID boiler and water tanks. Move rig components to 43-6. Clean ice from rig mats. Clean out boiler house. Replace bad steam valves. Set pump trailer and pits. Inlet Drilling Alaska Weaver Brothers R&K Industrial 18 5 1 216.00 Veco Alaska 60.00 Alaska Petroleum Contrac 12.00 1 4 12.00 48.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: Printed: 1/11/2002 6:44:54 PM ~, ~ ST KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 124 HRS PROG TMD DFS REPTNO. /DATE 2 3 1111/2002 I RIG PHONE AUTH MD AFE NO. I AFE COST 907-283-1312 5,713 9208002 735,000 IMOCWI INRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%) 19,093.00 71,713.00 I ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST NEXT CASING LEAKOFF PPG 0 (in) @ 0 (ft) WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS _RIU rig. 24 HR FORECAST Complete RIU rig. FIELD NAME Kenai OP COMMENTS: STATEIPROV I COUNTY/OTHER ¡LAST CASING Alaska Kenai Borough @ Cont. move and RIU rig. 06:00 12:00 6.00 AF MIRU RIU steam and water hoses. Pull electric lines. Lower sub base and move to 43-6. Unload trailers. Spot mud pits. RIU mud lines. Prep and raise sub. Pin and spot sub over well. Install mud boat. Attach ramp and RIU rig water lines. Fire up boiler. spot mechanic and parts trailer. Spot change house and RIU same. Set fuel tank. Spot carier. Fold down sub wings. Raise derrick and rear wind walls. Set carrier stairs spot second water tank and slop tank. RIU sub base outriggers. Set dog house and choke house. RIU floor plate, windwalls, stairs, catwalk, flowline, beaver slide. 12:00 00:00 12.00 AF MIRU 00:00 06:00 6.00 AF MIRU Inlet Drilling Alaska Weaver Brothers R&K Industrial 18 5 1 216.00 Veco Alaska 60.00 Alaska Petroleum Contrac 12.00 1 4 12.00 48.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: Printed: 1/12/2002 10:02:47 AM ~ ~. WEll NAME KU 43-6RD SUPERVISOR R.C. Lawson CURRENT STATUS RIU rig. 24 HR FORECAST Complete RIU rig. Fill tubing and casing. N/D tree. NIU BOP. FIELD NAME I STATEIPROV I COUNTY/OTHER ¡LAST CASING Kenai Alaska Kenai Borough @ ST IKB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 IGl 66.00 24HRSPROG TMD TVD DFS REPTNO. DATE 3 4 111212002 I RIG PHONE AUTH MD AFE NO. ¡ AFE COST 907-283-1312 5,713 9208002 735,000 I MOC WI INRI DAILY WEll COST CUM WEll COST 100.00 (%) 92.20 (%) 15,000.00 86,713.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None I NEXT CASING (in) @ 0 (ft) lEAKOFF PPG 0 OP COMMENTS: RIU rig. 06:00 12:00 6.00 AF MIRU RIU mud pits. RIU drillers console. Repair PLC power, extend mast, tighten guide wires, and set rig floor exterior lighting. Cont. RIU guide wires. RIU degasser u-tube and choke lines. RIU steam to rig floor. Hang tarps for carrier and sub. MIU stand pipe lines. Install mud shock hose. Cant. to RIU electricallinean and Geolograph lines. Plumb water line to tanks flwell chagre pump manifold. RIU top drive unit on stand. Set link tilt extend, Set torque and max connection RPM. Trouble shoot mud saver on top drive. Install rotary table motor. Block up ramps on carrier. Install choke hose. Cont. RIU stand pipe manifold. Install hydraulic cylinder socks. RIU windwalls on derrick board. RIU torque tube and hang T-bar. Install turnbuckles for torqul' tube. 12:00 00:00 12.00 AF MIRU 00:00 06:00 6.00 AF MIRU Inlet Drilling Alaska Weaver Brothers Veco Alaska 18 5 2 216.00 Alaska Petroleum Contrac 60.00 Tesco 12.00 4 1 48.00 12.00 LAST BOP TEST: LAST CASING TEST: NEXT BOP TEST: Printed: 1/12/2002 10:02:41 AM ~ ,,-., WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS N/D tree. 24 HR FORECAST Complete RlU rig. Fill tubing and casing. NID tree. N/U BOP. FIELD NAME I STATEIPROV COUNTY/OTHER ¡LAST CASI.NG Kenai Alaska Kenai Borough @. 24HRSPROG ITMD TVD DFS REPTNO. ¡DATE 4 5 1/13/2002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 5,713 9208002 735,000 IMOC WI INRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%~ 15,225.00 102,838.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None ¡NEXT CASING (in) @ 0 (ft) ST IKB GL 01 87.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 LEAKOFFPPG 0 OP COMMENTS: Complete RlU rig. RlU to long sting. Long string taking fluid. Fill TBG X CSG annulus while mix LCM pills. Pump LCM pill and fill long string. NID tree. 06:00 12:00 6.00 AF MIRU 12:00 14:00 2.00 AF MIRU 14:00 15:00 1.00 AF MIRU 15:00 16:00 1.00 AF OTHER 16:00 17:30 1.50 AF OTHER 17:30 19:30 2.00 AF OTHER 19:30 20:00 0.50 AF OTHER 20:00 21:30 1.50 AF OTHER 21:30 00:30 3.00 AF OTHER 00:30 01:30 1.00 AF OTHER 01:30 03:00 1.50 AF OTHER 03:00 06:00 3.00 AF OTHER Inlet Drilling Alaska Weaver Brothers Veco Alaska 18 5 2 Cont. RlU TDS add 118" shim to slider on both sides. Pump up TDS compensator wlnitrogen. Prepare extended hoses to TO compensator. Repair hydraulic leaks. RIU panic line. RlU panic line. RlU drill floor drain hoses. RlU cellar cranes. RlU long bales. N/U valve on x-mas tree. Pull BPV's from LS and SS. RlU kill line to LS. RlU choke to annulus. Pump down long string. Pumped 16bbls pressure 450psi. Pressure fell back and bullheaded 42bbls fresh water @ .73bpm w1150psi. Observe well. Well losing 26BPH. Blow down lines. Mix LCM pill. Pump 130bbls into 2 7/8" Dual X 7518" annulus.. Hold 250psil20min. Bleed off air and add 5bbls fresh water. Hold 250psil15min. Bleed off annulus. Blow down lines. Complete mixing LCM pill. Pump 30bbls (20PPB CaC02 Med, 10PPB CaC02 Course, 3PPB Flovis 8.4PPG 74Vis). Well on vaccum. Observe well taking 26BPH. Blow down line. Mix LCM pill. Pump 33bbls(30PPB CaC02 Med, 20PPB CaC02 Course, 4112PPB Flovis 9.0PPG 320Vis). Observed well to be on very slight vaccum. RlU on short string. Fill short string wl5bbls freash water and pressure up to 250psi. Bled off to 100psi in 3min. RID from short string. RID from TBG X CSG. Blow down lines. Set BPV's. N/D tree. 216.00 Alaska Petroleum Contrac 60.00 Tesco 12.00 4 1 48.00 12.00 LAST BOP TEST: NEXT BOP TEST: LAST CASING TEST: Printed: 1/13/2002 11:53:25 AM ~ .~ WELL NAME KU 43-6RD SUPERVISOR R.C. Lawson CURRENT STATUS R/U to cut jet tubing. 24 HR FORECAST Cut long string and short string. POOH UD dual 2 7/8. FIELD NAME I STATEIPROV I COUNTY/OTHER ILASTCASING Kenai Alaska Kenai Borough (in) @ KB GL /24HRSPROG TMD TVD IDFS 87.00 66.00 ¡RIG NAME &NO. ¡RIG # AUTH MD AFE NO. GLACIER DRILLING 1 907-283-1312 5,713 9208002 I MOC WI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 20,490.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. None 1/14/2002 NEXT CASING (ft) (in) @ (ft) REPT NO. /DATE 6 1/14/200~ AFE COST 1,449,250 CUM WELL COST 123,328.00 BOP PSI TEST 1/14/2002 LEAKOFF PPG 24 HR SUMMARY: N/U BOP. Test BOPE. Bullhead 30bbls down short string. 06:00 12:00 6.00 OTHER N/U 9" 3M X 11 "3M DSA and 11 "3M X 13 5/8"5M adaptor spool. N/D single gate BOP from stack. C/O upper rams to 2 718" duals. Function test stack. N/U 135/8" 5M A,Rd,S{w/dual 2 7/8" rams and blind rams) BOP Pull BPV's and install TWC's. Attempt BOP test. Tighten flange between mud cross and adaptor flange. Test choke valves 10,11,12,6,8,9, blind rams, outside and inside kill valves 250/3000psi 10min. Repair kill line check valve and test 250/3000psi 10min. Test choke valves 2,7,5,1,3,4 and manual choke 250/3000psi 10min. Test choke line HCR, manual choke line valve, 27/8" Dual rams, #1 floor valve, #2 floor valve, IBOP, upper and lower kelly cocks to 250/3000psi 10min. Pull TWC's{5bbls to fill well). M/U landing joint. RIU cement line to short string. Bullhead 30bbls fresh water down short string max pressure 850psi @ .8BPM. Shut off pumps and pressure bled off f/850psi to Opsi in 6.5 min. 12:00 16:30 4.50 OTHER 16:30 17:00 0.50 17:00 18:00 1.00 18:00 20:00 2.00 OTHER OTHER OTHER 20:00 21 :00 1.00 21 :00 00:00 3.00 00:00 03:30 3.50 OTHER OTHER OTHER 03:30 04:30 1.00 OTHER 04:30 06:00 1.50 OTHER Dr_... 1 24.00 1 4.00 Inlet Drilling Alaska Marathon 18 1 216.00 M-I Drilling Fluids 24.00 Alaska Pipe Recovery Printed: 1/14/2002 7:56:35 AM ~. ~ WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS RID Weatherford tubing tools. 24 HR FORECAST PIU DP. Run bit and scraper. FIELD NAME I Kenai ST /KB IGL 01 87.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 STATEIPROV I COUNTY/OTHER ¡LAST CASING Alaska Kenai Borough @ /24 HRS PROG TMD TVD DFS REPT NO. ¡DATE 7 1/15/2002 RIG PHONE AUTH MD AFE NO. IAFE COST 907-283-1312 5,713 9208002 735,000 MOCWI INRI DAILY WELL COST CUM WELL COST 100.00 (%~ 92.20 (%) 37,419.50 160,747.50 ¡ACCIDENTS 24HR LAST SAFETY MTG. BOP PSI TEST None 1115/2002 1/14/2002 ¡NEXT CASING LEAKOFF PPG (in) @ 0 (ft) OP COMMENTS: Cutt LS and SS tubing. Circulate tubing strings. POOH LID 2718" tubing. RID Weatherford. 0 06:00 09:00 3.00 AF OTHER 09:00 11:00 2.00 AF OTHER 11:00 12:00 1.00 AF OTHER 12:00 14:30 2.50 AF OTHER 14:30 15:30 1.00 AF OTHER 15:30 16:30 1.00 AF OTHER 16:30 19:00 2.50 AF OTHER 19:00 20:30 1.50 AF OTHER 20:30 ,05:00 8.50 AF OTHER 05:00 06:00 1.00 AF OTHER Inlet Drilling Alaska Marathon M-I Drilling Fluids 18 1 1 RlU electric line. PJSM prior to cutting tubing. RIH (LS) to 4367(had to work tool down last 150'). Shoot 21/8" jet cutter@ 4296'. Tool stuck immediatly after firing. Work stuck tool while circulating long string taking returns out the TBG X CSG valve. Tool came free after working 2hrs. POOH wljet cutter. RIH(SS) to 4390' and cut tubing @ 4319' w/2 118" tubing cutter. POOH. RID APRS. RlU to LS and circulate out wI4BPM 463psi. RID on LS and RlU to SS and circulate out w/4BPM 372psi. RID circulating hose. RlU Weatherford TBG pulling equipment. BIO lockdowns on tubing head. Work tubing free wl50K overn string wi. Pull hanger assy to floor. UD landing joints anf hanger assy. Organize rig floor. M/U safety valves to 2 718" BUTT XIO's. PJSM prior to UD i- 7/8" tubing. POOH LID 2 718" tubing(total 273jnts). RID Weatherford tubing tools. 2,047.50 7,027.50 1 3 4.00 36.00 LAST BOP TEST: 1/1412002 112112002 LAST CASING TEST: NEXT BOP TEST: Printed: 1/15/2002 10:00:07 AM ,~ '-.. ST IKB IGl 01 87.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 WEll NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS Prepare to POOH. 24 HR FORECAST POOH. Set 7 518" EZSV. FIELD NAME Kenai 124 HRS PROG TMD TVD DFS ¡REPT NO. /DATE 8 1/1612002 I RIG PHONE AUTH MD AFE NO. AFE COST 907-283-1312 5,713 9208002 735,000 MOC WI INRI DAILY WEll COST CUM WEll COST 100.00 (%1 92.20 (%) 56,068.00 230,565.50 ACCIDENTS 24HR lAST SAFETY MTG. BOP PSI TEST None 111512002 1/14/2002 I NEXT CASING lEAKOFF PPG (in) @ 0 (ft) Slueeze old perfs. STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough @ 0 OP COMMENTS: c/o pipe rams. Test BOP. PIU DP while RIH. Tag @ 4300'. Circulate while PIU 60 jnts DP and rack back. 06:00 10:00 4.00 AF SIDET 10:00 12:00 2.00 AF SIDET 12:00 15:00 3.00 AF SIDET 15:00 17:00 2.00 AF SIDET 17:00 00:00 7.00 AF SIDET 00:00 01:00 1.00 AF SIDET 01:00 06:00 5.00 AF SIDET CIO to short bales. C/O elevators. C/O moused holes. CIO upper rams to 4". Load pipe rack w/25-3 112" HWDP. Strap HWDP. PIU test joint and MIU test plug. Test upper 4" rams and annular 25013000psi 10min. Perform accumulator test. Pull test plug. Could not get wear bushing through DSA. UD wear bushing. RIU floor to PIU DP. Adjust new tong counterweight system. P/U 6 3/4" bit and 7 5/8" csg scraper BHA. PIU 4.0" DP while RIH. Tag @ 4300'. Pump 20bbl hi-vis sweep and circulate out. Change out air boot for flowline. Circulate while PIU 4.0" DP and rack back. BIT/RUN RPM I GPM I PRESS I WOB 7,652.00 14,679.50 PBIT I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP HRS I XR+ ,7518" CSG SCRAPER, 31/2"REG X 3 112"IF BIT SUB, 3112"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS, 3112" HWDP (21), 3 1/2" IF-P X 4" HT-38-B ,4" 14PPF S-135 DP 1 2 OILWELL OILWELL 8.000 8.000 Inlet Drilling Alaska Marathon M-I Drilling Fluids 5.000 5.000 75 75 143.82 143.82 447 447 287.64 287.64 18 1 1 216.00 Schlumberger 24.00 , Halliburton 24.00 3 1 9.00 3.00 LAST BOP TEST: 1/1412002 1/2112002 LAST CASING TEST: NEXT BOP TEST: Printed: 1/16/2002 10:15:14 AM Run bit and scraper. Set whipstock. I STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough (in) @ ~ WELL NAME KU 43-6RD SUPERVISOR R.C. Lawson CURRENT STATUS NID BOP. 24 HR FORECAST CIO tubing head. FIELD NAME Kenai ST KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ~ /24 HRS PROG TMD TVD I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208002 ¡MOCW' INRI DAILY WELL COST 100.00(%) 92.20(%) 62,126.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. None 1/15/2002 NEXT CASING (ft) (in) @ (ft) REPT NO. g /DATE 1/17/2002 AFE COST 735,000 CUM WELL COST 285,665.00 BOP PSI TEST 1/14/2002 LEAKOFF PPG OP COMMENTS: P/U 4.0" DP. POOH w/bit and scraper. Set 7 5/8" EZSV w/Schlumberger. RIH w/Halliburton stinger. Perform squeeze job. Circ. and POOH w/stinger. NID BOP. 06:00 06:30 0.50 06:30 07:30 1.00 07:30 09:30 2.00 09:30 11 :30 2.00 11:30 12:30 1.00 SIDET SIDET SIDET SIDET SIDET 12:30 13:00 0.50 13:00 15:00 2.00 SIDET SIDET 15:00 16:00 1.00 16:00 18:00 2.00 18:00 20:00 2.00 20:00 22:30 2.50 SIDET SIDET SIDET SIDET 22:30 23:30 1.00 SIDET 23:30 01 :30 2.00 01 :30 03:30 2.00 03:30 04:00 0.50 04:00 06:00 2.00 SIDET SIDET SIDET SIDET Circulate while PIU 4.0" DP. POOH. Repair derrick finger board. Perform koomey test for BLM. Cont. POOH w/bit and scraper. RlU Schlumberger. PJSM prior to electric line operations. Run 6.5" gauge ring to 4250'. POOH. Prepare setting tool. PJSM prior to using explosives. RIH and set 75/8" EZSV @ 4187'. POOH. RID Schlumberger. Test 7 5/8" CSG to 2000psi. MIU Halliburton cement stinger and RIH. Sting into 7 5/8" EZSV @ 4187'. Space out DP. C/O to long bales. RlU cement line. PJSM prior to cementing operations. Test cement lines to 2500psi. Test CSG X DP to 2000psi. Establish injection 2BPM @ 1190psi, 3BPM @ 1260psi(total 21 bbls fresh water injected). Mix and pump 295sxs "G" cement w/0.3% CD-32 and 0.5% FL-33 to yield 60bbls 15.8ppg slurry. Displace w/46bbis fresh water. Shut in w/600psi. Sting out of retainer. Reverse out 2 X DP volume. Circulate long way one time. CIO to short bales. Blow down BJ lines. Fill trip tank. POOH. UD Halliburton stinger. Test 7 5/8" CSG 2000psi/10min. Blow down lines. N/D BOP. BIT 1 RUN RPM I GPM I PRESS I WOB 8,278.00 PBIT I HRS ! 24Hr DIST 24Hr ROP I CUM HRS CUM DEPTH I CUM ROP I EZSV cement stinger, 3 1/2" IF X 4" HT-38 XJO , 4" 14PPF S-135 HT-38 DP Inlet Drilling Alaska 24.00 Printed: 1/17/2002 6:56:39 AM I STATEIPROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough (in) @ ~ WELL NAME KU 43-6RD SUPERVISOR R.C. Lawson CURRENT STATUS RIH wlwhipstock BHA. 24 HR FORECAST Mill window. FIT. CIO BHA. FIELD NAME Kenai ST IKB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ",.-...., 124 HRS PROG TMD TVD I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208002 MOCWI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 34,302.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/17/2002 I NEXT CASING (ft) (in) @ (ft) REPT NO. DATE 10 1/18/2002 AFE COST 735,000 CUM WELL COST 319,967.00 BOP PSI TEST 1/17/2002 LEAKOFF PPG OP COMMENTS: N/D 9" 3M tubing head. N/U 11" 3M tubing head. N/U BOP and test. RIH and tag EZSV. CBU. POOH. PIU whipstock BHA. RIH. 06:00 07:00 1.00 07:00 10:00 3.00 10:00 17:00 7.00 SIDET SIDET SIDET 17:00 18:00 1.00 18:00 20:30 2.50 SIDET SIDEr 20:30 22:30 2.00 22:30 23:30 1.00 23:30 02:00 2.50 02:00 05:30 3.50 05:30 06:00 0.50 SIDET SIDET SIDET SIDET SIDET BIT/RUN r I GPM I PRESS I WOB RPM NID 9" 3M tubing head. NIU 11" 3M TBG head. Test 1500psi/15min. NIU 135/8" 5M BOP. N/U kill and choke lines. Change bladder in #9 accumulator bottle. CIO 4" pipe rams to 2 7/8" X 5" variable rams. PIU 4" test joint and test plug. Test variable rams to 250/3000psi 10min. LID test joint and install wear bushing. P/U 63/4" bit and 7 5/8"scraper. RIH and tag 7 5/8" EZSV@4193'. CBU X 2. POOH. UD bit and scraper. P/U and scribe whipstock BHA. PIU 6-4 3/4" DC. RIH. 3,941.00 12,219.00 PBIT I 4,150.0 1/17/2002 24Hr DIST I 24Hr ROP I CUM HAS I CUM DEPTH CUM ROP HRS ~ / 6" Starter Mill , 6 1/8" Lower Mill ,63/4" Upper Window Mill ,3 1/2" HWDP , 43/4" Bumper Sub, 43/4" UBHO Sub, 4 3/4" DRILL COLLARS (6), 31/2" HWDP (24), 3 1/2" IF-P X 4" HT-38-B ,4" 14PPF S-135 DP Inlet Drilling Alaska Marathon M-I Drilling Fluids Baker Hughes Inteq 18 216.00 Baker Oil Tools 1 24.00 Gyrodata 1 24.00 Alaska Pipe Recovery 2 48.00 16.00 8.00 6.00 2 1 1 Printed: 1/18/2002 7:00:30 AM WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS Milling @ 4208'. 24 HR FORECAST Mill to 4219'. FIT. cIa fluid. cIa BHA. Drill ahead. FIELD NAME I STATEIPROV I COUNTY/OTHER LASTCASING Kenai Alaska Kenai Borough 7.875 (in) @ ;---. ST KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ,.-..., 124 HRS PROG TMD TVD DFS 21.0 21 3,625 1 I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208002 MOC WI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 40,629.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/17/2002 I NEXT CASING 4,174.0 (ft) 4.500 (in) @ 5,713.0 (ft) REPT NO. ¡DATE 11 1/19/2002 AFE COST 735,000 CUM WELL COST 360,596.00 BOP PSI TEST 1/18/2002 LEAKOFF PPG OP COMMENTS: RIH w/whipstock. Run Gyro survey and orient whipstock. Mill F/4174' to 4208'. 06:00 09:30 3.50 09:30 11 :30 2.00 11:30 14:00 2.50 SIDET SIDET SIDET 14:00 15:30 1.50 15:30 16:00 0.50 16:00 17:30 1.50 17:30 18:30 1.00 18:30 20:00 1.50 SIDET SIDET SIDET SIDET SIDET 20:00 06:00 10.00 SIDET BIT I RUN 2/1 RPM 601 I ~;; I P~:~S I WOB 2120 Cont. RIH w/whipstock assy. cIa to long bales. RIU TDS wireline guide. RIU Gyrodata w/APRS wireline unit. Modify TDS wireline guide to accomodate new grabber box. Run gyro going in. Orient whipstock(45deg left of high side). Run gyro pulling out. cIa bales and elevators. Set whipstock(tag retainer @ 4193'DD). Shear mills from whipstock. Displace hole to milling fluid. Mill F/4174' to 4208(window 4174' to 4187'). 3,941.00 16,160.00 PBIT I 93 4,187.0 1/18/2002 I 24Hr DIST I 24Hr ROP I CUM HAS I CUM DEPTH I CUM ROP 21.0 4.20 5.00 21.0 4.20 HAS 5.00 I 6" Starter Mill, 6 1/8" Lower Mill, 6 3/4" Upper Window Mill , 3 1/2" HWDP ,43/4" Bumper Sub, 43/4" UBHO Sub, 4 3/4" DRILL COLLARS (6), 3 1/2" HWDP (24), 3 1/2" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP 1 2 OILWELL OILWELL 8.000 8.000 5.000 5.000 88 88 168.75 168.75 705 780 337.50 337.50 0 0.00 0.00 0.00 0.00 0.00 0.00 850 20.51 12.51 839.74 102.89 14.69 102.89 100 0.48 355.42 100.00 0.42 -0.03 0.42 900 21.75 6.35 886.38 120.65 17.62 120.65 200 2.03 18.42 199.97 2.52 0.49 2.52 950 22.29 355.79 932.75 139.32 17.95 139.32 300 5.21 17.03 299.76 8.54 2.38 8.54 1,000 23.28 352.28 978.85 158.57 15.92 158.57 400 6.64 16.63 399.22 18.42 5.37 18.42 1,050 23.80 350.57 1,024.69 178.31 12.94 178.31 500 7.50 15.17 498.46 30.26 8.73 30.26 1,100 24.19 350.20 1,070.37 198.36 9.55 198.36 600 9.08 354.34 597.44 44.41 9.66 44.41 1,150 22.10 349.36 1,116.34 217.70 6.06 217.70 700 10.85 355.32 695.92 61.65 8.11 61.65 1,200 26.13 343.04 1,161.98 237.49 1.11 237.49 800 18.57 13.18 792.62 86.58 10.98 86.58 1,250 30.89 339.33 1,205.91 260.04 -6.63 260.04 Printed: 1/19/2002 9:36::J2 AM ~ ...-... WELL NAME KU 43-6RD 1ST IKB 01 87.00 GL 66.00 124 HRS PROG 21.0 ITMD 21 ITVD DFS 3,625 1 REPTNO. ¡DATE 11 1/19/2002 1,300 31.55 339.15 1,248.66 284.28 -15.82 284.28 2,750 38.41 338.71 2,456.10 1,044.09 -229.46 1 ,044.09 1,350 30.94 339.81 1,291.41 308.56 -24.91 308.56 2,800 38.07 339.53 2,495.37 1 ,073.00 -240.49 1,073.00 1,400 30.62 341.91 1,334.37 332.73 -33.30 332.73 2,850 36.04 346.62 2,535.291,101.77 -249.29 1,101.77 1,450 24.49 350.25 1,378.69 355.08 -39.02 355.08 2,900 36.22 348.13 2,575.68 1,130.54 -255.74 1,130.54 1,500 23.61 350.82 1,424.35 375.18 -42.37 375.18 2,950 37.85 348.26 2,615.591,160.02 -261.90 1,160.02 1,550 24.24 350.44 1,470.06 395.18 -45.67 395.18 3,000 38.45 348.75 2,654.91 1,190.28 -268.05 1,190.28 1,600 25.17 349.97 1,515.48 415.78 -49.23 415.78 3,050 39.93 348.53 2,693.66 1,221.26 -274.27 1 ,221.26 1,650 26.33 349.32 1,560.51 437.14 -53.14 437.14 3,100 38.96 354.61 2,732.291,252.65 -278.94 1 ,252.65 1,700 26.92 349.04 1,605.21 459.15 -57.34 459.15 3,150 38.42 359.69 2,771.32 1,283.84 -280.50 1 ,283.84 1,750 28.08 348.91 1,649.56 481.81 -61.76 481.81 3,200 39.19 359.85 2,810.29 1,315.17 -280.63 1,315.17 1,800 28.85 348.22 1,693.52 505.17 -66.49 505.17 3,250 38.81 359.86 2,849.151,346.64 -280.71 1,346.64 1,850 30.25 347.47 1,737.01 529.28 -71.68 529.28 3,300 38.79 359.90 2,888.11 1,377.97 -280.78 1,377.97 1,900 31.16 347.28 1,780.00 554.19 -77.26 554.19 3,350 38.16 359.99 2,927.26 1,409.08 -280.81 1,409.08 1,950 31.99 346.62 1,822.60 579.69 -83.18 579.69 3,400 37.55 359.78 2,966.73 1,439.76 -280.87 1,439.76 2,000 33.19 346.50 1,864.73 605.89 -89.44 605.89 3,450 37.50 359.72 3,006.39 1,470.21 -281.00 1 ,470.21 2,050 33.92 346.38 1,906.39 632.75 -95.92 632.75 3,500 37.28 359.71 3,046.11 1,500.58 -281.15 1 ,500.58 2,100 35.49 345.91 1,947.50 660.39 -102.73 660.39 3,550 36.75 359.61 3,086.04 1,530.68 -281.33 1 ,530.68 2,150 36.25 345.71 1,988.01 688.79 -109.92 688.79 3,600 36.15 359.50 3,126.261,560.38 -281.56 1 ,560.38 2,200 37.10 344.96 2,028.12 717.68 -117.48 717.68 3,650 35.97 359.77 3,166.68 1,589.81 -281.75 1 ,589.81 2,250 38.06 344.57 2,067.74 747.10 -125.49 747.10 3,700 35.75 359.98 3,207.20 1,619.10 -281.81 1,619.10 2,300 38.47 344.18 2,107.00 776.92 -133.83 776.92 3,750 36.05 0.08 3,247.70 1,648.42 -281.80 1,648.42 2,350 39.89 343.53 2,145.76 807.26 -142.62 807.26 3,800 35.74 359.87 3,288.21 1,677.74 -281.81 1,677.74 2,400 40.11 342.54 2,184.06 838.00 -152.00 838.00 3,850 35.46 0.15 3,328.86 1,706.84 -281.80 1,706.84 2,450 39.62 339.89 2,222.44 868.34 -162.31 868.34 3,900 35.38 0.06 3,369.61 1,735.82 -281.75 1,735.82 2,500 39.29 339.39 2,261.05 898.13 -173.37 898.13 3,950 35.30 0.47 3,410.391,764.74 -281.62 1,764.74 2,550 38.79 339.16 2,299.88 927.58 -184.51 927.58 4,000 35.09 0.29 3,451.25 1,793.56 -281.43 1,793.56 2,600 38.95 338.97 2,338.81 956.89 -195.72 956.89 4,050 34.96 0.49 3,492.20 1,822.25 -281.23 1 ,822.25 2,650 38.35 338.97 2,377.86 986.04 -206.93 986.04 4,075 34.99 0.44 3,512.68 1,836.58 -281.11 1 ,836.58 2,700 38.65 338.73 2,416.99 1,015.07 -218.16 1,015.07 4,129 34.88 0.16 3,556.95 1,867.51 -280.95 1,867.51 Inlet Drilling Alaska Marathon M-I Drilling Fluids ,Baker Hughes Inteq 18 216.00 BakerOiITools 1 24.00 Gyrodata 1 24.00 Alaska Pipe Recovery 2 48.00 R&K Industrial 2 1 1 2 48.00 24.00 12.00 24.00 Printed: 1/19/2002 9:36:32 AM ~ /-- WELL NAME KU 43-6RD SUPERVISOR RC. Lawson CURRENT STATUS CBU @ 4287'. 24 HR FORECAST POOH for bit change. FIELD NAME Kenai \KB IGL 124 HRS PROG TMD TVD IDFS 2 87.00 66.00 79.0 4,287 3,686 ¡RIG NAME & NO. ¡RIG # AUTH MD AFE NO. GLACIER DRILLING 1 907-283-1312 5,713 9208002 I MOC WI INRI DAILY WELL COST 100.00 (%~ 92.20 (%) 99,721.00 ACCIDENTS 24HR LAST SAFETY MTG. None 1/17/2002 NEXT CASING 4,174.0 (ft) 4.500 (in) @,713.0(ft) RIH. Drill ahead. I STATEIPROV I COUNTY/OTHER ILASTCASING Alaska Kenai Borough 7.875 (in) @ REPTNO. ¡DATE 12 1/20/2002 AFE COST 1,449,250 CUM WELL COST 475,258.00 BOP PSI TEST 1/18/2002 LEAKOFF PPG 10.74 24 HR SUMMARY: Mill F/4208' to 4219'. Perform LOT to 10.7PPG EMW. POOH. P/U directional BHA. RIH. Drill F/4219' to 4287'. 06:00 08:00 2.00 4,208 4,219 08:00 09:00 1.00 09:00 10:00 1.00 10:00 11:00 1.00 11:00 12:00 1.00 12:00 14:00 2.00 14:00 16:30 2.50 16:30 18:30 2.00 18:30 19:30 1.00 19:30 21:30 2.00 21:30 22:00 0.50 22:00 01:30 3.50 01:30 06:00 4.50 4,219 4,287 8.70 SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET Mill formation F/4208' to 4219', Circulate and work mills through window. Perform LOT 10.7ppg(8.6MW, 3592TVD, 409PSI). CIO mud. Adjust drawworks brake. POOH. Adjust drawworks brake. Cont. POOH. UD 6-4 3/4" DC and Mill assy BHA. PIU 63/4" PDC bit and 4 3/4" directional BHA. Test motor and MWD. Blow down lines. Service rig. RIH to 4219'. Dir. drill and survey F/4219' to 4287'(Rot:;:1 hr, Slide:;:3.5hrs). Very difficult to hold tool face and motor stalling. 6,267.00 22,427.00 2/1 6.125 Baker Starter Mi 16/16/16116/161 4,187.0 1/18/2002 0-0------ 3/1 6.750 Smith 15JS JS7013 12/12/12/1211 4,219.0 1/19/2002 O-O-NO-A-O-O-NO-PR BIT I RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 2/1 2/20 60/60 337 780 93 2.00 11.0 5.50 12.00 32.0 2.67 311 2/40 65/65 301 1,200 372 4.50 68.0 15.11 4.50 68.0 15.11 21 100 60 4/ 5 4.50 5 63/4" Smith PDC , M. MOTOR W/6 5/8"UBHS/1.2 AKO , 65/8" IBS , COLLAR MWD , RESTRICTOR SUB, Monel Collar, 31/2"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS, 31/2" HWDP (21), 3112" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP 1 2 OILWELL OILWELL Marathon M-I Drilling Fluids ~t Drilling Alaska 8.000 8.000 5.000 5.000 79 78 705 780 301.06 301.06 151.49 149.57 1 24.00 Baker Hughes Inteq 1 24.00 Baker Oil Tools 18 216.00 R&K Industrial 2 1 1 48.00 18.00 12.00 Printed: 1/22/2002 4:51:43 PM .~ .~ WELL NAME KU 43-6RD SUPERVISOR R.C. Lawson CURRENT STATUS Drilling ahead @ 5250. 24 HR FORECAST Drill ahead to 5280'. Wiper trir' Drill to 5713'. FIELD NAME STATEIPROV I COUNTY/OTHER LASTCASING Kenai Alaska Kenai Borough 7.875 (in) @ IKB IGL 124 HRS PROG TMD TVD DFS 3 87.00 66.00 963.0 5,250 4,420 ¡RIG NAME & NO. ¡RIG # AUTH MD AFE NO. GLACIER DRilLING 1 907-283-1312 5,713 9208002 IMOC WI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 50,217.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/20/2002 NEXTCASING 4,174.0 (ft) 4.500 (in) @,713.0 (ft) REPTNO. ¡DATE 13 1/21/2002 AFE COST 1,449,250 CUM WELL COST 525,475.00 BOP PSI TEST 1/18/2002 LEAKOFF PPG 10.74 24 HR SUMMARY: CBU and POOH. CIO bit. RIH. Dir drill and survey F/4287' to 5250'. 4,287 SIDET SIDET SIDET SIDET SIDET 3/1 6.750 Smith 15JS JS7013 12/12/12/1211 4,219.0 1/19/2002 O-O-NO-A-O-Q-NO-PR 4/1 6.750 Smith R10T MH18764 14/13/13111 4,287.0 1/2012002 0-0------ BIT I RUN WeB I RPM I GPM I PRESS I P EiITr--HRs-T-24H;-DIST I 24Hr ROP I CUM HRS ¡CUM DEPTH! CUM ROP 411 6/12 50170 296 1,485 433 11.50 963.0 83.74 11.50 963.0 83.74 130 9 6 1 .50 5 63/4" Smith TCI , M. MOTOR WI6 5/8"UBHS/1.2 AKO , 6 5/8" IBS , COLLAR MWD , RESTRICTOR SUB, Monel Collar, 3 1/2"HWDP (4), 4 3/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21), 3 1/2" IF-P X 4" HT-38-B ,4" 14PPF S-135 DP 6 BHA DESCRIPTION 1 2 OILWELL OILWELL 8.000 8.000 5.000 5.000 151.49 149.57 79 78 4,174 34.88 0.16 3,593.87 1,893.24 -280.88 1,900.93 4,731 40.20 322.30 4,025.91 2,216.99 -392.85 2,242.68 4,250 37.40 356.80 3,655.25 1,938.03 -282.11 1,944.48 4,792 40.40 322.30 4,072.44 2,248.21 -416.97 2,279.11 4,420 39.00 346.60 3,788.972,041.72 -297.40 2,048.57 4,858 40.70 322.30 4,122.59 2,282.16 -443.21 2,318.73 4,481 39.70 339.60 3,836.172,078.67 -308.65 2,087.18 4,919 40.20 325.20 4,169.01 2,314.06 -466.61 2,355.64 4,542 41.10 334.30 3,882.63 2,115.01 -324.14 2,126.30 4,982 40.40 325.50 4,217.062,347.59 -489.78 2,394.05 4,606 41.30 327.30 3,930.81 2,151.76 -344.68 2,167.14 5,045 40.80 325.20 4,264.892,381.31 -513.09 2,432.69 4,668 40.20 322.30 3,977.792,184.82 -367.98 2,205.13 5,108 40.90 324.50 4,312.55 2,415.00 -536.81 2,471.41 1 18 24.00 216.00 Printed: 1/22/2002 4:51:46 PM .~ ">.0 ... ~......., ~ IKB IGL 124 HRS PROG TMD TVD 87.00 66.00 490.0 5,740 4,787 RIG NAME & NO. ¡RIG # AUTH MD AFE NO. GLACIER DRILLING 1 907-283-1312 5,713 9208002 ¡MOCWI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 52,242.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/21/2002 I STATEIPROV I COUNTY/OTHER LASTCASING NEXTCASING Alaska Kenai Borough 7.875 (in) @ 4,174.0 (ft) 4.500 (in) @J,713.0 (ft) WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS TOOH to run production liner. 24 HR FORECAST FIELD NAME Kenai REPTNO. DATE 14 1/22/2002 AFE COST 1.449,250 CUM WELL COST 577,717.00 BOP PSI TEST 1/18/2002 LEAKOFF PPG 10.74 24 HR SUMMARY: Rotary drill FI 5250' to 5740'. Wiper trip to casing shoe. 06:00 07:00 1.00 5,250 5,291 07:00 08:00 1.00 5,291 5,291 08:00 09:30 1.50 5,291 5,291 09:30 10:00 0.50 5,291 5,291 10:00 10:30 0.50 5,291 5,291 10:30 22:30 12.00 5,291 5,740 22:30 00:30 2.00 5,740 5,740 00:30 03:00 2.50 5,740 5,740 03:00 04:00 1.00 5,740 5,740 04:00 06:00 2.00 5,740 5,740 SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET SIDET Rotary drill FI 5250' to 5291'. Circulate bottoms up. Wiper trip to casing shoe. Service rig & top drive. TIH to bottom @ 5291'. Rotary drill FI 5291' to TD @ 5740' MD I 4787' TVD. numerous tight spots while drilling. Circulate bottoms up FI samples. Wiper trip to casing shoe. Wash 70' to bottom. Circulate bottoms up. Slug pipe, TOOH SLM to run production liner. Ream I backream thru Add Fine & coarse calcium carbonate to system control losses. Lose +1- 150 BBLS 9.0 PPG mud to formation last 24 hours. BIT I RUN 4/1 WeB 5/15 I RPM I GPM I PRESS I 169/169 291 1,350 16,384.00 49,361.00 P BIT I HRS I 24Hr DIST I 24Hr ROP I CUM HRS I CUM DEPTH I CUM ROP 418 13.00 490.0 37.69 24.50 1,453.0 59.31 6 130 50 75 10,000/5,000 6 3/4" Smith TCI , M. MOTOR W/6 5/8"UBHS/1.2 AKO , 65/8" IBS , COLLAR MWD , RESTRICTOR SUB, Monel Collar, 3 1/2"HWDP (4), 43/4" DAILY HYDRAULIC JARS, 3 1/2" HWDP (21), 3 1/2" IF-P X 4" HT-38-B , 4" 14PPF S-135 DP 1 2 OILWELL OILWELL 8.000 8.000 5.000 5.000 75 75 145.35 145.35 1,350 1,350 290.70 290.70 50 50 420 420 5,171 41.00 324.80 4,360.132,448.68 -560.70 2,510.15 5,487 41.80 323.70 4,598.182,617.41 -682.00 2,704.69 5,233 41.00 324.50 4,406.92 2,481.86 -584.24 2,548.32 5,549 41.90 323.40 4,644.37 2,650.68 -706.58 2,743.22 5,297 40.80 324.50 4,455.30 2,515.97 -608.57 2,587.60 5,622 41.80 323.00 4,698.75 2,689.68 -735.75 2,788.48 5,360 41.00 324.50 4,502.91 2,549.55 -632.52 2,626.27 5,681 41.70 323.40 4,742.762,721.14 -759.28 2,824.99 5,425 41.40 323.70 4,551.82 2,584.23 -657.63 2,666.30 Printed: 1/22/2002 7:59: 53 AM !~ ~ ST KB IGL 01 B7.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS Running 4-1/2" production liner. 24 HR FORECAST 124 HRS PROG TMD TVD DFS 5,740 4,787 ¡RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 /MOCWI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 26,108.00 !ACCIDENTS 24HR LAST SAFETY MTG. None 1/23/2002 ¡NEXT CASING 4,174.0 (ft) 4.500 (in) @ 5,713.0 (ft) REPTNO. DATE 1 1/23/200:; AFE COST 513,000 CUM WELL COST 26,108.00 BOP PSI TEST 1/22/2002 LEAKOFF PPG 10.74 FIELD NAME Kenai STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough 7.875 (in) @ OP COMMENTS: Finish TOOH. UD 3-1/2" HWDP & BHA. Test BOPE. Running production liner. 06:00 07:30 1.50 5,740 5,740 07:30 10:00 2.50 5,740 5,740 10:00 14:30 4.50 5,740 5,740 14:30 20:30 6.00 5,740 5,740 20:30 00:30 4.00 5,740 5,740 00:30 04:30 4.00 5,740 5,740 04:30 06:00 1.50 5,740 5,740 Inlet Drilling Alaska Marathon M- Drilling Fluids Baker Hughes Inteq RUNPRL Finish TOOH W/ 4" drill pipe SLM. RUNPRL Hold safety meeting. UD 25 JTS 3-1/2" HWDP and steerable drilling assembly. RUNPRL Test Pipe & blind rams, annular, stack manual & HCR valves, IBOP & surface safety valve, choke manifold valves 1 thru 12, and top drive manual and automatic valves to 250 I 3000 psi F/5 minute tests. Local AÖGC represenative declined to witness test. RUNPRL Unthaw rig stand pipe. RUNPRL Change bails & elevators. R/U to run liner. Hold safety meeting. RUNPRL PIU and RIH WI 44 JTS 4-1/2" 12.6# L-80 IBT production liner casing. Install PIP tag in string. RUNPRL Change bails & elevators. Prep to P/U Baker liner hanger assembly. 1,522.00 1,522.00 18 1 1 2 216.00 R&K Industrial 24.00 Epoch Well Services 24.00 Weatherford Completion 12.00 Baker Oil Tools 1 2 2 2 Printed: 1/25/2002 7:42:29 AM ~ ,~ 124 HRS PROG TMD TVD I DFS 5,740 4,787 RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 MOCWI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 86,581.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/23/2002 .NEXTCASING 5,740.0 (ft) (in) @ (ft) ST KB GL 01 87.00 66.00 RIG NAME & NO. GLACIER DRILLING 1 WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS Waiting on cement 24 HR FORECAST REPT NO. 2 DATE 1/24/2002 AFE COST 513,000 CUM WELL COST 112,689.00 BOP PSI TEST 1/22/2002 LEAKOFF PPG FIELD NAME Kenai I STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: Run and cement 4-1/2" production liner WI 190 SX. TOOH and WOC. 06:00 07:00 1.00 5,740 5,740 07:00 09:00 2.00 5,740 5,740 09:00 10:30 1.50 5,740 5,740 10:30 12:30 2.00 5,740 5,740 12:30 14:30 2.00 5,740 5,740 14:30 17:00 2.50 5,740 5,740 17:00 17:30 0.50 5,740 5,740 17:30 19:00 1.50 5,740 5,740 19:00 20:30 1.50 5,740 5,740 20:30 22:30 2.00 5,740 5,740 22:30 01:00 2.50 01 :00 03:30 2.50 03:30 05:00 1.50 05:00 06:00 1.00 5,740 5,740 5,740 5,740 5,740 5,740 5,740 5,740 9.10 42 Inlet Drilling Alaska Marathon M-I Drilling Fluids RUNPRL M/U Baker model HMC hydraulic set liner hanger assembly WI tie-back extension. RUNPRL TIH wI liner on drill pipe to 4093'. RUNPRL Circulate bottoms up. RUNPRL MIU cement head on landing joint & place in V-door. RUNPRL Finish RIH WI liner on drill pipe to TD @ 5740'. RUNPRl M/U cement head. Circulate & condition hole. RUNPRL Set liner hanger WI top of tie-back extension @ 3984' WI landing collar @ 5657', float collar @ 5697', and float shoe @ 5740', Note PIP tag in collar @ 5102'. RUNPRL Circulate & condition. Hold safety meeting. Batch mix cement slurry. . RUNPRL Cement 4-1/2" production liner WI full retums as follows: Pump 30 BBLS 10.5 PPG spacer, followed by 190 sx class G cement WI 0.5% SMS + 2.5% BA-56 + 10%BA.90 + 0.1% ASA-301 + 2% calcium chloride + 1 GPS FP-6L batch mixed @ 13.5 PPG WI 1.84 yield. Drop plug, displace W/3 BBLS FW + 66 BBlS 9.0 PPG mud. Over displace WI 1/2 BBL, unable to land plug. SID WI 430 psi final pressure. CIP @ 20:00 HRS 1-23-02. Cement design WI 35% excess in open hole WI 80' in 7-5/8" casing above liner top. Note: BLM Rep Bo Brown on Location for cement job. RUNPRL Pull running tool out of liner hanger. UD cement head. TOOH W/5 stands drill pipe to 3651'. Circulate bottoms up, recover +1. 40 BBlS mud wI spacer. Slug pipe, TOOH. UD 42 joints excess drill pipe. UD liner running tool and cement head. Slip & cut drill line. Service rig & top drive. waco WBCO waco WBCO 1,188.00 2,710.00 '.. 18 1 1 216.00 R&K Industrial 24.00 Baker Oil Tools 24.00 BJ Services 24.00 48.00 144.00 2 2 6 Printed: 1/25/2002 7:44:13 AM ~ ,-.., WELL NAME KU 43.6RD SUPERVISOR Randy Ratliff CURRENT STATUS TOOH WI polish mill. 24 HR FORECAST ST IKB Gl 01 87.00 66.00 RIG NAME & NO. GLACIER DRilLING 1 124 HRS PROG TMD TVD DFS 5,740 4,787 'RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 MOCWI INRI DAILY WELL COST 100.00 (%~ 92.20 (%) 29,913.00 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/23/2002 /NEXTCASING 5,740.0 (ft) (in) @ (ft) REPT NO. I DA,.E 3 1/25/2002 AFE COST 513,000 CUM WELL COST 142,602.00 BOP PSI TEST 1/22/2002 LEAKOFF PPG RELD NAME Kenai I STATEIPROV 'COUNTY/OTHER LASTCASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: Wait on cement. Clean out to top of production liner. Clean out liner tie-back extension. 06:00 16:00 10.00 5,740 5,740 RCMP 16:00 18:00 2.00 5,740 5,740 RCMP 18:00 19:30 1.50 5,740 5,740 RCMP 19:30 20:30 1.00 5,740 5,740 RCMP 20:30 21:00 0.50 5,740 5,740 RCMP 21:00 22:00 1.00 5,740 5,740 RCMP 22:00 00:00 2.00 5,740 5,740 RCMP 00:00 01:00 1.00 5,740 5,740 RCMP 01:00 02:30 1.50 5,740 5,740 RCMP 02:30 03:00 0.50 5,740 5,740 RCMP 03:00 03:30 0.50 5,740 5,740 RCMP 03:30 06:00 2.50 5,740 5,740 RCMP Inlet Drilling Alaska Marathon 18 1 Wait on cement. Perform routine rig maintenance. Strap 2-7/8" drill pipe work string, and 3-1/8" drill collars. P/U & TIH WI 6-3/4" bit & 7-5/8" casing scraper to 3654'. Wash 330' F/3654' to top of liner @ 3984', Did not find any cement, Circulate Bottoms up. Test liner lap @ 3984' MD 13438' TVD to 10.6 PPG EMW (300 psi WI 9.0 PPG mud) F/15 minutes WI no leak off Blow mud out of stand pipe, choke & kill lines due to sub zero temperature. TOOH. UD bit & scraper, P/U 5-11/16" OD polish mill. TIH to top of liner. Clean out liner tie-back extension. Circulate bottoms up, slug pipe. TOOH to PIU liner top isolation packer assembly. 4,287.00 6,997.00 216.00 M-I Drilling Fluids 24.00 Baker Oil Tools 1 1 24.00 6.00 Printed: 1/25/2002 7:31:22AM ~ WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS Circulate & finish cleaning mud pits. 24 HR FORECAST ST IKB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ~ 124 HRS PROG TMD TVD IDFS 5,740 4,787 I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 MOC WI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 20,271.00 !ACCIDENTS 24HR LAST SAFETY MTG. None 1/23/2002 . NEXTCASING 5,740.0 (ft) (in) @ (ft) REPT NO. I DATE 4 1/26/2002 AFE COST 513,000 CUM WELL COST 162,873.00 BOP PSI TEST 1/22/2002 LEAKOFF PPG FIELD NAME Kenai I STATEIPROV I COUNTY/OTHER ¡LAST CASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: TIH, set & test liner top isolation packer. TIH wI tandem scraper assembly to clean out production liner. 06:00 07:00 1.00 5,740 5,740 WBCO 07:00 11:00 4.00 5,740 5,740 WBCO 11:00 14:30 3.50 5,740 5,740 WBCO 14:30 17:00 2.50 5,740 5,740 WBCO 17:00 18:30 1.50 5,740 5,740 WBCO 18:30 00:00 5.50 5,740 5,740 WBCO 00:00 00:30 0.50 5,740 5,740 WBCO 00:30 01:30 1.00 5,740 5,740 WBCO 01:30 04:00 2.50 5,740 5,740 WBCO 04:00 04:30 0.50 5,740 5,740 WBCO 04:30 05:00 0.50 5,740 5,740 WBCO 05:00 06:00 1.00 5,740 5,740 WBCO Inlet Drilling Alaska Marathon M-I Drilling Fluids 18 1 1 UD polish mill. P/U Baker Model "ZXP" hydraulic set liner top isolation packer assembly WI tie-back extension. TIH to 3950' and break circulation. Land seals in liner hanger. Internally test seals down drill pipe to 1000 psi wI 9.1 ppg mud. Drop ball & set ZXP packer WI top of tie back extension @ 3965' MD I 3422' TVD. Test packer to 19.0 ppg EMW (1770 psi WI 9.1 ppg mud). Monitor 30 psi pressure loss in 30 minutes. Release running tool. TOOH, UD setting tool. RIU floor to P/U work string. P/U 3-7/8" cement mill, and 4-1/2" casing scraper. TIH WI same picking up 6,3-1/8" drill collars & 52 joints 2-7/8" drill pipe. Circulate & change elevators. P/U 7-5/8" casing scraper. TIH to 5395'. Wash in hole 251', set down @ 5646'. Ream down 5' F/5646' to 5651', 6' above landing collar @ 5657'. Unable to drill deeper without getting aggressive WI slim hole drill pipe. SID WI PBTD @ 5651'. Circulate and finish cleaning mud pits. 821.00 II~liII11r&1 7,818.00 216.00 Baker Oil Tools 24.00 R&K Industrial 24.00 Weaver Brothers 1 2 1 12.00 30.00 4.00 Printed: 1/26/2002 9:36:06 AM ~ WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS P/U TCP guns. 24 HR FORECAST ST /KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ~ 24HRSPROG TMD TVD IDFS 5,740 4,787 I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 I MOC WI INRI DAILY WELL COST 100.00 (%~ 92.20 (%) 25,059.00 ¡ACCIDENTS 24HR LAST SAFETY MTG. None 1/27/2002 I NEXT CASING 5,740.0 (ft) (in) @ (ft) ~ /DATE 1/27/2002 REPT NO. 5 AFE COST 513,000 CUM WELL COST 187,932.00 BOP PSI TEST 1/22/2002 LEAKOFF PPG AELD NAME Kenai I STATEIPROV I COUNTY/OTHER LASTCASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: TIH WI casing scraper assembly. Displace hole WI fresh water. Lay down drill pipe. Run RST log. 06:00 07:00 1.00 5,740 5,740 waco 07:00 07:30 0.50 5,740 5,740 waco 07:30 09:00 1.50 5,740 5,740 waco 09:00 13:30 4.50 5,740 5,740 waco 13:30 14:30 1.00 5,740 5,740 waco 14:30 20:00 5.50 5,740 5,740 RCMP 20:00 23:00 3.00 5,740 5,740 RCMP 23:00 23:30 0.50 5,740 5,740 RCMP 23:30 00:00 0.50 5,740 5,740 RCMP 00:00 04:00 4.00 5,740 5,740 RCMP 04:00 05:30 1.50 5,740 5,740 RCMP 05:30 06:00 0.50 5,740 5,740 RCMP Circulate & finish cleaning mud pits @ PBTD 5651'. Build SafeKleen pill, fill #3 pit WI fresh water. Circulate around 40 BBL SafeKleen pill, displacing hole WI fresh water. Short trip 7-5/8" casing scraper to surface. Circulate around clean fresh water @ 5646'. Lay down 4" drill pipe & 7-5/8" casing scraper. Change elevators, Lay down 2-7/8" drill pipe, 3-1/8" drill collars, 4-1/2" casing scraper & cement mill. Pull wear bushing. Clear rig floor of drill pipe handling tools. RIU ELU. Run RST log. RIU handling tools to run tubing. Hold safety meeting. 1,260.00 9,078.00 Inlet Drilling Alaska 18 216.00 Schlumberger 3 18.00 Marathon 3 60.00 Weatherford Completion 2 6.00 M-I Drilling Fluids 1 24.00 Halliburton TCP 2 6.00 R&K Industrial 2 24.00 Printed: 1/27/2002 6:38:33 A.M ~ WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS ND BOPE 24 HR FORECAST ST KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 ..-... 124 HRS PROG TMD TVD DFS 5,740 4,787 I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 I MOC WI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 153,330.63 I ACCIDENTS 24HR LAST SAFETY MTG. None 1/27/2002 I NEXT CASING 5,740.0 (ft) (in) @ (ft) REPTNO. DATE 6 1/28/2002 AFE COST 513,000 CUM WELL COST 341,262.63 BOP PSI TEST 1/22/2002 LEAKOFF PPG FIELD NAME Kenai I STATE/PROV I COUNTY/OTHER I LAST CASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: TIH with TCP guns on 2-7/8" and 3-1/2" tubing. Run tie-in log, space out and land tubing. ND BOPE. 06:00 09:00 3.00 5,740 5,740 RCMP 09:00 14:00 5.00 5,740 5,740 RCMP 14:00 14:30 0.50 5,740 5,740 RCMP 14:30 15:30 1.00 5,740 5,740 RCMP 15:30 16:00 0.50 .5,740 5,740 RCMP 16:00 19:30 3.50 5,740 5,740 RCMP 19:30 20:00 0.50 5,740 5,740 RCMP 20:00 22:30 2.50 5,740 5,740 RCMP 22:30 00:30 2.00 5,740 5,740 RCMP 00:30 01:30 1.00 5,740 5,740 RCMP 01:30 02:00 0.50 5,740 5,740 RCMP 02:00 03:00 1.00 5,740 5,740 RCMP 03:00 06:00 3.00 5,740 5,740 RCMP 8.34 26 PU and TIH with 116' of 3-3/8", 5 spf, 50-degree phase Millinnium TCP guns. MU drop-bar firing assembly. PU and TIH with completion assembly on 42 joints of 2-7/8",6.5 ppf, L-80, ST-L tubing and 125 joints of 3-1/2",9.3 ppf, L-80, EUE 8rd mod tubing. Drift tubing in the v-door. Shut down running tubing due to vendor's tubing tong failure Continue TIH with tubing Shut down running tubing due to vendor's tubing tong failure Continue TIH with tubing Shut down running tubing due to vendor's tubing tong failure yet again. Continue TIH with tubing. MIRU Schlumberger. Held prejob safety meeting. RIH with GR/CCL log to correlate TCP guns. Locate RA tags in 2-7/8" tubing and 4-1/2" liner. POOH, RDMO Schlumberger. Space out tubing to position TCP guns to perforate 5304' - 5420'. Install pups and tubing hanger. Land tubing hanger with 2-way check. LD landing joint. Test tubing hanger seals to 1500 psi. Clean rig floor of tubing handling equipment. ND BOPE 0.00 Inlet Drilling Alaska 18 216.00 Halliburton TCP 2 48.00 Marathon 2 48.00 ABB Vetco Gray 1 9.00 Schlumberger 3 24.00 R&K Industrial 1 1.00 Weatherford Completion 3 36.00 Printed: 1/28/2002 7:04:12 AM / . ----\ ..--...., ST /KB 01 87.00 RIG NAME & NO. GLACIER DRILLING 1 /24 HRS PROG TMD TVD ¡ DFS 5,740 4,787 I RIG PHONE AUTH MD AFE NO. 907-283-1312 5,713 9208102 MOCWI INRI DAILY WELL COST 100.00 (%) 92.20 (%) 63,130.00 ACCIDENTS 24HR LAST SAFETY MTG. None 1/27/2002 ¡NEXT CASING 5,740.0 (ft) (in) @ (ft) REPTNO. /DATE 7 1/29/2002 AFE COST 513,000 CUM WELL COST 404,392.63 BOP PSI TEST 1/22/2002 LEAKOFF PPG WELL NAME KU 43-6RD SUPERVISOR Randy Ratliff CURRENT STATUS Rigging Down. 24 HR FORECAST FIELD NAME Kenai I STATEIPROV COUNTY/OTHER ILASTCASING Alaska Kenai Borough 4.500 (in) @ OP COMMENTS: N/U & test tree. Release rig. 06:00 09:00 3.00 09:00 12:00 3.00 5,740 5,740 5,740 5,740 XMBO XMBO Finish NID BOP stack. NIU 3-1/16" 3M tree. Shell test tree to 2000 psi WI methanol and water. Leave 2 way check in tubing hanger. Release rig @ 12:00 hours 1/28/2002. Inlet Drilling Alaska Marathon 18 1 108.00 ABB Vetco Gray 6.00 Weaver Brothers 6.00 6.00 Printed: 1/29/2002 6:54:42 AM ,". ,....-....". MARATHON Oil COMPANY DAILY WELL OPERATIONS REPORT DATE: 2/27/2002 FILL DEPTH/DATE: DATE LASTWL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: CREW: N/A FIELD: Kenai Gas Field TUBING: 3-1/2" CASING: TREE CONDITION: WIRE TEST: WEll #: KU 43-6rd 7 5/8 OK Sehlumberger WBS # DD.02.06039.CAP.CMP HRS PROD: X DRILL: SUMMARY OF OPERATIONS Ticket #: 0800 MIRU Schlumberger nitrogen unit on annulus of well KU 43-6rd. Held prejob safety meeting. Spent several hours locating chicksan and choke to replace ones that were robbed the night before. 1700 Rounded up all parts and pieces. Tested lines to 3000 psi. Circulated nitrogen down the 7-5/8" casing while taking completion fluid returns on the 3-1/2" tubing. Recovered 192 bbl of fluid before got nitrogen returns to surface. Shut down nitrogen and shutin well. SITP = 1700 psi. RDMO nitrogen. Vendor Sehlumberger Mise Equipment nitrogen Daily Cost Cumulative Cost $14,193.00 $1,000.00 DAilY COST: $15,193.00 CUM: REPORTED BY: Gary Eller DATE: 3/11/2002 FILL DEPTH/DATE DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: OTHER: TOOL STRING: WIRE LINE CRE' RSO #: 455-864 SUMMARY OF OPERATIONS Ticket #: 10:00 Mu 2" chicksan from tree to choke, through the gas buster to open top tank. 11 :00 PT with WHP 1300 psig. 11 :30 Halliburton arrived, MU listening head to tree. Drop Firing Bar, gun fired. RD lubricator. Released pollard boom truck, prior to flowing well to tank, WHP= 255 psig. Flow well to tank for 45 minutes. No water to tank. Used velocity string to flow well to tank. put well into flow line to production header. MARATHON OIL COMPANY /'. ~ DAILY WELL OPERATIONS REPO. FIELD: Kenai Gas Field WELL #: KU 43-6 RD TUBING: CASING: TREE CONDITION: 4 1/2" Bowing Drop Firing Bar WIRE TEST: N/A Complete N/A Vowell/Tomlinson was # DD,02.06039.CAP.CMP Hrs. PROD: X DRILL: 1430 Note: Suction pressure at 110 psig. Well flowing at 2500 MCFPD rate. Vendor Equipment Daily Cost Cumulative Cost Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. Pollard Wireline Inc. DAILY COST: CUM: REPORTED BY: cissell ~. Survey Report ,..--...... Kenai Gas Field Kenai. Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Pad 41-7 Section 7 Centered on KU 13-5 Site Position: From: Map Position Uncertainty: Ground Level: Site: Well: KU 43-6 Well Position: +NI-S +E/-W Position Uncertainty: 0.00 ft 66.00 ft -55.98 ft Northing: 61.17 ft Easting: 0.00 ft Northing: Easting: Wellpath: Sidetrack This is a sidetrack of the existing well Current Datum: SITE Height Ma~netic Data: 1011812001 Field Strength: 55183 nT Vertical Section: Depth From (TVD) ft 0.00 Survey Program for Definitive Wellpath Date: 112212002 Validated: No Actual From To Survey ft ft 100.00 4129.00 4174.00 5740.00 Survey Gyro Survey of Original Well MWD Survey of Sidetrack 2361844.31 ft 275073.22 ft 2361787.18 ft 275133.32 ft 87.00 ft +NI-S ft 0.00 Map Zone: Coordinate System: Geomagnetic Model: Alaska. Zone 4 Well Centre Wmm_95 Latitude: 60 27 32.631 N Longitude: 151 14 45.826 W North Reference: True Grid Convergence: -1.08 deg Slot Name: Latitude: Longitude: 60 27 32.080 N 151 14 44.606 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Version: Toolcode NS Gyro MWD/GYRO 2 OH Original hole 4129.00 ft Mean Sea Level 21.20 deg 73.46 deg Direction deg 344.87 Tool Name 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 850.00 900.00 950.00 1000.00 1050.00 1100.00 1150.00 1200.00 1250.00 1300.00 1350.00 1400.00 1450.00 0.00 0.48 2.03 5.21 6.64 7.50 9.08 10.85 18.57 20.51 21.75 22.29 23.28 23.80 24.19 22.10 26.13 30.89 31.55 30.94 30.62 24.49 0.00 355.42 18.42 17.03 16.63 15.17 354.34 355.32 13.18 12.51 6.35 355.79 352.28 350.57 350.20 349.36 343.04 339.33 339.15 339.81 341.91 350.25 0.00 100.00 199.97 299.76 399.22 498.46 597.44 695.92 792.62 839.74 886.38 932.75 978.85 1024.69 1070.37 1116.34 1161.98 1205.91 1248.66 1291.41 1334.37 1378.69 0.00 0.42 2.52 8.54 18.42 30.26 44.41 61.65 86.58 102.89 120.65 139.32 158.57 178.31 198.36 217.70 237.49 260.04 284.28 308.56 332.73 355.08 0.00 -0.03 0.49 2.38 5.37 8.73 9.66 8.11 10.98 14.69 17.62 17.95 15.92 12.94 9.55 6.06 1.11 -6.63 -15.82 -24.91 -33.30 -39.02 0.00 0.41 2.30 7.62 16.38 26.93 40.35 57.39 80.71 95.49 111.87 129.81 148.92 168.75 188.99 208.57 228.96 252.76 278.55 304.37 329.89 352.96 4.23 9.56 10.15 1.33 1.40 2.24 14.46 0.00 0.48 1.60 3.18 1.43 0.88 3.37 1.78 8.87 3.91 5.08 7.98 3.36 1.72 0.84 2.48 1.08 1.98 1.04 0.78 -4.18 8.06 9.52 1.32 -1.22 -0.64 -12.26 0.00 0.48 1.55 3.18 1.43 0.00 0.00 23.00 -1.39 -0.40 0.86 1.58 1.77 7.72 3.88 -1 .46 -20.83 0.98 17.86 -1.34 -12.32 -21.12 -7.02 -3.42 -0.74 -1.68 -12.64 -7.42 -0.36 1.32 4.20 16.68 TIE LINE NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro NS Gyro .~ ~ Survey Report Survey 1500.00 23.61 350.82 1424.35 375.18 -42.37 373.23 1.82 -1.76 1.14 NS Gyro 1550.00 24.24 350.44 1470.06 395.18 -45.67 393.41 1.30 1.26 -0.76 NS Gyro 1600.00 25.17 349.97 1515.48 415.78 -49.23 414.21 1.90 1.86 -0.94 NS Gyro 1650.00 26.33 349.32 1560.51 437.14 -53.14 435.86 2.39 2.32 -1.30 NS Gyro 1700.00 26.92 349.04 1605.21 459.15 -57.34 458.20 1.21 1.18 -0.56 NS Gyro 1750.00 28.08 348.91 1649.56 481.81 -61.76 481.23 2.32 2.32 -0.26 NS Gyro 1800.00 28.85 348.22 1693.52 505.17 -66.49 505.01 1.67 1.54 -1.38 NS Gyro 1850.00 30.25 347.47 1737.01 529.28 -71.68 529.64 2.90 2.80 -1.50 NS Gyro 1900.00 31.16 347.28 1780.00 554.19 -77.26 555.14 1.83 1.82 -0.38 NS Gyro 1950.00 31.99 346.62 1822.60 579.69 -83.18 581.31 1.80 1.66 -1.32 NS Gyro 2000.00 33.19 346.50 1864.73 605.89 -89.44 608.23 2.40 2.40 -0.24 NS Gyro 2050.00 33.92 346.38 1906.39 632.75 -95.92 635.85 1.47 1.46 -0.24 NS Gyro 2100.00 35.49 345.91 1947.50 660.39 -102.73 664.31 3.19 3.14 -0.94 NS Gyro 2150.00 36.25 345.71 1988.01 688.79 -109.92 693.61 1.54 1.52 -0.40 NS Gyro 2200.00 37.10 344.96 2028.12 717.68 -117.48 723.47 1.92 1.70 -1.50 NS Gyro 2250.00 38.06 344.57 2067.74 747.10 -125.49 753.96 1.98 1.92 -0.78 NS Gyro 2300.00 38.47 344.18 2107.00 776.92 -133.83 784.92 0.95 0.82 -0.78 NS Gyro 2350.00 39.89 343.53 2145.76 807.26 -142.62 816.51 2.96 2.84 -1.30 NS Gyro 2400.00 40.11 342.54 2184.06 838.00 -152.00 848.63 1.35 0.44 -1.98 NS Gyro 2450.00 39.62 339.89 2222.44 868.34 -162.31 880.61 3.54 -0.98 -5.30 NS Gyro 2500.00 39.29 339.39 2261.05 898.13 -173.37 912.25 0.92 -0.66 -1.00 NS Gyro 2550.00 38.79 339.16 2299.88 927.58 -184.51 943.59 1.04 -1.00 -0.46 NS Gyro 2600.00 38.95 338.97 2338.81 956.89 -195.72 974.81 0.40 0.32 -0.38 NS Gyro 2650.00 38.35 338.97 2377.86 986.04 -206.93 1005.87 1.20 -1.20 0.00 NS Gyro 2700.00 38.65 338.73 2416.99 1015.07 -218.16 1036.82 0.67 0.60 -0.48 NS Gyro 2750.00 38.41 338.71 2456.10 1044.09 -229.46 1067.79 0.48 -0.48 -0.04 NS Gyro 2800.00 38.07 339.53 2495.37 1073.00 -240.49 1098.58 1.22 -0.68 1.64 NS Gyro 2850.00 36.04 346.62 2535.29 1101.77 -249.29 1128.65 9.45 -4.06 14.18 NS Gyro 2900.00 36.22 348.13 2575.68 1130.54 -255.74 1158.10 1.82 0.36 3.02 NS Gyro 2950.00 37.85 348.26 2615.59 1160.02 -261.90 1188.16 3.26 3.26 0.26 NS Gyro 3000.00 38.45 348.75 2654.91 1190.28 -268.05 1218.99 1.34 1.20 0.98 NS Gyro 3050.00 39.93 348.53 2693.66 1221.26 -274.27 1250.51 2.97 2.96 -0.44 NS Gyro 3100.00 38.96 354.61 2732.29 1252.65 -278.94 1282.03 7.96 -1.94 12.16 NS Gyro 3150.00 38.42 359.69 2771.32 1283.84 -280.50 1312.55 6.44 -1.08 10.16 NS Gyro 3200.00 39.19 359.85 2810.29 1315.17 -280.63 1342.83 1.55 1.54 0.32 NS Gyro 3250.00 38.81 359.86 2849.15 1346.64 -280.71 1373.23 0.76 -0.76 0.02 NS Gyro 3300.00 38.79 359.90 2888.11 1377.97 -280.78 1403.49 0.06 -0.04 0.08 NS Gyro 3350.00 38.16 359.99 2927.26 1409.08 -280.81 1433.53 1.26 -1.26 0.18 NS Gyro 3400.00 37.55 359.78 2966.73 1439.76 -280.87 1463.16 1.25 -1.22 -0.42 NS Gyro 3450.00 37.50 359.72 3006.39 1470.21 -281.00 1492.60 0.12 -0.10 -0.12 NS Gyro 3500.00 37.28 359.71 3046.11 1500.58 -281.15 1521.94 0.44 -0.44 -0.02 NS Gyro 3550.00 36.75 359.61 3086.04 1530.68 -281.33 1551.05 1.07 -1.06 -0.20 NS Gyro 3600.00 36.15 359.50 3126.26 1560.38 -281.56 1579.78 1.21 -1.20 -0.22 NS Gyro 3650.00 35.97 359.77 3166.68 1589.81 -281.75 1608.24 0.48 -0.36 0.54 NS Gyro 3700.00 35.75 359.98 3207.20 1619.10 -281.81 1636.53 0.50 -0.44 0.42 NS Gyro 3750.00 36.05 0.08 3247.70 1648.42 -281.80 1664.83 0.61 0.60 0.20 NS Gyro 3800.00 35.74 359.87 3288.21 1677.74 -281.81 1693.13 0.67 -0.62 -0.42 NS Gyro 3850.00 35.46 0.15 3328.86 1706.84 -281.80 1721.23 0.65 -0.56 0.56 NS Gyro 3900.00 35.38 0.06 3369.61 1735.82 -281.75 1749.19 0.19 -0.16 -0.18 NS Gyro 3950.00 35.30 0.47 3410.39 1764.74 -281.62 1777.07 0.50 -0.16 0.82 NS Gyro 4000.00 35.09 0.29 3451.25 1793.56 -281.43 1804.84 0.47 -0.42 -0.36 NS Gyro 4050.00 34.96 0.49 3492.20 1822.25 -281.23 1832.49 0.35 -0.26 0.40 NS Gyro 4075.00 34.99 0.44 3512.68 1836.58 -281.11 1846.30 0.17 0.12 -0.20 NS Gyro ~ ~ Survey Report Survey 4129.00 34.88 0.16 3556.95 1867.51 -280.95 1876.10 0.36 -0.20 -0.52 NS Gyro 4141.25 34.88 0.16 3567.00 1874.51 -280.93 1882.86 0.00 0.00 0.00 Sterting Pool 3 4174.00 34.88 0.16 3593.87 1893.24 -280.88 1900.93 0.00 0.00 0.00 MWDIGYRO 4250.00 37.40 356.80 3655.25 1938.03 -282.11 1944.48 4.22 3.32 -4.42 MWDIGYRO 4404.61 38.82 347.49 3777.00 2032.30 -295.24 2038.92 3.82 0.92 -6.02 Sterting Pool 4 4420.00 39.00 346.60 3788.97 2041.72 -297.40 2048.57 3.82 1.17 -5.80 MWD/GYRO 4481.00 39.70 339.60 3836.17 2078.67 -308.65 2087.18 7.36 1.15 -11.48 MWDIGYRO 4542.00 41.10 334.30 3882.63 2115.01 -324.14 2126.30 6.08 2.30 -8.69 MWDIGYRO 4606.00 41.30 327.30 3930.81 2151.76 -344.68 2167.14 7.21 0.31 -10.94 MWDIGYRO 4668.00 40.20 322.30 3977.79 2184.82 -367.98 2205.13 5.55 -1.77 -8.06 MWDIGYRO 4674.82 40.20 322.30 3983.00 2188.30 -370.67 2209.19 0.00 0.00 0.00 Sterting Pool 5.1 4731.00 40.20 322.30 4025.91 2216.99 -392.85 2242.68 0.00 0.00 0.00 MWDIGYRO 4792.00 40.40 322.30 4072.44 2248.21 -416.97 2279.11 0.33 0.33 0.00 MWDIGYRO 4858.00 40.70 322.30 4122.59 2282.16 -443.21 2318.73 0.45 0.45 0.00 MWDIGYRO 4905.89 40.30 324.57 4159.00 2307.13 -461.74 2347.68 3.19 -0.83 4.74 Sterting Pool 5.2 4919.00 40.20 325.20 4169.01 2314.06 -466.61 2355.64 3.19 -0.77 4.79 MWDIGYRO 4982.00 40.40 325.50 4217.06 2347.59 -489.78 2394.05 0.44 0.32 0.48 MWDIGYRO 5045.00 40.80 325.20 4264.89 2381.31 -513.09 2432.69 0.71 0.63 -0.48 MWDIGYRO 5108.00 40.90 324.50 4312.55 2415.00 -536.81 2471.41 0.74 0.16 -1.11 MWDIGYRO 5171.00 41.00 324.80 4360.13 2448.68 -560.70 2510.15 0.35 0.16 0.48 MWDIGYRO 5233.00 41.00 324.50 4406.92 2481.86 -584.24 2548.32 0.32 0.00 -0.48 MWD/GYRO 5279.43 40.85 324.50 4442.00 2506.62 -601.90 2576.83 0.31 -0.31 0.00 Shifted KU 43-6 (C-1) 5297.00 40.80 324.50 4455.30 2515.97 -608.57 2587.60 0.31 -0.31 0.00 MWDIGYRO 5360.00 41.00 324.50 4502.91 2549.55 -632.52 2626.27 0.32 0.32 0.00 MWDIGYRO 5425.00 41.40 323.70 4551.82 2584.23 -657.63 2666.30 1.02 0.62 -1.23 MWDIGYRO 5487.00 41.80 323.70 4598.18 2617.41 -682.00 2704.69 0.65 0.65 0.00 MWDIGYRO 5549.00 41.90 323.40 4644.37 2650.68 -706.58 2743.22 0.36 0.16 -0.48 MWDIGYRO 5622.00 41.80 323.00 4698.75 2689.68 -735.75 2788.48 0.39 -0.14 -0.55 MWDIGYRO 5681.00 41.70 323.40 4742.76 2721.14 -759.28 2824.99 0.48 -0.17 0.68 MWDIGYRO 5740.00 41.70 323.40 4786.81 2752.65 -782.68 2861.52 0.00 0.00 0.00 MWDIGYRO Targets Shifted KU 43-6 (C-1) -Circle (Radius: 150) Shifted KU 43-6 (TD) -Circle (Radius: 250) 4442.00 2582.00 -632.20 2364380.68 274550.08 60 27 57.508 N 151 14 57.216 W 151 14 57.216 W 4787.00 2582.00 -632.20 2364380.68 274550.08 60 27 57.508 N Formations 4141.25 4404.61 4674.82 4905.89 3567.00 3777.00 3983.00 4159.00 Sterling Pool 3 Sterling Pool 4 Sterling Pool 5.1 Sterling Pool 5.2 SANDSTONE SANDSTONE SANDSTONE SANDSTONE 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1-., - \ ~~fÆ~! TI F fÆ~fÆ~~~fÆ ^T,ASIiA OIL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Leonard F. Shannon . Marathon Oil Company Senior Drilling Engineer PO Box 196168 Anchorage AK 99519 Re: Kenai Unit KU 43-6 RD Marathon Oil Company Permit No: 201-231 Sur Loc: 205' S and 4231' E from NW Comer Section 7, T4N, RllW, SM Btmhole Loc. 2613' N and 3784' E from SW Comer Section 6, T4N, RI1W, SM Dear Mr. Shannon: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Kenai Unit KU 43-6 RD. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, r~InA~- . ÁO11Jd-'~ ;a::~:~~li Taylor Chair . BY ORDER OF THE COMMISSION DATED this 4th day of January 2002 jjc/Enc1osures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA "-". AlAv"A Oil AND GAS CONSERVATION COM.....:>SION PERMIT TO DRILL 210 AAC 25.005 O;\EXCELIAOGCCPTD.XLW ';J6A t{ LilJ 'L Jfl1. Ii 1/ 4-ltv 1b. Type of well. ExPloratoryD Stratigraphic TestD ServiceD Development Gas[K Single zoneØ 1) 5. Datum Elevation (DF or KB) 10. Field and Pool 87' RKB feet Kenai Gas Field/Sterling 6. Property Designation A-O28142 1a. Type of Work DrillD Re-Entry[K 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 205' Sand 4231' E from NW corner Sec. 7, T4N, R11w, SM At top of Productive Interval 2358' Nand 3905' E from SW corner Sec. 6, T4N, R11W,SM AtTotal Depth 2613' Nand 3784' E from SW corner Sec. 6, T4N, R11W, SM 12. Distance to Nearest 13. Distance to Nearest Well Property Line 10505' FWL 14234' FSL 16. To be Completed for Deviated Wells Kickoff Depth 4195 feet Maximum Hole Angle 18. Casing Program Size Casing driven 103/4" 7 5/8" 4 1/2" Re-Drill[K DeepenD 3450' feet Hole 20" 143/4" 97/8" 6 314" Specifications Grade Coupling Length 52' 1297' 4195' 1668' Weight 78.60# 32.75# 26.4# 12.6# H-40 J-55 L-80 BTC Development OilD Multiple ZoneD 7. Unit or Property Name Kenai Unit 8. Well Number KU 43-6 RD 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth (MD and TVD) 9. Approximate Spud Date Dec. 27,2001 14. Number of Acres in Property 390 6000 5713' MD/4787' TVD 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2)) Maximum Surface 1761 psig at Total Depth (TVD) Setting Depth Bottom feet feet 4787 Top Quantity of Cement (including stage data) In place, Driven ( OKB 92' ) In place wI 1450 sks. (OKB 92') In place wI 700 sks. ( OKB 92" ) +1- 143 sks ( RKB 87') MD 0 0 0 4045' MD 52' 1297' 4195' 5713' 4787' TVD 0 0 0 3478' TVD Kenai unit well KU 43-6 will be plugged back according to AOGCC regulations and sidetracked at +1- 4195' MD/3601' TVD. KU 43-6 RD will be directionally drilled to a estimated depth of 5713' MD, 4787' TVD from the existing Kenai Gas Field pad 41-7. The production interval will be cased with 4.5" casing and cemented in place as a liner. Marathon's drilling rig will be used to drill and complete the well. The following documents are attached: Area maps, structure map, surface use plan, directional maps, mud pit drawing and blowout equipment drawing. [~U " ¿~. 2 íÌ n 1 ". ~ .. ¡J '-' ¡ ,_:. '~cç,s. Commission 20. Attachments Filing Fee[KJ Property Plat[8] BOP Sketch [8] Drilling Fluid Programrxl Time vs Depth Plotn Refraction Analysisn 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Diverter SketchD Seabed Reportn Drilling Program[KJ 20 AAC 25.050 Requirements n Phone: 564-6332 Title: Senior Drilling Engineer Commission Use Only Permit Numbe~ r--. j_. "Î '2/ IAPI Numbe! .' IAPproval Date Isee Cover Letter ~ - L-.:.J 50-- 1 ~:3 - / Dcfì 1- 0 I For Other Requirements Conditions of Approval Samples Required DYes IEJNO Mud Log Required DYes [X] No Hydrogen Sulfide Measures DYes ŒJNo Directional Survey Required [2gYes DNo Required Working Pressure for BOPE D 2M ~M D 5M D 1 OM D 15M Other: Signed LF. Shannon£...t ~...J{l- Approved by Form 10-401 Rev. 12-1-85 Original Signed By Cammy Dedasfi Date: Nov. 8, 2001 Commissioner by order of the Commission Date ORIGINAL Submit in Triplicate 131/8" 5M Manually I Operated Valves ~~ DJ1illJDJ1illJrn ŒillJ I~I)/ 113 5/8" 5M Cross ~ Flow Nipple I 1135/8" 5M Annular I Preventer 1135/8" 5M Double Ram Preventer Ie ----.. e 135/8" 5M Single Ram Preventer e ~ < , /' ¡/ I Cho ke I mrn@IIIIIß]] t Marathon Oil Well KU 43-6RD BOP Stack . . "> I I ) ~ I I < Pipe Ram I IBlind Ram I > I I " "- I I < Pipe Ram I > I 1,\ < I I í I Flow Line I I ~ ~ ~ ~ 3 1/8" 5M Hydraulically Operated Valve 131/8" 5M Manually I Operated Valve ç::::=:;I E œi r::=:::J t ~ ~ Marathon Oil Well KU 43-6RD Choke Manifold m[Ø[I]lli [lI@[I] '\ 13" 5M Valves I 29/16" 10M Swaco Hydraulically Operated Choke ç::::::;I t:::::j I, ,I ~ 0 [lI@]llI@ll. ~ I t ~ 131/8" 5M Manually Adjustable Choke ~ Marathon Oil Company Alaska Region ""-"'. PrE:.. .ced By: Approved By: Date: L. Shannon/W. Tank Nov. 8,2001 (Update) Drilling Program Well: KU 43-6RD AFE: 9206301 Area: Kenai Gas Field Drilling Contractor: Inlet Drilling Company . Rig: Glacier Drilling Rig No.1 Geologic Program Perm Pressure Bottom hole Depth MD TVD Tolerance 87' RKB 87' RKB 4154' 3567' 4413' 3777' 4674' 3983' 4902' 4159' 5266' 4442' 150' Radius 5713' 4787' 250' Radius Target Locations Surface Top Pool 3 300 275# md 1470 290# md 400 440# md 400 1440# md 1000 345# md Top Pool 4 Top Pool 5.1 Top Pool 5.2 TOp Pool 6 Bottom Hole RKB Elevation: 87' Total Depth: TVD 4787' MD 5713 ' Avg. Angle 39.26 Course 353.16 deg Abnormal Pressures: Subnormal Pressures: 275 psi to 1470 psi in Sterling Sands Coring and DST's: Mud Logging: Contractor: Epoch Start Depth: Below KOP Services: Basic with GCA, shale density, temperature in and out, sample collection. 10' samples to TD Logging Program: Contractor To be determined Surface Production LWD NA NA Wireline Logs GR/RST ( Cased hole logging run) Drilling Program Page 1 of 7 ~ Dri~ling Program Summary ,',"""",,, Production: The existing wellbore will be plugged back to +/- 4300' MD as per the AOGCC regulations. Set retainer approx. 6' above casing collar. Test plug and casing to 1500 psi. TIH with bottom trip whipstock and MWD. Set whipstock for 45 degrees left of highside for casing exit. Cut window and ensure all mills are worked thru window. CBU. Test shoe to leakoff (12.5 PPG anticipated). Drill a 6 3/4" hole to 5713' MD/ 4787' TVD per the attached directional program. Run logs as per program. Make a wiper trip and pull wear bushing. Run 4 ~" production liner and cement per the attached program. RDMO drilling rig. Casing Program API Values Casing Casing Hole Size Set Set To Weight Casing Conn Size Burst Collapse Tension (in) From (MD) (ppf) Grade Type (in) (psi) (psi) (K lbs) (MD) 7 5/8" 0' 4195' 26.4 J-55 LTC 9 7/8" 4140 2890 346 4 ~" 4045' 5713' 12.6 L-80 BTC 6 3/4" 8440 7500 289 Casing Design Fracture Formation Casing Casing Setting Gradient Pressure Design Factors Size Weight Casing Depth at Shoe at Shoe MASP (in) (ppf) Grade (TVD) (ppg) (ppg) (psi) Burst Collapse Tension 7 5/8" 26.4 J-55 3602' 12.5 9.0 1257 3.09 2.02 3.09 4 ~" 12.6 L-80 4787' 9.0 1796 3.31 3.35 1. 87 Drilling Program Page 2 of 7 ,r---. , ~ Directional Program Directional Co: Baker Hughes Inteq Gyro Co: To be determined KOP: 4195' Direction: 353.16 Gyro Survey Required: If determined to be necessary. Magnetic Multishots Required: Use MWD surveys. For more specific details please see attached directional program attached. Calculation of Maximum Anticipated Surface Pressures The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less a column of 30% mud on top of 70% gas. The MASP for the production casing is based on pore pressure less the hydrostatic pressure of gas. 7 5/8" Intermediate Casing @ 3601' TVD MASP = ((PP * .052 * TVDtd) - MASP = (9.0 * 0.052 * 4787) - MASP = 1233 psi (%mud * 0.052 * MWtd * TVDtd) - (%gas * GG * TVDtd)) (0.3 * 0.052 * 9.0 * 4787) - (0.7 * 0.1 * 4787)) 4 ¥:i" Production Liner @ 4787' TVD MASP = PP * 0.052 * TVDf - (GG * TVDf) MASP = 9.0 * 0.052 * 4787' - (0.1 * 4787') MASP = 1761 psi Cementing Program Contractor: BJ Services Production Casing Size: 4 'h" Setting Depth: 5713' MD/ 4787' TVD Annular Volume to 4195' with 6 3/4" gauge hole: 210 ft3 Tail Slurry: Top of Cement: Specifications: Density:~ ppg, Yield: 4045'MD/ 3491' TVD Class G + additives Mixed w/ fresh water 1.838 ft3/sx, Sx: 114 sx, cf: 210 ft3 Compress Strgth: 500 psi in 16.25 hrs, 820 psi in 24 hrs Total Volume: 263 ft3, 25% Open Hole Excess, WOC Time: 6 hrs Drilling Program Page 3 of 7 r---- ,-." Diverter and BOP Program The diverter system will consist of a 21 ~", 2000 psi annular preventer and a 16" O.D. nonbifurcated vent line. The vent line will be full opening and integrated with the annular in the fail safe design as stipulated in 20AAC 25.035. The vent line will be a minimum of 75' from any source of ignition. The blowout preventer stack will consist of a 13 5/8", 5000 psi annular, a 13 5/8", 5000 psi double ram preventer with blind rams on bottom and pipe rams on top, a 13 5/8", 5000 psi drilling spool (mud cross) with 3 1/8", 5000 psi flanged outlets, and a 13 5/8", 5000 psi single ram preventer with pipe rams. The choke manifold will be rated 3 1/8", 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a mud gas seperator. Casing Casing Test size MASP Test BOPS Low/High Casing (in) (psi) (psi) Size & Rating (psi) Intermediate 1233 1500 (1) 13-5/8" 5M Annular 250/3000 7 5/8" 250/3000 (9.2 (1) 13-5/8" 5M Blind ram ppg (2) 13-5/8" 5M Pipe ram 25013000 mud) Production 4 %" 2500 (1) 13-5/8" '5M Annular 25013000 1761 (10.0 (1) 13-5/8" 5M Blind ram 250/3000 ppg (2) 13-5/8" 5M Pipe ram 25013000 mud) Casing Test Pressure Calculations Casing test pressures are based on the lesser of (1) MASP, or (2) 70% of rated burst pressure of the casing adjusted for the mud weight used during the test less a 8.3 PPG back-up unless otherwise noted. 7 5/8" Intermediate Casing at CTPMASP = 1233 psi CTPBurst = 4140 * 0.7 - Test to 1500 psi 3601' TVD «9.0-8.3) * 0.052 * 3601) = 2766 psi 4 YP Production Casing at 4787' TVD CTPMASP = 1761 psi Test to 2500 psi CTPBurst = 8440 * 0.7 - «9.0-8.3) * 0.052 * 4787) = 5734 psi Drilling Program Page 4 of 7 .r---. ~ Mud Program Contractor: MI Drilling Fluids Interval (MD/TVD) From I 4195' /3601' To 5713'/4787' Mud Weight (ppg) 8.6 - 9.2 Water Loss <8 Mud Type Flo Pro/KC1 Wellhead Program Manufacturer Model Tubing Head Tubing Hanger Cameron DCB 10" 3M X 8" 3M DCB DCB 8" X dual 2 7/8" Split Hanger 8rd EVE up Note: CUrrently plans are being looked at to possibly change out this tubing spool. Detailed Drilling Procedure Fo~tion Leakoff Test Surface and Intermediate casing shoes will be tested to Leak-off. Prior to drilling out of casing strings, test BOPs and casing to the specified pressure listed in the BOP Program section. Plot test and record volume required on the drilling report. Leak-off tests (LOT) are to be conducted as described below: 1. Drill 20' to 25' of new formation below the casing shoe and condition the mud to the same properties in and out. 2. Pull drill string into the casing shoe and close ram preventer, and line up to the choke manifold with a closed choke. 3. Begin slowly pumping fluid down the drill string at 1/2 bpm drillpipe pressures at 1/2 bbl intervals. A running plot of kept by the drilling foreman while the test is in progress. 4. Stop pumping when the pressure curve departs form a straight line sufficiently to indicate leakage into the formation. Record as ppg equivalent mud density in the IADC and morning reports. 5. Monitor and plot pressure drop and time after shut-in for 10 minutes or until the shut-in pressure stabilizes. while recording casing and pressure versus volume should be Bit Program The following guidelines are recommended for use on this well. Interval Bit Size IADC WOB RPM (MD) (in) Bit Model Code (k lbs) 4165' - 4230' 6 3/4" Speed mill 117 5/25 150 4230' - 5713' 6 3/4" To be determined S222 5/10 200 Drilling Program Page 5 of 7 ~ .---.. DrilJ. String Item Ppf 3 l/z" HWDP, 3 112" IF 24.4 4", 8-135, HT 38 15.53 5 l/z" HWDP, 4Jj;¡" IF 49.3/53.6 Makeup Torque Max Pull - Premium 12000-13200 248,400 Ibs. ft.-lbs. 13,500-19,800 403,500 Ibs. ft.-lbs. 29,000 543,000 Ibs. ft.-lbs. Hydraulics Program Rig mud pumps available are shown below. Install 5 " liners in all mud pumps. Liner ID Stroke Max Press Gal/Stroke Max Rate Make Model (in) (in) (97% eff) (spm) Oilwell A 600 PT 4 ¥2" 8" 3207 1.6005 135 Oilwell A 600 PT 5.0 8" 2597 1.9788 135 0 ilwe 11 A 600 PT 5 '12" 8" 2147 2.3959 135 Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Pump Standpipe Nozzle Depth Hole Size Rate Pressure AV ECD Size (MD) (in) (gpm) (psi) (fpm) (ppg) (32"s) 5713' 6 3/4" 265 2200 - 219 9.5 12,12,14 2400 Remarks Motor Drilling Note: 5" liners are recommended. Drilling Program Page 6 of 7 r---. ~ OPERATIONAL PROCEDURE 1. The drilling rig will already be moved in and rigged up to abandon the current completion. 2. Ensure a casing scraper has been run prior to setting a cement retainer. Cement retainer should be set on wireline with the retainer 3' above any casing collar and positioned when whipstock assembly run to allow KOP @ +/- 4195'. 3. Perform cement abandonment procedure through retainer. Test casing. 4. The hole should be displaced with Flo-Pro/KCL drilling mud. 5. Change out tubing spool. 6. PU Baker bottom trip Window Master whipstock, window mills, MWD, 4 %" DC's, 20+ joints of 3 ~" HWDP on 4" drill pipe. TIH to just above cement retainer. Obtain PU and SO weights. Orient whipstock face at 45 degress to the left of highside and set whipstock. Mill off lug and start window cut. Cut window and drill enough open hole to get all mills thru window. 7. TOOH. PU 6 %" bit on directional BRA and TIH. Directionally drill well as per plan. Circulate hole clean and TOOH. Run OH logs as per geology ( currently none scheduled, however GR/RST after liner set). 8. Run 4 ~" liner. Cement same. Drilling Program Page 7 of 7 ~, ,~ Abandonment & Completion Procedure Following Sidetrack Well KU 43-6rd Kenai Gas Field AFE 9206301 1. Call out Vetco wellhead rep. Pressure test void on II", 3M casing head to 1400 psi (50% of collapse rating on 7%" casing). Lubricate and loosen nuts on tubing head and casing head. Release wellhead hand. 2. MIRU slickline on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with a PN plug for the 2.313" N nipple. Set plug in the N nipple at 5166' . POOH. 3. PU shifting tool for 2.313" Otis XO sliding sleeve. RIH, shift open the XO sliding sleeve at 5110'. POOH, RDMO slickline. 4. MIRU electric line on KU 43-61 (longstring). Pressure test lubricator to 1000 psi. RIH with jet cutter for 2%",6.3 ppftubing. Tie in with CCL, make longstring tubing cut at 4335'. POOH. RU on shortstring, test lubricator to 1000 psi. RIH with jet cutter for 2%",6.3 ppftubing. Tie in with CCL, make shortstring tubing cut at 4435'. POOH, RDMO electric line. 5. MIRU pump truck. Load casing and tubing with fresh water. Do not exceed 2000 psi on 7%" casing. Fill tree with methanol to prevent freezing. RDMO pump truck. 6. Callout Vetco wellhead rep. Set BPV s in both strings and bleed off surface pressure. Fill tree with methanol. 7. MIRU drilling rig. Prior to ND tree, confirm that no trapped pressure exists below BPVs. ND tree. Inspect lift threads on tubing hangers. NU BOPs. Œote: Will not be able to nipple up the single-gate rams due to height of the tubing head.) Pipe rams should be equipped ~th dual 2%", 5M rams. Pull BPVs, set 2- way checks. Test BOPE to 250/3000 psi. Pull 2-way checks. 8. Load hole with fresh water and establish circulation. Apply LCM as needed. 9. RU elevators, spiders, and tongs for pulling dual tubing strings. Pull dual strings of2%", 6.3 ppf, N-80, BTC tubing. Lay down all tubing, checking each joint for NORM. Haul off tubing as junk. 10. Install test plug in tubing spool. Replace dual 2%", 5M pipe rams with single 5M variable rams. Test BOPE as needed. Pull test plug. .~ ""-""'. Well KU 43-6rd Completion Procedure Page 2 11. PU 6%" bit, 7%" scraper, 4%" drill collars, and 4" drill pipe (15.12 ppf, S-135, HT-38) and TIH to top offish. All drill pipe should be drifted to 2.25". Circulate BU. TOH standing back drill pipe. 12. MIRU Schlumberger. PU and RIH with cement retainer for 7%",26.4 ppf casing. Tie in with CCL, set retainer at approximately 4200' iliote: Want to position the retainer so that the whipstock can be set for a kickoff at 4195'. Avoid a setting depth that would require the window to be cut through a casing collar.) POOH, RDMO Schlumberger 13. RIH with drill pipe and sting into cement retainer. Test backside to 2000 psi (50% of burst of 7%" casing). Establish injection rate below cement retainer with fresh water. / 14. MIRV cementing unit, pressure test lines. Bullhead 198 sx of class "G" cement (weight = 15.8 ppg, yield = 1.15 ft3/sack) below the cement retainer to abandon the perfs from 4593' - 4872'. The perfs from 5270' - 5488' are isolated by the PN plug (see step #2) and cement. Displace cement to the top of the retainer with contaminated fluid. Sting out of the retainer, reverse out any remaining cement. Do not exceed 2000 psi while reversing. Pressure test the 7%" casing and retainer to 2000 psi. RDMO cementing unit. TOH with drill pipe. 15. ND BOPE and the old 9", 3M tubing head. NU the new II", 3M tubing head. Test void to 1400 psi. NV BOPE. Set test plug and test BOPE. Pull test plug, install wear bushing. 16. PU 6%" bit and TIH. Drill out cement to the top of the cement retainer at =*=4200'. TOH. Note: The remainder of the procedure assumes that a whipstock is set on top of the cement retainer at =*=4200'. The desired kickoff point is 4195' with a 6%" hole. The procedure assumes that a 6%" hole has been drilled to =*=5713';- and the decision has been made to complete the well. 17. Condition hole in preparation for running 4%" liner. Install long bales. 18. MV and RIH with 4%", 12.6 ppf, L-80, IBT liner on 4" drill pipe. Liner will have a float shoe, one 4%" shoe joint, float collar, one 4%" joint, landing collar, and approximately 1700' of 4%" liner, and a Baker model HMC liner hanger. A radioactive pip should be placed in one of the 4%" casing collars at approximately 5100' MD. Place centralizers as per instructions of Drilling Engineer. RIH to TD and set hanger. ~, ,..-..., Well KU 43-6rd Completion Procedure Page 3 19. Set HMC liner hanger. Cement liner in place as per separate cementing design. Displace cement with mud. Release hanger setting tool and TOH one stand. Reverse out contaminated cement to surface. TOH. 20. PU and TIH with ZXP liner-top packer. Set packer on top ofliner hanger. Test liner-top packer to 19.0 ppg EMW. TOH. 21. PU and TIH with a 3Ye" bit, 4%" casing scraper, 2Ye" drill pipe (l0.4 ppf, X-95 pipe with 2%" SLH90HT tool joints) to the top of the liner, 7%" casing scraper, and 4" HT-38 drill pipe. Clean 4%" liner out to PBTD. 22. Swap hole over to fresh water by circulating a SafeKleen pill and fresh water at maximum rate. Circulate one full hole volume. Short-trip until the 7%" scraper is to surface, then TIH to bottom. Circulate one bottoms up volume with fresh water at maximum rate. 23. When returns are clean TOH laying down drill pipe. Pull wear bushing. / 24. MIRU Schlumberger. RIH with RST log. Log as per instructions of Geologist, but the log should cover at least the entire length of the 4%" liner. POOH, RD Schlumberger. 25. PU and TIH with the completion string consisting of 100' of 3%", 6 spfTCP guns, 2%" gun drop assembly, drop-bar firing head, crossover to 2Ye" flush-joint tubing (6.3 ppf, L-80, Grant-Prideco ST -L connections), one joint of slotted 2Ye" tubing, XN nipple (minimum ID = 2.205"), 2Ye" flush joint tubing to 40' above the liner top, crossover, and 3%" tubing (9.3 ppf, L-80, EUE 8rd) to surface. All tubing should be rabbited prior to installation. 26. When guns are approximately on depth, hang off the tubing in the slips and RU Schlumberger. RIH with a GR/CCL. Tie in the RST log obtained in step #22. Determine correction needed to put guns on depth. POOH, RDMO wireline. 27. Space out tubing. MU mandrel tubing hanger and landing joint. Land tubing. Run in lock-down pins. Close annular BOP, test hanger seals to 1500 psi. Bleed off pressure, open annular BOP. LD landing joint. Pump 20 bbl of diesel into annulus while taking returns up the tubing. Install 2-way check in tubing hanger. 28. ND BOPE, NU tree. Orient tree as per instructions of Brent Senette (283-1301). Test tree to 2000 psi using methanol. Pull2-way check, but do not install BPV. RDMO drilling rig. 29. Remove 7-1116", 3M blind flange. Pu116" BPV in tubing head side outlet. NU 7- 1/16" 3M valve and remainder of tree valves. Use a 6" 2-way check to test the first 7-1/16", 3M valve. Fabricate, install, and test spool pieces to flowline. ,---- ~, Well KV 43-6rd Completion Procedure Page 4 30. MIRV nitrogen pump onto )he 7%" casing and flowback tank onto the tree top. Pressure test lines to 3000 psi. Reverse out completion fluid using nitrogen. Do not exceed 2000 psi casing pressure. Total estimated recovery = 194 bbl. After all expected fluid is recovered, shut-in returns and continue to pressure up casing with nitrogen to 1500 psi. RDMO nitrogen unit. 31. Prepare to drop bar to fire TCP guns. Hold safety meeting. Install SPIDR gauge on annulus. When ready, drop the bar to fire the guns. Monitor annulus pressure, tubing pressure, and noise for indications of guns firing. When guns have fired, produce well back to flowback tank. 32. When nitrogen has sufficiently purged and well is producing adequately, turn well over to sales. Produce as per instructions of Production Engineer. JGE - December 19,2001 .~. ~ Drilling Fluids Proposal MARATHON OIL COMPANY Well KU 43-6 RD Kenai, Alaska Prepared by: Tony Tykalsky Reviewed by: Deen Bryan Presented to: Will Tank October 26th, ,2001 M-I Drilling Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ~ ~ r::J ~ .: DRilliNG "1' FLUIDS . " ,,~ M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 Phone (907) 274-5564 Fax (907) 2709-6729 Marathon Oil Company PO Box 190168 Anchorage, Alaska 99519 ATTN: Will Tank Will; Enclosed is the recommended drilling fluid program for Well KU 43-6RD to be drilled this winter. The following is a brief synopsis of the program. Overview: KU 43-6 is a sidetrack well targeting the Sterling fonnation in the Kenai Gas Field. The existing well- bore will be plugged back to +/- 4195' inside the 7 5/8" casing. After setting a whipstock, a 6 3/4" hole will be directionally drilled to a depth of 5712' MD (4787' TVD). A 4 1/2" liner will be run and cemented. Abandonment: We recommend drill water to be used while abondoning the existing wellbore. Cement plugs can be pumped while still using water. If excess cement needs to be circulated out, we would recommend Bi- ozan sweeps to insure hole cleaning. Biozan is cement tolerant whereas Flo Vis is not. After setting the whipstock, we recommend displacing the wellbore to a used FloPro fluid prior to milling the cas- ing. If needed for torque reduction, 1 - 3 % Lubetex may be added to the system as needed. Production Interval: Due to fonnation damage concerns expressed by Marathon engineers, we propose drilling this interval with two separate fluids. We recommend drilling the first part of this interval with a 3% KCL Polymer mud (or a used FloPro fluid). Bit balling from sticky clays can be treated with Drilling Detergent, SAPP and/or Nut Plug sweeps. Keep drill solids below 5% through aggressive use of all solids control equipment and dilution as needed. Conqor 404 will be used in the FloPro intervals in order to reduce corrosion problems. Fluid loss should be maintained between 8 - 10 cc's API for this interval. For the final part of the interval (drilling the depleted Sterling zone of production) we recommend displacing the wellbore to a new, clean FloPro fluid with properly sized calcium carbonate to bridge off the de- pleted Sterling sand. This would be the best way to both minimize fonnation damage (minimal drill solids and filtrate inva- sion) and maintenance cost of drilling fluid. Tony Tykalsky Project Engineer, M-I Drilling Fluids ---., ---- Project Summary Well KU 43-6 RD Casing Size Hole Size Casing Program Depth TVD Mud System Mud Weight Sum Days Interval Mud Cost N/A 4 $3,130 . After setting the whipstock, displace the hole to 3% KCI Polymer system (or a used FloPro fluid). Maintain a low mud weight throughout the 6 3/4" interval to by aggressive use of solids con- trol equipment. At a depth of +/- 5100', displace the wellbore to a new, clean 6% KCI FloPro fluid with the prescribed loading of sized calcium carbonate. After running and cementing the 4 1/2" liner, displace the wellbore to clean 3% KCI brine. . . . M-I Drilling Fluids LL.C. 721 W~:st First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLING FLUIDS ~ Economics Summary ~ Well KU 43-6 RD Abandonment To 3400' 4 $639 $2,500 4 Production Interval 3400 - 5650' $37,500 $4,375 7 11 Completion Interval $1,875 3 14 $2,501 . Well includes 3% KCL completion fluid. . Costs do not include any consideration for lost circulation, etc. . Cost does not include the use of any lubricants. M-I Drilling Fluids LL.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax $3,130 $45,005 $49,381 ~ 7 5/8" Abandonment :.. .---, Well KU 43-6 RD FloVis (sweeps if needed), KCI (dry jobs) . Shale Shakers / Desilter Yeild Point (lb.llOOft2) As needed IIIIIIRII' Plastic Viscosity (cp.) 1 API Fluid Loss (ml/30min) N/C . Fill wellbore and one surface pit with drillwater. . Mix high viscosity sweeps (if needed for hole cleaning) with Flo Vis. . Use KCI or NaCI to provide for dry jobs. M-I Drilling Fluids LL.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ~ ,..-, Interval Summary - 6 3/4" hole Well KU 43-6 3 % KCl Polymer (or used FloPro fluid) KeYPr()ducts Flo- Vis, Polypac UL, KC1, Greencide 25G, Barite Ventro1401, Mix II Fine / Conqor 404/ Drilling Detergent Shale Shakers / Centrifuge Coal sloughing, drill solids buildup, lost circulation Bit Balling I Yield API Point Fluid Loss. . . . (lb.!100ft2) (mIJ30min). 15 - 20 8 - 10 . Isolate one pit with drill water to accomplish the abandonment. . Clean other rig pits and build new 3% KCl Polymer fluid using the following fonnula* . Drill water; 10.5 PPB KC1; 0.25 PPB Greencide 25G; 1 PPB Polypac UL; . 2 PPB Flo-Vis; Caustic Soda for 9.0 - 9.5 pH, 0.5 PPBConqor 404 for 2000 ppm . Increase additions ofPolypac UL to maintain an API fluid loss ofless than 10 cc's. . Maintain Conqor 404 concentration at +/- 2000 ppm. . Add 2 - 3 PPB ofVentrol if running coal becomes a problem. . Centrifuge surface system during trips to aid in removing drill solids. . Add 1 - 2 drums of Drilling Detergent ifbit balling becomes a problem. . Estimated volume usage for interval- 590 barrels. * If no used fluid is available. M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ~ ~. Interval Summary - 6 3/4" hole Well KU 43-6 RD DriUingFluidSystem Flo-Pro Fluid Key Products Flo- Vis / DualFlo / KCl / Greencide 25G / SafeCarb Medium & Coarse / Ventrol 401 / Conqor 404 Shale Shakers / Centrifuge Coal sloughing, drill solids buildup, lost circulation Fonnation Porosity-1900 Millidarcy's 5100 - 5712' Plastic . LSRV API Viscosity 1 Min Fluid Loss (cp.) ... (lb.llOOftZ) (m1l30min) 8 - 12 > 40,000 +/- 6 cc's 9.0-9.5 +/- 2% 8.8 -9.0 . Isolate one pit with KCl Polymer fluid to drill to 5100'. . Clean other rig pits and build new 6% FloPro fluid using the following fonnula. . Drill water; 21 PPB KCl; 0.25 PPB Greencide 25G; 2.5 PPB DualFlo; 2 PPB Flo-Vis; Caustic Soda for 9.0 - 9.5 pH, 0.5 PPB Conqor 404 for 2000 ppm 18 PPB SafeCarb Medium; 2 PPB SafeCarb Coarse . . . Increase additions of DualFlo to maintain an API fluid loss ofless than 6 cc's. . Maintain Conqor 404 concentration at +/- 2000 ppm. . Add 2 - 3 PPB of Ventrol if running coal becomes a problem. . Maintain proper concentration of SafeCarb Medium and Coarse when accounting for any water additions. . Estimated volume usage for interval- 580 barrels. . NOTE: See attached Lost Circulation Recommendations for LCM Pills. M-I DriJJing Fluids LLC. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRilLING FLUIDS ~. ~" Project Team Well KU 43-6 RD . t ... :81 ~ t , . MI Project Engineer and Tech Service Engineer will coordinate between the Marathon office, rig, warehouse, and the M-I field engineers. . Well progress will be monitored to look for any changes which will improve the effi- ciency of the operation or avert trouble.. Project Team Title Home Cellular Craig Bieber District Manager 907345-1239 907229-1196 Deen Bryan Tech Service 907373-2713 907223-1634 Tony Tykalsky Project Engineer 907376-4613 907 227-2412 Gus Wik Warehouse Manager 907 776-8722 907776-8680 Bob Williams Field Engineer 907248-5857 Rod Mabeus Field Engineer 907 262-6643 M-I Drilling Fluids LLc. 721 W,est First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax DRILLlNI:i : FLUIDS ----- ----- PoInt _n-- TIe 00 "",,do.. ""IIOIT.... End of B.DOIT.... .... 01 Pool 6 TA . End of .... 3500-. 3600-. 3700, 3800 . ...-.. 3900- +- Q) Q) '>- '-" 4000. ..t: +- a.. Q) 4100. a C 4200- 0 +- .... Q) > 4300 - Q) ::J .... 4400 . l- I V 4500- 4600 - 4700 . 4800 - 4900 ~ ~ ~ \ \ '\ \ \ '\ , "- "- \. \. \. \. \. \ \ \. \ \ \ \ \ \. \ '.. \. "- \. \ \ \. \. \ \ "- "- \. ~'8 -~ MARATHON Oil Structure: Pad 41-7 Field: Kenol Gas FIeld WELL PROFILE DATA ---- "0 or.- - V. $oct """"'00 10. 1W ...t 4,.5.00 ""'0 4..00 .1600... '....... -,""-.. "39.<16 0.00 4215.00 ...... .... JOI.", "'..011 -,..... "44.77 6.00 ........ ....6 .JI.60 ..61» 2207.88 -157.78 1325... 4.00 <5267.42 ..... .JI.60 4442.DO 2""" -32..32 'BM"" 0.00 '712.99 ,.... .JI.60 4787.DO 2817... -447.27 11198.70 0.00 Strlg C1 Pool 6/KU436/20 OctO1 TO / KU43-6 / 20 Oct 01 35.10 KOP 35.31 36.07 DLS: 4.00 deg per 100 ft 36.56 37.41 38.60 39.26 End of Build/Turn Strlg C 1 Pool 6/KU436/20 OctO 1 TO / KU43-6 / 20 Oct 01 100 0 100 300 400 500 600 200 ~- Company Well: KU43-6RD Location: Kenol Peninsula, Alaska <- West (feet) 600 300 200 500 400 41/2 \ \ \ \ \ \ \ \ \ \ \ TARGET 4 1/2 TD 700 900 1100 800 1000 Vertical Section (teet) - > Azimuth 338.60 with reference 1944.48 N. 105.12 W from slot #KU 43-6X M MARATHON 100 0 100 - 2900 - 2800 - 2700 - 2600 - 2500 ^ I Z - 2400 0 ..., ....... :T ...-.. - 2300 - CD CD ....... '-" - 2200 -2100 - 2000 -1900 -1800 ~ KOP ill c_....."............ For: Will Tank Dot. plotted: 31-Oct-2ool Plot R.f.""",. I. KU43-6Rd _on 12- CoonIinoln ... in feet ..f....,.. oIot IKU OJ-ox. Tro. Vertical Depthe 0.. ..fe..... ,01o'1f t0518. -. .... INTEQ r----. /'"""'\ MARATHON Oil Company Pad 41-7 KU43-6RD slot #KU 43-6X Kenai Gas Field Kenai Peninsula. Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref: KU43-6Rd Version #2 Our ref: prop4938 License: Date printed: 31-0ct-2001 Date created: 22-Oct-2001 Last revised: 25-0ct-2001 Field is centred on n60 27 33.151.w151 16 7.223 Structure is centred on 270908.300,2362070.010.999.00000.N Slot location is n60 27 32.080.w15114 44.606 Slot Grid coordinates are N 2361787.175. E 275133.334 Slot local coordinates are 201.37 S 4229.87 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North ,'---"'" ~ MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7,KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised: 25-0ct-2001 Measured [nclin. Azimuth True Vert R E C TAN G U LA R Dogleg Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft 4195.00 35.10 4.00 3600.66 1944.48 N 105.12 W 0.00 4200.00 35.31 3.63 3604.74 1947.35 N 104.93 W 6.00 4215.00 35.96 2.55 3616.93 1956.08 N 104.45 W 6.00 4300.00 36.07 356.77 3685.71 2006.01 N 104.75 W 4.00 4400.00 36.56 350.07 3766.32 2064.76 N 111. 55 W 4.00 4500.00 37.41 343.57 3846.23 2123.25 N 125.28 W 4.00 4600.00 38.60 337.37 3925.06 2181.20 N 145.88 W 4.00 4646.50 39.26 334.60 3961.23 2207.88 N 157.78 W 4.00 5000.00 39.26 334.60 4234.94 2409.97 N 253.73 W 0.00 5267.42 39.26 334.60 4442.00 2562.84 N 326.32 W 0.00 TARGET 5500.00 39.26 334.60 4622.08 2695.80 N 389.46 W 0.00 5712.99 39.26 334.60 4787.00 2817.56 N 447.27 W 0.00 TO All data is in feet unless otherwise stated. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Bottom hole distance is 2852.84 on azimuth 350.98 degrees from wellhead. Total Dogleg for wellpath is 18.46 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ r-'-, ~ MARATHON Oil Company Pad 41.7,KU43.6RD Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref: KU43.6Rd Version #2 Last revised: 25.0ct.2001 Comments in wellpath ------- MD TVD Rectangular Coords. Comment """"""""""""""""""""""""""--"""",,""""""""""""""""""""'" 5267.42 4442.00 5712.99 4787.00 2562.84 N 2817.56 N 326.32 W TARGET 447.27 W TD Casing positions in string 'A' ----- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing """"""""""""""""""""""""""'""""""""""""""""""""""""""" n/a 3600.66 1944.48N 105.12W 5712.99 4787.00 2817.56N 447.27W 4 1/2" Targets associated with this wellpath Tal'get name Geographic Location T.V.O. Rectangular Coordinates Revised ................. """""" .......... """.....................,..... ......... ..........".... .......... TO 1 KU43.6 1 20 Oct 274850.000,2364375.000,0.0000 4787.00 Strlg C1 Pool 6/KU43274850.000,2364375.000,O.0000 4442.00 2581.99N 2581.99N 333.16W 23.0ct.2001 333.16W 23.0ct.2001 ./' ,..-, MARATHON Oil Company Pad 41-7 KU43-6RD slot #KU 43-6X Kenai Gas Field Kenai Peninsula. Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref: KU43-6Rd Version #2 Our ref: prop4938 License: Date printed: 31-0ct-2001 Date created: 22-0ct-2001 Last revised: 25-0ct-2001 Field is centred on n60 27 33.151.w15116 7.223 Structure is centred on 270908.300.2362070.010.999.00000.N Slot location is n60 27 32.080.w15114 44.606 Slot Grid coordinates are N 2361787.175. E 275133.334 Slot local coordinates are 201.37 S 4229.87 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North r-- /"""'\ MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 41-7.KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field,Kenai Peninsula. Alaska Last revised: 25-0ct-2001 Measured [nclin Azimuth True Vert R E C TAN G U LA R Dogleg Vert G RID COO R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect Easting Northing 4195.00 35.10 4.00 3600.66 1944.48N 105.12W 0.00 275065.71 2363733.24 4200.00 35.31 3.63 3604.74 1947.35N 104.93W 6.00 275065.96 2363736.11 4215,00 35.96 2.55 3616.93 1956.08N 104.45W 6.00 275066.60 2363744.82 4300.00 36.07 356.77 3685.71 2006.01N 104.75W 4.00 275067.26 2363794.75 4400.00 36.56 350.07 3766.32 2064.76N 111.55W 4.00 275061.60 2363853.62 4500.00 37.41 343.57 3846.23 2123.25N 125.28W 4.00 275049.00 2363912.36 4600 .00 38.60 337.37 3925.06 2181.20N 145.88W 4.00 275029.52 2363970.69 4646.50 39.26 334.60 3961.23 2207.88N 157.78W 4.00 275018.14 2363997.60 5000.00 39.26 334.60 4234.94 2409.97N 253.73W 0.00 274926.10 2364201.49 5267.42 39.26 334.60 4442.00 2562.84N 326.32W 0.00 274856.47 2364355.73 5500.00 39.26 334.60 4622.08 2695.80N 389.46W 0.00 274795.91 2364489.87 5712.99 39.26 334.60 4787.00 2817.56N 447.27W 0.00 274740.46 2364612.72 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Bottom hole distance is 2852.84 on azimuth 350.98 degrees from wellhead. Total Dogleg for wellpath is 18.46 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke. 1866 spheroid Presented by Baker Hughes INTEQ ~ /""\ MARATHON Oil Company Pad 41.7,KU43.6RO Kena' Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref: KU43-6Rd Version #2 Last revised: 25.0ct.2001 MO TVO Rectangular Coords. Comments in wellpath Comment """""""-""'--""-"""""'-""-""""'--.......-....-......................--..............,. 5267.42 4442.00 57:.2.99 4787.00 2562.84N 2817 . 56N 326.32W TARGET 447.27W TO Casing positions in string 'A' Top MO Top TVO Rectangular Coords. Bot MO Bot TVO Rectangular Coords. Casing . "--"'" -. -......'" - --.. - --... - -... -- - -..........""" --"",,"""""""""'" -.....' --..... "--'" ilIa 3600.66 1944.48N 105.12W 5712.99 4787.00 2817.56N 447.27W 41/2" Targets associated with this wellpath Target name Geographic Location T.V.O. Rectangular Coordinates Revised . . . -- . . . . . . . . . . . . . . . . . - . . . . . . . . . . . . . . . . - - . . . . . . . . . . . . . . . . . . . . . . . . . . . . . - . . . . . . . . . . . . . . . . . . . . - . . . . . . . - . . . - - - . - TO I KU43.6 I 20 Oct 274850.000,2364375.000,0.0000 4787.00 Stl'lg C1 Pool 6/KU43274850.000.2364375.000.0.0000 4442.00 2581.99N 2581.99N 333.16W 23.0ct.2001 333.16W 23-0ct-2001 ~ /""'\~ C",alod II)' Sutherland For: Will Tank Dolo plotted: 31-DcI-2001 Plot ""ferenco Is KU43-6Rd Vo...on f2. Coo"'i.at... a.. I. foot ..'...nco 0101 fKU 43-6X. MARATHON Oil Company Structure: Pad 41-7 Well: KU43-6RD M MARATHON Tnlo v.,¡I.." Deptho a", ",r.",."" ...to<y tabl.. .. Bf&\u - INTEQ field: Kenai Gas field LocatIon: Kenai PenInsula. Alaska TRUE NORTH <=>- c::J 350 0 10 340 20 240 330 30 320 40 310 50 300 60 290 70 280 80 270 90 260 100 250 11 0 120 230 130 220 140 210 150 200 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Created by Sutherland For: Will Tank I)ate platted: 31-00t-2oo1 Plot "',....... I. KU43-6Rd V...ran 12. CoonJr..too ... In root ..f...... .Iot IKU 43-6'. Tru. VoriJeol Depth. ... ..for.nco ..tory t.bro. .- If&\u 3200 3100 - 3000 - 2900 - 2800 - 2700 - 2600 - 2500 - ^ I 2400 - .......... Q) 2300 - CD ....... ~ ...c +- ~ 0 Z 2200 - 2100 - 2000 - 1900 - 1800 - 1700 - 1600. 1500 - 1400 - 130C INTEQ 1000 900 800 - 5900 5700 5500 5400 5300 5200 5100 5000 4900 4800 4700 4600 4500 4400 1000 900 800 ~. MARATHON Oil Com pany structure: Pad 41-7 Well: KU43-6RD Location: Kenol Peninsula. Alaska FIeld: Kenai Gas Field 700 600 8700 8600 8500 8400 8300 8200 8100 8000 7900 7800 7700 7700 7600 7600 7500 7500 7400 7300 7200 7100 7000 6900 6800 6700 6600 6500 6400 6300 6200 6100 6000 5900 5800 5700 5600 5500 5400 5300 5200 5100 -- -- ..... ..... ..... ..... ..... ...... ...... ...... ...... ",4600 ...... ...... ...... ...... ...... ...... ...... ...... ..... ...... ...... ..... ...... ...... ...... ..... ...... ~-2400 <- West (feet) 500 100 400 300 200 ?787 \ 4700 \ " 4600 \ 'II 4500 \ \ 4400 \ ~ 4300 \ \ 4200 \ \ ,4100 \ \ 4000. 4000 \ \ 3900, . 3900 \ 3800 ~ . 3800 \ 3700 I. 3700 . 4700 . 4500 . 4400 .4300 . 4200 .4100 . 3600 KOP .. 3500 . 3400 .. 3300 .. 3200 . 3100 . 3000 12900 rî) 200 100 0 4900 4800 4700 4600 4500 4400 4300 4200 t , 700 600 500 400 300 <- West (feet) ~ , 4500 . 4400 . 4300 . 4200 " 4100 . 4000 . 3900 . 3800 . 3700 "3600 ,3500 "3400 . 3300 . 3200 .3100 "3000 ~ 100 200 300 400 500 /"""""\ 0 100 200 300 ~ M MARATHON 400 500 3200 -3100 - 3000 - 2900 - 2800 -2700 -2600 - 2500 ^ I Z 0 ::¡ :::T - 2200 .......... -+. (1) (1) -2100 ~ - 2300 - 2000 -1900 -1800 -1700 -1600 -1500 -1400 1300 ~ ~ MARATHON Oil Company Pad 41-7 KU43-6RD slot #KU 43-6X Kenai Gas Field Kenai Peninsula, Alaska 3-D M I N I MUM D 1ST A N C E C LEA RAN C ERE PO R T ~ Baker Hughes INTEQ Your ref: KU43-6Rd Version #2 Our ref: prop4938 License: Date printed: 31-0ct-2001 Date created: 22-0ct-2001 Last revised: 25-0ct-2001 Field is centred on n60 27 33.151,w15116 7.223 Structure is centred on 270908.300,2362070.010.999.00000,N Slot location is n60 27 32.080,w15114 44.606 Slot Grid coordinates are N 2361787.175, E 275133.334 Slot local coordinates are 201.37 S 4229.87 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath MMS <0-7910'>"KBU33-7,Pad I?? GMS <0-5820'>"KU24-7,Pad #?? KU21-6X Version#4"KU21-6X,Pad #? PGMS <778 - 5567'>"KU21-6X,Pad #? MWD <3452 - 5650'>, ,KU21-6X,Pad #? MSS <0 - 5678'> Depth Shifted"KU21-6X,Pad #? PGMS <0-3300'>"WD-1,Pad #? MSS <0-4459'>, ,KU11.6,Pad #? Incl. only <0-5809'>, ,KU34-31,Pad #? GMS <0-10502'>, ,KDU5,Pad #? PGMS <0.5700'>"KU14-32,Pad #? GMS <0-11095'>, ,KDU6,Pad #? MSS <0-4453'>, ,KU21-7,Pad 14.6 PMSS <0 - ????>"KBU24-6,Pad 14-6 GMS <0-7375'>.,KBU31-7,Pad 14-6 PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 WD-2 Version #l"WD-2,Pad 14-6 INCLINATION ONLY"KU14-6,Pad 14-6 GMS <0-6950'>"KBU23X-6,Pad 14-6 MSS <0-5500'>, ,KU13-6,Pad 14-6 MSS <0-9895'>"KDU-1,Pad 14-6 GMS <0-10225'>, ,KDU-8,Pad 14-6 MSS <0-6530'>"KU43-12.Pad 14.6 PMSS <O-???'>,.KU 31-7.Pad 14.6 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 31-May-1995 5809.7 4195.0 4195.0 31-May-1995 7186.7 4195.0 4195.0 24-Aug.2001 2863.6 5713.0 5713.0 18-0ct-2001 2879.9 5713.0 5713.0 18-0ct-2001 2857.9 5713.0 5713.0 18-0ct-2001 2759.1 5713.0 5713.0 3D-May. 1995 5476.4 5713.0 5713.0 30-May-1995 3966.4 5713.0 5713.0 30-May-1995 5403.9 5713.0 5713.0 3D-May. 1995 3113.1 5713.0 5713.0 3D-May. 1995 3829.0 5713.0 5713.0 30-May-1995 5665.4 5713.0 5713.0 12-May-1995 3122.9 4195.0 4195.0 12-Mar-2001 2473.1 5220.0 5220.0 14-Sep-1995 2994.8 4195.0 4195.0 28-Sep.1995 2994.8 4195.0 4195.0 26-Mar.1999 3566.2 4195.0 4195.0 26-Mar.1999 3513.5 4195.0 4195.0 12-May-1995 2271.0 5713.0 5713.0 12-May-1995 3407.4 4195.0 5713.0 12-May-1995 3471.0 4195.0 5713.0 12-May-1995 3254.8 4195.0 4195.0 12-May-1995 4423.0 4195.0 4195.0 10-Jan-2001 2282.1 4195.0 4195.0 MSS <0-5706'>, ,KU43-6,Pac"""'--"7 MSS <0-5300'>,,43-6A,Pad ~- I KTU43-6XRd Ver.7,,43-6X Rd,Pad 41-7 PGMS <0-8370'>,,43-6,Pad 41-7 PMSS <7670-9464'>,,43-6X Rd,Pad 41-7 KBU 44-6 Version #l"KBU 44-6,Pad 41-7 KU 25-5Rd Version #la"KU24-5,Pad 41.7 GMS <0-5900'>,.KU24-5,Pad 41-7 PMSS <0 - 7570>..KBU42.7,Pad 41-7 GMS <O-7010'>,.KBU41-7,Pad 41-7 PMSS <8846 - 10960>,.KTU24-6H,Pad 41.7 MSS <0-10522'>.,KDU#2,Pad 41-7 GMS <0-5350'>"KU11-8,Pad 41-7 MSS <0-5707'>. ,KU 43-7.Pad 41-7 GMS <0-5549'>. ,KDU4.Pad 41-7 ~ISS <4320 - 10810'>, ,KDU4Rd, Pad 41- 7 GMS <0-8120'>"KU13-5,Pad 41-7 GMS <0-7902'>"KBU33-6,Pad 41-7 PMSS <0-8864>,.KTU32-7,Pad 41-7 KU~:4-5Rd Version #4a, .KU24-5Rd,Pad 41- 7 GMS <0 - 5893'> Depth Shifted. ,KU24-5Rd,Pad 41 MSS <0 - 5701'> Depth Shifted,.KU43-6RD.Pad 41 20-Jan-1994 20-Jan-1994 20-Apr-1999 23-Jul-1995 16-Aug-1995 25-0ct-2000 9.0ct-2001 21-Jan-1994 9-Feb-2001 21-Jan-1994 1-Aug-2000 21-Jan-1994 21-Jan-1994 21-Jan-1994 5-May-1995 5-May-1995 21-Jan-1994 22-Jun-2000 31-Aug-2000 9-0ct-2001 12-Jul-2001 25-0ct-2001 0_3 421. 2 3674_6 805.7 805.7 1304.0 1904.9 1912.6 2440.6 1925.2 1772.8 2563.8 2715.1 3335.8 2952.3 2952.3 1083.2 623.2 2244.9 1905.2 1912.6 0.0 4195.0 ~ 4252.8 5713.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4252.8 5713.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 4195.0 ,r---. ---- MARATHON Oil Company CLEARANCE LISTING Page 2 Pad 41-7,KU43.6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0.5706'>, ,KU43.6,Pad 41-7 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 4195.0 3600.7 1944.5N 105.1W 4200.2 3600.8 1944.3N 105.3W 215.6 0.3 0.3 4197.5 3602.7 1945.9N 105.0W 4202.7 3602.9 1945.7N 105.2W 215.0 0.3 0.3 4200.0 3604.7 1947.4N 104.9W 4205.2 3604.9 1947.1N 105.1W 213.1 0.3 0.3 4205.0 3608.8 1950.2N 104.8W 4210.2 3609.0 1950.0N 104.9W 205.8 0.3 0.3 4210.0 3612.9 1953.2N 104.6W 4215.2 3613.1 1952.9N 104.7W 195.1 0.4 0.4 4215.0 3616.9 1956.1N 104.5W 4220.2 3617.2 1955.7N 104.5W 183.2 0.4 0.4 4224.4 3624.6 1961.6N 104.2W 4229.6 3624.9 1961. IN 104.1W 164.2 0.6 0.6 4233.9 3632.2 1967.2N 104.1W 4239.0 3632.7 1966.5N 103.7W 150.4 0.9 0.9 4243.3 3539.9 1972. 7N 104.0W 4248.5 3640.4 1971.9N 103.3W 140.6 1.2 1.2 4252.8 3647.5 1978.3N 104.0W 4257.9 3648.1 1977.3N 103.0W 133.6 1.5 1.5 4262.2 3655.2 1983.8N 104. OW 4267.4 3655.9 1982.7N 102.6W 128.4 1.9 1.9 4271. 7 3662.8 1989.4N 104.1W 4276.8 3663.6 1988.1N 102.2W 124.4 2.4 2.4 4281.1 3670.4 1994.9N 104.2W 4286.2 3671.3 1993.4N 101.8W 121.3 3.0 3.0 4290.6 3678.1 2000.5N 104.5W 4295.6 3679.1 1998.8N 101. 5W 118.7 3.6 3.6 4300.0 3685.7 2006.0N 104.8W 4305.1 3686.8 2004.2N 101.lW 116.7 4.2 4.3 4310.0 3693.8 2011.9N 105.1W 4315.0 3695.0 2009.8N 100.7W 114.8 5.0 5.0 4320.0 3701. 9 2017.8N 105.6W 4325.0 3703.2 2015.5N 100.3W 113.2 5.9 5.9 4330.0 3709.9 2023.6N 106.1W 4334.9 3711.3 2021.2N 99.9W 111.7 6.8 6.8 4340.0 3718.0 2029.5N 106.6W 4344.9 3719.5 2026.9N 99.5W 110.3 7.8 7.8 4350.0 3726.1 2035.4N 107.3W 4354.8 3727.6 2032.6N 99.1W 109.1 8.8 8.8 4360.0 3734.1 2041.3N 108.0W 4364.8 3735.8 2038.3N 98.7W 107.9 9.9 10.0 4370.0 3742.2 2047.1N 108.8W 4374.7 3743.9 2044.0N 98.3W 106.9 11.1 11.2 4380.0 3750.2 2053.0N 109.6W 4384.6 3752.0 2049.7N 97.9W 105.9 12.3 12.4 4390.0 3758.3 2058.9N 110.6W 4394.5 3760.1 2055.4N 97.5W 105.0 13.6 13.8 4400.0 3766.3 2064.8N 111.5W 4404.4 3768.2 2061.1N 97.1W 104.2 15.0 15.2 4410.0 3774.3 2070.6N 112.6W 4414.4 3776.3 2066.8N 96.7W 103.4 16.5 16.6 4420.0 3782.4 2076.5N 113.7W 4424.2 3784.3 2072.5N 96.3W 102.8 18.0 18.2 4430 .0 3790.4 2082.3N 114.9W 4434.1 3792.3 2078.3N 95.9W 102.1 19.6 19.8 4440.0 3798.4 2088.2N 116.2W 4444.0 3800.4 2084.0N 95.5W 101. 5 21.2 21.5 4450.0 3806.4 2094.1N 117.5W 4453.8 3808.4 2089.7N 95.1W 101. 0 22.9 23.3 4460.0 3814.4 2099.9N 119. OW 4463.6 3816.3 2095.4N 94.7W 100.5 24.7 25.2 4470.0 3,822.4 2105.7N 120.4W 4473.4 3824.3 2101.1N 94.3W 100.0 26.6 27.1 4480.0 3,830.3 2111. 6N 122.0W 4483.2 3832.2 2106.9N 93.9W 99.5 28.5 29.1 4490.0 3;838.3 2117.4N 123.6W 4493.0 3840.2 2112. 6N 93.5W 99.1 30.6 31.2 4500.0 3846.2 2123.3N 125.3W 4502.8 3848.1 2118.3N 93.1W 98.7 32.7 33.4 4510.0 ~:854.2 2129.1N 127.0W 4512.6 3856.0 2124.0N 92.6W 98.4 34.8 35.7 4520.0 3862.1 2134.9N 128.9W 4522.2 3863.8 2129.6N 92.2W 98.2 37.1 38.1 4530.0 3870.0 2140.7N 130.7W 4531. 9 3871.7 2135.3N 91.8W 97.9 39.4 40.5 4540.0 3877.9 2146.5N 132.7W 4541. 6 3879.5 2141. ON 91.3W 97.6 41.8 43.1 4550.0 3885.8 2152.3N 134. 7W 4551.3 3887.4 2146.7N 90.9W 97.3 44.2 45.7 4560 .0 3893.7 2158.1N 136.8W 4561. 0 3895.2 2152.4N 90.4W 97.1 46.8 48.4 4570.0 3901. 5 2163.9N 139.0W 4570.5 3902.9 2157.9N 90.0W 96.9 49.4 51.2 4580.0 3909.4 2169.7N 141. 2W 4580.1 3910.6 2163.6N 89.5W 96.7 52.1 54.1 4590.0 3917.2 2175.4N 143.5W 4589.7 3918.4 2169.2N 89.0W 96.5 54.8 57.1 4600.0 3925.1 2181.2N 145.9W 4599.3 3926.1 2174.9N 88.6W 96.3 57.7 60.2 4609.3 3932.3 2186.6N 148.1W 4608.2 3933.3 2180.1N 88.1W 96.1 60.4 63.2 4618.6 :1939.6 2191. 9N 150.5W 4617.1 3940.5 2185.3N 87.7W 96.0 63.2 66.2 4627.9 3946.8 2197.2N 152.8W 4625.9 3947.6 2190.5N 87.2W 95.8 66.0 69.3 4637.2 3954.0 2202.6N 155.3W 4634.8 3954.8 2195.8N 86.7W 95.7 68.9 72.5 4646.5 3961.2 2207.9N 157.8W 4643.6 3961.9 2201. ON 86.3W 95.5 71.8 75.7 4700.0 4002.7 2238.5N 172.3W 4694.6 4002.8 2231.3N 83.8W 94.6 88.8 93.5 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~, ,.~ MARATHON Oil Company CLEARANCE LISTING Page 3 Pad 41-7,KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field,Kenai Peninsula, Alaska Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0-5706'>"KU43-6,Pad 41-7 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D, T.V.D. Rect Coordinates Bearing Dist Dist 4800.0 4080.1 2295.6N 199.4W 4789.9 4078.7 2288.7N 79.6W 93.3, 120.1 126.5 4900,0 4:.5 7 . 5 2352.8N 226.6W 4883.6 4152.7 2346.1N 75.2W 92.5 151. 6 160.1 5000.0 4;~34. 9 2410.0N 253.7W 4977.2 4225.9 2404. IN 70.0W 91.8 184.0 195.3 5100.0 4312.4 2467.1N 280.9W 5068.1 4296.3 2461.3N 63.9W 91.5 217.7 231.8 5200.0 4389.8 2524.3N 308.0W 5163.4 4369.3 2522.2N 56.9W 90.5 251.9 267.2 5267.4 4442.0 2562.8N 326.3W 5228.4 4418.6 2564.5N 52.9W 89.7 274.4 291.5 5300.0 4467.2 2581. 5N 335.2W 5259.1 4441. 8 2584.5N 51.1W 89.4 285.2 303.6 5400.0 4!j44.7 2638.6N 362.3W 5348.8 4509.7 2642.6N 44.8W 89.3 319.4 340.7 5500.0 4622.1 2695.8N 389.5W 5443.5 4581.8 2703.6N 37.5W 88.7 354.3 377.1 5600.0 4699.5 2753.0N 416.6W 5538.9 4654.7 2764.8N 30.7W 88.2 388.6 413.4 5700.0 4776.9 2810.1N 443.7W 5632.7 4727.0 2824.1N 24.3W 88.1 422.7 5713.0 4787.0 2817.6N 447.3W 5644.9 4736.5 2831.8N 23.4W 88.1 427.1 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ /~ ~ MARATHON Oil Company CLEARANCE LISTING Page 4 Pad 41-7.KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field.Kenai Peninsula. Alaska Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0-5300'>..43.6A.Pad 41.7 Horiz Min'm TCyl M.D, T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 4195.0 3600.7 1944.5N 105.1W 4266.5 3704.7 1800.2N 277.8E 110.6 422.2 422.6 4197.5 3602.7 1945.9N 105.0W 4269.0 3706.8 1801. 5N 277 . 7E 110.7 422.1* 422.4* 4200.0 3604.7 1947.4N 104.9W 4271. 5 3708.9 1802.9N 277. 6E 110.7 422.0* 422.3* 4205.0 3608.8 1950.2N 104.8W 4276.5 3713.1 1805.5N 277 . 5E 110.7 421. 8* 422.1* 4210.0 3612.9 1953.2N 104.6W 4281.5 3717.4 1808.2N 277 . 3E 110.8 421.7* 421.8* 4215.0 3616.9 1956.1N 104.5W 4286.5 3721. 6 1810.8N 277.2E 110.8 421.6* 421.7* 4224.4 3624.6 1961. 6N 104.2W 4295.9 3729.5 1815.8N 276.9E 110.9 421.4* 421.4* 4233.9 3632.2 1967.2N 104.1W 4305.3 3737.5 1820.8N 276.6E 111.0 421.2* 421.3* 4243.3 3639.9 1972. 7N 104.0W 4314.7 3745.5 1825.8N 276.4E 111.1 421. 2* 421.2* 4252.8 3647.5 1978.3N 104. OW 4324.1 3753.4 1830.9N 276.1E 111.2 421.2* 421.2* 4262.2 3655.2 1983.8N 104. OW 4333.5 3761.4 1835.9N 275.8E 111.3 421. 2 421.3 4271.7 3662.8 1989.4N 104.1W 4341. 9 3768.5 1840.3N 275.6E 111.4 421.4 421.4 4281.1 3670.4 1994.9N 104.2W 4351.3 3776.4 1845.3N 275.3E 111.5 421.5 421. 6 4290.6 3678.1 2000.5N 104.5W 4360.7 3784.4 1850.4N 275.1E 111.6 421.8 421. 9 4300.0 3685.7 2006.0N 104.8W 4370.2 3792.4 1855.4N 274.8E 111.6 422.1 422.3 4310.0 3693.8 2011.9N 105.1W 4380.1 3800.8 1860.7N 274.5E 111.7 422.4 422.8 4320.0 3701.9 2017.8N 105.6W 4390.1 3809.3 1865.9N 274.3E 111.8 422.9 423.4 4330.0 3709.9 2023.6N 106.1W 4400.1 3817 . 7 1871.2N 274.0E 111.9 423.4 424.1 4340.0 3718.0 2029.5N 106.6W 4410.0 3826.2 1876.5N 273.7E 111.9 424.0 424.8 4350.0 3726.1 2035.4N 107.3W 4420.0 3834.7 1881.8N 273.4E 112.0 424.6 425.7 4360.0 3734.1 2041.3N 108.0W 4430.0 3843.1 1887.0N 273.1E 112.0 425.4 426.6 4370.0 3742.2 2047. IN 108.8W 4438.6 3850.4 1891.6N 272. 9E 112.2 426.1 427.6 4380.0 3750.2 2053.0N 109.6W 4448.5 3858.9 1896.8N 272. 6E 112.2 427.0 428.7 4390.0 3758.3 2058.9N 110. 6W 4458.5 3867.3 1902.1N 272.4E 112.3 427.9 429.9 4400.0 3766.3 2064.8N 111. 5W 4468.4 3875.8 1907.3N 272.1E 112.3 428.9 431. 2 4410.0 3774.3 2070.6N 112.6W 4478.4 3884.2 1912.5N 271.8E 112.4 430.0 432.5 4420.0 3782.4 2076.5N 113.7W 4488.3 3892.7 1917.7N 271.5E 112.4 431.1 434.0 4430.0 3790.4 2082.3N 114.9W 4498.2 3901.1 1922.9N 271.3E 112.4 432.3 435.5 4440.0 3798.4 2088.2N 116. 2W 4508.2 3909.6 1928.1N 271.0E 112.5 433.5 437.2 4450.0 3806.4 2094.1N 117. 5W 4518.1 3918.0 1933.3N 270.7E 112.5 434.8 438.9 4460.0 3814.4 2099.9N 119. OW 4526.6 3925.3 1937.7N 270.5E 112.6 436.2 440.7 4470.0 3822.4 2105.7N 120.4W 4536.5 3933.7 1942.9N 270.2E 112.6 437.6 442.6 4480.0 3830.3 2111.6N 122.0W 4546.3 3942.2 1948.0N 269.9E 112.7 439.2 444.6 4490.0 3838.3 2117.4N 123.6W 4556.2 3950.6 1953.2N 269.7E 112.7 440.7 446.7 4500.0 3846.2 2123.3N 125.3W 4566.1 3959.0 1958.3N 269.4E 112.7 442.4 448.8 4510.0 3854.2 2129.1N 127.0W 4575.9 3967.4 1963.4N 269.1E 112.7 444.1 451.1 4520.0 3862,1 2134.9N 128.9W 4585.8 3975.8 1968.5N 268.9E 112.7 445.9 453.5 4530.0 3870.0 2140.7N 130.7W 4595.6 3984.2 1973.6N 268.6E 112.7 447.7 455.9 4540.0 3877 . 9 2146.5N 132.7W 4605.4 3992.6 1978.7N 268.3E 112.7 449.6 458.4 4550.0 3885.8 2152.3N 134.7W 4615.2 4001. 0 1983.8N 268.1E 112.7 451.6 461.1 4560.0 3893.7 2158.1N 136.8W 4623.6 4008.2 1988. IN 267.9E 112.8 453.6 463.8 4570.0 3901. 5 2163.9N 139.0W 4633.3 4016.5 1993.1N 267.6E 112.8 455.7 466.6 4580.0 3909.4 2169.7N 141. 2W 4643.1 4024.9 1998.1N 267.3E 112.8 457.9 469.5 4590.0 3917.2 2175.4N 143.5W 4652.8 4033.2 2003.2N 267.1E 112.8 460.1 472.6 4600.0 3925.1 2181.2N 145.9W 4662.6 4041. 6 2008.2N 266.8E 112.7 462.4 475.7 4609.3 3.932.3 2186.6N 148.1W 4671.6 4049.3 2012.8N 266.6E 112.7 464.6 478.7 4618.6 3,939.6 2191.9N 150.5W 4680.6 4057.1 2017.4N 266.3E 112.7 466.8 481.7 4627.9 3,946.8 2197.2N 152.8W 4689.6 4064.8 2022.0N 266.1E 112.7 469.2 484.9 4637.2 ~;954. 0 2202.6N 155.3W 4698.6 4072.5 2026.7N 265.8E 112.7 471.5 488.1 4646.5 ~;961. 2 2207.9N 157.8W 4707.6 4080.2 2031. 2N 265.6E 112.6 473.9 491. 5 4700.0 4002.7 2238.5N 172.3W 4758.0 4123.5 2056.9N 264.2E 112.6 488.0 506.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KU 43.6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~ ~ MARATHON Oil Company Pad 41-7,KU43-6RD Kenai Gas Field,Kenai Peninsula, Alaska CLEARANCE LISTING Page 5 Your ref: KU43-6Rd Version #2 Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0-5300'>,,43-6A,Pad 41-7 M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Horiz Min'm Bearing Dist TCyl Dist All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ~ ~ MARATHON Oil Company CLEARANCE LISTING Page 6 Pad 41.7.KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field.Kenai Peninsula. Alaska Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0 - 5701'> Depth Shifted..KU43-6RD,Pad 41-7 Horiz Min'm TCyl M.D. TV.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 4195.0 3600.7 1944.5N 105.1W 4195.0 3600.7 1944.5N 105.1W 90.0 0.0 0.0 4197.5 3602.7 1945.9N 105.0W 4197.5 3602.7 1945.9N 105.0W 135.3 0.0 0.0 4200.0 3604.7 1947 AN 104.9W 4200.0 3604.7 1947.3N 104.9W 135.3 0.0 0.0 4205.0 3608.8 1950.2N 104.8W 4205.0 3608.8 1950.2N 104.7W 135.3 0.1 0.1 4210.0 3612.9 1953.2N 104.6W 4210.0 3612.9 1953.1N 104.5W 135.3 0.1 0.1 4215.0 3616.9 1956.1N 104.5W 4215.0 3617.0 1955.9N 104.3W 135.3 0.2 0.2 4224.4 3624.6 1961.6N 104.2W 4224.4 3624.8 1961. 3N 103.9W 132.7 0.4 0.4 4233.9 3632.2 1967.2N 104.1W 4233.9 3632.5 1966.7N 103.6W 128.7 0.7 0.7 4243.3 3639:9 1972.7N 104.0W 4243.3 3640.2 1972.1N 103.2W 125.2 1.1 1.1 4252.8 3647.5 1978.3N 104.0W 4252.8 3648.0 1977.5N 102.8W 122.2 1.4 1.4 4262.2 3655.2 1983.BN 104.0W 4262.2 3655.7 1982.9N 102.4W 119.6 1.9 1.9 4271. 7 3662.8 1989.4N 104.1W 4271.6 3663.4 1988.3N 102.1W 117.5 2.4 2.4 4281.1 3670.4 1994.9N 104.2W 4281.0 3671. 2 1993.7N 101. 7W 115.8 2.9 3.0 4290.6 3678.1 2000.5N 104.5W 4290.5 3678.9 1999.0N 101.3W 114.2 3.6 3.6 4300.0 3685.7 2006.0N 104.8W 4299.9 3686.6 2004.4N 100.9W 112.9 4.3 4.3 4310.0 3693.8 2011.9N 105.1W 4309.9 3694.8 2010.1N 100.5W 111. 7 5.0 5.1 4320.0 3701. 9 2017.BN 105.6W 4319.8 3703.0 2015.7N 100.lW 110.5 5.9 5.9 4330.0 3709.9 2023.6N 106.1W 4329.8 3711.2 2021.4N 99.7W 109.4 6.8 6.8 4340.0 371B.0 2029.5N 106.6W 4339.7 3719.3 2027.1N 99.3W 108.4 7.8 7.8 4350.0 3726.1 2035.4N 107.3W 4349.7 3727.5 2032.8N 98.9W 107.4 8.8 8.9 4360.0 3734.1 2041.3N 108.0W 4359.6 3735.6 2038.5N 98.5W 106.4 10.0 10.0 4370.0 3742.2 2047.1N 10B.8W 4369.5 3743.7 2044.2N 98.1W 105.5 11.1 11.2 4380.0 3750.2 2053.0N 109.6W 4379.5 3751.9 2049.9N 97.7W 104.7 12.4 12.5 4390.0 3758.3 2058.9N 110.6W 4389.4 3759.9 2055.6N 97.3W 104.0 13.7 13.8 4400.0 3766.3 2064.8N 111. 5W 4399.3 3768.0 2061.3N 96.9W 103.3 15.1 15.2 4410.0 3774.3 2070.6N 112.6W 4409.2 3776.1 2067.0N 96.5W 102.6 16.5 16.7 4420.0 3782.4 2076.5N 113.7W 4419.1 3784.2 2072.8N 96.1W 102.0 18.1 18.3 4430.0 3790.4 2082.3N 114. 9W 4428.9 3792.2 2078.5N 95.7W 101.4 19.7 19.9 4440.0 3798.4 2088.2N 116.2W 4438.8 3800.2 2084.2N 95.3W 100.8 21.3 21.6 4450.0 3806.4 2094.1N 117.5W 4448.6 3808.2 2089.9N 94.9W 100.3 23.0 23.4 4460.0 3814.4 2099.9N 119.0W 4458.5 3816.2 2095.6N 94.5W 99.9 24.8 25.3 4470.0 3822.4 2105.7N 120.4W 4468.3 3824.1 2101.4N 94.1W 99.5 26.7 27.2 4480.0 3830.3 2111.6N 122.0W 4478.1 3832.1 2107.1N 93.7W 99.1 28.7 29.2 4490.0 3838.3 2117.4N 123.6W 4487.9 3840.0 2112.8N 93.3W 98.7 30.7 31.3 4500.0 3846.2 2123.3N 125.3W 4497.6 3847.9 2118. 5N 92.9W 98.3 32.8 33.5 4510.0 3854.2 2129.1N 127.0W 4507.4 3855.9 2124.2N 92.5W 98.0 34.9 35.8 4520.0 3862.1 2134.9N 128.9W 4517.0 3863.7 2129.8N 92.0W 97.8 37.2 38.2 4530 .0 3870.0 2140.7N 130.7W 4526.8 3871. 5 2135.5N 91.6W 97.5 39.5 40.7 4540.0 3877.9 2146.5N 132.7W 4536.5 3879.4 2141.2N 91.2W 97.3 41.9 43.2 4550.0 3885.8 2152.3N 134. 7W 4546.1 3887.2 2146.9N 90.7W 97.0 44.4 45.8 4560.0 3893.7 2158.1N 136.8W 4555.8 3895.0 2152.6N 90.3W 96.8 46.9 48.6 4570.0 3901. 5 2163.9N 139.0W 4565.3 3902.7 2158.1N 89.8W 96.7 49.5 51.4 4580.0 3909.4 2169.7N 141. 2W 4574.9 3910.5 2163.8N 89.3W 96.5 52.2 54.3 4590.0 3917.2 2175.4N 143.5W 4584.5 3918.2 2169.4N 88.9W 96.3 55.0 57.3 4600.0 3925.1 2181.2N 145.9W 4594.1 3926.0 2175.1N 88.4W 96.1 57.8 60.4 4609.3 3932.3 2186.6N 148.1W 4603.0 3933.2 2180.3N 88.0W 95.9 60.5 63.3 4618.6 3939.6 2191.9N 150.5W 4611. 9 3940.3 2185.5N 87.5W 95.8 63.3 66.4 4627.9 3946.8 2197.2N 152.8W 4620.8 3947.5 2190.8N 87.0W 95.6 66.1 69.5 4637.2 3954.0 2202.6N 155.3W 4629.6 3954.6 2196.0N 86.6W 95.5 69.0 72.6 4646.5 3961.2 2207.9N 157.8W 4638.4 3961.7 2201. 2N 86.1W 95.3 71.9 75.9 4700.0 4002.7 2238.5N 172.3W 4689.4 4002.6 2231. 5N 83.7W 94.5 88.9 93.7 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KU 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ .r---. ~ MARATHON Oil Company CLEARANCE LISTING Page 7 Pad 41-7.KU43-6RD Your ref: KU43-6Rd Version #2 Kenai Gas Field.Kenai Peninsula. Alaska Last revised: 25-0ct-2001 Reference wellpath Object wellpath : MSS <0 - 5701'> Depth Shifted..KU43-6RD,Pad 41-7 Horiz Min'm TCyl M.D. 1. V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 4800.0 4080.1 2295.6N 199.4W 4784.7 4078.5 2288.9N 79.4W 93.2 120.2 126.6 4900.0 4157.5 2352.8N 226.6W 4878.4 4152_5 2346.3N 75.0W 92.4 151.8 160.3 5000.0 4;~34. 9 2410.0N 253.7W 4972.0 4225.7 2404.3N 69.9W 91.8 184.2 195.4 5100.0 4~112 . 4 2467. IN 280.9W 5062.9 4296.2 2461. 5N 63.7W 91.5 217.9 232.0 5200.0 4389.8 2524.3N 308.0W 5158.2 4369.1 2522.4N 56.8W 90.4 252.1 267.4 5267.4 4442.0 2562.8N 326.3W 5223.3 4418.4 2564.7N 52.8W 89.6 274.6 291. 7 5300.0 4467.2 2581.5N 335.2W 5253.9 4441. 6 2584.7N 50.9W 89.4 285.4 303.8 5400.0 4~i44 . 7 2638.6N 362.3W 5343.6 4509.5 2642.8N 44.7W 89.2 319.6 340.9 5500.0 4622.1 2695.8N 389.5W 5438.3 4581.6 2703.8N 37.4W 88,7 354.5 377.3 5600.0 4699.5 2753. ON 416.6W 5533.7 4654.6 2765.0N 30.6W 88.2 388.8 413.6 5700.0 4i'76.9 2810.1N 443.7W 5627.5 4726.8 2824.3N 24.1W 88.1 422.8 5713.0 4ï'87.0 2817.6N 447.3W 5639.7 4736.3 2832.0N 23.3W 88.1 427.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #Ku 43-6X and TVD from rotary table (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEG \ X \ , \ " x.. \ ," """~ :i~'" \ {"'Xi-~ 10\1 \~ I \i.?{\~ ~ 7~ :J:.' \/ 'X )f"~-':~-- ~ ~ ~' I I ~~~:j~<t + \~~. ./ j' a ' J I , , .~ " I-. I ' "' Ja .-. "' ... + :ro-.'-"~ L._:~ - - - - - - - í;.:f ~ I 0 r----.. )C Sterling Productive Area Bottom hole location ~ + \ I T5N-R1.jW \ ....... -. \ a '\ L.~ UNIT \ I BOUNDARY. \, --1../ \ L. a , , , -J.-. 17-" I ~tb.. \\ ~.1 \ a \ \ L.--: \ I \ a ~ I I T4 ~R11W' a \ \ \ \ \ \ \ I I :r : i t .. t ..... f .. , I I . / I ,1"-" +- ... , KDU-7 X , I [j , 1'* + STERUNG FORMATION Pool 6 1 I MILE MARA1HON OIL COMPANY ALASKA REGION KENAI FIELD COOK INLET, ALASKA NETW.I.: 100% May 2001 596 15' ,597 I , I '.- :~", " " f ,,', \',: ¡~,.-:- , \' ,--' ',. 2 g, - ) 8 ~- UNITED STATES PARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ,.-...., ~ I 17' 30" I I 595O00m-[. . \.~~=Ji ,..-...-.. II . 'ì' :i ¡ II '='1'" II i 11 i 11 1"$ ,~==J):====='If=Ì\ ~""¡'" 3 0 . II' II ',~/ , ! ' II," " . GAS WELLS ~ ----- o~. <¡¡' g (' 11; ç , I 1\' (,;)=,,~======,þ==-'- ,,\1','4T r I,. .,. 'J' i \ "", '" ,', c: ., "', '-~~~+,..::-.:): GA:?'WE'LL5' ,:.\ '.. ¡ i 2 Z F'\ (1 598 + 191 33 21T .I., ,,' ,~, .-, Alaska Region Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 November 12, 2001 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KU 43-6 RD Permit No.: Not assigned Regarding: Sidetrack of well KU 43-6 Dear Mr. Maunder: Enclosed please find the permit application, drilling plan, directional survey, mud program, property plat, BOP sketch, property plat, structure map, and filing fee. If you require further information, I can be reached at 907-564-6332 or bye-mail at Ifshannon @ marathonoiLcom. Sincerely, 'f!.J . ~ tJ;f. JL ..! Leona~F.Shannon Senior Drilling Engineer '¡ .~ ~ ". ORIGINAL .....'.."'. "....' ..."'. .',.'.. .A\:JWØR1~ø.ßi~~~)\ . i: 1::1 :'~t8 ~JrtIJ.ili: I !-"'IIIIIlil] ~T/I: ~. 1.81:1] ~. ;~, I ~!-_~, ~ IJ~':I i I ¡ [8 ,~,8T¡Th'i: :~\T/'~':~~.: [Ii. ..~~,~, ~ Ir~'~ [èf. ai..,il:t\¡T .. 11100 I. 5 5 "'"1 I: I. 2 5 2000 5 71: 0 1.1110 7 a 5 b 11111 OR I~~I :\, :l1]:1 i I ~ [~'ì ;~, "11-"- NON-REPORTING 100% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT NON-EMPLOYEE COMPo PRIZES. IW>lAADS. OR DAMAGES OPERATOR CITY STATE ------- - - -- 1]~-\8:U~IIi[I]~ Filing.FE'eJor,.ErmL~to._.nr.i 11 KU 43-6 RD . - ,~',~~~--"'--- _... ...__.__.__.._-~_._._- - »--- "'-" ._._.__...._.-_--_._----~.~, ---~~_._--- ¡!\¡a~¡<e 011 &: -------,-,.-..---..--.'" '---"'" .'" ,--,----_.~--., .._--_._--.~.. .----- ._--_..__.~'_____d_~_' ~, ~~ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER ;/3 -~ KD CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPM7N RED RILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL WELL NAME /< tt. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) / ANNULAR mSPOSAL L6NO ANNULAR DISPOSAL L-) YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well -------' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated.. . ANNULUS L-) YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved . subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. I / Kif.. WELL PERMIT CHECKLIST COMPANY/f/(tVta~ WELL NAME...£j -t:, ¡?L:> PROGRAM: exp - dev / redrll L serv - wellbore seg _ann. disposal para req - FIELD & POOL '-I ~ Çf 5"tof5 INIT CLASS -P6V f (j;éZ ~ GEOL AREA ßZ/) UNIT# 05//2D ON/OFF SHORE On ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . , . . . . . . . . . N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . N 3.Uniquewellnameandnumber.................. N 4.Welllocatedinadefinedpool.................. 'N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . ' N 11. Permit can be issued without conservation order. . . . . . . . N 12. Permit can.be issued without administrative approval.. . . . . N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided. . . . . . . . " . . . . . . . . . ÆJ N E:4 $'......... 15. Suñace casing protects all known USDWs. . . . . . . . . . . 'fi) N .. ~ 16. CMT vol adequate to circulate on conductor & surf csg. . . . . Y N N/^ 17. CMT VO.I adequate to tie-in long string to suñ csg. . . . . . . . j N N/A 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . N 21. If a re-drill, has a 10-403 for abandonment been approved. . . Y N TGM ~ ON- c-~ "'^I""I-f'" d£~c II'L/OL. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . ffl N 23. If diverter required, does it meet regulations. . . . . . . . . . '1 N H/A. 24. Drilling .fluid program schematic & equip list adequate. . . . . ~ N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N . ¡APP.)R DA""ÇE .26. BOPEpressratingapp,ropriate;testto3.0DO psig. N ¡YlAs.P -=- 17(,{ f'V. : VJ61t I t(7/0{ 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N iJ. "',4If'\ (Ç) ~ 28. Work will occur without operation shutdbwn. . . . . . . . . . . ~. ~" I ~ \ 29. Is presence of H:zS gas probable.. . . . . . . . . . . . . . . . Y ~ : GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . ... ~y , 31. Data presented on potential overpressure zones. . . . . . . , 32. Seismic anal~~is of shallow gas zones. . . . . . . . . . . . . ¡J Y N ¿¿ DATE ¡. 33. Seabed condition survey (If off-shore). . . . . . . . '.~ Y N , . /2. ..t . D 34. Contact name/phone for weekly progress reports [~oratory only) Y N ! NNULAR DISPOSAL35. With proper cementing records. this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater. or cause drilling waste. " Y N to suñace; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GE~LO: ENGINEERING: UIC/Annular COMMISSIO N: Rþ ~ ~ WCtIr 1"7/0 r WM8~s . S . +~~~~ ~ l';;}-/~ , JMH~~ :J 1/41 ó-¿' A~KR DATE (' /llJ /2.(;.0 : ENGINEERING APPR DATE c 0 Z 0 ~ ~ :xl ) ~ m \ÑC).>~ ~E:) b~ ~~~..~ <..\~~~à ~\~~~~~ ~~~ ~ z ~ :x: - en » :xl m » I } Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100)