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202-252
e e # ' " ., . ~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) @v~\'rrrrry, ~ ® í ® @~r; ® @ U In.\ J l1: (l J 1nJ ~1nJ ~ L~l0J ) ¡ FRANK H. MURKOWSKI, GOVERNOR AI,ASKA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Willard Tank Seniör Drilling Engineer Marathon Oil Company PO Box 196168 Anchorage AK 99519 Re: Kenai Unit KU 14X-6RD Marathon Oil Company Permit No: 202-252 Surface Location: 422' FSL, 1147' FWL, Sec. 6, T4N, Rl1 W, SM Bottomhole Location: 282' FSL, 1484' FWL, Sec. 6, T4N, Rll W, SM Dear Mr. Tank: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. A workover is initially planned on the existing well KU 14X-6 and was approved via Sundry 302-386. If the workover activities are successful, you have indicated there will be no need to perform the work authorized by this permit. Prior to initiating work authorized by this permit approvals must be received by an Application for Sundry Approvals for the abandonment of the original wellbore section. Your request to run the liner without 7" rams as required by 20 AAC 25.285 (c)(2)(A)(i) is granted. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). \ . Sincerely, ~éT~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this 17~ day of January, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refmeries Section g:\cmn\drlg\sterling\su44-10\KU 14X-6 AOGCC Drilling Permit.xls ) STATE OF ALASKA) '- ~. ALASKA OIL AND GAS CONSERVATION COMMISSIÓN ¡¿rq l \ð PERMIT TO DRILL ' 210 MC 25.005 1a. Type of Work DrillD Re-Entry[K 2. Name of Operator MARA THONOJL COMPANY Re-Drill[K Deepen D 1 b. Type of well. ExploratoryD Stratigraphic TestD Service D Development Gas [K Single Zone [K 5. Datum Elevation (DF or KB) 10. Field and Pool 87' KB feet Kenai Gas Field / Sterling Pool 6 Development Oil D Multiple Zone D 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 422' FSL, 1147' FWL, Sec. 6, T4N, R11W, S.M. At top of Productive Interval 282' FSL, 1484' FWL, Sec. 6, T4N, R11W, S.M. At Total Depth 282' FSL, 1484' FWL, Sec. 6, T4N, R11W, S.M. 12. Distance to Nearest 13. Distance to Nearest Well Property Line(unit boundary) 6900 feet 16. To be Completed for Deviated Wells Kickoff Depth 2700 feet Maximum Hole Angle 17.3 0 18. Casing Program Size Specifications Hole Casing Weight Grade Coupling Length MD Driven 20" 94 K-55 PE 85' 0' 17-1/2" 133/8" 61 K-55 BTC 2566' 0' -;112 1/4" 95/8" 47 N-80 BTC 7282' 0' t 81/2" 7" 26 L-80 BTC 2433' 2500' "-. "1:::.l c;.::" C "I,. "-\ '" \. ~ \ ~(1) "'- ) '\ "- \" kl V\- "'" J 1600 6. Property Designation A-028142 7. Unit or Property Name Kenai Unit 11. Type Bond (see 20 AAC 25.025) Blanket Surety Number 5194234 Amount $200,000 15. Proposed Depth 8. Well Number KU 14X-6RD (also known as KDU-8) 9. Approximate Spud Date 1/13/2003 14. Number of Acres in Property (MD and TVD) feet 6000 4933 MD / 4889 TVD feet 17. Anticipated Pressure (see 20 AAC 25.035 (e) (2» Maximum Surface 1026 psig at Total Depth (TVD) Setting Depth Bottom 4889' Top Quantity of Cement (including stage data) In place, Driven (OKB 95') In place w/ 1675 sks. (OKB 95') In place w/ 1450 sks. (OKB 95') +1- 253 sks. TVD 0' 0' 0' 2500' MD 85' 2566' 7282' 4933' TVD 85' 2566' 7194' 4889' ~ è)..,\ (f'JC) tI Kenai unit well KU 14X-6 will be plugged back according to AOGCC regulations and sidetracked at +1- 2700' MDI 2700' TVD. KU 14X-6 RD will be directionally drilled to a estimated depth of 4933' MD, 4889' TVD from the existing Kenai Gas Field pad 14-6. The production interval will be cased with 7" 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: Drilling Program, Area Maps, Location Map, Structure Map, Directional Maps, Mud pit drawing and Blowout Prevention Equipment drawings. 20. Attachments Filing Fee [8] Property Plat[K BOP Sketch [K Drilling Fluid Program0 Time vs Depth PlotO Refraction Analysis 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge A . A I J~ Phone: 564-6310 Signed W. J. Tank )4ØÃH Title Senior Drilling Engineer Commission Use Only Permit 2:;;2.- 2 5.2- APt~~~;33 ~ 203cj2.~O/pproval Date 1 '() 3 ~Rf{~t¥fO Conditions of Approval Samples Required DYes ~No Mud Log Requ red .=JYes ~No Hydrogen Sulfide Measures DYes [XI No Directional Survey Required ~Yes DNo DEC 20 2002 Required Working Pressure for BOPE D2M D3M D5M D10M D15M Other: SOc.:>(J Dìt ~~'\\l~ \- ~fl:..Q \(l ~(,~,~C"\~( ~rt'v\J\W k~iI&GaSCons.CommiSSlo.n , . Anchorage by order of the Commission Approved by Form 10-401 Rev. 12-1-85 ORIGINAL SIGNI:U tit ML.BI Diverter Sketch [K Seabed ReportO Drilling Program [8] 20 AAC 25.050 Requirements 0 Date: 12/20/2002 Commissioner Date tl/1 J O~ Suí!mit in Triplicate \ ') ) MARATHON MARATHON Oil COMPANY DRilliNG PROGRAM KU 14X-6RD Original 12/20/02 Originator: W.J. Tank Drilling Superintendent: P.K. Berga Drilling Manager: C.W. Truby Page 1 of 1 0 ') } Table of Contents General Well Data............................................................................................................................................. ......................3 Geologic Program Summary .... .......................................................... ....... ..............................................................................3 Summary of Potential Drill ing Hazards....................................................................................................................................4 Formation Evaluation Summary................. .................................................... ............... ..................... ........ ..... ........................4 Drilling Program Summary. ......... ........... ....... .................. ............................ .......................... .............. ............ .........................4 Casing Program....................................................................................................................................................... ................5 Casing Design .........................................................................................................................................................................5 Maximum Anticipated Surface Pressure ............................ ............ .... ....... ........ ..... ............. .................... ....... ....... ..................5 BOP E Program................................................................................................................................................................... .....6 Wellhead Equipment Summary ....... .................................. ............ .... ....................... .......... ..... ........ ......... ...... ...... ..................6 Directional Program Summary.............. ................ ............. ....... ..... ............... ...... ....... ........ .......... ..... ................................. ..... 7 Directional Surveying Summary .. ..... ................. ......... ...... ......... ......... ............ ....... .... ... ....... ..... ...... ........ ... ..... ......... ... ....... ... ...8 Drilling Fluid Program Summary............. ............. ...................... ..... .................................... ....... ......... ................ .....................8 Drill ing Flu id Specifications......................................................................................................................................................8 Sol ids Control Equ ipment ................................................................................................................................................ ........9 Cement Program Summary........................................................................................................................ .............................9 Bit Summary................................... .... ..... .............. ........ ..... .......... ......... .............. ............... .............. .................. ...................10 Hydraulics Summary.......... ......... ...... ..... ................. .... ........ ................ ............. ................... .................. ...... ........ ...................10 Formation Integrity Test Procedure .... ............... ................................. ............. ................... .......... ........................ .................10 Page 2 of 10 General Well Data Well Name Surface Location Slot/Pad KBElev. GroundLevelElev. Perm. Datum Water Depth Water protection .. D~pth Comments: ) KU 14X-6RD 422' FSL, 1,147' FWL, Sec. 6, T4N, R11W 14-6 Field 87 Borough 66 State I Country KB Total MD N/A TotalTVD (casing in place) GeoloQic PrOQram Summary Formation Sterling Pool 3 (A-8) Sterling Pool 4 (B-1) Sterling Pool 5.1 (B-3) Sterling Pool 5.2 (B-5) Sterling Pool 6 (C-1) Primary Target Sterling Pool 6 (C-2) Secondary Target Comments: From Lease/Blò¢k Lines Latitude Longitude UTMNorth (Y) UTMEªst (x) Tolerance Target Sterling Pool 6 (C-1) Well TD Comments: . MD- RKB (ft) 3,559 3,894 3,924 4,187 4,487 4,650 Kenai Gas Field Kenai Peninsula Alaska 4,933' 4,889' TVD ~ RKB (ft) 3,537 3,857 3,886 4,144 4,443 4,606 Sµrface. Location Coordinates 422' FSL, 1,147' FWL, Sec. 6, T4N, R11W 600 27' 38.242" N 1510 15' 46.088" W 2,362,471.5' 272,062.8' Depth MD (ft) 4,487 4,933 TVD (ft) 4,443 4,889 Location UTM 2,362,325' N, 272,397' E UTM 2,362,325' N, 272,397' E Page 3 of 10 Pore Pressure (psi) 206 199 770 1440 300 300 Lease/License WBS Code Spud Date API·No. Well Class Rig Contractor Rig Name Pore. Pressure (ppg) 1.1 1.0 3.8 6.7 1.3 1.3 J RW.03.0801 O.CAP .DRL 1/13/03 50-133-20342 .,. ~ I Á Development Glacier Drilling #1 Lithology Sandstone Sandstone Sandstone Sandstone Sandstone Sandstone Horizontal Displacement (ft) N/S EIW (Y) (X) -140 337 -140 337 Possible Fluid Content Gas 1 Water Gas 1 Water Gas 1 Water Gas 1 Water Gas 1 Water Gas 1 Water Tolerance (ft) Circle 50' radius N/A ) ) Summary of Potential Drilling Hazards Hazard Event Discussion Lost Circulation Control losses by using sufficient sized LCM. Comments: Potential Hazards Statement To comply with state regulations the Potential Hazards section and the well shut-in procedures must be posted in the drillers dog house. The man on the brake (driller or relief driller) is responsible for shutting the well in (BOPE or diverter as applicable) as soon as warning signs of a kick are detected and an influx is suspected or confirmed. A copy of the approved permit to drill must be kept on location and be readily available to the AOGCC or BLM inspector. . This well's primary objective is gas and no oil sands are expected to be encountered. No H2S is anticipated. Gas sands will be encountered from +1- 3559' MD/3537' TVD to total depth of the well. These sands will run from normal pressured to severely depleted and lost circulation and differential sticking are potential hazards. The fresh water gel and FLOPRO mud systems that will be used to drill the well will help reduce these risks and lost circulation materials will be on location. No well interference hazards exist. Formation Evaluation Summary Interval LWD Surf/Inter (existing) None Sidetrack (openhole) None Sidetrack (cased hole) None Electric Logs Mud Logs None Triple combo (PEX), Digital Sonic (DSI) GR / RST None Mud log without sample collection None Coring Requirements: None Comments: Drilling Program Summary 1. If the sidetrack is required, the drilling rig will already be on the well, with the BOP stack installed and tested. Set wear bushing. 2. Abandon existing perforations according to program to be filed with AOGCC. 3. RIH and set CIBP at +1- 2700' md. Test plug and casing to 1500 psi. 4. MU and RIH with bottom trip whipstock. RU and run gyro to set whipstock for 110.98° orientation. Cut window and ensure that all mills are worked thru window. CBU and test shoe to leakoff (- 12.5 ppg anticipated). 5. Drill an 8-1/2" hole to 4,933' MDI 4,889' TVO per the attached directional program. Backream each stand. Lost circulation is possible throughout this interval. Maintain sized CaC03 LCM to prevent losses in the low pressure payzones as per the mud prognosis. Monitor torque and drag to indicate hole cleaning problems. 6. At TO, circulate the hole clean. Short trip to shoe. TIH and circulate the hole clean. POOH, laying down 5" HWDP. Run logs as per geology requirements. Pull wear bushing. 7. Locate casing swage and safety valve. Function safety valve and place on rig floor. Record function test in IADC book. RU and run 7" casing liner. 8. Set liner hanger. Cement casing as per the attached cementing program, while rotating liner. Ensure circulation of cement to above top of liner. 9. Pull out of liner hanger and circulate cement clean. Set liner hanger packer. Pull out of hole with setting tool. 10. Clean out liner. Test casing, liner and liner lap to 1500 psi. 11. Prepare for completion. A separate completion procedure will be developed. Page 4 of 10 ) ) Casin~ Pro~ram Casing Size (in) 13 3/8 95/8 7 Top Surface Surface 2,500 Bottom 2,558 2,700 4,933 Weight (Ibs/ft) 61 47 26 Grade K-55 N-80 L-80 Connection API Ratings Makeup 0> c:: ..... ,,-.. :ft:::- 0 (i) ~ ëi) ctJ (J) ëj) 0- O.D. Torque Hole Size ::J .a =0- c:: ;g, co 0- 0> Type (in) (ft-Ibs) (in) () I- BTC 14.375 17.5 3,090 1,540 962 BTC 10.625 12.25 4,720 3,880 746 BTC 7.656 8.5 7,240 5,410 604 MD (ft) Comments: The make up of the buttress connection will be to the proper mark. Casin~ Desi~n Casing Shoe Safety Factors Setting MudWt Form Maximum Surface 0> c:: Casing Frac. (J) 0- 0 ..... .!2 ïñ Size Weight D~pth When Set Grad Press Pressure ~ Ö c:: ::J 0> (in) (lb/ft) Grade (TVD) (Ib/gal) (Ib/gal) (Ib/gal) (psi) co () I- 13 3/8 61 K-55 2,558 Existing Casing String 95/8 47 N-80 2,700 10.40 13.00 9.35 1,026 2.61 3.26 4.65 7 26 L-80 4,889 9.20 12.50 1.30 1,026 2.80 2.32 2.20 Comments: The 13 3/8" and 9 5/8" strings are existing casings. A casing exit will be made in the 9 5/8" casing below the 13 3/8" surface casing shoe. The 7" liner to be put in place will be new tubulars. Maximum Anticipated Surface Pressure Setting Depth Casing Size TVD MAWP * MASP ** Mud/Gas (in) (ft) (psi) (psi) Ratio 13 3/8 2,558 Not Applicable, 9 5/8" Intermediate is already in place. 95/8 2,700 1,026 1,026 0/100 7 4,889 1,026 1,026 0/100 * MAWP = Maximum anticipated wellhead pressure ** MASP = Maximum anticipated surface pressure Comments: The Maximum Anticipated Surface Pressure (MASP) for the intermediate casing is based on the highest exposed pore pressure less the hydrostatic pressure of gas. The MASP for the production liner is MASP for the 9 5/8" casing. 9 5/8" Intermediate Casing (Pore pressure from Sterling Pool 5.2 - 1440 psi @ 4,441' TVD) MASP = PP - (GG * TVDf) MASP = 1,440 psi - (0.1 * 4,144') MASP = 1 ,026 psi Page 5 of 10 ) ) 7" Production Liner MASP = MASP for 9 5/8" Intermediate = 1,026 psi BOPE ProQram Intermediate 9 5/8 1,026 1,026 1,500 9.2 BOPS Size & Rating (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 135/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets Test Pressure Low/High (pSi) Casing Casing Size (in) MAWP (psi) MASP (psi) Casing Test Test Fluid Press Density (psi) (Ib/gal) 250/3000 Intermediate with Production Liner 7 1,026 1,026 1,500 9.2 (1) 13-5/8" 5M annular (1) 13-5/8" 5M pipe ram (1) 13 5/8" 5M blind ram (1) 13-5/8" 5M drilling spool with 3-118" 5M outlets 250/3000 Comments: Blowout Preventers The blowout preventer stack will consist of a 13-5/8" x 5000 psi annular preventer, a 13-5/8" x 5000 psi double gate ram type preventer with blind rams in the bottom and pipe rams in the top and a 13-5/8" x 5000 psi drilling spool (mud cross) with 3-118" x 5000 psi outlets. The choke manifold will be rated 3-1/8" x 5000 psi. It will include a remote hydraulic actuated choke and a hand adjustable choke. Also included is a poor-boy gas buster, and a vacuum-type degasser. A flow sensor will be installed in the flowline and the mud pits will contain sensors to measure the volume of fluid in the surface mud system. Both sensors will contain readouts convenient to the drillers console. Casing Test Pressures 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. Wellhead Equipment Summary Component Casing Head Casing Spool Tubing Head Description 20",2,000 psi flange top X 20",2,000 psi SOW bottom 135/8", 5,000 psi flange top X 20",2,000 psi flange bottom 11",5,000 psi flange top X 13 5/8", 5,000 psi flange bottom Casing Hanger Type Mandrel Slip Dual Tubing Slips Comments: After the 7" liner has been cemented in place existing tubing head will be replaced with an 11",3,000 psi X 135/8",5,000 psi head. Page 6 of 10 ) ') Directional ProQram Summary Build Turn Coordinates Sec. MD TVD Rate Rate. Dogleg Inclination Azimuth NIS ElW VS No. Description (ft) (ft) (°/100') ¡ (°/100') (°/100') (deg) (deg) (ft) (ft) (ft) Surface 21 21 0 0 0 0 0 2 Kickoff Point 2,700.00 2,699.90 0.00 0.49 116.89 -13.07 7.03 11.49 3 Build Off 2,720.00 2,719.89 12.00 -29.55 12.00 2.89 110.98 -13.29 7.57 Whipstock 12.08 4 Continue Build 3,296.59 3,286.06 2.50 0.00 2.50 17.30 110.98 -49.38 101.69 112.85 5 Hold Angle 3,794.44 3,761.38 0.00 0.00 0.00 17.30 110.98 -102.41 239.93 260.86 6 Drop to Target 4,486.53 4,443.00 -2.50 0.00 2.50 0.00 110.98 -139.54 336.76 364.53 7 Hold to TD 4,932.53 4,889.00 0.00 0.00 0.00 0.00 110.98 -139.54 336.76 364.53 Comments: Potential Well Interference: Vertical section calculated from a reference azimuth of 112.510 taken from surface location to bottom hole location. Well KBU 24-6 KDU 1 KU 14-6 WD2 Depth (MD) 2,700 2,700 2,700 2,700 Distance (ft) 255 234 259 309 No serious interference exists. See attached directional plan and anticollision analysis for more details. -1000 :s ~ o o o ~ !, ¡ " ! !. ' : ! : ! i ! \ i ~:··'·I:':··r:··:f··l:': - . v ! ...... 1000 "...,. - ... .... , ! ! ! ~~~~ ~vvv ! ! ¡ ! ! ! ........ Ll ; ; r- -;;-;;-¡o,¡ ] ! ; , , >- :/8" !............... 3000 ! i l , í \ ,..., , I . -. !. I··· ······1.· · ... ·············f Ii: I ~ ...!\..... l4X-t iRD Sterlinl: Target ..vvv \ ............. T f '1, T . ..'.. : ., , . ;J l , -'- .. , ! . 5000 ' , ¿J ..1..:> --,-- 7" I , . , , , , , , , , , ..g e- O ] '€ <I) > ~ -1000 1000 Vertical Section at 112.51 ° [2000ftlin] l 8 !:!. f t West(-YEast(+) [200tvin] Page 7 of 10 ) ) Directional SurvevinQ Summary Interval 0-2,700 2,700 - 4,933 MWD Survey Magnetic Multishot Gyro Multishot X Comments X Tie into Gyro at 2,700' MD Comments: A gyro orientation will be required for the setting of the whipstock and pointing the motor at KOP. DrillinQ Fluid ProQram Summary Interval - TVD From To (ft) (ft) o 2,700 Density (Ib/gal) 8.4 Fluid Description Drill Water Additives Flo-Vis for sweeps Flo-Vis, DualFlo, KCI, Caustic, Ventrol 401, Lubetex, Asphasol D, SafeCarb F, Conqor 404, Detergent Minimum..lnventory Gel Viscosifier Barite 2,700 4,933 9.0 - 9.2 6% KCL FLOPRO System Comments: See mud prognosis for details. Sized CaC03 (SafeCarb) will be used to controlleakoff into the high perm, low pressure pay zone. Minimizing leakoff is critical to well productivity upon completion. DrillinQ Fluid Specifications Interval,. TVD From To Density Vis PV YP Fluid Loss MBT OillWater (ft) (ft) (I 1)/9a I) (~edqt) (cP) (lb/100 tr) (cc) pH (Ib/bbl) Ratio 0 2,700 8.4 26 1 N/A N/A 7 2,700 4,933 9.0 - 9.2 10 - 14 15 - 20 6-8 9.0 - 9.5 Comments: Page 8 of 10 ) ) Solids Control Equipment c: 0 (]) ~ t5 Q; (]) e> ~ (]) (\] ~ c: (]) CI £' -§ (\] (]) (]) C) I/) I/) I/) "'C ~ .a Q; c: :ê ü C) C) ë5 ~ (\] .1:: c: I:: (\] I/) ïñ "'C ë E E e .c (]) (]) ::J Q) ::J ::J ~ Interval en CI CI ~ 0 (,) 0 Comments o - 4,933 X X X X Item Shaker 2 - Derrick ModeI2E48-90F-3TA Desander N/A Desilter 1 - Derrick Model 0522 Mud Cleaner N/A Centrifuge 2 - Ml/Swaco units Cuttings Dryer N/A Cutting$lnjection Marathon G&I Facility Zero Discharge NI A Equipment SpecificatiOns (quantity, design type,brand,fnodel,fJowbélpacity, etc) Comments: The solids control equipment will consist of two flowline cleaners, a desilter, and the MI centrifuge van. Included will be equipment to de-water the underflow from the mud processing equipment to allow for disposal of the cuttings and solids by slurrification and injection into the disposal well at the KGF. Cement Program Summary Depth Gauge Top of Cement Open Casing Hole Ann Vol Slurry WOC Hole Size MD TVD Size MD TVD To TOC Vol Time Excess (in) (ft) (ft) (in) (ft) (ft) (ft3) (fe) (hrs) (%) 7 2,500 4,933 8.5 2,500 2,500 309 464 N/A 50 Mix Water Compressive Casing Slurry TOC Strength Size Density Qty Yield Vol MD Qty WL FW (psi) (in) Slurry Cement Description (Ib/gal) (sx) (felsx) (fe) (ft) (gal/sx) Type (cc) (%) 12 hr 24 hr Lead 7 Tail Class "G", Gas Tight 13.5 253 1.84 464 2,500 9.27 Fresh 10 0 300 820 Comments: See cement prognosis for details and spacer specifications. Page 9 of 10 ) ) Bit Summary Interval- MD PDC Recommended was (kips) RPM 5 I 25 150 5 110 200 - 300 Estimated Rotating Hours ROP (ftlhr) From (ft) 2,700 2,720 To (ft) 2,720 4,933 SiZè (in) 8.5 8.5 TYPè Window mill Comments: See bit prognosis for details. Hydraulics Summary Rig mud pumps available are shown below. Max Press @ Displacement @ Liner 10 Strc;>ke 90%<WP 95% eft Max Rate Hole Sections Used Qty Make Model (in) (in) (psi) (gal/stroke) (spm/gpm) On National Oil 5 8 2,597 2.04 175/357 All Sections 3 A600PT Well 6 8 1,804 2.94 175/514 All Sections Tabulated below are the expected flow rates, standpipe pressures and nozzle sizes for each hole section. Hole Standpipe Min Nozzle Dèpth-MD Size Pump Rate Pressure AV ECD Size (ft) (in) (gpm) (psi) (fprn) (Ib/gal) (32"s) 4933 8.5 460 1250 190 9.5 3 -18 Remarks Actual Data from KU 24-5RD Sidetrack Comments: Formation Intearity Test Procedure 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 while recording casing and drillpipe pressures at 1/2 bbl intervals. A running plot of pressure versus volume should be 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. Page 10 of 10 ) ') SURFACE USE PLAN FOR KENAI UNIT KU 14X-6RD Surface Location: NW 1/4 of SW 1/4, Sec. 6, T4N, R11W, S.M. 1. Existing Roads Existing roads that will be used for access to Kenai Unit KU 14X-6RD are shown on the attached map. Kenai, Alaska, is the nearest town to the site and is also shown on the map. \ 2. Access Roads to be Constructed or Reconstructed No new roads will be required to access KU 14X-6RD. 3. Location of Existing Wells Well KU 14X~6RD will be re-drilled on pad 14-6. A pad drawing is attached that shows existing wells. 4. Location of Existing and/or Proposed Facilities The location of existing production facilities in the Kenai Unit are shown on the attached pad drawing. 5. Location of Water Supply The location of the water well is shown on the pad drawing. Water will be used to make and maintain the drilling mud. 6. Construction Materials No road or pad modifications or improvements are planned. 7. Method of Handling Waste Disposal a) Mud and Cuttings Cuttings will be dewatered on location. The cuttings and excess mud will be hauled to Pad 41-18 of the Kenai Gas Field for disposal into Well KU 24-7, a Class II disposal well (AOGCC Disposal Injection Order No.9, Permit #81-176). O:\Permanent\MILES\Projects\Kenai\KGF Pad 14- 6\KU 14x-6 WO\KU 14X-6RD Surface Use.doc Surface Use Plan Kenai Unit KU 14X-6RD Page 2 ') ') b) Garbage All household and approved industrial garbage will be hauled to the Kenai Peninsula Borough Soldotna Landfill. c) Completion Fluids Clear fluids will be hauled to Pad 34-31 of the Kenai Gas Field and injected in Well WD #1, an approved disposal well (AOGCC Permit #7-194). d) Chemicals Unused chemicals will be returned to the vendor who provided them. Efforts will be made to minimize the use of all chemicals. e) Sewage Sewage will be hauled to the Kenai sanitation facility. 8. Ancillary Facilities A minimal camp will be established on the pad to house various supervisory and service company personnel. Approximately four trailer house type structures will be required for this purpose. Bottled water will be used for human consumption. Potable water will be obtained from the existing water well on the pad . Town & Country will collect and transport sanitary wastes to their ADC approved disposal facility. No additional structures will be necessary. 9. Plans for Reclamation of the Surface Kenai Unit KU 14X-6RD will be re-drilled from an existing pad. Reclamation of the pad will occur after abandonment of KU 14X-6RD and the other existing wells on the pad. Approval of the plan of reclamation will be obtained from CI RI Native Corporation prior to any reclamation work beginning. 10. Surface Ownership The surface owner of the land in the Kenai Unit is the CIRI Native Corporation. 11. Operator's Representative and Certification Surface Use Plan Kenai Unit KU 14X-6RD Page 3 ) ) I hereby certify that I, or persons under my direct supervision, have inspected the proposed drill site and access route; that I am familiar with the conditions that currently exist; that the statements made in this plan are, to the best of my knowledge, true and correct; and that the work associated with operations proposed herein will be performed by Marathon Oil Company and its contractors and subcontractors in conformity with this plan and the terms and conditions under which it is approved. This statement is subject to the provisions of 18 U.S.C. 1001 for the filing of a false statement. Date: Name & Title: Marathon Oil Company P. O. Box 196168 Anchorage, Alaska 99519-6168 (907) 561-5311 ) ) Marathon Oil Well KU 14X-6RD BOP Stack I Flow Line I I Flow Nipple I - .. 13 5/8" 5M Annular Preventer ~ "> / I I I I > < 13 5/8" 5M Double Ram Preventer I -----. I I Pipe Ram I IBlind Ram I 3 1/8" 5M Hydraulically Operated Valve 2 1/16" 5M Manually Operated Valves > I I ........ < I /1 ,t choke()@[I xl t ~~ IxlIxl)KiII I ~:/ 113 5/8" 5M Cross I ) I '\ ....... I I < I í 3 1/8" 5M Manually Operated Valve ) ) Marathon Oil Well KU 14X-6RD Choke Manifold \ ,I []@[] \ ,I ( ~ ¡' 'I ~=( IL-" ~ ~ 8 JŒJ[JŒJ[ 0 JŒJ[J®l. '\ I ~I I I 13" 5M Valves I i I To Gas Buster I [JŒJ[J I \ I I { I ~I r--ï I I ~ t 2 9/16" 10M Swaco Hydraulically Operated Choke To Blooey Line Bleed off Line to Shakers r-'1 ~ I From BOP Stack 3 1/8" 5M Manually Adjustable Choke Created by Sutherland For: W Tank Date platted : 11-oec -2002 Plat Reference is KUI4X-6Ro VersIon # 1. Coordinates ore In feel reference sial #KoU 6 A. True Vertical Deplhs ore reference wellhead. limiil8 Bt.~~\ES INTEQ 2600 - 2800 - 3000 - ----- 3200 - - Q) Q) 4- '--'" 3400 - ..c - Q.. Q) 3600 - 0 0 3800 - () - L Q) > 4000 - Q) ::¡ L 4200 - l- I V 4400 - 4600 - ) ) ____~M_~.__........."M..."'_"._.MM"._'....._.._..__.."._...,_....._....._M"._....._.RM.....MMM............__.'''._".._____.....__._.._".__........_.__........,......."... MARATHON Oil Company M MARATHON -\ Structure: Pad 14-6 Well: KU14X-6Rd Field: Kenai Gcs Field Locction : Kenai Peninsula. Alaskc East (feet) -> 112.51 AZIMUTH 364.5' TO TARGET 200 500 100 o 100 200 300 400 i\ .¡ ":J \.:! Ò /0 _ cf ~ ~ 0'< (; qO ~ b<. <:)' t'.0 9J ~ cf ~ v ~,,, 0 qO 0' ....."'~ ò .",c>, ). c; t'. <:' 0' <:' l.) v c.,"- '" «) ^' <:) '<1 v·.··.. <- . ,,0 /0 v~ "\ co cf qO f:..,,,c>, c., "- '" - 100 0<:< ~~ ***Plane of Proposol*** (f) o c: :T - 0 8...· - 200 ~ '!<...0 'Ò,O 0'0 o' " <:'~ <r:; \ 9J Q> - 300 - 100 .---... -0, <1> ~ I V TRUE GJ jgL KOP 9 5/8 Intermediate 2.B9 5.00 7.50 10.00 WELL PROFILE DATA ---- ---- MD Norlh East V. Sect De9/100 Dir lVD Palnl ----- Inc DLS: 2.50 deg per 100 ft KDP 0.49 116.69 2699.90 -13.07 7.03 11.49 2.69 110.98 2719.89 -13.29 7.57 12.08 17.30 110.98 3266.06 -49.38 101.69 112.65 17.30 110.98 3761.38 -102.41 239.93 260.86 2700.00 0.00 12.50 15.00 17.30 EOC Continue Build 2720.00 12.00 End of Build 3296.59 2.50 End of Hold 3794.~4 0.00 Sterling Pool 3 (A- B) 0.00 0.00 4443.00 -139.54 336.76 Torget KU14X6Rd - 5119 4466.53 364.53 2.50 4932.53 0.00 4669.00 -139.54 336.76 ._.~~~...___.._.~9E_ T.D. &< End of Hold 0.00 17.30 End of Hold 14.66 Sterling Pool 4 (8-1) 12.16 DLS: 2.50 deg per 100 ft 9.66 7.16 4.66 2.15 0.00 End of Drop Sterling Pool 6 (C-1) Sterling Pool 6 (C-2) 4800 - TD j~ 7 Liner 5000 - ~ 200 0 200 400 600 800 1000 1200 Vertical Section (feet) -> Azimuth 112.51 with reference 0.00 N, 0.00 E from slot #KDU 8 A ) ) MARATHON Oil Company Pad 14-6 KU14X-6Rd slot #KDU 8 A Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License KU14X-6RD Version #1 prop5375 Date printed Date created Last revised ll-Dec-2002 10-Dec-2002 ll-Dec-2002 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on n60 27 33.151,w151 16 7.223 Slot location is n60 27 38.237,w151 15 46.083 Slot Grid coordinates are N 2362471.000, E 272063.000 Slot local coordinates are 516.49 N 1060.10 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ') ) MARATHON Oil Company PROPOSAL LISTING Page 1 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Fie1d,Kenai Peninsula, Alaska Last revised : 11-Dec-2002 Measured Inc1in. Azimuth True Vert R E CTANGULAR Dogleg Vert Depth Degrees Degrees Depth C 0 o R DIN ATE S Deg/100ft Sect 2700.00 0.49 116.89 2699.90 13.07 S 7.03 E 0.00 11.49 KOP 2720.00 2.89 110. 98 2719.89 13.29 S 7.57 E 12.00 12.08 2804.50 5.00 110. 98 2804.18 15.37 S 13.00 E 2.50 17.89 2904.50 7.50 110.98 2903.58 19.26 S 23.16 E 2.50 28.77 3004.50 10.00 110.98 3002.41 24.71 S 37.37 E 2.50 43.98 3104.50 12.50 110.98 3100.48 31.70 S 55.58 E 2.50 63.48 3204.50 15.00 110.98 3197.61 40.21 S 77.77 E 2.50 87.24 3296.56 17.30 110.98 3286.03 49.38 S 101.68 E 2.50 112.84 EOC 3296.59 17.30 110.98 3286.06 49.38 S 101.69 E 2.50 112. 85 3500.00 17.30 110.98 3480.26 71.05 S 158.17 E 0.00 173.32 3559.43 17.30 110.98 3537.00 77.38 S 174.67 E 0.00 190.99 Sterling Pool 3 (A-8) 3794.44 17.30 110.98 3761.38 102.41 S 239.93 E 0.00 260.86 End of Hold 3800.00 17.16 110.98 3766.69 103.00 S 241.47 E 2.50 262.51 3893.95 14.81 110.98 3857.00 112.26 S 265.63 E 2.50 288.37 Sterling Pool 4 (B-1) 3900.00 14.66 110.98 3862.85 112.81 S 267.07 E 2.50 289.91 4000.00 12.16 110.98 3960.11 121.12 S 288.73 E 2.50 313.10 4100.00 9.66 110.98 4058.30 127.90 S 306.40 E 2.50 332.02 4200.00 7.16 110.98 4157.21 133.14 S 320.06 E 2.50 346.65 4300.00 4.66 110.98 4256.67 136.83 S 329.68 E 2.50 356.95 4400.00 2.16 110.98 4356.49 138.96 S 335.24 E 2.50 362.90 4486.52 0.00 90.00 4442.99 139.54 S 336.76 E 2.50 364.53 End of Drop 4486.53 0.00 0.00 4443.00 139.54 S 336.76 E 2.50 364.53 KU14X6Rd - Stlg P6 (C1) - 10 Dee 02 4500.00 0.00 0.00 4456.47 139.54 S 336.76 E 0.00 364.53 4649.53 0.00 0.00 4606.00 139.54 S 336.76 E 0.00 364.53 Sterling Pool 6 (C-2) 4932.53 0.00 0.00 4889.00 139.54 s 336.76 E 0.00 364.53 TD All data is in feet unless otherwise stated. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 364.53 on azimuth 112.51 degrees from wellhead. Total Dogleg for wellpath is 34.12 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) MARATHON Oil Company Pad l4-6,KU14X-6Rd Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref KU14X-6RD Version #1 Last revised : 11-Dec-2002 Comments in wellpath MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 2700.00 2699.90 13.07 S 7.03 E KOP 3296.56 3286.03 49.38 S 101.68 E EOC 3559.43 3537.00 77.38 S 174.67 E Sterling Pool 3 (A-8) 3794.44 3761. 38 102.41 S 239.93 E End of Hold 3893.95 3857.00 112.26 S 265.63 E Sterling Pool 4 (B-1) 4486.52 4442.99 139.54 S 336.76 E End of Drop 4486.53 4443.00 139.54 S 336.76 E KU14X6Rd - Stlg P6(C1) - 10 Dee 02 4649.53 4606.00 139.54 S 336.76 E Sterling Pool 6 (C-2) 4932.53 4889.00 139.54 S 336.76 E TD Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- nla 2699.90 13.07S 7.03E 4932.53 4889.00 139.54S 336.76E 7 Liner nla 2699..90 13.07S 7.03E 2700.00 2699.90 13.07S 7.03E 9 5/8 Intermediate nla 2699.90 13.07S 7.03E nla 2699.90 13.07S 7.03E 13 3/8 Surface Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KU14X6Rd - Stlg P6(C 272397.000,2362325.000,0.0000 4443.00 139.54S 336.76E 10-Dec-2002 ') ) MARATHON Oil Company Pad 14-6 KU14X-6Rd slot #KDU 8 A Kenai Gas Field Kenai Peninsula, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License KU14X-6RD Version #1 prop5375 Date printed Date created Last revised ll-Dec-2002 10-Dec-2002 ll-Dec-2002 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on n60 27 33.151,w151 16 7.223 Slot location is n60 27 38.237,w151 15 46.083 Slot Grid coordinates are N 2362471.000, E 272063.000 Slot local coordinates are 516.49 N 1060.10 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ') MARATHON Oil Company PROPOSAL LISTING Page 1 Pad l4-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 11-Dec-2002 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 2700.00 0.49 116.89 2699.90 503.43N 1067.13E 0.00 11.49 272069.77 2362457.80 2720.00 2.89 110.98 2719.89 503.21N 1067.67E 12.00 12.08 272070.32 2362457.57 2804.50 5.00 110.98 2804.18 50l.13N 1073.10E 2.50 17.89 272075.70 2362455.39 2904.50 7.50 110.98 2903.58 497.23N 1083.26E 2.50 28.77 272085.79 2362451.29 3004.50 10.00 110.98 3002.41 491. 78N 1097.47E 2.50 43.98 272099.88 2362445.57 3104.50 12.50 110.98 3100.48 484.79N 1115.68E 2.50 63.48 272117.96 2362438.24 3204.50 15.00 110.98 3197.61 476.28N 1137.87E 2.50 87.24 272139.98 2362429.30 3296.56 17.30 110.98 3286.03 467.11N 1161.78E 2.50 112.84 272163.70 2362419.67 3296.59 17.30 110.98 3286.06 467.11N 1161.79E 2.50 112.85 272163.71 2362419.67 3500.00 17.30 110.98 3480.26 445.45N 1218.27E 0.00 173.32 272219.77 2362396.92 3559.43 17.30 110.98 3537.00 439.12N 1234.77E 0.00 190.99 272236.14 2362390.28 3794.44 17.30 110.98 3761.38 414.09N 1300.03E 0.00 260.86 272300.91 2362364.00 3800.00 17.16 110.98 3766.69 413.50N 1301. 57E 2.50 262.51 272302.43 2362363.38 3893.95 14.81 110.98 3857.00 404.23N 1325.73E 2.50 288.37 272326.41 2362353.65 3900.00 14.66 110.98 3862.85 403.68N 1327.17E 2.50 289.91 272327.84 2362353.07 4000.00 12.16 110.98 3960.11 395.37N 1348.83E 2.50 313.10 272349.33 2362344.35 4100.00 9.66 110.98 4058.30 388.59N 1366.50E 2.50 332.02 272366.87 2362337.23 4200.00 7.16 110.98 4157.21 383.35N 1380.16E 2.50 346.65 272380.43 2362331.73 4300.00 4.66 110.98 4256.67 379.66N 1389.78E 2.50 356.95 272389.97 2362327.85 4400.00 2.16 110.98 4356.49 377.53N 1395.34E 2.50 362 . 90 272395.49 2362325.61 4486.52 0.00 90.00 4442.99 376.95N 1396.86E 2.50 364.53 272397.00 2362325.00 4486.53 0.00 0.00 4443.00 376.95N 1396.86E 2.50 364.53 272397.00 2362325.00 4500.00 0.00 0.00 4456.47 376.95N 1396.86E 0.00 364.53 272397.00 2362325.00 4649.53 0.00 0.00 4606.00 376.95N 1396.86E 0.00 364.53 272397.00 2362325.00 4932.53 0.00 0.00 4889.00 376.95N 1396.86E 0.00 364.53 272397.00 2362325.00 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from NW Corner of Sec. 7, T4N, R11W, SM and TVD from wellhead (87.00 Ft above mean sea level). Bottom hole distance is 364.53 on azimuth 112.51 degrees from wellhead. Total Dogleg for wellpath is 34.12 degrees. Vertical section is from wellhead on azimuth 112.51 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 14-6,KU14X-6Rd Kenai Gas Field,Kenai Peninsula, Alaska PROPOSAL LISTING Page 2 Your ref KU14X-6RD Version #1 Last revised : 11-Dec-2002 Comments in wellpath Me TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 2700.00 2699.90 503.43N 1067.13E KOP 3296.56 3286.03 467.11N 1161. 78E EOC 3559.43 3537.00 439.12N 1234.77E Sterling Pool 3 (A-8) 3794.44 3761.38 414.09N 1300.03E End of Hold 3893.95 3857.00 404.23N 1325.73E Sterling Pool 4 (B-1 ) 4486.52 4442.99 376.95N 1396.86E End of Drop 4486.53 4443.00 376.95N 1396.86E KU14X6Rd - Stlg P6(C1) - 10 Dee 02 4649.53 4606.00 376.95N 1396.86E Sterling Pool 6 (C-2) 4932.53 4889.00 376.95N 1396.86E TD Casing positions in string 'A' Top Me Top TVD Rectangular Coords. Bot Me Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- nla 2699.90 503.43N 1067.13E 4932.53 4889.00 376.95N 1396.86E 7 Liner nla 2699.90 503.43N 1067.13E 2700.00 2699.90 503.43N 1067.13E 9 5/8 Inte~ediate nla 2699.90 503.43N 1067.13E nla 2699.90 503.43N 1067.13E 13 3/8 Surface Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- KU14X6Rd - Stlg P6(C 272397.000,2362325.000,0.0000 4443.00 376.95N 1396.86E 10-Dec-2002 -) ) .....~,__"..'__R...._····_.__·_·····____..._·..·········~·"..R__".__._.___.......__._.__....__....._..__.._._._..__..''._____....._,,__..,..."".........__..............._._ Created by Sutherland For: W Tank Dote plotted: 11-0ec-2002 Plot Reference is KUI4X-6RO Version # 1. Coordinotes ore in reel reference slol #KOU B A. True Verticol Depths ore reference wellhead. '''ill BAKIR HUGHIS TNTEQ MARATHON Oil Company structure: Pad 14-6 Well: KU14X-6Rd M MARATHON Field: Kenai Gas Field Location: Kenai Peninsula. Alaska East (feet) -> 120 80 40 0 40 80 120 I 2BO - ~ \ 240 - 1400 200 - 160 200 240 280 320 360 400 440 480 ..@ ;<r"--/ ...--,/' '>0. ""./ Vo ./. 6',9. ./Ý./.... 00 ...../ 6'~ ........../;~ 00 ......... 00 ...-.....'.... 6'6'0. ...........-; V .......... 15'00 - 280 - 240 - 200 150 - 6''9'Q 1200 6',x .? .~.~............... ~.. 1100 ........../ 6'-2Q \~ ....·...---é· V ........../....... /00 1000 ...~... 6'00. ....--'~ V ./ \9Q - ."'....15' V Çì.... C?o. 40 _'e/ 0 - 160 120 - - 120 16001 1500 1000 / c9,..., ~ Vo .>t/- / /' '>0/ -80 0/ /~ /" Vo //" /~ /,1l1 / °0 "...././ '9'00 ........./ /~ ."..... °0 // 1 000-e 1 300 /-2Q ./. ':)r::::fJ ._---<>._--~~ 60~?00 Y ...---.---- "J QQ /0. " ,P" _....--..---....--.'~ '-0...... "J1>i. -2'¡7, Vo~__·------~.> 00 ...... 0... 00 _or' ~,-.'~ 00 "':>0", -.'''':>0 ...... _-...---.Ji------;-... 1 800'"-..°0 / v. <2....---- !:J ...... ./ " ó'0o ,.~-"'......-.... "JV:Jr::5 e-'(;............ ~ 1900 .... (Q() 0...... "" <:::.'7.....'8 '\) ,,\QQ ...... ............ '" 2000 0. "J QQ 0........., QQ 9> Vo ,,?q) !:JQ...."~,, boo'); Cè;q) "JC!> QQQ ,,~ ~ 2 1 00 'IÇ::I ~" 22~~, "" 230~-o.." " '" '" 2400" " " 250~~ - ~ - 280 - 40 80 - 120 - oQ. !:J~ 1000~r::::¡QQ rÇi !:J !:J() _..----. ...... ") 1 9 0 _.._....-.-.-_G-'-'-'-'" ~ ""Q., .......... 40 8·....·-·- ~ °0 ...... - 6'~ 6'11: 00 0 ~ 00 00 BO -~ '-" 1000 ...,..,.... 1100 ···'.......1200 ""'Q 1 300 ""-'''- 1400 ""'Q 1500 ""'''- 1600 """ 1700 ""'''- 1800 ""n 1900 ""n 2000 ""'~ 1 00 ',,- 2200 ",'.... 2300 "'''- 2400 ''-..~500 \,,~600 "... 2700 ""'n 2800 ....",'-... 2900 """".,.3000 """" 3100 "'....'n 3200 ,·......'·,"-...3300 .............. .3400 """'" 3500 ,.,.,...... 3600 .~ o - --6- _..-----"'-¡-----.4"-:;;~-- - 0 ---....::f /0 V _--Ji-;;'--'- 0Q v -900 V - 40 tf) o C -+ ::r ......-... - Q) Q) "I- "-'" ..c: - ::J o (/) I V - 80 ......-... -+. ([) ([) -+ "-'" - 120 I V 160 - - 150 200 - - 200 240 - - 240 2BO - 320 - - 320 350 - - 350 400 .. - 400 440 - - 440 120 80 40 o 40 80 120 160 200 240 280 320 360 400 440 480 East (feet) -> ) ) _._..___~_._....'_'__'__"_M_'___'''_·''''_'·'__''_·''··'''····....._..._._..._..,......__....._ Created by Sutherland For: W Tank Dote plotted: 11-00c-2002 Pial Reference is KU 14X-6RD Version # 1. Coordinates ore in feet reference slot #KOU B A. True Vertical Depths ore reference wellhead. "ill BAKER HUGHI5 TNTEQ MARATHON Oil Company I Structure: Pad 14-6 Well: KU14X-6Rd M MARATHON Field: Kenai Gas Field Location: Kenai Peninsula. Alaska TRUE NORTH ~ c:::J 350 0 10 340 20 330 30 240 ~ ~""""a 2 700 310 50 320 40 300 60 2 9 0 ~,_'<> 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 Referenc e Well ) MARATHON Oil Company Pad 14-6 KU14X-6Rd slot #KDU 8 A Kenai Gas Field Kenai Peninsula, Alaska ) 3-D M I N I MUM D I S TAN C E C LEA RAN C ERE P 0 R T by Baker Hughes INTEQ Your ref Our ref License KU14X-6RD Version #1 prop5375 Date printed Date created Last revised 12-Dec-2002 10-Dec-2002 11-Dec-2002 Field is centred on n60 27 33.151,w151 16 7.223 Structure is centred on n60 27 33.151,w151 16 7.223 Slot location is n60 27 38.237,w151 15 46.083 Slot Grid coordinates are N 2362471.000, E 272063.000 Slot local coordinates are 516.49 N 1060.10 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 200 feet Objectwe11path DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Closest approach with 3-D Minimum Distance method KTU 32-7H Version #2"KTU32-7H,Pad 41-7 MND <0 - 11857'>"KTU32-7H,Pad 41-7 MSS <4305 - 5701>"KU43-6,Pad 41-7 MND <4250 - 5740>"KU43-6RD,Pad 41-7 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 PMSS <0-8864>"KTU32-7,Pad 41-7 MSS <0-5300'>,,43-6A,Pad 41-7 MSS <0-10522'>"KDU#2,Pad 41-7 GMS <0-8120'>"KU13-5,Pad 41-7 GMS <0-7902'>"KBU33-6,Pad 41-7 PMSS <8846 - 10960>"KTU24-6H,Pad 41-7 GMS <0-5900'>"KU24-5,Pad 41-7 GMS <0-5350'>"KU11-8,Pad 41-7 PMSS <0 - 7570>"KBU42-7,Pad 41-7 MSS <0-5707'>"KU 43-7,Pad 41-7 GMS <0-5549'>"KDU4,Pad 41-7 MSS <4320 - 10810'>"KDU4Rd,Pad 41-7 MND <3470 - 4816>"KU24-5Rd,Pad 41-7 MWD <0-7440>"KBU 44-6,Pad 41-7 GMS <0-7290>"KBU41-7,Pad 41-7 MND <0-5300>"KBU41-7X,Pad 41-7 PGMS <778 - 5650>"KU21-6X,Pad #? MSS <0 - 5678'> Depth Shifted"KU21-6X,Pad #? Last revised Distance 25-Jan-2002 2863.0 17-May-2002 2859.2 31-Jan-2002 2831.1 30-Jan-2002 2831.1 20-Apr-1999 4879.1 23-Jul-1995 2567.5 16-Aug-1995 2567.5 31-Aug-2000 2708.9 20-Jan-1994 3324.1 21-Jan-1994 3667.6 21-Jan-1994 3224.2 22-Jun-2000 2470.3 1-Aug-2000 2644.3 21-Jan-1994 3687.1 21-Jan-1994 3666.6 9-Feb-2001 3240.3 21-Jan-1994 3493.5 5-May-1995 2293.9 5-May-1995 2330.6 9-Jan-2002 3687.1 3-Mar-2002 3038.2 13-Mar-2002 2817.9 19-Mar-2002 2404.4 11-Jan-2002 4549.3 18-0ct-2001 4433.8 M.D. 4932.5 4932.5 3580.0 3580.0 4932.5 4175.0 4175.0 4337.5 3975.0 2700.0 4012.5 4137.5 4932.5 2700.0 2700.0 2700.0 2700.0 4474.2 4212.5 2700.0 4112.5 4932.5 4932.5 4932.5 4932.5 Diverging from M.D. 4932.5 4932.5 3580.0 3580.0 4932.5 4175.0 4175.0 4337.5 3975.0 2700.0 4012.5 4137.5 4932.5 2700.0 2700.0 3320.0 2700.0 4474.2 4212.5 2700.0 4112.5 4932.5 4932.5 4932.5 4932.5 ') ') MWD <3452 - 5650'>"KU21-6X,Pad #? 18-0ct-2001 4573.3 4932.5 4932.5 PGMS <0-3300'>"WD-1,Pad #? 30-May-1995 5674.9 2715.0 2715.0 MSS <0-4459'>"KU11-6,Pad #? 30-May-1995 4549.4 3520.0 3520.0 Incl. only <0-5809'>"KU34-31,Pad #? 30-May-1995 5693.5 2700.0 2700.0 GMS <0-10502'>"KDU5,Pad #? 30-May-1995 4983.1 4932.5 4932.5 PGMS <0-5700'>"KU14-32,Pad #? 30-May-1995 5812.7 2700.0 2700.0 GMS <0-11095'>"KDU6,Pad #? 30-May-1995 6119.1 2700.0 2700.0 MMS <0-7910'>"KBU33-7,Pad #?? 31-May-1995 4005.8 4932.5 4932.5 GMS <0-5820'>"KU24-7,Pad #?? 31-May-1995 5135.3 4820.0 4820.0 MSS <0-4453'>"KU21-7,Pad 14-6 12-May-1995 335.6 2700.0 3835.2 PMSS <0 - ????>"KBU24-6,Pad 14-6 12-Mar-2001 255.1 2700.0 2700.0 GMS <0-7375'>"KBU31-7,Pad 14-6 14-Sep-1995 563.9 2700.0 2700.0 PMSS <5814 - 7575'>,,31-7Rd,Pad 14-6 28-Sep-1995 563.9 2700.0 2700.0 WD-2 Version #1"WD-2,Pad 14-6 26-Mar-1999 309.2 2700.0 2700.0 GMS <0-6950'>"KBU23X-6,Pad 14-6 12-May-1995 358.7 2700.0 2700.0 MSS <0-5500'>"KU13-6,Pad 14-6 12-May-1995 887.3 2700.0 2700.0 MSS <0-9895'>"KDU-1,Pad 14-6 12-May-1995 233.8 2700.0 4932.5 MSS <0-6530'>"KU43-12,Pad 14-6 12-May-1995 1393.9 2700.0 2700.0 PMSS <O-???'>"KU 31-7,Pad 14-6 10-Jan-2001 793.1 2700.0 2700.0 GMS <0 - 9500>"KU14X-6,Pad 14-6 11-Dec-2002 0.0 2700.0 4932.5 MSS <9776 - 10225>"KU14X-6,Pad 14-6 11-Dec-2002 0.0 2700.0 4932.5 INCLINATION ONLY"KU14-6,Pad 14-6 26-Mar-1999 258.6 2700.0 2700.0 MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 1 11-Dec-2002 0.0 2700.0 4932.5 GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6, 11-Dec-2002 0.0 2700.0 4932.5 ) ) MARATHON Oil Company CLEARANCE LI5TING Page 2 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai peninsula, Alaska Last revised : 11-Dec-2002 Reference wellpath Object wellpath GM5 <0 - 9500>"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2700.0 2699.9 13.15 7.0E 2708.0 2699.9 13.15 7.0E 163.6 0.0 0.0 2705.0 2704.9 13.15 7.1E 2713.0 2704.9 13.15 7.1E 252.2 0.0 0.0 2710.0 2709.9 13.15 7.2E 2718.0 2709.9 13.15 7.1E 282.3 0.1 0.1 2715.0 2714.9 13.25 7.4E 2723.0 2714.9 13.15 7.1E 286.8 0.2 0.2 2720.0 2719.9 13.35 7.6E 2728.0 2719.9 13.25 7.2E 288.2 0.4 0.4 2732.1 2731.9 13.55 8.2E 2740.1 2732.0 13.25 7.3E 289.3 0.9 0.9 2744 .1 2744.0 13.85 8.8E 2752.1 2744.0 13.25 7.4E 289.7 1.5 1.6 2756.2 2756.0 14.05 9.5E 2764.2 2756.1 13.35 7.5E 290.0 2.2 2.2 2768.3 2768.1 14.35 10.3E 2776.2 2768.1 13.35 7.6E 290.1 2.9 2.9 2780.4 2780.1 14.75 11. 2E 2788.3 2780.2 13.45 7.7E 290.3 3.7 3.7 2792.4 2792.2 15.05 12.0E 2800.3 2792.2 13.45 7.7E 290.4 4.6 4.6 2804.5 2804.2 15.45 13.0E 2812.3 2804.2 13.45 7.8E 290.5 5.5 5.5 2817.0 2816.6 15.85 14.0E 2824.8 2816.7 13.55 7.9E 290.5 6.5 6.6 2829.5 2829.1 16.25 15.2E 2837.2 2829.1 13.55 8.0E 290.6 7.6 7.7 2842.0 2841.5 16.65 16.3E 2849.7 2841.6 13.55 8.1E 290.6 8.8 8.8 2854.5 2853.9 17.15 17.6E 2862.1 2854.0 13.65 8.2E 290.7 10.1 10.1 2867.0 2866.4 17.65 18.9E 2874.5 2866.4 13.65 8.2E 290.7 11.4 11.4 2879.5 2878.8 18.15 20.2E 2887.0 2878.9 13.65 8.3E 290.7 12.8 12.8 2892.0 2891.2 IB.75 21.7E 2B99.3 2B91.2 13.75 8.4E 290.7 14.2 14.3 2904.5 2903.6 19.35 23.2E 2911. 8 2903.6 13.75 8.4E 290.7 15.7 15.9 2917.0 2916.0 19.95 24.7E 2924.1 2916.0 13.75 B.5E 290.7 17.3 17.5 2929.5 2928.3 20.55 26.3E 2936.5 2928.4 13.75 B.5E 290.7 19.0 19.2 2942.0 2940.7 21. 15 2B.OE 294B.9 2940.B 13.85 B.6E 290.8 20.8 21.0 2954.5 2953.1 21. 85 29.8E 2961.3 2953.2 13.85 8.6E 290.8 22.6 22.8 2967.0 2965.4 22.55 31.6E 2973.6 2965.5 13.8S B.7E 290.8 24.5 24.8 2979.5 2977 . B 23.25 33.4E 29B6.0 2977.9 13.85 B.7E 290.B 26.4 26.8 2992.0 2990.1 23.95 35.4E 2998.2 2990.1 13.85 8.7E 290.8 28.5 28.9 3004.5 3002.4 24.75 37.4E 3010.6 3002.4 13.95 8.BE 290.8 30.6 31.1 3017.0 3014.7 25.55 39.4E 3022.9 3014.8 13.95 8.8E 290.8 32.8 33.3 3029.5 3027.0 26.35 41. 5E 3035.2 3027.0 13.95 8.8E 290.B 35.0 35.6 3042.0 3039.3 27.25 43.7E 3047.4 3039.3 13.95 8.8E 290.B 37.3 38.0 3054.5 3051.6 28.05 46.0E 3059.7 3051.6 13.95 B.BE 290.B 39.7 40.5 3067.0 3063.B 28.95 48.3E 3072.0 3063.9 13.95 8.8E 290.8 42.2 43.1 3079.5 3076.0 29.B5 50.7E 30B4.2 3076.1 13.95 8.BE 290.8 44.7 45.7 3092.0 30BB.3 30.75 53.1E 3096.4 308B.3 14.05 8.8E 290.B 47.3 48.4 3104.5 3100.5 31.75 55.6E 3108.6 3100.5 14.05 8.8E 290.8 50.0 51.2 311 7 .0 3112.7 32.75 58.1E 3120.B 3112.7 14.05 B.BE 290.B 52.B 54.1 3129.5 3124.9 33.75 60.BE 3133.0 3124.9 14.05 B.BE 290.B 55.6 57.0 3142.0 3137.0 34.75 63.4E 3145.2 3137.1 14.05 B.8E 290.8 58.4 60.1 3154.5 3149.2 35.B5 66.2E 3157.3 3149.2 14.05 B.BE 290.B 61.4 63.2 3167.0 3161. 3 36.B5 69.0E 3169.4 3161. 3 14.05 8.8E 290.B 64.4 66.3 3179.5 3173.4 37.95 71.9E 3181.6 3173.5 14.05 8.BE 290.8 67.4 69.6 3192.0 31B5.5 39.15 74.BE 3193.7 3185.6 14.15 8.BE 290.B 70.6 72.9 3204.5 3197.6 40.25 77.BE 3205.8 3197.6 14.15 8.8E 290.8 73.7 76.3 3216.0 320B.7 41. 35 80.6E 3216.9 3208.B 14.15 8.8E 290.B 76.7 79.5 3227.5 3219.B 42.45 B3.4E 322B.0 3219.9 14.15 B.8E 290.B 79.8 82.B 3239.0 3230.9 43.55 B6.3E 3239.0 3230.9 14.15 B.8E 290.7 B2.9 B6.1 3250.5 3241.9 44.65 B9.3E 3250.3 3242.1 14.25 8.BE 290.7 86.1 B9.5 3262.0 3253.0 45.B5 92.3E 3261. 3 3253.2 14.25 B.8E 290.7 B9.3 93.0 3273.5 3264.0 47.05 95.4E 3272.3 3264.2 14.25 B.9E 290.7 92.5 96.6 3285.1 3275.0 4B.25 98.5E 32B3.4 3275.3 14.25 8.9E 290.7 95.9 100.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU B A and TVD from wellhead (B7.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ) MARATHON Oil Company CLEARANCE LI5TING Page 3 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version U Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Dec-2002 Reference wellpath Object well path GM5 <0 - 9500>"KUl4X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 3296.6 3286.0 49.45 101.7E 3294.4 3286.3 14.25 8.9E 290.7 99.2 103.9 3296.6 3286.1 49.45 101.7E 3294.4 3286.3 14.25 8.9E 290.7 99.2 103.9 3300.0 3289.3 49.75 102.6E 3297.7 3289.5 14.35 8.9E 290.7 100.2 104.9 3400.0 3384.8 60.45 130.4E 3393.3 3385.2 14.55 9.0E 290.7 129.7 135.8 3500.0 3480.3 71. 05 158.2E 3488.9 3480.8 14.85 9.3E 290.7 159.2 166.5 3559.4 3537.0 77.45 174.7E 3545.8 3537.7 15.05 9.4E 290.7 176.6 184.8 3600.0 3575.7 81. 75 185.9E 3584.6 3576.4 15.15 9.5E 290.7 188.6 197.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ) MARATHON Oil Company CLEARANCE LI5TING Page 4 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Dec-2002 Reference wellpath Object well path M55 <9776 - 10225>"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2700.0 2699.9 13.15 7.0E 2708.0 2699.9 13.15 7.0E 163.6 0.0 0.0 2705.0 2704.9 13.15 7.1E 2713.0 2704.9 13.15 7.1E 252.2 0.0 0.0 2710.0 2109.9 13.15 7.2E 2718.0 2709.9 13.15 7.1E 282.3 0.1 0.1 2715.0 2714.9 13.25 7.4E 2723.0 2714.9 13.15 7.1E 286.8 0.2 0.2 2720.0 2719.9 13.35 7.6E 2728.0 2719.9 13.25 7.2E 288.2 0.4 0.4 2732.1 2731.9 13.55 8.2E 2740.1 2732.0 13.25 7.3E 289.3 0.9 0.9 2744 .1 2744.0 13.85 8.8E 2752.1 2744.0 13.25 7.4E 289.7 1.5 1.6 2756.2 2756.0 14.05 9.5E 2764.2 2756.1 13.35 7.5E 290.0 2.2 2.2 2768.3 2768.1 14.38 10.3E 2776.2 2768.1 13.35 7.6E 290.1 2.9 2.9 2780.4 2780.1 14.78 11.2E 2788.3 2780.2 13.45 7.7E 290.3 3.7 3.7 2792.4 2792.2 15.08 12.0E 2800.3 2792.2 13.45 7.7E 290.4 4.6 4.6 2804.5 2804.2 15.48 13.0E 2812.3 2804.2 13.45 7.8E 290.5 5.5 5.5 2817.0 2816.6 15.88 14.0E 2824.8 2816.7 13.55 7.9E 290.5 6.5 6.6 2829.5 2829.1 16.28 15.2E 2837.2 2829.1 13.55 8.0E 290.6 7.6 7.7 2842.0 2841.5 16.65 16.3E 2849.7 2841.6 13.55 8.1E 290.6 8.8 8.8 2854.5 2853.9 17.18 17.6E 2862.1 2854.0 13.65 8.2E 290.7 10.1 10.1 2867.0 2866.4 17.68 18.9E 2874.5 2866.4 13.65 8.2E 290.7 11.4 11.4 2879.5 2878.8 18.18 20.2E 2887.0 2878.9 13.65 8.3E 290.7 12.8 12.8 2892.0 2891.2 18.75 21.7E 2899.3 2891.2 13.75 8.4E 290.7 14.2 14.3 2904.5 2903.6 19.38 23.2E 2911.8 2903.6 13.75 8.4E 290.7 15.7 15.9 2917.0 2916.0 19.98 24.7E 2924.1 2916.0 13.75 8.5E 290.7 17.3 17.5 2929 . 5 2928.3 20.55 26.3E 2936.5 2928.4 13.75 8.5E 290.7 19.0 19.2 2942.0 2940.7 21.15 28.0E 2948.9 2940.8 13.85 8.6E 290.8 20.8 21.0 2954.5 2953.1 21. 85 29.8E 2961.3 2953.2 13.85 8.6E 290.8 22.6 22.8 2967.0 2965.4 22.55 31.6E 2973.6 2965.5 13.85 8.7E 290.8 24.5 24.8 2979.5 2977.8 23.25 33.4E 2986.0 2977.9 13.85 8.7E 290.8 26.4 26.8 2992.0 2990.1 23.95 35.4E 2998.2 2990.1 13.85 8.7E 290.8 28.5 28.9 3004.5 3002.4 24.75 37.4E 3010.6 3002.4 13.95 8.8E 290.8 30.6 31.1 3017.0 3014.7 25.55 39.4E 3022.9 3014.8 13.95 8.8E 290.8 32.8 33.3 3029.5 3027.0 26.35 41. 5E 3035.2 3027.0 13.95 8.8E 290.8 35.0 35.6 3042.0 3039.3 27.25 43.7E 3047.4 3039.3 13.9S 8.8E 290.8 37.3 38.0 3054.5 3051.6 28.05 46.0E 3059.7 3051.6 13.95 8.8E 290.8 39.7 40.5 3067.0 3063.8 28.95 48.3E 3072.0 3063.9 13.95 8.8E 290.8 42.2 43.1 3079.5 3076.0 29.85 50.7E 3084.2 3076.1 13.95 8.8E 290.8 44.7 45.7 3092.0 3088.3 30.75 53.1E 3096.4 3088.3 14.05 8.8E 290.8 47.3 48.4 3104.5 3100.5 31.75 55.6E 3108.6 3100.5 14.0S 8.8E 290.8 50.0 51.2 311 7 . 0 3112.7 32.75 58.1E 3120.8 3112.7 14.0S 8.8E 290.8 52.8 54.1 3129.5 3124.9 33.75 60.8E 3133.0 3124.9 14.0S 8.8E 290.8 55.6 57.0 3142.0 3137.0 34.75 63.4E 3145.2 3137.1 14.05 8.8E 290.8 58.4 60.1 3154.5 3149.2 35.85 66.2E 3157.3 3149.2 14.05 8.8E 290.8 61.4 63.2 3167.0 3161.3 36.85 69.0E 3169.4 3161. 3 14.05 8.8E 290.8 64.4 66.3 3179.5 3173.4 37.95 71.9E 3181.6 3173.5 14.05 8.8E 290.8 67.4 69.6 3192.0 3185.5 39.15 74.8E 3193.7 3185.6 14.15 8.8E 290.8 70.6 72.9 3204.5 3197.6 40.25 77 .8E 3205.8 3197.6 14.15 8.8E 290.8 73.7 76.3 3216.0 3208.7 41. 35 80.6E 3216. 9 3208.8 14.15 8.8E 290.8 76.7 79.5 3227.5 3219.8 42.45 83.4E 3228.0 3219.9 14.15 8.8E 290.8 79.8 82.8 3239.0 3230.9 43.58 86.3E 3239.0 3230.9 14.15 8.8E 290.7 82.9 86.1 3250.5 3241.9 44.65 89.3E 3250.3 3242.1 14.25 8.8E 290.7 86.1 89.5 3262.0 3253.0 45.85 92.3E 3261. 3 3253.2 14.25 8.8E 290.7 89.3 93.0 3273.5 3264.0 47.05 95.4E 3272.3 3264.2 14.25 8.9E 290.7 92.5 96.6 3285.1 3275.0 48.25 98.5E 3283.4 3275.3 14.25 8.9E 290.7 95.9 100.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ) MARATHON Oil Company CLEARANCE LISTING Page 5 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Dec-2002 Reference wellpath Object wellpath MSS <9776 - 10225>"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 3296.6 3286.0 49.4S 101.7E 3294.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3296.6 3286.1 49.4S 101.7E 3294.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3300.0 3289.3 49.7S 102.6E 3297.7 3289.5 14.3S 8.9E 290.7 100.2 104.9 3400.0 3384.8 60.4S 130.4E 3393.3 3385.2 14.55 9.0E 290.7 129.7 135.8 3500.0 3480.3 71.0S 158.2E 3488.9 3480.8 14.8S 9.3E 290.7 159.2 166.5 3559.4 3537.0 77.4S 174.7E 3545.8 3537.7 15.0S 9.4E 290.7 176.6 184.8 3600.0 3575.7 81. 75 185.9E 3584.6 3576.4 15.15 9.5E 290.7 188.6 197.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ") MARATHON Oil Company CLEARANCE LISTING Page 6 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 11-Dec-2002 Reference wellpath Object well path MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2700.0 2699.9 13.1S 7.0E 2700.0 2699.9 13.1S 7.0E 270.0 0.0 0.0 2705.0 2704.9 13.1S 7.1E 2705.0 2704.9 13.15 7.1E 290.0 0.0 0.0 2710.0 2709.9 13.1S 7.2E 2710.0 2709.9 13.1S 7.1E 290.0 0.1 0.1 2715.0 2714.9 13.25 7.4E 2715.0 2714.9 13.15 7.1E 290.0 0.2 0.2 2720.0 2719.9 13.3S 7.6E 2720.0 2719.9 13.15 7.2E 290.0 0.4 0.4 2732.1 2731.9 13.55 8.2E 2732.1 2732.0 13.25 7.3E 290.1 1.0 1.0 2744.1 2744.0 13.85 8.8E 2744 .1 2744.0 13.25 7.4E 290.2 1.6 1.6 2756.2 2756.0 14.05 9.5E 2756.2 2756.1 13.3S 7.5E 290.3 2.2 2.2 2768.3 2768.1 14.35 10.3E 2768.2 2768.1 13.35 7.6E 290.4 3.0 3.0 2780.4 2780.1 14.75 11.2E 2780.3 2780.2 13.35 7.6E 290.5 3.7 3.8 2792.4 2792.2 15.05 12.0E 2792.3 2792.2 13.45 7.7E 290.6 4.6 4.6 2804.5 2804.2 15.4S 13.0E 2804.3 2804.2 13.45 7.8E 290.6 5.5 5.5 2817.0 2816.6 15.85 14.0E 2816.8 2816.7 13.55 7.9E 290.7 6.5 6.6 2829.5 2829.1 16.25 15.2E 2829.2 2829.1 13.55 8.0E 290.7 7.6 7.7 2842.0 2841. 5 16.65 16.3E 2841.7 2841.6 13.55 8.1E 290.7 8.8 8.9 2854.5 2853.9 17.15 17.6E 2854.1 2854.0 13.65 8.2E 290.7 10.1 10.1 2867.0 2866.4 17.65 18.9E 2866.5 2866.4 13.65 8.2E 290.8 11.4 11.4 2879.5 2878.8 18.15 20.2E 2879.0 2878.9 13.65 8.3E 290.8 12.8 12.8 2892.0 ·2891. 2 18.75 21.7E 2891. 3 2891.2 13.65 8.4E 290.8 14.2 14.3 2904.5 2903.6 19.35 23.2E 2903.8 2903.6 13.7S 8.4E 290.8 15.8 15.9 2917.0 2916.0 19.95 24.7E 2916.1 2916.0 13.75 8.5E 290.8 17.4 17.5 2929.5 2928.3 20.55 26.3E 2928.5 2928.4 13.75 8.5E 290.8 19.0 19.2 2942.0 2940.7 21.15 28.0E 2940.9 2940.8 13.85 8.6E 290.8 20.8 21.0 2954.5 2953.1 21.85 29.8E 2953.3 2953.2 13.85 8.6E 290.8 22.6 22.9 2967.0 2965.4 22.55 31.6E 2965.6 2965.5 13.85 8.7E 290.8 24.5 24.8 2979.5 2977.8 23.25 33.4E 2978.0 2977.9 13.8S 8.7E 290.8 26.5 26.8 2992.0 2990.1 23.9S 35.4E 2990.2 2990.1 13.85 8.7E 290.8 28.5 28.9 3004.5 3002.4 24.75 37.4E 3002.6 3002.4 13.8S 8.8E 290.8 30.6 31.1 3017.0 3014.7 25.55 39.4E 3014 . 9 3014.8 13.95 8.8E 290.8 32.8 33.3 3029.5 3027.0 26.35 41. 5E 3027.2 3027.0 13.95 8.8E 290.8 35.0 35.6 3042.0 3039.3 27.25 43.7E 3039.4 3039.3 13.95 8.8E 290.8 37.4 38.0 3054.5 3051.6 28.05 46.0E 3051.7 3051.6 13.95 8.8E 290.8 39.7 40.5 3067.0 3063.8 28.95 48.3E 3064.0 3063.9 13.95 8.8E 290.8 42.2 43.1 3079.5 3076.0 29.85 50.7E 3076.2 3076.1 13.95 8.8E 290.8 44.7 45.7 3092.0 3088.3 30.75 53.1E 3088.4 3088.3 13.95 8.8E 290.8 47.3 48.4 3104.5 3100.5 31. 75 55.6E 3100.6 3100.5 13.95 8.8E 290.8 50.0 51.2 311 7 . 0 3112.7 32.75 58.1E 3112.8 3112.7 14.05 8.8E 290.8 52.8 54.1 3129.5 3124.9 33.75 60.8E 3125.0 3124.9 14.05 8.8E 290.8 55.6 57.1 3142 . 0 3137.0 34.7S 63.4E 3137.2 3137.1 14.0S 8.8E 290.8 58.4 60.1 3154.5 3149.2 35.85 66.2E 3149.3 3149.2 14.05 8.8E 290.8 61.4 63.2 3167.0 3161.3 36.85 69.0E 3161. 4 3161.3 14.05 8.8E 290.8 64.4 66.4 3179.5 3173.4 37.95 71.9E 3173.6 3173.5 14.05 8.8E 290.8 67.4 69.6 3192.0 3185.5 39.15 74.8E 3185.7 3185.6 14.05 8.8E 290.8 70.6 72.9 3204.5 3197.6 40.25 n.8E 3197.8 3197.6 14.15 8.8E 290.8 73.8 76.3 3216.0 3208.7 41. 35 80.6E 3208.9 3208.8 14:15 8.8E 290.8 76.8 79.5 3227.5 3219.8 42.45 83.4E 3220.0 3219.9 14.15 8.8E 290.8 79.8 82.8 3239.0 3230.9 43.55 86.3E 3231.0 3230.9 14.15 8.8E 290.8 82.9 86.2 3250.5 3241.9 44.65 89.3E 3242.3 3242.1 14.15 8.8E 290.8 86.1 89.6 3262.0 3253.0 45.8S 92.3E 3253.3 3253.2 14.25 8.8E 290.8 89.3 93.0 3273.5 3264.0 47.0S 95.4E 3264.3 3264.2 14.25 8.8E 290.7 92.5 96.6 3285.1 3275.0 48.25 98.5E 3275.4 3275.3 14.2S 8.9E 290.7 95.9 100.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level) . Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) MARATHON Oil Company CLEARANCE LISTING Page 7 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : ll-Dec-2002 Reference wellpath Object wellpath MSS <9768 - 10217> DepthShifted"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 3296.6 3286.0 49.4S 101.7E 3286.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3296.6 3286.1 49.4S 101.7E 3286.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3300.0 3289.3 49.7S 102.6E 3289.7 3289.5 14.2S 8.9E 290.7 100.3 104.9 3400.0 3384.8 60.4S 130.4E 3385.3 3385.2 14.5S 9.0E 290.7 129.7 135.8 3500.0 3480.3 71. OS 158.2E 3480.9 3480.8 14.8S 9.3E 290.7 159.2 166.5 3559.4 3537.0 77.4S 174.7E 3537.8 3537.7 15.0S 9.4E 290.7 176.7 184.8 3600.0 3575.7 81. 7S 185.9E 3576.6 3576.4 15.1S 9.5E 290.7 188.6 197.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ') ) MARATHON Oil Company CLEARANCE LISTING Page 8 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai peninsula, Alaska Last revised : 11-Dec-2002 Reference wellpath Object wellpath GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 2700.0 2699.9 13.1S 7.0E 2700.0 2699.9 13.1S 7.0E 270.0 0.0 0.0 2705.0 2704.9 13.15 7.1E 2705.0 2704.9 13.1S 7.1E 290.0 0.0 0.0 2710.0 2709.9 13.15 7.2E 2710.0 2709.9 13.15 7.1E 290.0 0.1 0.1 2715.0 2714. 9 13.25 7.4E 2715.0 2714.9 13.15 7.1E 290.0 0.2 0.2 2720.0 2719.9 13.35 7.6E 2720.0 2719.9 13.15 7.2E 290.0 0.4 0.4 2732.1 2731.9 13.55 8.2E 2732.1 2732.0 13.28 7.3E 290.1 1.0 1.0 2744 .1 2744.0 13.88 8.8E 2744.1 2744.0 13.28 7.4E 290.2 1.6 1.6 2756.2 2756.0 14.05 9.5E 2756.2 2756.1 13.38 7.5E 290.3 2.2 2.2 2768.3 2768.1 14.35 10.3E 2768.2 2768.1 13.38 7.6E 290.4 3.0 3.0 2780.4 2780.1 14.75 11.2E 2780.3 2780.2 13.38 7.6E 290.5 3.7 3.8 2792.4 2792.2 15.08 12.0E 2792.3 2792.2 13.48 7.7E 290.6 4.6 4.6 2804.5 2804.2 15.48 13.0E 2804.3 2804.2 13.45 7.8E 290.6 5.5 5.5 2817.0 2816.6 15.85 14.0E 2816.8 2816.7 13.55 7.9E 290.7 6.5 6.6 2829.5 2829.1 16.25 15.2E 2829.2 2829.1 13.55 8.0E 290.7 7.6 7.7 2842.0 2841.5 16.68 16.3E 2841.7 2841.6 13.55 8.1E 290.7 8.8 8.9 2854.5 2853.9 17.15 17.6E 2854.1 2854.0 13.65 8.2E 290.7 10.1 10.1 2867.0 2866.4 17.65 18.9E 2866.5 2866.4 13.68 8.2E 290.8 11.4 11.4 2879.5 2878.8 18.18 20.2E 2879.0 2878.9 13.68 8.3E 290.8 12.8 12.8 2892.0 2891. 2 18.75 21.7E 2891. 3 2891.2 13.68 8.4E 290.8 14.2 14.3 2904.5 2903.6 19.35 23.2E 2903.8 2903.6 13.78 8.4E 290.8 15.8 15.9 2917.0 2916.0 19.98 24.7E 2916.1 2916.0 13.78 8.5E 290.8 17.4 17.5 2929. 5 2928.3 20.58 26.3E 2928.5 2928.4 13.78 8.5E 290.8 19.0 19.2 2942.0 2940.7 21.15 28.0E 2940.9 2940.8 13.88 8.6E 290.8 20.8 21.0 2954.5 2953.1 21.85 29.8E 2953.3 2953.2 13.88 8.6E 290.8 22.6 22.9 2967.0 2965.4 22.55 31.6E 2965.6 2965.5 13.85 8.7E 290.8 24.5 24.8 2979.5 2977 .8 23.25 33.4E 2978.0 2977 . 9 13.85 8.7E 290.8 26.5 26.8 2992.0 2990.1 23.98 35.4E 2990.2 2990.1 13.85 8.7E 290.8 28.5 28.9 3004.5 3002.4 24.75 37.4E 3002.6 3002.4 13.85 8.8E 290.8 30.6 31.1 3017.0 3014.7 25.58 39.4E 3014.9 3014.8 13.98 8.8E 290.8 32.8 33.3 3029.5 3027.0 26.35 41.5E 3027.2 3027.0 13.98 8.8E 290.8 35.0 35.6 3042.0 3039.3 27.28 43.7E 3039.4 3039.3 13.98 8.8E 290.8 37.4 38.0 3054.5 3051.6 28.05 46.0E 3051.7 3051.6 13.95 8.8E 290.8 39.7 40.5 3067.0 3063.8 28.98 48.3E 3064.0 3063.9 13.9S 8.8E 290.8 42.2 43.1 3079.5 3076.0 29.85 50.7E 3076.2 3076.1 13.95 8.8E 290.8 44.7 45.7 3092.0 3088.3 30.78 53.1E 3088.4 3088.3 13.9S 8.8E 290.8 47.3 48.4 3104.5 3100.5 31.75 55.6E 3100.6 3100.5 13.95 8.8E 290.8 50.0 51.2 311 7 . 0 3112 . 7 32.75 58.1E 3112.8 3112.7 14.05 8.8E 290.8 52.8 54.1 3129.5 3124.9 33.75 60.8E 3125.0 3124.9 14.05 8.8E 290.8 55.6 57.1 3142.0 3137.0 34.78 63.4E 3137.2 3137.1 14.0S 8.8E 290.8 58.4 60.1 3154.5 3149.2 35.88 66.2E 3149.3 3149.2 14.05 8.8E 290.8 61.4 63.2 3167.0 3161. 3 36.85 69.0E 3161.4 3161. 3 14.05 8.8E 290.8 64.4 66.4 3179.5 3173.4 37.98 71.9E 3173.6 3173.5 14.08 8.8E 290.8 67.4 69.6 3192.0 3185.5 39.1S 74.8E 3185.7 3185.6 14.08 8.8E 290.8 70.6 72.9 3204.5 3197.6 40.28 77.8E 3197.8 3197.6 14.1S 8.8E 290.8 73.8 76.3 3216.0 3208.7 41.35 80.6E 3208.9 3208.8 14.15 8.8E 290.8 76.8 79.5 3227.5 3219.8 42.48 83.4E 3220.0 3219.9 14.15 8.8E 290.8 79.8 82.8 3239.0 3230.9 43.55 86.3E 3231.0 3230.9 14.15 8.8E 290.8 82.9 86.2 3250.5 3241.9 44.65 89.3E 3242.3 3242.1 14.1S 8.8E 290.8 86.1 89.6 3262.0 3253.0 45.85 92.3E 3253.3 3253.2 14.25 8.8E 290.8 89.3 93.0 3273.5 3264.0 47.0S 95.4E 3264.3 3264.2 14.25 8.8E 290.7 92.5 96.6 3285.1 3275.0 48.25 98.5E 3275.4 3275.3 14.25 8.9E 290.7 95.9 100.2 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) MARATHON Oil Company CLEARANCE LISTING Page 9 Pad 14-6,KU14X-6Rd Your ref KU14X-6RD Version #1 Kenai Gas Field,Kenai Peninsula, Alaska Last revised : 11-Dec-2002 Reference we1lpath Object wellpath GMS <0 - 9492> DepthShifted 12/10/02"KU14X-6,Pad 14-6 Horiz Min'm TCyl M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 3296.6 3286.0 49.4S 101.7E 3286.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3296.6 3286.1 49.4S 101. 7E 3286.4 3286.3 14.2S 8.9E 290.7 99.2 103.9 3300.0 3289.3 49.7S 102.6E 3289.7 3289.5 14.2S 8.9E 290.7 100.3 104.9 3400.0 3384.8 60.4S 130.4E 3385.3 3385.2 14.5S 9.0E 290.7 129.7 135.8 3500.0 3480.3 71. OS 158.2E 3480.9 3480.8 14.8S 9.3E 290.7 159.2 166.5 3559.4 3537.0 77.4S 174.7E 3537.8 3537.7 15.0S 9.4E 290.7 176.7 184.8 3600.0 3575.7 81.7S 185.9E 3576.6 3576.4 15.1S 9.5E 290.7 188.6 197.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #KDU 8 A and TVD from wellhead (87.00 Ft above mean sea level). Total Dogleg for wellpath is 0.00 degrees. Vertical section is from wellhead on azimuth 112.51 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) Drilling Fluids Program MARATHON OIL COMPANY Well KU 14X-6RD Kenai, Alaska Prepared by: Tony Tykalsky Reviewed by: Lee Dewees Presented to: Will Tank December 12th, 2002 M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax .-r"H.... .. DRILUNG , ..~ FLUIDS ) ') DRILiLING fLU:IDS 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 A TTN: Will Tank Will; Enclosed is the recommended drilling fluid program for Well KU 14x-6rd to be drilled next year. The following is a brief synopsis of the program. Overview: KU14X-6 RD is a potential redrill if workover operations are not successful. The plan is to sidetrack out of the 9-5/8" casing at +/- 2700' MD. A 8-1/2" hole woud be directionally drilled to a depth of +/- 4933' MD. The main concern is formation losses while drilling through the depleted Sterling sand. The recommendation is to design the bridging material for the largest expected permeability of the Sterling-1200 millidarcy. Abandonment: If workover operations are not successful, a whipstock will be set in the 9-5/8" casitn at +/- 2700'. Workover including milling the 9-5/8" casing, cleanout, and setting of the whipstock should be accomplished using drillwater. High viscosity sweeps may be required to clean the wellbore of debris. This can be done by mixing adding 2-3 PPB Flovis to the drillwater. Sidetrack Interval: This sidetrack will be drilled with the standard FloPro fluid with 6% KCl. Safe- Carb (20 ppb), will be added to provide wallcake and help bridgeoff the porous formations. Aggres- sive use of solids control equipment may be needed in order to run the lightest weight fluid as possible. The fluid should be conditioned prior to running and cementing 7" casing. Completion: Completion fluid for this well is planned to be 6% KCI brine. Tony Tykalsky Project Engineer M-I Drilling Fluids ) ) Project Summary Well KU 14X-6 RD Casing Hole Casing Depth TVD Mud Mud Sum Interval r Size Size Program System Weight Days Mud Cost ~ Existing Drill Water 9-5/8" 2700' 2699' High Viscosity 804 4 $4,500 'II Sweeps -. l 7" 4933' 4889' Flo-Pro w/SafeCarb 9.0 - 9.2 14 $46,225 I Bridging. Material 7 Completion 6% KCLBrine 4 $6,825 4933' 4889' 8.65 · Costs include 6 % KCL brine for completion. · Costs assume no significant losses to the formation. · Costs do not include the use of lubricant. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~... . DRilliNG r ,WA FLUIDS ') ) Product Usage Summary Well KU 14X-6 RD Abandonment Sidetrack Completion Total MI Bar 0 120 0 120 Caustic Soda 0 17 0 17 Bicarb 0 10 0 10 Soda ASH 0 4 0 4 Greencide 26G 0 6 0 6 Conqor404 0 2 0 2 Desco CF 0 0 0 0 Polypac UL 0 0 0 0 Flovis 10 80 5 95 DualFlo 0 52 0 52 KCI 0 367 224 591 Lubetex 0 0 0 0 Safecarb Fine 0 70 0 70 SafeCarb Medium 0 280 0 280 Safekleen 0 0 1 Asphasol D 0 0 0 0 Ventrol 401 0 0 0 0 Engineering 4 14 4 22 . Product usage include using 60/0 KCI completion fluid. . Product usage does not include losses to the formation. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ DRilliNG FLUIDS ") ) HSE Issues Well KU 14X-6 RD HANDLING OF DRilliNG FLUID PRODUCTS HEAL TH AND SAFETY 1. Drilling crews should be instructed in the proper procedures for handling fluid products. 2. Personal Protective Equipment (PPE) charts should be posted in the pit room, the mud lab, and the office of the Drilling Forman. 3. PPE must be in good working order and be utilized as recommended by the PPE charts. 4. Product additions should be made with the intent to use complete unit amounts of products (sacks, drums, cans) as much as possible in order to minimize inventory of partial units. 5. Insure all MSDS sheets are up to date and readily available for workers to access for information. ENVIRONMENTAL 1. Insure that all product stored outside is protected from the weather. 2. Do not store partial units (sacks, etc) outside if possible. 3. Properly secure all products for shipment between job sites. 4. When transferring fluid and or cuttings from the rig to trucks, insure all hoses are properly secured. 5. When utilizing the centerfuge solids van, insure all hoses and connections between the van and the rig are secure. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~. 'DRilliNG r j'~i/=. FLUIDS Product Function PPE M-I BAR Weighting Agent E M-I GEL Viscosity control E GELEX Bentonite Extender E FlOVIS Viscosifier E DUAL-FLO Modified Starch E POLYPAC Fluid Loss Reducer E XCD Viscosifier E HEC Loss Circulation Mate- E Safe-Carb F,M,C Bridging and weighting E lOWATE Weighting agent E Nut Plug E M-I Seal F, M, C E Mix II F,M,C E DESCO CF Dispersant E SPERSENE CF Dispersant E TANNATHIN Dispersant E VENTROl 401 Surfactant ? SAl T (Solar) Densifier E BROMIDE (NaBr) & Densifier F Brine Solution POTASSIUM Shale Inhibitor E CHLORIDE - M-I Drilling Fluids L.L.c. 721 West First A venue r=J DRILUNG Anchorage, Alaska 99501 , . FLUIDS (907) 274-5564 (907) 279-6729 Fax '} ') Product Health and Safety Reference HMIS HAZARD RATINGS Well KU 14X-6 RD Product Function PPE CAUSTIC SODA Alkalinity control X CAUSTIC POTASH pH Modifier X BORAX E SAPP E SODA ASH E SODIUM Alkalinity control E BICARBONATE CITRIC ACID pH Adjuster E MYACIDE - AS Biocide J GREEN CIDE 25G - Biocide J DEFOAM X - Defoamer J BUBBLE BUSTER Defoamer J KLA-GARD Shale Control agent J LUBE TEX Lubricant J D-D CWT Detergent J Concor 404 Corrosion Inhibitor J SAFEKLEEN Drilling fluid additive J AsphasolD Shale Inhibitor J Soltex Shale Inhibitor J ) Product Health and Safety Reference HMIS HAZARD RATINGS M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ') Well KU 14X-6 RD ....,-.. . DRILLING , ~ FLUIDS ) ) Product Health and Safety Reference HMIS HAZARD RATINGS Well KU 14X-6 RD HAZARDOUS MATERIALS IDENTIFICATION SYSTEM (HMIS) HAZARD RATINGS 4 - Severe hazard 3 - Serious hazard 2 - Moderate hazard 1 - Slight hazard o - Minimal hazard * An asterisk next to the health rating indicates that a chronic hazard is associated with the mate- rial. HMIS PERSONAL PROTECTIVE EQUIPMENT INDEX A - Safety Glasses B - Safety Glasses, Gloves C - Safety Glasses, Gloves, Synthetic Apron D - Face Shield, Gloves, Synthetic Apron E - Safety Glasses, Gloves, Dust Respirator F - Safety Glasses, Gloves, Synthetic Apron, Dust Respirator G - Safety Glasses, Gloves, Vapor Respirator H - Splash Goggles, Gloves, Synthetic Apron, Vapor Respirator I - Safety Glasses, Gloves, Dust and Vapor Respirator J - Splash Goggles, Gloves, Synthetic Apron, Dust and Vapor Respirator K - Air Line Hood or Mask, Gloves, Full Suit, Boots X - Consult your supervisor for special handling directions M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ..",-.. . DRllllNIj r ~ FLUIDS ) ) " Plans & Procedures Well KU 14X-6 RD => COMMUNICATION - The Field Mud Engineer will communicate daily. with the In- Town Project Engineer. The Project Engineer will then communicate dally with the rig Drilling Engineer. Communications should be about, but not limited to, fluid proper- ties, nole aifficulties, possible changes to the mud program, and proposals to use products not included In the mud program. => Whole Mud Losses to the Sterling Sands - Refer to fluid formulas for maintaining proper bridging material concentration in the mud system while drilling production in- terval. => FLUID LOSS CONTROL - In the production interval the API fluid will be maintained at less than 8 cc's at all times. In aädition to sufficient fluid loss agent additions, this may require adequate dilution of the mud system in order to keep reactive drill solids to a minimum. It is Qarticularly imRortant to maintain a low hardness «200 ppm Ca) for effective use of DualFlo, therefore cement contamination should be completely treated as rapidly as possible prior to adding DualFlo to control or reduce fluid loss. NOTE: If adäitions of DualFlo do not appear to be lowering the fluid loss adequately, then switch to additions of Polypac Supreme SL after consultation with town. => LSRV - When drilling with a FloPro fluid, the low shear rate rheology_should be main- tained around 35tOOO cps. In addition to adequate additions of FloVis Plus, this will also require keeping reactive drill solids to a minimum in order to reduce or eliminate false and unwanted-high LSRV. => DRILL SOLIDS - MBT - The MBT should be kept at less than 5 ppb in the production interval through aggressive use of solids equipment and dilution as needed. => MIXING CONDITIONS - Whenever possible all treatments to the mud system should be made as pre-mix additions. Polymers and KCI should first be mixed in fresh water in that order and then blended into the active system over one or two circulations as needed. => CORROSION - Conqor 404 additions should be made dailY when drilling with FloPro fluid in order to maintain a Conqor 404 concentration of +/- 2000 PPM. => GREENCIDE 25G ADDITIONS - Greencide 25G additions should be made daily when drilling with FloPro fluid, in the range of 5 gallons per day. => SLOUGHING COALS - Ventrol 401 and Asphasol D (Soltex) should be added at a 2 ppb concentration (of each product) if running coals become a problem. => SOLIDS VAN USAGE - The Solids Van should be used whenever drill solids become un-acceptably high and reduction of drill solids in the mud can be more economically done with centrifuging and dilution then just with dumping and diluting. The weight of the drilling fluid alone should not be the determining condítion for when to use the Sol- ids Van. => WEIGHTING UP - All increases in mud weight should be accomplished with barite ad- ditions. In the intermediate and production Intervals, insure chloride concentration is maintained at 30,000 to minimize the need for barite additions. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~... . DRILLING , .~ FLUIDS ) ) Abandonment Well KU 14X-6 RD :}O':: ···.2~tOtl::~ .. :-.-:","¡ V", Drilling Fluid System Drill water Key Products Flovis (for sweeps) Solids Control Shale Shakers / Desilter PotentialProblems Hole cleaning, junk, etc. . .._.m.. L__'._III,m"..""'''__'II_' .",'j' . -. . If'-- '-'<""':. ' . '. ',. . >.". :':~: . . ····:·:···.··.,~9¥~r'tª'}'J>'r,j'J\¥~,i:'~~~i(J....··p~#p~.t:!i,~s.:. '" ·~.:\::;.(I·' . . "v.~." ,~:.<>~:::.:.:::~. ';:. ,.,'"..,', . ,....... , :.:;~:;. -: . .. '.: .' , . .,' , ',~.' ,:", >: :-':~~¡-:'" .;.:-: . . Ðepth Mud .Plastic .Funnel A·Pl Interval Weight Viscosity Viscosity Fluid Loss (ft) (ppg) (cp.) (sec/qt) (ml/30min) 0-2700' 8.4 1 26 N/A 7.0 . Fill wellbore and one surface pit with drill water. . If viscosity is needed to aid in hole cleaning, mix a 25 - 30 barrel high viscosity pill using 2.5 PPB Flovis in drill water. M-I Drilling Fluids L.L.c. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax r=J. .. DRILLING FLUIDS '-.1 JI ) ) Interval Summary - 8-1/2" Well KU 14X-6 RD '217ÖÔ·:···.··.··.·..~þ33·:' .:.... Drilling Fluid System 6% KCI FloPro System Estimated Permeability 500-1200 millidarcies Key Products Flo- Vis, DualFlo, KCI, Caustic Soda, Ventrol 401, Lubetex, Asphasol D, SafeCarb F , Conqor 404, Drilling Detergent Solids Control Shale Shakers / Desilter / Centrifuge Potential Problems Coal sloughing, drill solids buildup, seepage losses -."'flk ,-- ._....._---_.~.- . .. "'. :"," .'." ", "... . "." ,", . ..... . ..... .... . .'.";".. ..... .., .. ........ '.,.. . ·I·>··f·:···· :·f,]::)··:· ·ll···..·:···,.:·:~FI:<···(fpc:·····:····t:·'.. .,..:... .....~:"~~~~: ...:: ...11! ...Jp.~...... .... ·;,J1.';,Vi..º.P..~....:....:....:.·.e.....:.... ..:r..~................... ,I. :e~': '.;. ," "d:.~~,:.:<~.... "..:: ..... . ',"{ :::.~ . ~ .~; ~-.". ;.:':':;'. :.~-:~.",: .~: ",' . . < 'Depth :M'ud .Plastic Yield A·Pl .Drill Interval Weight Viscosity Point Fluid Loss pH Solids (ft) (ppg) (cp.) (lb.ll00ft2) (mI130min) (% ) I . 2700-4933' 9.0-9.2 10 - 14 15 - 20 6-8 9.0-9.5 +/- 5% ~ · Build new FloPro fluid using the following formula: · Drill water; 21 PPB KCI; 0.25 PPB Greencide 25G; 2 PPB DualFlo; 2 PPB Flo- Vis; Caustic Soda for 9.0 - 9.5 pH, 0.5 PPB Conqor 404 for 2000 ppm, 4 PPB SafeCarb Fine, 16 PPB SafeCarb Medium · Maintain Conqor 404 concentration at +/- 2000 ppm. · Add 2 PPB Ventrol 401 and Asphasol D if running coal becomes a problem. · If swabbing becomes a problem, condition mud (reduced rheology) and add 1- 2 % KlaGuard. · Maintain Safecarb Fine & Medium concentrations throughout entire invterval and when build- ing additional volume. · Centrifuge surface system during trips to aid in removing drill solids. · Add 1 - 2 drums of Drilling Detergent if bit balling becomes a problem. · Estimated volume usage for interval - 875 barrels. M-I Drilling Fluids L.L.c. 721 West F irst Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax rJ"C-j. DRILLING r .w-JI FLUIDS ) Bridging Formula :'t~ìt\'i.~~~~:\~II!I~:fr~~~~·;·, .',.. Ii ;: Ii Ii I ,\: !I '~':C; ~.,¡ -,-. . " ¡ '.. .~. , , -;¡,; .... .' ~,~;.-" .r:!¡1 QpTIBRIDGETM © 1999·2001 M./ L.L.C . All Rights Reserved Operator: Marathon Oil Co. Well Name: KU 14X-6RD Location: Kenai Gas Field Comments: Optimum Blend 1.0 0.9 0.8 c: .12 :í 0.7 :ê i ë 0.6 Q) N c;; <II 0.5 U t IU Q. Q) 0.4 ;> :; "5 E 0.3 ~ U Optimum Bridging Agent Blend 0.2 !! " I' I' I: ji Ji r ¡. 10X10·2· 1x10·1 1x10o 1x101 1x102' .. '1'x103 ~¡" d _ _ _ __ _ __ """......:...1..._":_- 1_:.....~"""<'I\o\ ·!IIIIs~IIJ:~",d:~U~~·; MCr~o·:·I·rI~~~:l¡mKi.1l1x:.ERD,MCrQ···1 ~r-.roria~i, : 0.1 ) Well KU 14X-6 RD ·C·¡·,.,:¡~J~.:~·,I~!,:,~·~~~~~~f Max Permeability : Sand Control Device: 1200 mDarcy D10 - D50 - 090 D10 Target I Blend: 1.4 I 2.1 microns D50 Target I Blend: 34.7 I 31.0 microns D90 Target I Blend: 112.3 I 178.7 microns Optimum Blend for 0 to 100 % CPS Range Brand Name Bridqinq Aqent (lblbblJJol % B=Safe-Carb 10 (F) 3.7 18.62 D=SafeoCarb 40 (M) 16.3 81.38 E=Safe-Carb 250 (C) 0.0 0.00 D 81.4% Simulation Accuracy Calcium Carbonate added: 20 Iblbbl . . ·1·x10. Avg Error 0 -100 % CPS Range: 2.28 % Max Error 0 ·100 % CPS Range: 14.53 % ····nJj~~..~~.Slze·~~{;1,:~::,::<:~..hI·:~f'f'~L;~'~;tgJ~~~,@·~~ø~~jp\~~; M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ~ DRilliNG FLUIDS ) ) Project Team Well KU 14X-6 RD RºtiMª1:j~t1Š Field Engineer =~-¡f':¡ t~ ... ~ t~ I ötis:~ik;····· . Wareh0l.1seMai)ager . 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 907 373-2713 907 223-1634 Tony Tykalsky Project Engineer 907 376-4613 907 227-2412 Gus Wik Warehouse Manager 907776-8722 907 776-8680 Bob Williams Field Engineer 907 248-5857 907 252-4331 Rod Mabeus Field Engineer 907 262-6643 907 252-4331 M-I Drilling Fluids L.L.C. 721 West First Avenue Anchorage, Alaska 99501 (907) 274-5564 (907) 279-6729 Fax ..---J, '.. .. DRILLING r ,~ FLUIDS KENAI GAS FIELD DIAGRAMMATIC CROSS SECTION A 1t8;L~j~~41-7 Pad STERLING UPPER BeLUGA MIDDLE BELUGA UPPER TYONEK DEEP TYONEK .10,000· ) L't T5N-R~W . L.... UNIT ¡BOUNDARY. "_I~ ..I 1.1 . -J.-. I -'·1 i.1~ I . I , I T4 -R11WI I . I + II_II +- / /f'.J 11-. . =--._.~ l-! I o I ) ) " + KDU-7 X , I cj , '- r'* " +~ C:>Oø .. x , , , , , , " .. ...... + ~ o o (.) (' 'x ,," I . » ~" J . I ',.; ~ \. ""- \ , v \, -¥ ~ ,..... \," --/ ~ .......... J'",; (~, E:t + " ,-. I .....-., + HM4094 --A' r . I . ...... . + Structure Sterling 84 C.I. : 100' 1 I MILE MARATHON OIL COMPN-JY ALASKA REGION KU 14x-6rd Location KENAI GAS FIELD COOK INLET, ALASKA November 2002 n·\frøøh~nrl\IcIl~1_7In,., fh7 . . .~.~=-:---:::.:;::. -"'-:-':~ '~"!~~~'=';=-'-~~30 :>1 (KENAI "-4~~ . I '; .... ~ ~ . .. ._.~_._-~-:::~... ì t 'j It ) GaS .. ,,:!~~n.!.-: ~:;..~.. -:I"G~~;:O"~ ~. :~, r·..·~"~~~~6" '. . i 25 r= ..."'!'"..... ',i ¡...- --.,.------ . ·ia.· I'It" 27 ''"1. ~,~;. '. I ~: ')1" !tf~--- ,9 : "'. .... .:~ J¡; '\ 9'N:~~ ~:. '. . .. I \ , , . . .. '., _....: ! ; I, ; ,,-. ~"........__ ""'; ~CO P Y I' . ; ; i I jJjJ_~,;¡_-3HL._ .-f- ..--- .___u~,: -;"~ppy L:ån" , . :. . ;¡:--t,Çl. <60 . i . '~.~, '¡, : l· l~ "'~;"~. . .\. ~'i' !ë""[ P ,Iv, t .;J.;::;;;t-';'-'i.:;5 \;\; !,:¡¡ . <,36 ' --, · I , r;3000" . I' ~ to, '^__ ".__ iJ' WI ,., 32· :' , " ¡ ~'..;, " ,¡ ,r -",. ',' ~ . ",. '''1.''' i, ".·;8d~:1~("~~:~~---'~~~~:;~-;;~~;~~----~~~"I~Wl r~~'j~'i~~ ",' ';\.' , 'j -- "; , j, "'" }',.' 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'1"'. . ~ ,~, ''': . 31· ": ,f>, '--':.. /':" :..¿" .'t' ~ '::._.: :1 'b, ... .':'.::'\.') I . "" ,:. "(J{.~,,..... I" .,~ . ,~.. \ . .. K .snQ '.);l'.';~( ).r'~~\JS su.' i. Y '.:' ~__:~'_: '·i " ," --~2~1j! -::.. r ,::3-~-~~-c;.:: ~~"~_I: :: .' .::....~,~~Ij-~~-'.~-¡~_. ..._:........ '\'. ~I ~~:":. + ---------:" .---- I ,(7/. '2~<Ä . II. ,r- ,\ '. .. I - 1-- . (¡. '.'~'''(. '.", <1!~.'~ : . .:; '; " _', "' , : ì" .' ¡. .' .... ~ ........._""-. II.' l ~ " 6 p ¡-</:~",'))~~ .... 'r.:if':.. 2'~ _ ....Dj_~~~\.:_-,..____ .. ::.){_;;.::....___~J ~... L:;,:>':J:.. l.._..._.:..:_..~·:_~~___c.:._~.:.--.~ I'"~. 5N -:-. 4 ~¡ ..,..... ~.5 2 '1 : \1 ;:; ~..:::.': .~,' ~ ;;::.:.:-: . ~o . .'~-.:~ ~q~::::" . : [tånding ~ " , )P 1 ._ __ $.~rjp -::. _ :..... .. _ ~~~...,-:-¡~- ·Source M¡¡p: USGS, 1951 Kena~,...~laSka 8-4, 1:63,36~.....__..______._._.. ...---.---,-.... . SCÄÜ: 1:63360 4 MIL'S .....-_!.....-......... ...--.-----.~ ;~ ---;¡ÕÕo~T k.c,~",j.~"'.~~_:_..-;;;;., _·=~~.c ,.. .... ~~. '-=- ----;; ,';;';;;;,... Marathon Oil C ()mpany ~-3C - ;::."":;!;;~<.k"',.,,=:,==.~=c,,=.,""",,i:-~~_..,.,;:===_·,,~..·--·-·; Project: . KU 14 x -6rd ¡'é~ ('~~') \RI2W' , Rn~ '-...L9!I..- ., ~ X-270.9OII.",4 ...... V-2,JG.140..1 ",' ~ - S ~ :r:: , 6 ~¡":iI:1u.IiI(I! .æ 12 7 K.U. 14-15 CONe. 1""'01\ <!) 10' II _I. HWIIE '\ J (T'IP.) ~r.m.~M ~,r'" n'lf.J1'tIQIÆ CIIIILE. !to)( , ·'1 ",,1M ð'1'<fl' GUAAO PtP[ ð"O'JUI.1 ..., "r ~~:¡:;.~ ......,~ · r--- ~ ;-1'\1 "r¡:~. ~2'Xð.2' KTIIl I<.U, 43-12 COMe. ._~L.:r.]'-' i \UX{;· ---··--tPK ~VER ~,""" 0 :::"",'..:.'!. ¡~~ ~ ~ . ,e A.P.L. .. Nfb O.H. (T'II".) , V-:¡'3112.22<6.WI: _ ·F ,,""'""'.... '"'' "'...... '" Jf-}: ,- \ U,Q. 1IlDG'P1t~ ioI£1ER ~- !9PIIŒ IN :~O' ---~ QUAAO 3.0'X6.1' METAl. _ :.t=- )~T -,=--= . 'l~ j') ØI..IXò. Jj . CONe. COlIER !'LA lE ÐlClWlGER -.-. 20. lIII.O' -+--::.:: P X8.0' fIRE PADS P AÐS 8.0·X12.0' \ . '- DlOG. A 3 01Ø.0' METAl . /'~ =~ u.... ;g¿¡..~ ~.."", ~ ' , - 100 P!.AlE "-- ....-f/' =,.'. . BU.1G. 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PILL PlY ) ) Alaska Region Domestic Production " , M MARATHON Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 20, 2002 Mr. Tom Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: Field: Kenai Gas Field Well: KU 14X-6RD Permit No.: 81-92 Dear Mr. Maunder Enclosed please find the PERMIT TO DRILL application, along with the associated attachments. This permit is being requested as a contingency in the case where the planned workover (Sundry application submitted by J.G. Eller 12/17/02) is unsuccessful and a sidetrack of the original wellbore is necessary to re-establish a completion in the Sterling reservoir. In accordance with our discussions on well control utilizing the BOP configuration described in the permit and attachments, I am providing a document that discusses Marathon's proposal for well control while running the proposed 7" completion liner. If you require further information, I can be reached at 907-564-6310 or bye-mail at wjtank@marathon.com. Sincerely, fr1ÞJ ~ Willard J. Tank Senior Drilling Engineer Enclosure RECEIVED DEC 20 2002 Alaska Oil & Gas Cons. Commission Anchorage ) ') Well KU 14X-6RD Kenai Gas Field, Pad 14-6 Well Control During Completion While Running a 7" Production Liner The purpose of this letter is to address concerns related to well control while running a 7" production liner during a sidetrack of well KU 14X-6 in the Kenai Gas Field. Well KU 14X-6RD will be completed in the Sterling Pool 6. All existing perforations will be isolated prior to the well being sidetracked. The total length of this 7" liner is approximately 2,433' . The concern is that Marathon will be unable to install a set of pipe rams for the 7" liner as required by 20 AAC 25.285( c )(2)(A)(i). The height of the tubing head on well KU 14X-6RD will not allow a separate set of pipe rams to be installed specifically for the 7" liner, although pipe rams will be in place for the 4" work string. Neither are variable-bore rams available that will span the range from 4" and 7" diameter pipe. Therefore, Marathon requests that the commission review the following information to authorize a variance in accordance with 20 AAC 25.285(h), which reads: « Upon request of the operator, the commission will, in its discretion, approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. " Anticipated Formation Pressure Well KU 14X-6RD openhole section would be exposed to the Sterling Pools 3,4,5.1,5.2, and 6 reservoirs. The maximum formation pressure in these intervals is about 1440 psi occurring at a TVD of 4,144'. This formation pressure estimate is highly reliable and verifiable given the large number of completions currently producing from both of these pools and an extensive production history. This pressure equates to a gradient of 6.7 ppg EMW with a maximum possible surface pressure of 1,026 psi. Primary Well Control While Running 7" Production Liner The primary well control measure that will be used while running this 7" liner will be maintaining a hole full of kill weight fluid. Marathon will employ lost circulation material (LCM) as needed to control losses to the Sterling sands prior to running the 7" liner. Experience has shown that we can successfully control fluid losses in these zones, and Marathon will not run the 7" liner without being able to keep the hole full. Until the 7" liner is suspended on work string and below the BOPE, a continuous fill trip tank will be used to ensure that the hole remains full. Secondary Well Control While Running 7" Liner Marathon will have available on the drill floor a valve capable of making up onto any pipe that is run, which includes the 7" liner, 6'i4" drill collars, and 4" work string. In the event of a kick, this floor valve will be stabbed onto the pipe that is being run then the valve would be closed. The annular preventer would be closed on the 7" liner. A surface pressure of 1 ,026 psi acting on the area of the 7" liner (i.e. 38.5 in2) will produce a lifting force of39,500 Ibs. This would be opposed by the weight of the 7" liner and 4" drill pipe being run, which is approximately 63,260 Ibs for the full 2,433' of liner. Therefore the weight of7" liner itself is adequate to balance the piston force on the ) ) liner during a kick. The weight of the top drive and traveling block could also be used to assist in holding the liner in place during a kick. Summary Marathon believes that the low bottomhole pressure of well KU 14X-6RD combined with the relatively short length of proposed 7" liner, the ability to maintain a full column of kill weight fluid, and the ability to shut-in the well with an annular preventer constitutes an equally effective method of well control as that outlined in 20 AAC 25.285( c )(2)(A)(i). Accordingly, Marathon requests that a variance be granted for well KU 14X-6RD allowing the 7" liner to be run without 7" pipe rams. Alaska Bus"~ Unit Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 20, 2002 Mr. Tom Maunder Alaska Oil and Gas Commission 333 West ih Ave Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: RECEIVED Subj ect: Well KU 14X-6 Kenai Gas Field, Pad 14-6 Recomplete as Annular Producer Potential Problems Addressed DEC 20 2002 Alaska Oil & Gas Gons. Commission Anchorage This workover will target gas from the Sterling C-1 and C-2 sands (Pool 6) in well KU 14x-6. Production will be up 9Y8" casing and a 20/8" tubing string. This style of completion has allowed high gas deliverability from these depleted intervals at a relatively low cost. Potential problems associated with this type of completion are addressed below. Potential Problem Solution Erosional Velocity The highest potential for erosive flow exists at the 11", 3M flanged outlet of the tubing head. The large side outlet (5.875" minimum ID) on the tubing spool was selected specifically to reduce erosional velocity. Erosion could potentially occur if flow out an annular outlet exceeds 40 MMCFD. Marathon plans to produce the well below erosive limits. Also, Marathon will conduct periodic UTT inspection of the wellhead and flowlines for signs of unusual wear. Corrosion Partial-pressure of CO2 is less than 1.0 psi for natural gas produced from the Sterling Pool 6. If the partial pressures of C02 is less than 7 psi the gas is generally considered noncorrosive. Furthermore, there is no H2S produced in the Kenai Gas Field. Corrosion of the casing is highly unlikely. Environmentally aware for the long run. ) ) Surface Safety Controls The annulus will be produced via a separate flowline from the existing tubing completion. Surface safety controls will be similar to that of other Kenai Gas Field completions. Burst/Collapse of Casing Shut in pressure for Sterling Pool 6 is 392 psia. Pressures imposed on the 90/8" casing during this procedure will not compromise the integrity of the casing. If further information is needed, I can be reached at 907-564-6315 or jgeller{cl1marathonoil.com. bjv ) Alaska Bus ~ Unit Marathon Oil Company P.o. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 Fax 907/564-6489 December 20, 2002 Mr. Tom Maunder Alaska Oil and Gas Commission 333 West ih Ave Suite 100 Anchorage, AK 99501 RECEIVED Dear Mr. Maunder: DEC 20 2002 Subject: Well KU 14x-6 Kenai Gas Field, Pad 14-6 Well Control During W orkover While Running a 7" Scab Liner Alaska Oil & Gas Cons. l;omoUSSlOn Anchorage The purpose of this letter is to address concerns related to well control while running a 7" scab liner during a recompletion of well KU 14x-6 in the Kenai Gas Field. Well KU 14x-6 will be completed in the Sterling Pool 6 as an annular producer up the 9Y8" casing and 20/8" tubing strings. Existing Pool 3 and Pool 4 perforations will be isolated using a 7" scab liner with packers. The total length of this 7" liner is approximately 320'. The concern is that Marathon will be unable to install a set of pipe rams for the 7" liner as required by 20 AAC 25.285(c)(2)(A)(i). The height of the tubing head on well KU 14x-6 will not allow a separate set of pipe rams to be installed specifically for the 7" liner, although pipe rams will be in place for the 4" work string. Neither are variable-bore rams available that will span the range from 4" and 7" diameter pipe. Therefore, Marathon requests that the commission review the following information to authorize a variance in accordance with 20 AAC 25.285(h), which reads: "Upon request of the operator, the commission will, in its discretion, approve a variance from the requirements of this section if the variance provides at least an equally effective means of ensuring well control. " Anticipated Formation Pressure Well KU 14x-6 is currently completed in the Sterling Pool 3 and Pool 4 reservoirs. The maximum formation pressure in these two intervals is about 200 psi. This formation pressure estimate is highly reliable and verifiable given the large number of completions currently producing from both of these pools and an extensive production history. This pressure equates to a gradient of 1.3 ppg EMW with a maximum possible surface pressure of 160 psi. Environmentally aware for the long run. ) ) Primary Well Control While Running 7" Liner The primary well control measure that will be used while running this 7" liner will be maintaining a hole full of kill weight fluid. The only open perforations in well KU 14x-6 are those that will be isolated by the 7" scab liner. Therefore, Marathon will employ lost circulation material (LCM) as needed to control losses to these perforations prior to running the 7" liner. Experience has shown that we can successfully control fluid losses in these zones, and Marathon will not run the 7" liner without being able to keep the hole full. Until the 7" liner is suspended on the work string and below the BOPE, a continuous fill trip tank will be used to ensure that the hole remains full. Secondary Well Control While Running 7" Liner Marathon will have available on the drill floor a valve capable of making up onto any pipe that is run, which includes the 7" liner, 6'ï4" drill collars, and 4" work string. In the event of a kick, this floor valve will be stabbed onto the pipe that is being run, then the valve would be closed. The annular preventer would be closed on the 7" liner or the 6'ï4" drill collars. A surface pressure of 160 psi acting on the area of the 7" liner (i.e. 38.5 in2) will produce a lifting force of6,160 Ibs. This would be opposed by the weight of the 7" liner and packers being run, which is approximately 7,400 Ibs for the full 320' of liner. Therefore the weight of 7" liner itself is adequate to balance the piston force on the liner during a kick. The weight of the top drive and traveling block could also be used to assist in holding the liner in place during a kick. Summary Marathon believes that the low bottomhole pressure of well KU 14x-6 combined with the short length of proposed 7" liner, the ability to maintain a full column of kill weight fluid, and the ability to shut-in the well with an annular preventer constitutes an equally effective method of well control as that outlined in 20 AAC 25.285(c)(2)(A)(i). Accordingly, Marathon requests that a variance be granted for well KU 14x-6 allowing the 7" liner to be run without 7" pipe rams. If further information is needed, I can be reached at 907-564-6315 or jgeller(á¿marathonoil.com. bjv } ) Ii ¡ I, ",'~?~'~,:~ REV 4197 Marathon Oil Co~any i ·;·~<ff¿tj:.t~~:~-~;r;i~'?i:·~E§~::::;;'~::>?L~::;: :-::::::i.;\":f;0~~%:;~:::~;~s¿ \ . ....-. ...., 'I~:".·::· 'j'~,.::~ ,,01:5,9-6·..··· .I...."..,).~~:': \. " ,. ....,.' ~ :~'.:... . ,. :-,~ ~:. ·a'~.~,.<!.>':::.::;. JtJl~Ft :·.1~~.:::;;· ':··:ÄAl~ka.:" º-il.Á.Gª.~...Gon.uJli~t$ :Lpn ¡ " '. '<..:..::..~3.33;:~~W.~a~.ltll. Aye_..- ... ._.S.y';i.t.e .J 00. MATCH .AMOÜNt.iN·:·.{~~;·~¡~.} ':';~:~O:_~:-.29.:¡.Q1-...::.;., __ . . .. .. __ .. . ::.,. . ;!'Jr~··:2:~~i··~·.· . '" ","., ,. ..... ".qN.,.-.:A..!. l.p~AL ~ANK OF ALASKA j __~ -) J ~':' .,.: <. . ..' :i~~,t>:-.·;..·./·~~~: ::i .. ";:<,~:ANCHORAGE ALASKA By ~ '^'-./ fel 1 (7~ ~-. ". ;::~,' . ~.~« ~'....~. '.) ......:.... :' .:'. ' . .' 1:1~:fi;~~~.m:~II.IlIlh'jl:t~.II{.]~.fi'I~(.~i':..liiI1!lri.1&'~..j'i':~~.=['].=~~.i~~~~~:;E' . '. '. "">':!,,'¿'"""<. ;... > .V~IIEaW 11~..Ö(j.·....~·.·.5..·.·g.þ····.II~i...···..···..···...:.....···....··..·2·.··.·s·.····..·.2.0··.C)·(:J·...s.···.'?·.:.·Ø.~iIIIlO...·.·?á·š.·~.~..JI.· ... "- ....... ...,........ "..", ,.., ·~I~jlÏ.;~·i~~~~~l~h'jl:):t: _1~.tllillÎiìll.~t=!..," [.I., f.t!'i1.B A.F.E. 7 ACCT. COD ..,,~ ...., .."., .. ,,' .... ..,~ -,. ~..~ "'" -'- .- _. "-' "".,--""" ~-,'- '-.... ......,..-,..- -.-." OR [.~~I:\:t..]:...I~[~-¡f£'..~~ NON~REPORTING 1.00% REPORTABLE INTEREST IF REPORTABLE RENTS INDICATE SERVICES TYPE OF PAYMENT ------- Filing fee for permit to Drill KU 14-6RD RECEIVED DEC 20 2002 1lISl<a Oil & Gas Gons. Commission Anchorngø ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ku It/X -~ Rb WELL NAME PTD# :2-C>? . - ?c:: 2- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) "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. HOLE In accordance with 20 AAC 25.005(t), 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). SPACING EXCEPTION DRY DITCH SAMPLE 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. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. ~~,.;:)( \ as:: ~ \1 Ç(>.'^-<-., û"->, ~S- \,] "\ t£) by d () ~ ß... C; é) c; ,-;)1; S (c\ C~\ CA \ (\) CJ ~~ \-c: J Rev: 07/10/02 C\jody\templates ,. l~ 1. Perm it fee attached ................................................................................................ 2. Lease number appropriate...... ...... ...... ... ............ ......... ...... ......... ... ... ... ............ ......... 3. Unique well name and number ................................................................................. 4. Well located in a defined pool................................................................................... 5. Well located proper distance from drilling unit boundary................................. ...... .......... 6. Well located proper distance from other wells......... ............ ........................ .................. DATE 7. Sufficient acreage available in drilling unit............................ ........................................ 8. If deviated, is well bore plat included ........................................................................... 12/24/2002 9. Operator only affected party ..................................................................................... 10. Operator has appropriate bond in force ..................................................................... 11. Permit can be issued without conservation order ... ...... ... ...... ...... ... ... ... ...... ... .,. ...... ... ... 12. Permit can be issued without administrative approval.................. .................. ............... 13. Can permit be approved before 15-day wait....................................... ........................ 14. Well located within area and strata authorized by Injection Order # 15. All wells within 1/4 mile area of review identified .......................................................... 16. Pre-produced injector: duration of pre-production less than 3 months.............................. 17. ACMP Finding of Consistency has been issued for this project ... ... ... ... ............ ...... ... ...... WELLPERMITCHECKL!ST FIELD & POOL ADMINISTRATION APPR SFD (For Service Well Only) (For Service Well Only) (For Service Well Only) ENGINEERING APPR DATE TEM 1/16/20~ ~~ (For Service Well Only) COMPANY WELL NAME KU 14-X-6RD Initial Class/Type DEV / 1-GAS Marathon 448568 - Kenai, Sterling 6 18. Conductor string provided....................................................................................... 19. Surface casing protects all known USDWs ................................................................. 20. CMT vol adequate to circulate on conductor & surf csg ................................................. 21. CMT vol adequate to tie-in long string to surf csg ......................................................... 22. CMT will cover all known productive horizons ...... ... ......... ... ... ... ... ... ... ... ... ................... 23. Casing designs adequate for C, T, B & permafrost....................................................... 24. Adequate tankage or reserve pit... ... ... ... ... ...... ........................ ... ... ......... ............... ... 25. If a re-drill, has a 10-403 for abandonment been approved............................................ 26. Adequate well bore separation proposed.................................................................... 27. If diverter required, does it meet regulations.............................. ...... ............ ......... ...... 28. Drilling fluid program schematic & equip list adequate ... ... ... ... ... ... ... ...... ... ... ... ... ... ... ..... 29. BOPEs, do they meet regulation .............................................................................. 30. BOPE press rating appropriate; test to ........................ 3000 psig ........................... 31. Choke manifold complies w/API RP-53 (May 84) ........................................................ 32. Work will occur without operation shutdown ... ...... ......... ...... ... ... ... ... ............ ...... ...... .... 33. Is presence of H2S gas probable............................................................................. 34. Mechanical condition of wells within AOR verified ......... ... ... ... ... ...... ...... ... ... ...... ........... APPR 35. Permit can be issued w/o hydrogen sulfide measures... .......................................... ...... 36. Data presented on potential overpressure zones ... ... ... ... .... ........ ...... ... ... ... ...... ... ... ... ... DATE 37. Seismic analysis of shallow gas zones ........................ .............................................. 38. Seabed condition survey (if off-shore) ...... ... ...... ...... ............ ... ... ... ......... ......... ... ........ 12/24/2002 39. Contact name/phone for weekly progress report~xploratory only] .............................. GEOLOGY SFD RPC: GEOLOGY: ENGINEERING: RES. ENGINEERING: COMMISSION: JDH: TEM: rEM COT: Drs: ð iJ /.f, (ò3 MLB: all/7/0 '3 SFD: SFD WGA: MJW: PROGRAM Exploratory (EXP) GEOL AREA 820 Annular disposal para req Development (DEV)~ Redrill...!... Service (SER) UNIT No. 51120 ON/OFF SHORE On Well bore seg Yes #01596 Yes Yes Yes 448568 - Kenai, Sterling 6 Yes Yes Per CO 175, no restrictions as to well spacing. Yes Per CO 175, no restrictions as to well spacing. Yes Yes Yes Yes Yes Yes NA Not Applicable NA Not Applicable NA Not Applicable NA Proposed re-drill of existing well. NA Not Applicable NA Proposed re-drill of existing well. NA Not Applicable NA Not Applicable « Yes Yes Yes Yes Yes Existing rig. All mud/cuttings in steel tanks and waste transported to class II disposal well. 302-386 was approved for work over. Specific plugging information must be provided if needed. Closest well will be the abandoned well. NA Not Applicable Yes Yes Due to wellhead heigth, only one set of pipe rams can be used. Marathon has applied for an exception to run their 7" liner without 7" rams. This was approved for the original workover with a liner length of 320'. Liner length is longer in this application, well will be full of drilling mud. Target zone is partially depleted. J recommend approval of their waiver request to run liner without installing rams. Marathon has provided a mitigation strategy. /f 0 ?J1.Jl No i~"~ \11 \ -0 ~ NA Not Applicable I I <0 Yes No H2S is produced in the Kenai Gas Field No Gas sands expected from -3550' MD to TD. They may vary from normally pressured to severely depleted (see p.3 for table). SFD NA Not Applicable NA Not Applicable NA Not Applicable Yes Yes ./ \ Comments/I nstructions
