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Home My WebLink About205-131 DATA SUBMITTAL COMPLIANCE REPORT 11/23/2007 ~~ ~~ ~~ r ~; ~ ~~ J Permit to Drill 2051310 Well Name/No. KALOA 4 Operator AURORA GAS LLC API No. 50-283-20115--00-00 MD 4431 / TVD 3700 ~~"- Completion Date 10/6/2005 "~ Completion Status~._P&A ,a Current Status P&A UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surveys; `Yes DATA INFORMATION Types Electric or Other Log s Run: LD Platform Express 9-30- 05, DSI /FMI 10-01-05 (data taken fro m Logs Portion of Master Well Data Maint Well Log Information: Log/ Elects Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D C Pds 13317 Induction/Resistivity 668 4416 Open 10/17/2005 PEX AIT, DSI, FMI, GPIT (.pdf .pds) MudLog (.las i .pdf) Directional Survey (.xls) Log /' Mud Log 2 Col ~~~ ~ 67 4431 Open 10/17/2005 Mud Log MD (horizon Well Logging, Inc) Log J Mud Log 2 Col y'~/~ 67 4431 Open 10/17/2005 Mud Log TVD (Horizon Well Logging, Inc) Log~•-°~"~ Drill Rate 2 Col 67 4431 Open 10/17/2005 Drillimg Parameters (Horizon Well Logging, Inc) '~~ Log Induction/Resistivity 25 Blu 1 ~~ 668 4416 Open 10/17/2005 PEX Array Induction / ~ Comp Neutron Triple-Litho Density SP GR Caliper Log 1/" Induction/Resistivity 25 Blu 1 ~ VA 668 4416 Open 10/17/2005 PEX Array Induction / Comp Neutron Triple-Litho Density SP GR Caliper / ~i Log c/ Sonic 5 Col 2 668 4366 Open 10/17/2005 Dipole Sonic Imager Monopole P & S Upper Dipole Log.rr'`~ Formation Micro Ima 5 Blu 2 668 4408 Open 10/17/2005 Fullbore Micro-Imager Dual Axis Caliper Dip Log t/ ~ Directional Survey Blu 2 668 4390 Open 10/17/2005 Presentation General Purpose Inclinometry Tool Directional Survey D C Las 13317 Induction/Resistivity 103 1110 Open 12/18/2006 LAS, GR, RHOZ, SPHI, DEVI, AHT10 DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2051310 Well Name/No. KALOA 4 Operator AURORA GAS LLC MD 4431 TVD 3700 Completion Date 10/6/2005 Completion Status P&A Current Status P&A Well Cores/Samples Information: Name ~~` Cuttings ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N Received? Comments: Compliance Reviewed By: Sample Interval Set Start Stop Sent Received Number Comments 60 4431 1158 Daily History Received? Y / N Formation Tops Y / N API No. 50-283-20115-00-00 UIC N Date: Revised completion report and survey for Kal Subject: Revised completion report and survey for Kaloa 4 Fro~t~:.lohn 13reitmeier <john.breitmeier@fairweather.com> Date: Thu. ?6 Jan 2UO6 09:39:58 -0900 To: bob fleckcnstein~'a;~idmin.sl~~tc.ak.us CC: Lid ,ionc~ l~_1~~~~csra:~uu-orapower.con~~~=~ Bob, I have attached the requested actual survey data for the Kaloa 4 well as well as an updated 10-407 with the location data changed to reflect the final surrey. Thanks for the heads - up on this. John Breitmeier Content-Description: 10-407, Kaloa #4.xls 10-407, Kaloa #4.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 __ _ _ _ 'Content-Description: Sperry Final Actual Svy K4 'i'' Sperry Final Actual Svy K4 Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 1/26/2006 11:28 AM ~~ E & P SERVICES, INC. December 22, 2005 Mr. Steven Davies Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Re: Corrected version of 10-407 Completion Report: Kaloa #4 (API # 50-283-20115-00) Dear Mr. Davies, r~ c. , . -~ ~- ~ ~ _H :.._; r z ~S~~atEi ~~i.v ~~- i~~ Aurora Gas, LLC hereby submits the corrected version of the 10-407 Completion Report. This report reflects the correct well location of Kaloa #4. Operations were completed on October 6, 2005. Pertinent information included under. cover of this letter includes the following: 1) Form 10-407 "Well Completion Report and Log" - 2 copies. If you have any questions or require additional information, please contact Ed Jones of Aurora Gas, LLC at 277-1003 or Richard Tisch of Fairweather E&P Services, Inc at (907) 258-3446. Sincerely, A Richard Tisch for J. Edward Jones. Executive Vice President Engineering -Operations cc: Jesse Mohrbacher John Breitmeier 2000 East 88th Avenue • Anchorage, Alaska 99507 • (907) 258-3446 • FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505 • Houston, Texas 77060 • (281) 445-5711 • FAX (281) 445-3388 STATE OF ALASKA ~ R~EC , '~ ZO05 ALA OIL AND GAS CONSERVATION COM .ION WELL COMPLETION OR RECOMPLETION REPOR~-~ '"'~"'' ~`` 1a. Well Status: Oil^ Gas Plugged ~ Abandoned ~ zoaaczs.~os GINJ ^ WINJ ^ WDSPL^ No. of Completions Suspended WAG 2oanc2s.»o Other 1b. Wel! Class: Development ^ Exploratory0 Service ^ Stratigraphic Test^ 2. Operator Name: Aurora Gas, LLC 5. Date Comp., Susp., or Aband.: 06-Oct-0S 12. Permit to Drill. Number: 205-131 3. Address: 1400 West Benson Blvd, Suite 410 Anchorage, AK. 99503 6. Date Spudded: 13~ep-05 13. API Number: 50-283-20115-00 4a. Location of Well (Governmental Section): Surface: 1146' FNL, 1732' FEL, Sec.26, T11N, R12W, SM 7. Date TD Reached: 29-Sep-05 14. Well Name and Number: Kaloa #4 Top of Productive Horizon: N/A 8. KB Elevation (ft): 211' MLLW 15. Field/Pool(s): Total Depth: 89' FNL, 165' FEL, Sec. 25, T11N, R12W, SM 9. Plug Back Depth(MD+TVD): To Surface Kaloa 4b. Location of Well (State Base Plane Coordinates): Surface: x- 260742 y- 2566987.7 Zone- 4 10. Total Depth (MD + TVD): MD 4431" TVD 3700' 16. Property Designation: C-061393 TPI: x- y- Zone- 4 Total Depth: x- y- Zone- 4 11. Depth Where SSSV Set: N/A 17. Land Use Permit: Ciri Lease 18. Directional Survey: Yes ~ No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: N/A 21. Logs Run: Schlumberger Hole Logs: LD Platform Express 9-30-05, DSI / FMI 10-01-05 22. CASING, LINER AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8 48# H-40 Surface 67' Surface 67' driven 9 5/8 40# K-55 Surface 668' Surface 668' 12 1/4 77 bbls 14.5 ppg Class "G" cement to surface 23. Perforations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) NONE 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Surface to 171' 12.5 bbls of 15.8 ppg Class "G" cement 493' to 590' top of retainer 7.5 bbls 15.8 ppg Class "G" cement 590' to 890' 19 bbls 15.8 ppg Class "G" cement 1700' to 2545' 46 + 5 bbls 15.8 ppg Class "G" cement 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: Hours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing Press. Casing Press: .Calculated 24-Hour Rate -- Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~~j~.f~,r. y~ rY1~ i ~ -~ l~ ~ ._ > . _~ ,_ (c , L Form 10-407 Revised 12/2003 V ~ ~ ~ 1 ~C~1~UED ON REVERSE 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME M TVD Include and briefly su rize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". "None" 30. List of Attachments: rrect to the best of my knowledge. Contact: g is true and 31. I hereby certify that the foregoin co // /L g _ G'1 ~ ~? j ~ ~/ ~''° , ={ y1 / j Title: ~ Printed Name: , rV/ '" t ~ "" ~ ~ ° ~~ ~ ~ ~ - L~ ~l `~ D ~~ a e: Phone: - 7 Signature: i ~- u1,..1-~- INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated .pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Halliburton Global ('umpan~: Aurora Gas. LLC. 1);rte: 10!412005 Time: 165 16 Pa~~c: t I~icl~l: Cook Inlet (-o-onlin;ilcl:'YN:) Reference: We ll_ Kaloa #4, Gr id North Sic: Kaoa Unit ~ cr tical (~~ D) Refer ence: K4 + 14.7' ~C)2.4 ~1 ell: Kaloa #4 ticclion (~Si Rcfcrrn re: We ll i0-OON.D.OOE ,6L70Azi) \~clip>if6: h.aloa #4 lur~c~ ('nl~~ulntion M ethod: h~in lmum Curvatur e flb: Oracle Field: Cook Inlet USA Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cl arke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: Kaloa #4 Slot Name: Well Position: +N/-S 0.00 ft Northing: 2566962.63 ft Latitude: 61 1 9.438 N ~ +E/-W 0.00 ft Easting : 260749. 55 ft Longitude: 151 20 55.398 W Position Uncertainty: 0.00 ft Wellpath: Kaloa #4 Drilled From: Well Ref. Point 502832011500 Tie-on Depth: 3.70 ft Current Datum: K4 + 14.T Height 202.40 ft Above System Datum: Mean Sea Level Magnetic Data: 9/18/2005 Declination: 19.84 deg Field Strength: 55557 nT Mag Dip Angle: 73.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 3.70 0.00 0.00 61.79 Survey Program for Definitive Wellpath ~ Date: 10/4/2005 Validated Yes Version: 4 ~ Actual From To ~ Survey Toolcode Tool Name ~ ft ft 504.00 504.00 Rig Totco (504.00-504.00) INC - Inclinometer (Totco/Teledrift) ~ 690.62 4375.53 Sperry MWD (690.62-4375.53) MWD MWD -Sta ndard Survey ~ }111 Intl zim ll~U ti.,"fell \ S t'\~ \la~iA ~lapE foul ft deg deg ft ft fi ft Ft ft 3.70 0.00 0.00 3.70 -198.70 -_ 0.00 0.00 2566962.63 260749.55 __ TIE LINE 504.00 1.00 0.00 503.97 301.57 4.37 0.00 2566967.00 260749.55 INC 690.62 2.01 287.89 690.54 488.14 7.00 -3.11 2566969.63 260746.44 MWD 722.10 1.92 299.45 722.00 519.60 7.43 -4.10 2566970.06 260745.46 MWD 753.10 2.08 327.83 752.98 550.58 8.16 -4.85 2566970.79 260744.70 MWD 784.16 2.72 356.73 784.02 581.62 9.37 -5.19 2566972.00 260744.36 MWD 815.26 3.90 15.63 815.07 612.67 11.13 -4.95 2566973.76 260744.60 MWD 846.49 5.56 29.66 846.19 643.79 13.47 -3.92 2566976.10 260745.64 MWD 877.16 7.44 38.76 876.66 67426 16.31 -1.94 2566978.94 260747.62 MWD 907.49 9.36 46.03 906.67 704.27 19.55 1.07 2566982.18 260750.62 MWD 938.72 11.50 49.79 937.38 734.98 23.32 5.27 2566985.95 260754.83 MWD ~ 970.09 13.84 51.64 967.98 765.58 27.67 10.60 2566990.30 260760.16 MWD 1001.24 16.01 53.15 998.08 795.68 32.56 16.96 2566995.19 260766.52 MWD 1032.32 18.15 54.27 1027.79 825.39 37.96 24.32 2567000.59 260773.88 MWD 1063.85 20.64 54.40 1057.53 855.13 44.06 32.83 2567006.69 260782.38 MWD 1095.43 23.04 55.18 1086.84 884.44 50.83 42.43 2567013.46 260791.98 MWD 1126.65 25.17 55.87 1115.33 912.93 58.05 52.94 2567020.68 260802.50 MWD ~ 1158.01 27.29 55.92 1143.46 941.06 65.82 64.42 2567028.45 260813.97 MWD i 1189.41 29.24 56.32 1171.12 968.72 74.10 76.76 2567036.73 260826.32 MWD 1220.12 30.64 56.34 1197.73 995.33 82.60 89.52 2567045.23 260839.07 MWD 1251.48 32.42 56.56 1224.46 1022.06 91.66 103.19 2567054.29 260852.74 MWD 1281.28 34.01 57.24 1249.39 1046.99 100.58 116.86 2567063.20 260866.41 MWD ~ 1312.58 35.54 57.95 1275.10 1072.70 110.14 131.94 2567072.77 260881.49 MWD 1343.88 36.90 58.87 1300.35 1097.95 119.83 147.69 2567082.45 260897.24 MWD I 1375.21 38.18 59.28 1325.19 1122.79 129.64 164.07 256709226 260913.62 MWD 1406.35 39.49 59.93 1349.45 1147.05 139.51 180.91 2567102.14 260930.46 MWD 1435.67 40.61 61.07 1371.89 1169.49 148.80 197.33 2567111.43 260946.88 MWD 1467.40 42.28 61.39 1395.67 1193.27 158.91 215.74 2567121.53 260965.29 MWD 1498.77 43.24 61.93 1418.71 1216.31 169.02 234.49 2567131.64 260984.03 MWD Halliburton Global ( vmpany : Aurora Gas, LLC Uatc: 1014;2005 Lime: 16.59 16 Parr. .. I~icld: Co ok Inlet l~ u-or~l inau~(~I) Rc femncc Well. Kaloa #4, Gr id North Site: Kal oa Unit V~ erticn l fl ~'I7j Refe rence: K4 + "14.7' 202.4 ~~cll: Kal oa #4 S ection (\ tii Referen ce: Welf (O.OON,O OOE ,61]9Azi1 ~Pellpuih: Kal oa #4 S uncs ('alculatinn Vcihoil: P~4infmum Curvatur e Uh: Oracle Sun~~~ Slll Incl \iim IVD Sc~~C~ ll S,'S 4:;1~ AlapA \I:~pf. Tuol ft deg deg ft ft ft ft ft ft 1530. 37 44.50 62 .67 1441 .49 1239 .09 179 .20 253.87 2567141. 82 261003 .42 MWD 1561. 87 45.78 63 .12 1463 .71 1261 .31 189 .37 273.75 2567151. 99 261023 .30 MWD 1593. 17 45.78 62 .98 1485 .54 1283 .14 199 .54 293.75 2567162. 16 261043 .29 MWD 1624. 52 45.65 62 .16 1507 .42 1305 .02 209 .87 313.67 2567172. 50 261063 .21 MWD 1655. 80 45.53 61 .92 1529 .31 1326 .91 220 .35 333.40 2567182. 97 261082 .95 MWD 1687. 20 45.15 60 .57 1551 .39 1348 .99 231 .09 352.98 2567193. 72 261102 .52 MWD 1718. 50 44.67 61 .11 1573 .55 1371 .15 241 .86 372.28 2567204. 48 261121 .82 MWD 1749. 91 44.54 62 .08 1595 .92 1393 .52 252 .35 391.68 2567214. 97 261141 .22 MWD 1781. 31 44.03 63 .18 1618 .39 1415 .99 262 .43 411.15 2567225. 05 261160 .69 MWD 1812. 76 43.50 63 .58 1641 .11 1438 .71 272 .18 430.60 2567234. 80 261180 .14 MWD 1844. 23 43.23 63 .75 1663 .99 1461 .59 281 .77 449.96 2567244. 39 261199 .50 MWD ~ 1907. 17 43.41 62 .66 1709 .78 1507 .38 301 .23 488.51 2567263. 85 261238. 04 MWD 1969. 44 43.17 62 .63 1755 .10 1552 .70 320 .85 526.43 2567283. 47 261275. 97 MWD 2030. 97 43.32 62 .66 1799 .92 1597 .52 340 .22 563.87 2567302. 84 261313. 41 MWD 2093. 57 43.08 62 .95 1845 .56 1643 .16 359 .81 601.99 2567322. 43 261351. 52 MWD 2155. 42 42.75 62 .56 1890 .85 1688 .45 379 .09 639.43 2567341. 70 261388. 96 MWD 2218. 33 42.50 61 .81 1937 .14 1734 .74 398 .96 677.11 2567361. 58 261426. 64 MWD 2281. 04 42.80 62 .43 1983 .27 1780 .87 418 .83 714.66 2567381. 45 261464. 19 MWD 2312. 18 42.99 62 .76 2006 .08 1803 .68 428 .59 733.48 2567391. 20 261483. 01 MWD 2375. 14 43.61 63 .21 2051 .90 1849 .50 448 .20 771.95 2567410. 81 261521. 48 MWD 2437. 36 43.51 63 .50 2096 .99 1894 .59 467 .43 810.27 2567430. 04 261559. 80 MWD 2500. 45 43.34 63 .86 2142 .81 1940 .41 486 .66 849.14 2567449. 27 261598. 67 MWD 2562. 96 42.76 63 .51 2188 .49 1986 .09 505 .57 887.39 2567468. 19 261636. 92 MWD 2625. 64 42.47 62 .95 2234 .62 2032 .22 524 .69 925.28 2567487. 30 261674. 81 MWD 2688. 55 42.37 63 .29 2281 .06 2078 .66 543 .87 963.13 2567506. 49 261712. 66 MWD 2754. 48 42.42 63 .87 2329 .75 2127 .35 563 .65 1002.94 2567526. 26 261752. 46 MWD 2813. 49 42.42 63 .38 2373 .31 2170 .91 581 .34 1038.61 2567543. 95 261788. 12 MWD 2875. 96 43.31 60 .60 2419 .10 2216 .70 601 .30 1076.11 2567563. 91 261825. 63 MWD 2938. 28 42.52 58 .87 2464 .74 2262 .34 622 .68 1112.76 2567585. 29 261862. 28 MWD 3000. 62 41.14 59 .54 2511 .20 2308 .80 643 .97 1148.47 2567606. 57 261897. 99 MWD 3062. 32 41.89 63 .58 2557. 40 2355 .00 663 .42 1184.42 2567626. 03 261933. 94 MWD 3125. 27 42.55 65 .25 2604 .02 2401 .62 681 .69 1222.57 2567644. 29 261972. 09 MWD 3188. 16 42.44 64 .27 2650. 39 2447 .99 699 .80 1261.00 2567662. 41 262010. 51 MWD 3250. 55 42.54 62 .48 2696. 40 2494 .00 718 .69 1298.67 2567681. 29 262048. 18 MWD 3311. 92 41.72 62 .10 2741. 92 2539 .52 737 .83 1335.12 2567700. 43 262084. 63 MWD 3374. 64 39.87 62 .80 2789 .40 2587 .00 756 .78 1371.45 2567719. 39 262120. 95 MWD 3437. 42 38.79 64 .16 2837 .96 2635 .56 774 .55 1407.04 2567737. 16 262156. 55 MWD 3500. 37 38.06 64 .44 2887 .27 2684 .87 791 .52 1442.30 2567754. 12 262191. 80 MWD 3563. 06 36.54 62 .54 2937. 14 2734 .74 808 .46 1476.29 2567771. 07 262225. 79 MWD 3626. 35 35.45 62 .74 2988. 35 2785 .95 825. 56 1509.33 2567788. 16 262258. 83 MWD 3689. 18 34.15 63 .61 3039. 94 2837 .54 841. 74 1541.32 2567804. 35 262290. 82 MWD 3751. 37 33.18 63 .87 3091. 70 2889 .30 857. 00 1572.24 2567819. 60 262321. 74 MWD 3813. 13 32.39 63 .96 3143. 62 2941 .22 871. 70 1602.27 2567834. 30 262351. 77 MWD 3875. 49 30.09 64 .11 3196 .93 2994 .53 885 .86 1631.35 2567848. 46 262380. 84 MWD 3936. 33 27.75 63 .43 3250. 18 3047 .78 898 .86 1657.74 2567861. 46 262407, 24 MWD 3998. 81 26.67 64 .51 3305. 75 3103 .35 911 .40 1683.41 2567874. 00 262432. 90 MWD 4060. 55 26.10 63 .93 3361. 06 3158 .66 923. 33 1708.11 2567885. 93 262457. 61 MWD 4123. 07 25.09 63 .76 3417. 44 3215 .04 935 .24 1732.36 2567897. 84 262481. 85 MWD 4185. 81 24.74 64 .24 3474. 34 3271 .94 946. 82 1756.11 2567909. 42 262505. 61 MWD 4249. 93 23.53 64 .34 3532. 86 3330 .46 958. 20 1779.73 2567920. 80 262529. 23 MWD 4312. 79 23.33 64 .26 3590. 53 3388 .13 969. 04 1802.26 2567931. 63 262551. 75 MWD 4375. 53 20.93 64 .41 3648. 65 3446 .25 979. 27 1823.56 2567941. 87 262573. 05 MWD Halliburton Global omp:un: Aurora Gas. LLC Il;~lc: 1Q/4/200~ lini~: 16-5,3:16 I'n~~e: 3 Ficl~l: Cook INet (~o-onlinatc(~1~-) kctrrcacc: ~^~1~11~ Kaloa #4, GYid ~~dorth Jite: Kaoa Unit ~~erfical (11-I1~ lteferrner, K4 +..14.7' 202.4 ~~cll: Kaloa #4 ti~~ctiun (\~51ltrfcrrucr: ~^Jell (O.OON,QOOE,G1J9Azi) ~1"cllparh: Kaloa #4 Suture (:~Icul:~iiun VMhoil: h-linimUm Curvature I~h: Orade ~ tiu rcc~ )1D Incl \iim llD ~~cTVD A;S H/~~ AI>i~iA ~Ia~il': l'uuI tt deg deg ft ft ft tt ft ft __ 4431.00 20.93 64.41 3700.46 3498.06 987.83 1841.43 2567950 .43 262590.92 PROJECTED to TD DSVl UWI: 50283201 1500 Depth: FT Conf. Factor: DSV2 Common: Kaloa #4 DSV3 Survey Name: Kaloa #4 Method: DSV4 Company: Auro ra Gas, LLC Date: 2005-10-04 DSV5 Remarks: DSV6 Measr. Depth Deviation Direction DSV7 3.70 0.00 0.00 DSV7 504.00 1.00 0.00 DSV7 690.62 2.01 287.89 DSV7 722.10 1.92 299.45 DSV7 753.10 2.08 327.83 DSV7 784.16 2.72 356.73 DSV7 815.26 3.90 15.63 DSV7 846.49 5.56 29.66 DSV7 877.16 7.44 38.76 DSV7 907.49 9.36 46.03 DSV7 938.72 11.50 49.79 DSV7 970.09 13.84 51.64 DSV7 1001.24 16.01 53.15 DSV7 1032.32 18.15 54.27 DSV7 1063.85 20.64 54.40 DSV7 1095.43 23.04 55.18 DSV7 1126.65 25.17 55.87 DSV7 1158.01 27.29 55.92 DSV7 1189.41 29.24 56.32 DSV7 1220.12 30.64 56.34 DSV7 1251.48 32.42 56.56 DSV7 1281.28 34.01 57.24 DSV7 1312.58 35.54 57.95 DSV7 1343.88 36.90 58.87 DSV7 1375.21 38.18 59.28 DSV7 1406.35 39.49 59.93 DSV7 1435.67 40.61 61.07 DSV7 1467.40 42.28 61.39 DSV7 1498.77 43.24 61.93 DSV7 1530.37 44.50 62.67 DSV7 1561.87 45.78 63.12 DSV7 1593.17 45.78 62.98 DSV7 1624.52 45.65 62.16 DSV7 1655.80 45.53 61.92 DSV7 1687.20 45.15 60.57 DSV7 1718.50 44.67 61.11 DSV7 1749.91 44.54 62.08 DSV7 1781.31 44.03 63.18 DSV7 1812.76 43.50 63.58 DSV7 1844.23 43.23 63.75 DSV7 1907.17 43.41 62.66 DSV7 1969.44 43.17 62.63 DSV7 2030.97 43.32 62.66 DSV7 2093.57 43.08 62.95 DSV7 2155.42 42.75 62.56 DSV7 2218.33 42.50 61.81 DSV7 2281.04 42.80 62.43 DSV7 2312.18 42.99 62.76 DSV7 2375.14 43.61 63.21 DSV7 2437.36 43.51 63.50 DSV7 2500.45 43.34 63.86 • DSV7 2562.96 42.76 63.51 DSV7 2625.64 42.47 62.95 DSV7 2688.55 42.37 63.29 DSV7 2754.48 42.42 63.87 DSV7 2813.49 42.42 63.38 DSV7 2875.96 43.31 60.60 DSV7 2938.28 42.52 58.87 DSV7 3000.62 41.14 59.54 DSV7 3062.32 41.89 63.58 DSV7 3125.27 42.55 65.25 DSV7 3188.16 42.44 64.27 DSV7 3250.55 42.54 62.48 DSV7 3311.92 41.72 62.10 DSV7 3374.64 39.87 62.80 DSV7 3437.42 38.79 64.16 DSV7 3500.37 38.06 64.44 DSV7 3563.06 36.54 62.54 DSV7 3626.35 35.45 62.74 DSV7 3689.18 34.15 63.61 DSV7 3751.37 33.18 63.87 DSV7 3813.13 32.39 63.96 DSV7 3875.49 30.09 64.11 DSV7 3936.33 27.75 63.43 DSV7 3998.81 26.67 64.51 DSV7 4060.55 26.10 63.93 DSV7 4123.07 25.09 63.76 DSV7 4185.81 24.74 64.24 DSV7 4249.93 23.53 64.34 DSV7 4312.79 23.33 64.26 DSV7 4375.53 20.93 64.41 DSV7 4431.00 20.93 64.41 • ' ~ ~ '~'=~~ GRID N:2568072.421 `" f J ~ -~_: GRID E:262504.083' 'g '~ ~ ~ ~ » ''` ' t,,; 'ti ,;,~•-; ,~~ t: - LATITUDE: 61°01'20.719"N ~x y " ° ' ' . „ ~ ~ ~ • W . 20.263 20 LONGITUDE:151 +. "~ ,; ~~~: ~ ~ - -. ,, SEC 24 . • - `~~~+~ "~' ,k,~. - ~~ SEC 26 ~ - ' i_~ ~ ~•' ~ ~ "' '"^' LL- ~ _ . - SEC 25 165,.. FWL NORTH -.- ~~~k tzi ° '~.~~-` . L.~~ ~ ., co ~...,'-; .°. ~-, •~,.~ TD PROPOSED . `q . ~ ' ,~~` ~" - ~ KALOA #4_ WELL 39T FEL~~' "~ ~ - ~ ~ ~ ~ N 2567980.32 ~~ E 262667 18 °' ~` TARGET PROPOSED ~,.,._• . t*.,~.~ .~ -. = X41 ' .,~ `.,~- ~. '~"y'~AI. ~ : ' ~ . ~' ~ . ,,~~%~.~,~ ~ ~ I .. . • .~ KALOA #4 WELL AS-BUILT ;~ ~ N 2567700 ,, ~ ~ _ ~ ~r ` ` ' , ~ ,~lr rr,1 E 262100 ~ ~ GRID N:2566962.631 >w~~~ ,,: GRID E:260749.555 ! - ; ~ "P~•• ~ ~ , ''''~' R ~ _a " ~ ~' " ° ' ~ « ~• ~4~.' • ' r ~ ~ #~ ,"~ ~' .~A N r. ' 09.438 01 LATITUDE: 61 f a;,,~ ~ LONGITUDE: 151 2055.398 W ~ • ~ .. •~ ° _ ,,,. ~•• - * ~ ,y-;,, '~ ,, w ` _ . ELEV. 198.7' ^ o `~ .~ ;•`~a,. ; .~" ~ ~,~°~:- ,~ i ~: +. ~ ~.. ~ -? . ~.-.: r ,, i~ 4 t~ Y ~ .'~. ' L y » ` >) ~ - ~ 7 L 1 ~L ~ sp . ~ R ~ ~ ~ ~ '> \ ~ ~ .. i J-. .~... yam,, .~l~ ' KALOA #2 WELL AS-BUILT '..; ~ °~~~•= `.~'r ~~~ :- ° ~ ~. a - ~ ~' ~~ ~ "~.~ ~ N 2566864.6410 -y ' , r 4 ~ ~{,. `` ~ - *~ r , :' E 260774.4660 ~ ' " r ~: ~~. • • A t• .t f~ ~ . 1 o r 4. ~ ~~• .. ~, ~ 1 .~~ ~ r~ (^C ~. ,~ ~_ r }, V •. 9 . : '~~+~ ~ ,~~ _~ , •# ~~_ ' rat" _ iii~---7i, - ~ ~ ~ - ~~ •'r \ 1 ~ F.-~.~'~, . ~~~6 ~'. ~ ~ Ia/ .11.• val. ,. p ' K ~. : - ~ b .y ~~ Aj rlP.~~.§. - .. 1 ~ ~ `~ ~ {` ~ 1) BASIS Or i:OORDiNiaTcS iS ALASKA STATE 4 ,j_ ~ ~,OF q.f ~ ' ~ ~ ~ ~' q ~ _. ; ~ PLANE NAD 27 ZONE 4 FROM A DIRECT TIE - .. ,,~; ,. ' S ~ •~ ~P -~ ~ TO ADL NO. 31270. • ~ . 2) BASIS OF ELEVATION IS FROM TIDAL j `'a '•- . '~ ~ ~ ~ M IS MLLUv '~ ~ * 4 "~ * ~ +4, . • ` ~ a ~ ` °~' " OBSERVATION ON 9-22-93. DATU ALL ELEVATIONS SHOWN HEREON WERE ~ '~ ...... ..... ~ : ;t, ~ .~ , a ~' .. e ` . . ..A , .. TAKEN ON GROUND. 3) SECTION LINES SHOWN HEREON ARE ~, c^~ dA.. SZ)0[T wtCLAI!!Er ~ s , ~ , ~"` ~ ` ' ~ '~a `~, BAS =,:~ ~ti N~~~ ~ ~h~ ~ ~ v~l.'~~E~ •: 4928-S ~" -' ~ ` ~' ,~ ~ ~-~' ~, ~ , ~~ s. =fi FO A' ..... • ~ : ~ I SCALE 1 inch = 500 ft. ~, ~ ~ ~~ , ._ 0 500 750 1000 - ~` ~;;" ~i. . ~: e^; ',r0~~~``. _- 4 ~" . _ ... „ r _ . ~ ~ c 1 3.y. KALOA NO. 4 WELL AS-BUILT SURFACE LOCATION DIAGRAM IV~cLane Consulting Inc APPLICANT: EN PI AK G99669NG X 468PSOLDOTNA E ~~~ ~~~~~ ~~~~ ~~~ , O. BO VOICE: (907) 283-4218 FAX: (907) 283-3265 EMAIL: msmclaneC~nclanecg.com PROJECT NO. DRAWN BY: DATE: Sept. 12, 05 SEC. LINE LOCATION: OFFSETS: PROTRACTED SECTION 26 osso~s MSM 1146' FNL TOWNSHIP 11 NORTH, RANGE 12 WEST 1732' FWL SEWARD MERIDIAN, ALASKA Kaloa No. 4 Surface Location • Subject: Kaloa No. 4 Surface Location From: Stephen Davies <steve_davies@admin.state.ak.us> Date: Tue, 20 Dec 2005 07:57:03 -0900 To: Ed Jones <jejones@aurorapower.com> Dear Mr. Jones, I need your help to ensure that the Alaska Oil and Gas Conservation Commission's records concerning Kaloa No. 4 are accurate. Could you please provide the correct surface location for the well? I need coordinates specified from governmental section lines as well as coordinates in Alaska State Base Plane (Zone 4, NAD 27, Clarke 1866 spheroid). There is a discrepancy between the permitting and reporting forms provided by Aurora Gas, LLC to the Commission. Discussion On September 9, 2005, the Commission issued a permit to drill for Aurora's Kaloa No. 4 well. The permitted surface location for this well was 1121 feet from the north line and 1740 feet from the east line of Section 26, T11N, R12W, Seward Meridian. On September 19, 2005, the Commission received an application from Aurora requesting revision of the permit to drill for Kaloa No. 4 to a surface location of 1146 feet from the north line and 1732 feet from the east line in Section 26. Although the change is small, Alaska's regulations require that ANY change in surface location requires a revision to the permit to drill. On November 17 and again on December 6, 2005, the Commission received "Well Completion and Recompletion Report and Log" forms for Kaloa No. 4. Both of these forms list the location of the well as being 1121 feet from the north line and 1740 feet from the east line of Section 26, which is the originally permitted location of the well, not the revised location. Could you or someone on your staff please provide the proper coordinates to the Commission? Thank you for your help. Sincerely, Steve Davies Petroleum Geologist Alaska Oil and Gas Conservation Commission 907-793-1224 1 of 1 12/20/2005 7:57 AM • ~ DATA TRANSMITTAL Please reply to: AURORA GAS, LLC 2500 CITYWEST BLVD, STE. 2500 HOUSTON, TX 77042 ATTN: ANDY CLIFFORD State of Alaska Oil & Gas Conservation Commission 333 W. 7t1i Avenue Suite 100 Anchora¢e AK 99501 ATTENTION: Howard Okland Enclosed CD From Aurora Gas LLC Area Moquawkie Area Cook Inlet Alaska Date: 13 December, 2006 CD: 1. Kaloa #4 well data: PDS, PDF and LAS files for Directional Survey, Platform Express, Dipole Sonic Imager, Fullbore Micro-Imager (Unprocessed), plus LAS and PDF files for Horizon Mudlog data. ~,. ~- `; ;, TA BY SIGNING SENDING A COPY BACK TO AURORA GAS FOR O Received by: Date: AURORA GAS, LLC, 2500 CITYWEST BLVD, STE 2500, HOUSTON, TX 77042 TEL: 713-977-5799, FAX: 713-977-1347 aes-r~r ~~~r~ • n ~~V~i V ~l1 NOV ~. '~ Z0~5 November 12, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7~' Ave., Suite 100 Anchorage, Alaska 99501 Re: Final well completion report and operations summary: Kaloa #4 (API # 50-283-20115-00) Dear Mr. Norman, Afnsk~ Oii ~ Gas Cons. C~mmissior Anchorage Aurora Gas, LLC hereby submits the final well report, which covers the plug and abandon of Kaloa #4. Operations were completed on October 6, 2005. Pertinent information included under cover of this letter includes the following: 1) Form 10-407 "Well Completion Report and Log" - 2 copies. 2) Summary of daily well work and operations. 3) Wellbore schematic. Copies of electrical well logs and mud-logging reports will be submitted under separate cover. If you have any questions or require additional information, please contact Ed Jones of Aurora Gas, LLC at 277-1003 or Richard Tisch of Fairweather E&P Services, Inc at (907) 258-3446. Sin~ely, ~ f'~~ J.,~dvvard Jones utive Vice President ~~' Engineering -Operations cc: Jesse Mohrbacher Richard Tisch ~~. '~` ALA OIL AND WELL COMPLETION OR ~~~1I~[~ ~-EG~IVE~ STATE OF ALASKA ~~~ ~(~~~ N~V ~ -~ 2a~~ GAS CONSERVAT NCOM SION RECOM PL~I I V~'~~ ~Rl~aMti~9ilL&~ons.~ommission 1a. Well Status: Oil Gas Plugged ~ Abandoned ~ 20AAC 25.105 GINJ [] WINJ ~ WDSPL^ No. of Completions Suspended A 2oaac 2s.~ i o Other ell Class: Development ~ loratory Q Service ^ Str graphic Test 2. Operator Name: Aurora Gas, LLC 5. Date Comp., Susp., or Aband.: 06-Oct-05 ' 12. Permit to Drill tuber: 205-131 3. Address: 1400 West Benson Blvd, Suite 410 Anchorage, AK. 99503 6. Date Spudded: 13~ep-05 13. API N ber: 5 83-20115-00 ~ 4a. Location of Well (Governmental Section): 3~r~r2t~ L~=4... t~~~•'n~ - Surface: 1121' FNL, 1740' FEL, Sec.26, T11N, R12W, SM ~~ L-~ 7• Date TD Reached: 29-Sep-05 14. ell Name and Number: Kaloa #4 /. 3 Top of Productive Horizon: N/A 8. KB Elevation (ft): 211' MLLW 15. Field/Pool(s): Total Depth: 89' FNL, 165' FEL, Sec. 25, T11N, R12W, SM 9. Plug Back Depth( +TVD): To Surface Kaloa 4b. Location of Well (State Base Plane Coordinates): Surface: x- 260742 y- 2566987.7 Zone- 4 10. Total Dept D + TVD): MD 443 TVD 3700' 16. Property Designation: C-061393 TPI: x- y- Zone- 4 Total Depth: x- y- Zone- 4 11. Dept here SSSV Set: N/ 17. Land Use Permit: Ciri Lease 18. Directional Survey: Yes ~ No 19. ater Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: N/A 21. Logs Run: Schlumberger Hole Logs: LD Platform Express 9- -05, DSI / FMI 10-01-05 22. CASING, LINE AND CEMENTING RECORD CASING WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZ E CEMENTING RECORD AMOUNT FT TOP BOTTOM TOP BOTTOM PULLED 13-3/8 48# H-40 Surface 6T Surface 6T driven 9 5/8 40# K-55 Surface 668' Surface 668' 12 1/4 77 bbls14.5 ppg Class "G" cement to surface 23. Perforations open to Produc tion (MD + TV of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "n a"): SIZE DEPTH SET (MD) PACKER SET (MD) l NONE a ~ ~ ~ ? 25. ACID, FRA CTURE, CEMENT SQUEEZE, ETC. ~ ~ ~ DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ~~ ~ Surface to 171' 12.5 bbls of 15.8 ppg Class "G" cement ,~ ~ ` 493' to 590' top of retainer 7.5 bbls 15.8 ppg Class "G" cement ~ ~~ ~~/ 590' to 890' 19 bbls 15.8 ppg Class "G" cement 1700' to 2545' 46 + 5 bbls 15.8 ppg Class "G" cement 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): Date of Test: ours Tested: Production for Test Period Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Flow Tubing ~ Press. ?` Casing Press: Calculated 24-Hour Rate -i Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity -API (corr): 27. ~ CORE DATA Brief descri ion of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit co chips; if none, state "none". ,A~.,y,~„~„~~ r. _ ~~'~~' '< <~ .i --- ,- J ; y -s ~.. Form 10-407 Revised 12/2003 ~„~,~ ~ i ~jO~JTINUED ON REVERSE fi~ 28. GEOLOGIC MARKE 29. ORMATION TESTS ~ NAME M TVD Include and briefly su rize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". "None" 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: ~ J Printed Name: ~i~~i~G~GJ j~~-~JC,~ ~~.5 Title: ~,,~~(, ~ ~C y~JJ ~. --~ - Phone: ~f07`Z 7 7"~OD3 Date: ~ 2 ~ ~S signature: -- INSTRUCTIONS if - General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for 1 njection, Observation, or Other. Multiple completion. is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: True vertical thickness. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • WELL DRILLING AND COMPLETION REPORT Aur+~ra Gas, LLC Kaloa - 4 Tyonek, Alaska 11-October-2005 Aurora Gas, LLC Page 1 of 7 • Background Information: The Kaloa #4 well was permitted to be drilled as a natural gas exploration well by Aurora Gas, LLC, with approval given on August 26, 2005, PTD # 205-131. The well was drilled on a newly constructed pad, Kaloa #4 was drilled using the Aurora Well Services Rig #1. The well was spudded on September 13, 2005 and reached TD on September 29, 2005. Prior to rig mobilization and spud. The conductor was installed using the drill and drive technique with final conductor set depth at 82' KB. After successfully installing the conductor, the remainder of the drilling rig was moved to the site and rigged up to drill the Kaloa #4 well. The following well work summary details the drilling and completion work chronology. Dates indicated reflect date morning report(s) were received in office and reflect site activities over previous 24 hour period, i.e. 0700 hrs on day previous to 0700 hrs on date of report generation and submittal. Attachment I is a schematic of the well as completed this time. Work Summary and Daily Activities: The following operations took place on the dates indicated: 9/10/05 Lay down felt and Herculite, prep pad for setting in rig components. Mobilize in Aurora Well Service Rig #1 from the Aspen No. 1 well site. 9/11/05 Set matting boards, and spot rig modules on Kaloa #4. 9/12/05 Complete rig up on well site, rig accepted at midnight. 9/13/05 Repair flow line, repair #1 pump. Drill from 67' to 159'. Aurora Gas, LLC Page 2 of 7 • 9/14/05 Dri117 7/8" hole from 159' to 670'. Set back power swivel. POH and lay down singles, pick up 12 '/4" bit and BHA, RIH to 68', pick up swivel and break circulation. Attempt to open up hole to 12 1/4", there appears to be a pinched shoe, metal cutting at shakers with no other cuttings. Pull bit to surface and inspect, straight groves started on bottom of gauge protection of bit, no damage to cones, bearings or teeth. Change bit to XSC1 and RIH to and thru shoe, all OK. 9/15/05 Pull and inspect bit, some wear showing on bottom of gauge protection, RIH with RR 12 %4", tag shoe, ream and work through slowly, work until free of torque. Open hole to 12 1/4" from 68' to 427'. Circulate bottoms up and prep to pull bit. POH, all bearing shot on bit pulled. RIH with RR12 '/4", wash to bottom and open up hole from 427' to 454'. Pull single and replace leaky hose on power swivel. 9/16/05 Open up hole from 454' to 474'. Tighten nuts and bolts on power swivel. Open up hole from 474' to 494', stop and change out motor on hydraulic unit of power swivel. Open up hole from494' to 670', circulate bottoms up, run survey and set back swivel. Short trip to BHA at 380', run back to bottom and circulate bottoms up, POH. Lay down bit, near bit and prep for running 9 5/8" casing. Run 9 5/8" casing to bottom, rig up cement head and establish circulation. Rig up BJ Services and hold pre job safety meeting. Pump 15 bbl fresh water spacer, 77 bbls of 14.5 ppg cement, displace and bump plug as calculated. Test float and plug, OK. 9/17/05 Wait on cement, drain and flush stack, flowline, shakers and cement head. Disconnect trip tank lines, diverter lines and knife valve. Lay down mouse hole, remove excess bolts on diverter stack. Slack weight off casing and nipple down diverter stack, cut 9 5/8" and 13 3/8" casing. Preheat well head, make final cut on 9 5/8" casing and weld on head. Clean pits and dump mud while the well head cools. Clean gas buster line, rig up and test well head; small leak in weld. Preheat head, grind and fix weld, retest well head weld, test good. 9/18/05 Nipple down BOPS, choke line, Koomey lines and poor boy degasser. Test BOPS, choke manifold, kill line and floor valves. Pull test plug and set wear ring, lay down test joint, set mouse hole. Pick up bit, junk basket and near bit sub on 6" drill collars. RIH and tag float shoe at 620', pick up swivel. Finish mixing new mud, break circulation, circulate cement contaminated mud out of hole, rig up to test casing. 9/19/05 Test casing to 1500 psi. Drill out float collar, cement and float shoe. Displace hole with new mud weighing 9.4 ppg. Drill to 690', circulate bottoms up, line up and circulate thru choke. Perform formation integrity test to 15.4 EMW. POH laying down 6 1/4" drill Aurora Gas, LLC Page 3 of 7 • collars, install wear ring, pick up BHA and function test MWD. RIH to 690', drill and slide as directed from 690' to 863'. 9/20/05 Drill and slide for 863' to 1206', circulate bottoms up and short trip to shoe. Pick up swivel, ream 15' to bottom. Drill and slide from 1206' to 1488'. #1 mud pump down for new swab, circulate hole with #3 pump. Drill and slide from 1488' to 1536'. 9/21/05 Drill from 1536' to 1740', rod oiler on #1 mud pump down, drill from 1740' to 1766'. Check slow pump rate. Circulate bottoms up, survey, pump dry job and POH. Check bit, change jets to 2 -14s and 1 -18, change stabilizer lobes to 7.5 and change out MWD. RIH to 1733', ream to 1766', drill from 1766' to 1814'. Change liner gasket and tighten liner adapter nut on #1 mud pump. Drill from 1814' to 1976'. 9/22/05 Drill from 1976' to 2266'. Circulate hole clean, set swivel in shuck and short trip to 1641'. Circulate bottoms up, 200 units of gas, weight up to 9.7 ppg. Drill from 2226' to 2360', circulate hole clean, check for flow and pump dry job. Set swivel in shuck and POH to bit. Break out bit #6, make up bit #7, and change out MWD pulsar. RIH, test MWD, fill pipe and break circulation at 1500'. 9/23/05 RIH for short trip, pick up swivel and wash to bottom, circulate bottoms up and survey hole. Drill from 2360'to 2642'. Change swab on #1 pump (same swab and liner as before) Drill from 2642' to 2861', circulate bottoms up and short trip to 2250', circulate hole while repairing arm on power swivel. Drill form 2861'to 2892'. 9/24/05 Drill from 2892' to 3454'; circulate bottoms up and short trip to 2736', lots of coal and 850 units of gas. 9/25/05 Drill from 3454' to 3705', circulate bottoms up and POH. Stand back BHA and bit, clear the rig floor and rig up to test BOPS. Observe hole for losses and set test plug. Test BOPs; rams, choke and kill line valves, choke manifold, floor valves and kelly valve, all tested 250 / 3000 psi. Test annular 250 / 1500 psi. 9/26/05 Finish testing BOPS. Pick up bit #7 and BHA, RIH to 240', notice leak in bell nipple flange, and repair same. RIH to 578,' test mud pump, RIH to 3705' and ream last joint to bottom, circulate bottoms up, 1720 units of trip gas. Drill to 3821', replace swab and liner on mud pump (same swab/liner as before). Aurora Gas, LLC Page 4 of 7 • 9/27/05 Drill from 3821' to 3933'. Swab #2 washed out in OPI, repair same. Drill from 3933' to 4046'. Swab #3 in OPI washed out, repair same. Drill form 4046' to 4110', circulate bottoms up, set swivel back and short trip 10 stands to 3480'. RIH to bottom and drill from 4110' to 4120'. 9/28/05 Drill from 4120' to 4168', circulate bottoms up, mix and pump slug and stand back swivel. POH, change bit and orient MWD. RIH with BHA #10, drill form 4163' to 4330'. 9/29/05 Drill from 4340 to 4430', circulate and condition mud, wiper trip to 3830', circulate and ' condition mud. POH to shoe, tight spot at 890', monitor well and RIH to 4430'. Circulate and condition mud, mix and pump slug, stand back swivel and POH. Rack back collars and lay down bit, mud motor, stabilizer and MWD. Rig up Schlumberger wireline. 9/30/05 Finish rigging up Schlumberger, run in hole with Platform Express, logging tool would not go past 1680', attempt to work tool through tight area with no success. POH and rig down Schlumberger, lay down non-mag flex collars. Make up BHA and RIH, circulate and condition hole and mud, POH and rig up Schlumberger. RIH with Platform Express to 1680', tools will not go down hole, POH and reconfigure Schlumberger tools. RIH and log to 4418', POH and lay down Platform Express tools, pick and RIH with DSI, FMI to 4427', log out. 10/01/05 Run DSI-FMI on Schlumberger wireline, rig down Schlumberger. Wait on orders and repair hydraulic hose. RIH with BHA, come out laying down BHA. Make up mule shoe and RIH to 4153'. Reposition swivel and shuck; pump slug and POH laying down drill pipe. 10/02/05 Lay down drill pipe to 2466'. Mix and spot 7 bbl, 16 ppg heavy pill at 2450', continue to lay down drill pipe, spot mule shoe at 2350'. Rig BJ Services, pump 5 bbl spacer and test lines to 2000 psi, pump 46 bbls of Class "G" 15.8 ppg cement and 1.5 bbls of water, displace with 10 bbls mud. POH with 11 stands of pipe and reverse string clear of cement, WOC. RIH to top of plug at 1782', circulate and condition mud. Rig up BJ Services, pump 5 bbls water spacer and test lines to 2000' psi, pump 5 bbls Class "G" 15.8 ppg cement followed by 1 bbl of water, displace with 11 bbls of mud. Lay down 4 joints of drill pipe, reverse circulate string clear of cement and lay down 53 joints of drill pipe and break off mule shoe. Make up Weatherford's 9 5/8" cement retainer. Aurora Gas, LLC Page S of 7 • 10/03/05 RIH and set 9 5/8" retainer at 590', establish injection rate at .75 bpm, broke down at 1000 psi, FCP at .75 bpm 525 psi, FCP at 2 bpm 990 psi, FCP at 3 bpm 800psi. POH with cement retainer and running tool, close blind rams and pressure test retainer to 1500 psi for 15 minutes, blow down choke manifold. RIH and stab into retainer at 590'. Rig up BJ Services and test lines, pump 19 bbls of 15.8 ppg Class "G" cement, unsting from retainer and pump 7.5 bbl of cement. POH and stand back 3 stands, lay down remaining drill pipe, pressure test casing to 1500 psi. Rig down power swivel and run 3 stands of drill pipe in the hole. Rig up BJ Services, pressure test lines and pump V15 bbls of cement to surface, POH laying down remainder of drill pipe. Nipple down BOPE and clean up cellar area. Clean mud pits, tear down and winterize manifold. 10/04/05 Clean pits and choke manifold, rig down floor and prep derrick to lower. Rig down pit system and brine tank. Move sub-base, pits and some support buildings, stage at Kaloa #4 airstrip. 10/05/05 Rig down and prep mud pumps, re-hang operator controls, ready conex for move, ready boiler house for move. Pump cellar clean, pump off water tanks, transfer fuel and rig down fuel tank. Cut 54' of drilling line, repair derrick board, pull electric wires and rig down lighting. Release guide and load lines, retract top section of derrick and secure blocks. Lower derrick, roll up lines and secure for move. Move fuel house, boiler house, hydraulic unit, parts house and mud pumps. Pick up matting boards, skim and clean liner. Prep BOP's for move, drive rig off base, disconnect heat duct and secure. Cut and fold liner, prep cellar for final casing cut, pull mouse hole sleeve. 10/06/05 Cut and fold liner, load matts on trailer, pick up felt, clean cement from cellar, cut casing 5' below ground level. Aurora Gas, LLC Page 6 of 7 • • Kaloa #4 Current Well Configuration 10/11/OS P & A Marker FIGU Top of Cement at 4 Retainer at 590' Cement from 595' Drilling Mud Cement in tw 1782'to 2545 1782' to 1700 ement Ylug at surface in 9 5/8" 3 3/8" and 9 5/8" casing strings below Ground Level ' Structural Conductor to refusal, 67' 9 5/8" 75# J-55 casing set at 668' Cemented with 77 bbls of 14.5 ppg "G", good returns indicated at surface 31' MD (3700' TVD) Aurora Gas, LLC Page 7 of 7 RE: Kaloa #4 and TMCU #2 t • • Subject: RE haloa #4 and TMCU #2 From: Jes~c [Mohrbacher <jessc(u fair«~eathcr.com? Date: Mon, ~-~ Oct 20(1> 1(,:?-x:54 -0S(ii7 Ta: Thomas Maunder ~~=lommaundcr~u'admin.state.ak.us ~-, Ecf .tones ~~jcjonesrci'aurorapo~wer.com== CC: Jim Re~~~~ ~~-Jii71_re~~r~r~idmin.srate.ak.us=~..Tohn Spauldill~~ `~lo}1n spauldin«iu?admin.state.ak.t«=, Rigsite~ aurora ~ ~aurorawellsite(u~yahoo.com-. "Richard E,. Tisch" ~ -richard~u:(ailtiveather.com~%, John $reitmcier ~~-john.E~rcitmcirn~i)fainvcathcr.com= Hi Tom, ~S- t3 ~ Regarding the TMCU#2 knife valve(s), the rig crew remedied the slow closing of the valves prior to spud per John Spaulding's directive. Also, I have a call in to the rig to round up a copy of the diverter test report and will have that sent in as soon as I can contact them. On Kaloa 4, there was water in the cellar excavation prior to and after cutoff of the well but no bubbling was present. Then came a significant rainstorm just prior to John Spaulding's site visit and the bubbling in the excavation was present. This phenomena may be the result of shallow swamp gas being displaced by water percolation. This situation has been observed on other wells in wetland areas on the west side of Cook Inlet. I suggested that the cellar be allowed to breath for a week or so and then we would go back and look for the bubbling and/or check the area around the casing with a gas meter. We'll let you know the results of this next survey after we have a look at the Kaloa 4 well, probably during WOC time on the surface string for TMCU2 which will be within the next day. Please call with any questions. Regards ~; Jesse Mohrbacher -----Original Message----- From: Thomas Maunder [mailto:tom maur_der~~admin.state.ak.usl Sent: Monday, October 24, 2005 2:43 PM To: Jesse Mohrbacher; Ed Jones Cc: Jim Regg; John Spaulding Subject: Kaloa #4 and TMCU #2 Jesse and Ed, John Spaulding performed inspections at both of these locations last week and I am informed there are a couple of issues that need attention. I do not have John's reports yet on these matters otherwise I would have included them. 1. Kaloa #4--This well was recently drilled and the Plugged and Abandoned. John informs us that he observed "some bubbling" around the conductor.. 2. Three Mile Creek Unit #2--This well was recently spudded. When John conducted the diverter inspection, the knife blade did not completely open before the "bag" was closed. Would you please investigate these issues and provide comments back to us. Also, for any diverter or BOP test, the operator should be submitting a report of the test regardless of an Inspector being there. Thus far, we have not seen a diverter test report from the rig. 1 of 2 10/25/2005 8:49 AM RE: Kaloa #4 and TMCU #2 Thanks in advance for your with any questions. Tom Maunder, PE AOGCC • • attention to these matters. Call or message 2 of 2 10/25/2005 8:49 AM u MEMORANDUM TO: FROM: Jim Regg P. I. Supervisor • State of Alaska Alaska Oil and Gas Conservation Commission John Spaulding, Petroleum Inspector DATE: October 18, 2005 a ate- ~ 3 ~ SUBJECT: urface Cement Plug Koloa Wells 1 & 4 Aurora Well Services October 18. 2005: I traveled to Beluga, AK to witness the surface cement plugs in preparation for abandonment of the above noted wells. Koloa 1 was found to have cement to surface in both the casing strings. I recommend this well to have the casing cap to be welded on and abandoned. Subsequent location clearance at a later date. Koloa 4 appeared to have gas bubbles coming up in the cellar area as well as the annular area of the well. Please note the attached pictures. 1 do not recommend this well for final abandonment at this time. I am deferring judgment to the AOGCC engineering staff. '~ ~ } ~} ~ , 1` ' r} 11 `t le, i*< V SUMMARY; Attachments: NON-CONFIDENTIAL 2005-1018_Surr P&A_Koloa4Jhs.doc ~ i Kaloa #4 (Aurora) Location Clearance Inspection Photos by AOGCC Inspector John Spaulding October 18, 2005 Casing Stub; No Cement to Surface in Annulus - Kaloa #4 Outside of Conductor - Kaloa #4 Marker Plate - Kaloa #4 2005-1018_Surf P8~A_Koloa4Jhs.doc L J r~ u DATA TRANSMITTAL Please reply to: AURORA GAS, LLC 10333 RICHMOND, STE. 710 HOUSTON, TX 77042 ATTN: ANDY CLIFFORD Anchorage, AK 99501 ATTENTION: Howard Okland Enclosed CD and Paper Prints From Aurora Gas LLC Area Moquawkie Area, Cook Inlet, Alaska Date: 17 October, 2005 1. Kaloa #4 well data: PDS and PDF files for Directional Survey, Platform Express, Dipole Sonic Imager, Fullbore Micro-Imager (Unprocessed). 2. KaIoa #4 well data:_ LAS and PDF files for Horizon Mudlog data. Pier Prints: 1. Kaloa #4 well data: Platform Express 2"/100' plus 5"/100' MD, Platform Express 2"/100' plus 5"/100' TVD, Directional Survey, Dipole Sonic Imager 5"/100', Fullbore Micro-Imager (Unprocessed) 5"/100', Horizon Mudlog 2"/100' MD, Horizon Mudlog 2" /100' MD-DP, Horizon Mudlog 2"/100' TVD. PLEASE ACKNOWLEDGE RECEIPT OF DATA BY SIGNING BELOW AND AURORA GAS, LLC, 10333 RICHMOND, STE 710, HOUSTON, TX 77042 TEL: 713-977-5799, FAX: 713-977-1347 2a>'~i3! ~~~ Date: I ? ~ 6 ~ 1 r E & P SERVICES, INC. October 10, 2005 Mr. John Norman, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 ArGh€rrrW~,e -~~_~-~~ RE: Final Weekly Report of Operations: Kaloa # 4 ~ Dear Mr. Norman, Aurora Gas, LLC hereby submits its report of operations for the week of October 1 thru October 7, 2005 for its Kaloa #4 well. If you have any questions or require additional information, please contact Ed Jones, Aurora Gas, LLC at 277-1003 or Richard Tisch at 258-3446. Sincerely, AURORA GAS, LLC Richard E. Tisch, Fairweather E&P Services, Inc. for J. Edward Jones Executive Vice President Engineering -Operations cc: Jesse Mohrbacher • • k era ~~; ~ ~' a ,.,~` :_ 2000 East 88th Avenue • Anchorage, Alaska 99507 • (907) 258-3446 • FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505 • Houston, Texas 77060 • (281) 445-5711 • FAX (281) 445-3388 • • Aurora Gas, LLC Kaloa 4 Well Weekly Operations Report October 1- 7, 2005 ~-~ ~ -- The following operations took place on the dates indicated: 10/Ol/OS Run DSI-FMI on Schlumberger wireline, rig down Schlumberger. Wait on orders and repair hydraulic hose. RIH with BHA, come out laying down BHA. Make up mule shoe and RIH to 4153'. Reposition swivel and shuck; pump slug and POH laying down drill pipe. 10/02/05 Lay down drill pipe to 2466'. Mix and spot 7 bbl, 16 ppg heavy pill at 2450', continue to lay down drill pipe, spot mule shoe at 2350'. Rig BJ Services, pump 5 bbl spacer and test lines to 2000 psi, pump 46 bbls of Class "G" 15.8 ppg cement and 1.5 bbls of water, displace with 10 bbls mud. POH with 11 stands of pipe and reverse string clear of cement, WOC. RIH to top of plug at 1782', circulate and condition mud. Rig up BJ Services, pump 5 bbls water spacer and test lines to 2000' psi, pump 5 bbls Class "G" 15.8 ppg cement followed by 1 bbl of water, displace with 11 bbls of mud. Lay down 4 joints of drill pipe, reverse circulate string clear of cement and lay down 53 joints of drill pipe and break off mule shoe. Make up Weatherford's 9 5/8" cement retainer. 10/03/05 RIH and set 9 5/8" retainer at 590', establish injection rate at .75 bpm, brake down at 1000 psi, FCP at .75 bpm 525 psi, FCP at 2 bpm 990 psi, FCP at 3 bpm 800psi. POH with cement retainer and running tool, close blind rams and pressure test retainer to 1500 psi for 15 minutes, blow down choke manifold. RIH and stab into retainer at 590'. Rig up BJ Services and test lines, pump 19 bbls of 15.8 ppg Class "G" cement, unsting from retainer and pump 7.5 bbl of cement. POH and stand back 3 stands, lay down remaining drill pipe, pressure test casing to 1500 psi. Rig down power swivel and run 3 stands of drill pipe in the hole. Rig up BJ Services, pressure test lines and pump 15 bbls of cement to surface, POH laying down remainder of drill pipe. Nipple down BOPE and clean up cellar area. Clean mud pits, tear down and winterize manifold. 10/04/05 Clean pits and choke manifold, rig down floor and prep derrick to lower. Rig down pit system and brine tank. Move sub-base, pits and some support buildings, stage at Kaloa #4 airstrip. • • 10/05/05 Rig down and prep mud pumps, re-hang operator controls, ready conex for move, ready boiler house for move. Pump cellar clean, pump off water tanks, transfer fuel and rig down fuel tank. Cut 54' of drilling line, repair derrick board, pull electric wires and rig down lighting. Release guide and load lines, retract top section of derrick and secure blocks. Lower derrick, roll up lines and secure for move. Move fuel house, boiler house, hydraulic unit, parts house and mud pumps. Pick up matting boards, skim and clean liner. Prep BOP's for move, drive rig off base, disconnect heat duct and secure. Cut and fold liner, prep cellar for final casing cut, pull mouse hole sleeve. 10/06/05 Cut and fold liner, load matts on trailer, pick up felt, clean cement from cellar, cut casing 5' below ground level. • • ~ 3 ,iy~ ' ~~~ ' '~ ~ ~ ~ ~ FRANK H. MURKOWSKI, GOVERNOR /~--~1~~r ~~ OI~ ~ ~7 ~ 333 W. T" AVENUE, SUITE 100 CO1~T5ERQA~`IO1Q COh'II-iISSIOI~T s' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Ed Jones FAx (907> 27s-7s42 Executive Vice President of Operations Aurora Gas, LLC 1400 W. Benson Blvd, Ste 410 Anchorage, AK 99503 Re: Kaloa #4 Sundry Number: 305-305 Dear Mr. Jones: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this day of October, 2005 Encl. STATE OF ALASKA 77~~ ~L / ALAS IL AND GAS CONSERVATION C~JMMIS~G ~ QCT 4 ~ ZO~~ ~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend Operational shutdown Perforate Waiver Other Anchorage Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Aurora Gas, LLC Development ^ Exploratory ^~ 205-131 3. Address: Stratigraphic ^ Service ^ 6. API Number: 1400 W. Benson Blvd, Ste 410, Anchorage, AK 99503 50-283-20115-00 7. KB Elevation (ft): 9. Well Name and Number: 211.5' MLLW Kaloa #4 8. Property Designation: 10. Field/Pools(s): C-061393 Kaloa 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 4431 3700.5 4431 3700.5 none none Casing Length Size MD ND Burst Collapse Structural 80 13.375 80 80 NA NA Conductor Surface 655 9.625 670 670 3520 2020 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type: Packers and SSSV MD (ft): 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory Q Development ^ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/1/2005 Oil ^ Gas ^ Plugged Q Abandoned Q 16. Verbal Approval: i,~~~-- Date: 1-Oct WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Winton Aubert 17. I hereby certify lhat the foregoing is true and correct to the best of my knowledge. Contact Printed Name Ed J ones Title Executive Vice President of Operations Signature ,~~ ~,,,- ,TG, J-Phone 907-277-1003 Date 3-Oct-05 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 05~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other. D ~ ~F~~ Q C I$ ~P ~~a~ Subsequent Fo equ' Approve APPROVED BY /0 ~ /'~ ~/ COMMISSIONER THE COMMISSION Date: ` (/ Alaska Oil & Cas CpnaR ~ammia~idn Form 10-403 Revised 07/2005 ~ ~ ~ ~ ~ ~ A ~ Submit in Duplicate • AURORA GAS, LLC. Kaloa #4 P&A Procedure Note: Inform AOGCC inspector of plans to plug and abandon well in order to give inspector ample opportunity to witness all or part of the abandonment. Open Hole Plug RIH w! OEDP to 2,350'MD and place a balanced cement plug across the interval 1,750'MD to 2,350'MD to isolate the potentially gas-bearing interval indicated on logs at 1,860'MD to 2,250'MD. Pull one stand above cement, reverse out and POH. Casing /Open Hole Segregation Plug M/U a 9-5/8" cement retainer and stinger and RIH. Set retainer at 590'MD (75' above the 9-5/8" casing shoe) and establish injection below it. Un-sting from the retainer and pressure test above it to 1,500 psi for ten minutes to ensure retainer has set and sealed. Mix and pump 20 bbls of Class G cement and displace to the stinger. Sting into retainer and pump 15 bbls through it. Un- sting from the retainer and deposit the remaining 5 bbls on top of the retainer. Pull one stand above cement, reverse out and POH, laying down all except 200' of drill pipe. Surface Plug Install a 9-5/8" cementing wiper plug in the 9-5/8" casing and push it to 200' with tubing or drill pipe. Fill the 9-5/8" casing from the cementing plug to the surface with cement. L/D drill pipe/tubing. Wellhead Abandonment and Well Marker NJD BOP stack and drilling rig and move to the next drilling location. N/D wellhead and send in to vendor for servicing for re-use. Excavate around cellar. Remove cellar and cut off all casing strings at least 5' below ground level. Check 9-5/8" casing and outer annuli for cement to surface. Top offany voids with cement. Weld on marker plate as follows: Plate to be 1/4" steel cut in a circle measuring 18" in diameter with the following information bead welded to one side: Aurora Gas, LLC Kaloa #4 PTD # 205-131 API # 50-283-20115-00 Place the plate, wording side up, over the cut-ff casing subs and weld to the outer casing string. Fill in excavation, including casing stubs w/ marker plate, level pad and clean up all debris after rig and .other drilling equipment has been demobed. 1 • E & P SERVICES, INC. ' September 29, 2005 Mr. John Norman, Chair Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: Weekly Report of Operations: Kaloa # 4 Alaska ~i~ ,& G~~ laQr~s. CO-T)R11,Px1AE ~r~chotage Dear Mr. Norman, / ~' ~~ Aurora Gas, .LLC hereby submits its .report of operations for the week of September 10 thru September 16, 2005 for its Kaloa #4 well. If you have any questions or require additional information, please contact Ed Jones, Aurora Gas, LLC at 277-1003 or Richard Tisch at 258-3446. Sincerely, AURORA GAS, LLC ~ '~ ~~ ~- /~ Richar~ E. Tisch, Fairweather E&P Services, Inc. for J. Edward Jones Executive Vice President Engineering -Operations cc: Jesse Mohrbacher 2000 East 88th Avenue • Anchorage, Alaska 99507 • (907) 258-3446 • FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505 • Houston, Texas 77060 • (281) 445-5711 • FAX (281) 445-3388 • Aurora Gas, LLC Kaloa 4 Well Weekly .Operations Report September 10 -16, 2005 The following operations took place on the dates indicated: Alaska (fat ~ Gay Gans, Cammssior~ Anchorage 9/10/05 Lay down felt and Herculite, prep pad for setting in rig components. Mobilize in Aurora Well Service Rig #1 from Aspen No. 1 wellsite. 9/11/05 ~ ~ ~, Set matting boards, and spot rig modules on Kaloa #4. 9/12/05 Complete rig up on well site, rig accepted at midnight. 9113!05 Repair flow line, repair #1 pump. Drill from 67' to 159'. 9/14/05 Drill 7 7/8" hole from 159' to 670'. Set back power swivel. POH and lay down singles, pick up 12 1/a" bit and BHA, RIH to 68', pick up swivel and break circulation. Attempt to open up hole to 12 1/4", there appears to be a pinched shoe, metal cutting at shakers with no other cuttings. Pull bit. to surface .and inspect, straight groves started on bottom of gauge protection of bit, no damage to cones, bearings or teeth. Change bit to XSC1 and RIH to and thru shoe, all OK. 9/15/05 Pull and inspect bit, some wear showing on bottom of gauge protection, RIH with RR 12 '/4", tag shoe, ream and work through slowly, work until free of torque. Open hole to 12 '/4" from 68' to 427'. Circulate bottoms up and prep to pull bit. POH, all bearing shot on bit pulled. RIH with RRl2 1/4", wash to bottom and open up hole from 427' to 454'. Pull single and replace leaky hose on power swivel. 9/16/05 Open up hole from 454' to 474'. Tighten nuts and bolts on power swivel. Open up hole from 474' to 494',. stop and change out motor on hydraulic unit of power swivel. Open up hole from494' to '670', circulate bottoms up, run survey .and set back swivel. Short trip to BHA at 380', run back to bottom and circulate bottoms up, POH. Lay down bit, near bit and prep for running 9 5/8" casing. Run 9 5/8" casing to bottom, rig up cement head and establish circulation. Rig up BJ Services and hold pre job safety meeting. Pump 15 bbl fresh water. spacer, 77 bbls of 14.5. ppg cement, displace and bump plug as calculated. Test float and plug, OK. • s ~.. v I ~ ~ i r 'mow °,~ ~i ~ ~ ~~. ~rmq ~ Y'q 1 1 ~ ~ ~ ~ ~ i1 yg 1 ~ a~ ~ ~ „ - ~ y l~ ~ 3 ~ ~ ~ J { ALASKA OIL A1~TD GAS CO1~T5ERQATI011T COMN-IISSIOIQ J. Edward Jones Executive vice President of Operations and Engineering Aurora Gas, LLC 1400 West Benson Blvd, Suite 410 Anchorage, Alaska 99503 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Kaloa #4 Aurora Gas, LLC Permit No: 205-131 Surface Location: 1146' FNL, 1732' FEL, SEC. 26, T11N, R12W, SM Bottomhole Location: 89' FNL, 165' FWL, SEC. 25, T11N, R12W, SM Dear Mr. Jones: Enclosed is the approved application for the revised permit to drill for the above referenced exploration well. This revision is necessary due to the change of surface location from 1121' FNL, 1740' FEL, SEC. 26, T11N, R12W, SM to 1146' FNL, 1732' FEL, SEC. 26, T11N, R12W, SM. This permit replaces the permit originally issued to you on September 9, 2005 and that permit is null and void. Because of the potential for encountering shallow gas-bearing sands, gas detection, PVT, and mud logging equipment must be fully operational prior to drilling out of the surface conductor pipe. Samples and a mud log are not required for Kaloa #4. Samples and a mud log were acquired across the same geologic section in nearby exploratory well Albert Kaloa # 1. A mudlog was also recorded in nearby well Kaloa #2. A spacing exception is required to drill, test and operate Kaloa #4. Testing or regular production of hydrocarbons from any reservoir interval common to existing gas production well Kaloa #2 is prohibited until the Commission approves a spacing exception. Aurora Gas, LLC assumes all liability and risk of expense if a spacing exception is not granted. This permit to drill 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. • ~ Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation. or suspension of the permit. Please provide at least twenty- four (24) .hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this!!r'day of September, 2005 cc: Department of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMION PERMIT TO DRILL 20 AAC 25.005 ~1'~ 1a. Type of Work: Drip ^ ftednll ^ Reentry ^ 1b. Current Well Ciass: Exploratory ^ Development Oii ^ Mupiple Zone ^ Stratigraphic Test ^ Service ^ Development Gas ^ Single Zone ^ 2.Operator Name: Aurora Gas, LLC 5. Bond: Blanket ~ Single Well ^ Bork No- NZS 429815 11. We[I Name and Number: Kaloa No. 4 ' 3. Address: 1400 W. Benson Blvd, Ste 410, Andwrage, AK 99503 6. Proposed Depth: MD: 4730' ~~ 4000' 12. Field/Pool{s): 4a. Location of Wep (Governmental Section): Surface: ~ 1146' FNL, 1732' FEL, Sec 26, T11N, R72W, SM 7. Property Designation: C-061393 Kaloa Top of Productive Horizon: ' 381' FNL, 39T FEL, Sec 26, T11 N, R12W, SM (2750' TVD) 8. Land Use Permit: Private '13. Approximate Spud Date: 9/1312005 Total Depth: 89' FNL, 165' FWL, Sec 25, Tt 1 N, R12W, SM (4000` TVD) 9. Acres in Property: 3435 14. Distance to Nearest Property: 1121 ' ' 4b. Location of Well (State Base Plane Coordinates): Surface:x- 260750 ~ y- 2566963 ~ Zone- 4 10. KB Elevation - 211-5' Above MLLW (Height above GL): 14.5 15. Distance t0 Nearest WeII Within Poolc 1566 ft at TOP 16. Deviated wells: Kickoff depth: 660 feet Maximum Hole Angle: 43 degrees ~ 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1840 psig ' Surface: 1400 psig i 18- Casing Program: Size Specfications Setting Depth Top Bottom Quantity of Cement e.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD {including stage data) Driven 13 318" 54.5 J-55 Welded 90 0 ' 0 90 90 'Driven 12 1/4" 9 5/$" 36 J-55 BTC 625-5 0 0 640 ~ 640 74.5 bbls @ 100 % OH Excess 7 718" 5 112" 15.5 J-55 BTC 4715.5 0 0 4730 ~ 4000 190 bbls ~ 25% OH Excess 19. PRESENT WELL CONDITION SUMMARY (To be tx>lrrpleted for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND {tt): Plugs (measured): Effect. Depth MD (tt): Effect. Depth TVD (tt): Junk {measured): Casing Length Size Cerrrent Volume MD ND Structural Conductor Surface Inteiate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (tt): 20. Attachments: Filing Fee f BOP Sketch. Drilling Program ~ Time v. Depth Plot J Shallow Hazard Analysis Property Plat 0 Diverter Sketch ^ Seabed Report ^ Drlling Fluid Program ^ 20 AAC 25.050 requirements ^ 21. Verbal Approval: Commission Representative: Date 22- I hereby certify that the foregoing is true and correct to the best of my knowledge- Contact Printed Name J. Edward Jones Title Aurora Gas, LLC Signature Phone 907-277-1003 Date 16-Sep-05 Commission Use Only PemtR to Drill Number. ~ ~ ~ API Nu r: c~2 ~v3"~ ~f~'Vd Permit r vaI Date: ~ See cover letter for other requirements. Conditions of approval metes wired Yes ^ No ~'" Mud keg required Yes ^ No gen ulfide measures Yes ^ No ~ Directional survey required Yes ~ No ^ Other- Q Q ~ ~ES,O- , APPROVED BY Approv THE COMMISSION Date: g ,~ Fo -40 vis /20 ubmit inDuplicate Kaloa 4 Surface Location Subject: Kalua 4 Surface Locati~in From: Step}~~n ~)a~~ie~ ~tcve_da~i~~<<nadmin.state .ikus% Date: Tlni, 1 ~ Sep i ~U 1 h: ;<): ,9 -000 To: jcsse(cr!1air~~catt~cr.corl~ Jesse, Please submit a revised 10-401 form with the correct Section line footages and X, Y coordinates. Please fax or email the revised for to the Commission, and briefly state on the cover letter the reason for the change (surface obstacle, surveyor error, etc.). Thanks, Steve Davies Aalska Oil & Gas Conservation Commission -------- Original Message -------- Subject: kaloa 4 surface location Date: Thu, 15 Sep 2005 16:14:48 -0800 From: Jesse Mohrbacher <jesse~fai_rweather.ccm> To: Winton Aubert <=rrinton aube.rtG~admin.state.ak.us> Hi Winton, the permitted Kaloa 4 surface location is the following: X = 260742, y = 2566988, zone 4. I just received a surveyors drawing that puts it at x=260750, y=2566963. Is this a big enough difference to require any paperwork at this time or save it until the 10-407? We are currently opening our pilot hole to 12.25" with surface TD at 670'. Regards, Jesse Mohrbacher Fairweather E&P Services, Inc. 2000 East 88th Avenue, Suite 200 Anchorage, AK 99507 907-258-3446 650 N Sam Houston Pkwy E, Suite 505 Houston, TX 77060 281-445-5711 i ~~ 1 of 1 9/26/2005 11:15 AM WELL PERMIT CHECKLIST Field 8 Pool ALBERT KALOA, UNDEFINED GAS -40500 Well Name: KALOA 4 Program EXP Well bore seg ^ PTD#:2051310 Company AURORA GAS LLC Initial Class/1-ype EXP 11-OIL GeoArea 820 Unit OnlOff Shore On Annular Disposal ^ Administration 1 Permitfee attached_ _ _ - _ - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ - - - 9-26.05: Application_noting_change of surface_loeation_8' E and 25' $ of previously permitted location.- . - - - 2 Lease number appropriate, _ _ - - - - . - ... - . Yes _ Remaining_ program remains unchanged from "' I permitted program._ _ _ CIRI Lease C06t393 _ . - _ - _ _ ~ 3 Unique well-name and number---- -- ------ -- ----- ---- --- - Yes- ..-...-- ------ --- ----------...------- - "L- -- - - --- 4 Well located in a_defnedpool_____ _____________________ ___-_..-_- No-- ----__Exploratorystep-outwell__--____________---_,__-___ _-,__ ____ _,-_ ._ 5 Well located proper distance from drilling unit-b-oundary_ - - - - . - - . - No_ - - _ . Drilling unit is govt section: willbe 2nd produce[ in S, 25. Nearby Kaloa 2 has been_ongas prod sipce_10l04 6 Well located proper distance from other wells_ _ - - _ No_ _ -Reg. 25.055 stipu_lates_>3,0~0' to nearest gas well in pool._ This well_will be_ 1,500'_f[om_ Kaloa #2 producer. _ . , 7 Sufficient acreageayailablein_drillingunit---------- -------_ ..-_--__..-- No_- -_---_Willbe2pdproducer,inS._26,_-_.___--___--_-_--__---___---.___-.-_-.-_--- 8 If_deyiated,is-we_Ilboreplat_included-_-------------------- ------------ Yes_ __---_____-.---___.--.-__--.---____..__.-.__- --------------------------- 9 Oper_atorgnlyaffectedpafij____--____-_,___--___ ---___--- Yes- -------------- -- - -- - - - - 10 Operatorhas_appropriatebopd in force--------------------- ------------ Yes. --_-.-Letterofc[edik..-.--..-.--_---_.-__._.--_-.._--_-.._.._._.----.-_-..---- 11 Permit_canbeissuedwithoutconseryatignorder__------------- -----_ No__ ___-______-___._--___-.___-__--.__--___.-_--.---------.--- Appr Date 12 Permiteanbeissuedwithoutadministrative_approval-___________ ______ _____ Yes_ ___-_____-_____.-_--__...---__-_.-__._-__...__-.-_-.-.--_-.-__--_-- SFD 9126!2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Orde[ # (put1O# in_comments)_ (For- NA_ - - .. - . - - ... . _ - .. - - - - - - - -- - - - - -- - - - - - - - - - - 15 All wells within 1/4_mile ar@a.of review identified (For service well gnly)_ _ _ _ _ __ _ _ _ _ _ _ _ _ NA_ _ _ _ - - - _ _ _ _ _ _ ... _ _ _ - .... - - - .. _ 16 Pre-produced injector duration of pre productionf_essthan3months_(Forsetvicewellonly)__ NA-- ----------------__-.._____--___.-____-.---__.-__---.-_..-____--_--_ 17 ACMP_Finding of Consistency_h_as been issued_fo[this project - . , _ - - - - - - Yes _ _ _ - - ACMP:- No Reu_iewRequired letter issued on Oct..-21, 2003._ _ _ _ _ . Engineering 18 Copductorst[ing_provrded_______________________---__ -.-_-__ Yes 9.. -..-. -- 13-3!8" - -- - ----------- 19 Surface casingprotects all_known USDWs - . - - Yes _ - _ - - Surface & production casing will be cemented back_to surface, protecing any freshwater sands._Sfd - 20 CMT_vgl,adequate_tocireulateonconductor&surf_csg____________ ____________ Yes_ _____Adequateexcess,______----______-____-..___--____.-__.--_.----_--.-_-. 21 CMT_vol_ adequate_to tie-in long string to surf cs9- - - - - - - - Yes - - - - - - - - . 22 C_MT_willcoverallknownpro_ductiyehorizon_s_________________ ____________ Yes_ _______-__-____-_-____..-.._____..__---.-__--____..__--.__.___-_.--. 23 Casing designs adequateforC,T,B&_permafrost-------------- ------------ Yes- -----------.---------------------------------------------------_ 24 Adequate tankage_o_r reserye pit - - - - - - - - - - - - Yes - - - AW$ 7: - - - - - - - - - - - - 25 Ifa_re-drill,has_a10.403for abandonment beep approved__________ ____________ NA__ ____-_Newwell,_,-,____________-_____---__.---__.-____.-_--.--___-__-.-_- 26 Adequatewellboreseparaticnproposed-------------- ----- ---- ---- Yes- ------- -- ------------- ------------- ------------- --------- --- --- 27 Ifdiverterrequired,doesitmeetregulations__,---__-.-___.- ____--.-__ Yes_ -____Pilothole planned_______________-___----__.._ ---------------------------- Appr Date 28 Drillingfluid-programschematic&equiplistadequate____.-__- ____...__ YeS- ______MaxMW_10,0-ppg.-___-_---__-_.__-_._-------------_.__---.__.-__.. TEM 9/2612005 29 BOPES,dotheymeetregulation__,--___---___-__ .__--___-_ Yes- -------------------------------------------------.----.------------- (~(~ ' 30 BOPE_pressratingappropriate;testko-(pu_tpsigincomments)_-______ -_____--__ Yes_ -_-___Testto3000psi._MSP 1400 psi_________________________--__..-.-__--_-____-__. ~ `~`;(~1 '~ 31 Choke manifold complieswlAPI_RP-53(M_ay84)_____,-__-_____ ____,_-____ Yes_ _____________-______-_____._____.-.-__..-____--__-_.___---__---__.- 32 Work willgccu[withoutoperationshutdow_n_,_______________ _______-___ Yes- ______--.____,-_______-______--___-.-_.-__.____..__-.-..__.-__-_.--__-- 33 Is presence.of H2S gas_probable - - - N~- - - - - - - - - - - - - - - - - 34 Mechanical condition of wells within AORyerifed(Fo[servicewellonly)__ ____________ NA__ __--____.--_-__---_--__..---____---__.----_-..__-.._-.---__-.-__.---- Geology 35 Permit-can be issuedwlohyd[ogen_sulfidemeasures-_-___--____ ____________ Yes_ ______.-----_-_-..___-__--..-___-..__-.---___--.___-.---_-.-___.-_---.-- 36 Data_presepted on_ potential overpressure zones _ - _ _ _ Yes . _ - Recent, nearby Kaloa 2 indicates 4.46 psilft (8.9 ppg EMW)_gradient. Wilt be_d_rilled with 9,8-10,0_ppg mud._ _ . _ Appr Date 37 Seismic analysis_ of shallow gas-zones_ - _ ----------- --------- No_ - _ Mudloggers and H2$Igas detection equipment will be used during afl drilling operations. _ - .. - - . _ . - - ---- SFD 9/26!2005 38 Seabed condition survey_(if off-shore) - _ - .. _ - - - .. - - . . _ _ - ... - N_A.. _ - 39 Contact namelphone far weekly progress-repolts [exploratory oply]_ - _ _ - _ _ - Yes _ - - . - Duane Vaagen, 907-356-3446 - - - - _ _ _ - - - - - - - - - - - - - --- - - -- - - Geologic Engineering c Date Date: Date 9-26-05: Application noting change of surface location 8' E and 25' S of previously permitted location. Remaining program Commissioner: Commissioner: is er remains unchanged from original permitted program. SPACING EXCEPTION NEEDED. Mudlog and samples not required DTS CPF ! ~ ~ as nearby Albert Kaloa 1 has mudlog and cuttings samples from 36' to 13600'. Nearby Kaloa 2 was recently mudlogged from SFD 116'to3720' . ~~'' ~ ~ r°°s ~' ^'~ ~ ~ ~ ' ' ~, .;~ ~ ~ ~ 1 i ~'~~ , , ~ ; ~ ~ ,~ ; 1 1 FRANK H. MURKOWSKl, GOVERNOR ~~ OIL ~ t7[ ~ 33 W `" .~7 COI~TSERQA,TIOi~ COM1rIISSIOI~T f~ 3 . 7 AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 J. Edward Jones Executive vice President of Operations and Engineering Aurora Gas, LLC 1400 West Benson Blvd, Suite 410 Anchorage, Alaska 99503 Re: Kaloa #4 Aurora Gas, LLC Permit No: 205-131 Surface Location: 1121' FNL, 1740' FEL, SEC. 26, T11N, R12W, SM Bottomhole Location: 89' FNL, 165' FWL, SEC. 25, T 11 N, R 12W, SM Dear Mr. Jones: Enclosed is the approved application for permit to drill the above referenced exploration well. Because of the potential for encountering shallow gas-bearing sands, gas detection, PVT, and mud logging equipment must be fully operational prior to drilling out of the surface conductor pipe. Samples and a mud log are not required for Kaloa #4. Samples and a mud log were acquired across the same geologic section in nearby exploratory well Albert Kaloa # 1. A mudlog was also recorded in nearby well Kaloa #2. A spacing exception is required to drill, test and operate Kaloa #4. Testing or regular production of hydrocarbons from nap reservoir interval common to existing gas production well Kaloa #2 is grohibited until the Commission approves a spaciag exception. Aurora Gas, LLC assumes all liability and risk of expense if a spaciag exception is not granted. This permit to drill 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result • in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commissions's petroleum field inspector at (907) 659-3607 (pager). ~~ Norman DATED this~day of September, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. R • E & P SERVICES, INC. a~ ~,,.. ~, ~,,~_ August 26, 2005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7t" Ave., Suite 100 Anchorage, Alaska 99501 Attn: Mr. Tom Maunder P.E. RE: Application for Permit to Drill: Kaloa No. 4 Dear Mr. Norman: On behalf of Aurora Gas, LLC, Fairweather E&P Services, Inc. hereby submits a Permit to Drill application for an onshore natural gas exploration well on the northwest side of the Cook Inlet. The well, Kaloa No. 4, will be located approximately 7 3/4 miles west by southwest of Tyone aska. Aurora Gas, LLC proposes to spud the Kaloa No. 4 on September 005. Kaloa No. 4 will be drilled off the Kaloa No. 2 pad, a producing well-site. Access wi11 be via roads already in place to support production operations at the Kaloa 2 site. Pertinent information in and attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill - 2 copies 2) Fee of $100.00 payable to the State of Alaska 3) Location As-Staked plat 4) Days vs. Depth drilling curve 5) Drilling Procedure 6) Wellbore Schematic 7) Pressure and casing design information. 8) Description of the BOP equipment to be used per 20 AAC 25.035 (a)(1) and (b) 9) Cement program description 10) Drilling fluid program description 11) A summary of potential well hazards. 2000 East 88th Avenue • Anchorage, Alaska 99507 • (907) 258-3446 • FAX (907) 279-5740 650 North Sam Houston Parkway East, Suite 505 • Houston, Texas 77060 • (281) 445-5711 • FAX (281) 445-3388 ,,C ~ • Mr. Norman August 26, 2005 Page 2 If you have any questions or require additional information, please contact the undersigned at 258-3446, or Mr. J. Edward Jones, Vice President Enginerring and Operations, Aurora Gas, LLC at 277-1003. M1ely, ..~~`. ~1. ~. -~~~ Duane H. Vaagen Project Engineer Fairweather E&P Services, Inc. Attachments cc: Andy C{ifford J. Edward Jones STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM aION PERMIT TO DRILL ~n aac ~~ nn~ ~i;~;.: 1a. Type of Work: Drill ~ Redrill 1b. Current Well Class: Exploratory ~ Development O<I Multiple Zone ~ Re-entry ~] Stratigraphic Test ~ Service ~ Development Gas Q Single Zone [~ 2, Operator Name: 5. Bond: Blanket ~ Single Well 11. Well Name and Number: Aurora Gas, LLC Bond No. NZS 429815 Kaloa No. 4 ~ 3. Address: 6. Proposed Depth: 12. Field/Pool(s): 1400 W. Benson Blvd, Ste 410, Anchorage, AK 99503 MD: 4730' ND: 4000' 4a. Location of Well (Governmental Section): 7. Property Designation: Kaloa Surface: 1121' FNL 1740' FEL,~Sec 26, T11 N, R12W, SM ~ C-061393 Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: ' 381' FNL, 397' FEL, Sec 26, T11N, R12W, SM (2750' ND) 9/2/2005 Total Depth: ~ , 9. Acres in Property: 14. Distance to Nearest 89' FNL, 165' FWL, Sec 25, T11 N, R12W, SM (4000' ND) 3435 Property: 1121 ' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 211.5' Above MLLW 15. Distance to Nearest Well Surface:x- 260742 ~ y- 2566987.7 Zone- 4 (Height above GL): 14.5 Within Pool: 1566 ft at TOP 16. Deviated wells: Kickoff depth: 660 feet 17. Maximum Anticipated Pressures in prig (see 20 AAC 25.035) Maximum Hole Angle: 43 degrees Downhole: 1840 psig ~ Surface: 1400 psig ~' 18. Casing Program: Setting Depth Quantity of Cement Size Specifications Top Bottom c.f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) Driven 13 3/8" 54.5 J-55 Welded 90 0 0 90 90 Driven 12 114" 9 518" 36 J-55 BTC 625.5 0 0 640 ~ 640 74.5 bbls @ 100 % OH Excess 7 7/8" 5 1/2" 15.5 J-55 BTC 4715.5 0 0 4730 4000 190 bbls @ 25% OH Excess 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effect. Depth MD (ft): Effect. Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD ND Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ~ Time v. Depth Plot ~ Shallow Hazard Analysis Property Plat Q Diverter Sketch [~ Seabed Report ~ Drilling Fluid Program ~ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: Date 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Nam ' Duane Vaa en Title Project Engineer (Fairweather E&P Svcs, Inc) /~ / ) /~~z Signature ~ V ~'' ~... f~• ~' Phone 258-3446 Date 28-Aug-05 - Commission Use Only Permit to Drill i ~~' ~ ~ API Number: Permit Approval See cover letter for other 1 Number: 50- .~ ~,~ ~ JCj~/~ ~-~ Date: y ~ ~ requirements. Conditions of approval S Ales r uired Yes ~ No ~ Mud log required Yes ~ No ydroge sulfide measures Yes ~ No y~f' Directional survey required Yes ~ No Other: ~~~ ~ - f~ p ~ ~ S , APPROVED BY A r d MI O pp ove SSI N Date: z TH OM 4,.,:' 9 i ',4i 8 f Ie. F 10-4 R sed 06/ // S~mit inDuplicate p,~.. ~~ '~'"-_ ~ .~ GRID N:2568072.429; ' ~`~ , ~ :~ r "~ GRID E:262504.083 ~, •~~`. • x is . -` ,, :,, . ',~„r: - ,, ~-~' ~. ~ ,~, ": , a-` LATITUDE: 61°01'20.719"N " ° ' ~ 4~ • ` ` ~'' ~i'' ` " ` '~ J , Z ~' "` 20.263 W . . ~ LONGITUDE:151 20 '~'+~ ' - 1> : , y- V ~ - . ~, ~~x _ +. I Jam.. " 1~ •~~ SEC 23 I~: 3. ' ~ SEC 24 ^« ~ K .•,,~. ~ .~, SEC 26 ~ ~ ,. ~~°% SEC 25 .: ~ ~ 165' FWL ~, '=~~~ ~ w,~ ` " ~ NORTH j-"~~~ ~ ,. '~ ~~ _ . .~ •-s~,~: TD PROPOSED c. .- ., .'=~, r '`~~ :. ~' ~ KALOA #4 WELL ~'" 397 FEL ~ . _ ~ rr, `- ~;y!~A.~ TARGET PROPOSED ~ ,~ .~_. ;ice ~- . ,~: •~'~"` '~` - ;: N 2567980.32 ~'. ;L' E 262.667.18 - _ * „ ~. .r ~ . -.~ ~ KALOA #4 WELL AS-STAKED ~',~,~ ,.: N 2567700 - ~, ~~., ~ ~ .,`~~- - ` GRID N:2566987.730 ~ _ E 262100 ~# '' ~ ~.~ ~. ?~ , +a-'- ~ : ~ n• • •, ~! GRID E:260742.000 , ~# ;.~,t~. ~. `o ~ LATITUDE: 61°01'09.684"N °~,•'' • '~ ~"^~+~ .1- ~ :'~ ~~'' ~ ~ '~ ~ _ 7 _ . # ~~ •r _~ ` • .~.. ' ~ LONGITUDE: 151°20'55.561"W' ~~ ~'~ - •r '• '~ ~/ 1970 `~,, ,oc vr. ,~, '~", ~`.+~ ELEV °i '~ w ~' ~- « .. ' ~ . . ~ . ., i ' • ,4~ ~ ~ . s.. ~ •. ,. v, > ~. • 1740' FEL ..,~ °y~; ~'~ . ~ .. "~ , M{ , B ILT' ~ •~ ~ S ~ T ~~ - ~~ - . ~ KALOA #2 WELL A - U r,,.~ ? +~ , " . ~„ , N 2566864.6410 ~,;~~., ~ ~,`~3~ ~ ~ . ~ _ ~' ' ~ , .°. E 260.774.4660 , ` : ~.~ ` .~ t ~,~ ~ ,~' x ~ ~.., h ~ ~ a ~Y +~ '~~ Rlf. .fig ,~ 5 ~ .- 1 r. z , A .x . ~ 1) BASIS O COORDINATES IS ALASKASTATE ~ '' `~ ~ 0 F AE 1 ' - ~a • ~S ' ~ ~• v'.~~c PLANE NAD z7 ZONE 4 FROM A DIRECT TIE ' ~,. ' , . TO ADL NO. 31270. '~,; ~ ~'`P ~ V~~. ~ ~~ ~ ~ ~,~ . ~ 2) BASIS OF ELEVATION IS FROM TIDAL ~ r . ~, * . ~~3 ~,: ~, DATUM IS MLLW ;}~ 4~' *s ' ' ON ON 22 93 ~ . _ ~., .,,,. !- ; ..~,~~ .~.;, ,, /~ - . OBSERVATI 9- ALL ELEVATIONS SHOWN HEREON WERE ?~ . • ~ s '"°~ ~ ~ : "2° jk " * . ' - w: . • • ~ ' -, TAKEN ON GROUND. 3) SECTION LINES SHOWN HEREON ARE ~ ~ cjO^' Mt';SCO~i' M'C{.A1VE;~ ~ i `~..° s ~ ~ * ~ ` ' d , .~ ,,.~;; ,. f -";~`'t!F's. ~ j ".` • l a ~ ~ ~~~ BASED ON PROTRACTED VALUES. ~, . + ~, ,' 4928 S •.~~ = ~ ' SCALE ~,. ~ F'o ' • ~= ~ ~ i~'~-~ A ...... ~ ~ ~;''` .1 inch = 500 ft,~. .} _ - ~ ~ II ~ `~OFessla:a~ `' ~~ ~.-~ .~ ~ ~ - r ~ "+~,.-~' ' ~,~ - 500 750 1000 ° ~ .: ~, ! ~ r; ~~~. • _ ~~ ~ b. ' y~.~ (•X i?y~~C ~ ~•r sY ~ y~, ~ y ~ ~ • .'~~ Y. KALOA NO. 4 WELL AS-STAKED SURFACE LOCATION DIAGRAM IV~cLane Consulting Inc gPPIICANT: EN PI O EBOX 468PSOLDOTNA AK G99669NG -'~- ~~~~~ ~~~~ ~~~ , . . - VOICE: (907) 283-4218 FAX: (907) 283-3265 EMAIL: msmclane®mclanecg.com PROJECT NO. DRAWN BY: DATE: August 25, 05 SEC. LINE LOCATION: OFFSETS: PROTRACTED SECTION 26 osso7s MSM 1121' FNL TOWNSHIP 11 NORTH, RANGE 12 WEST 1740' FWL SEWARD MERIDIAN, ALASKA • • `Q~~ QF A~qs ~~ . '~ • ~- ~~ ~9* ~j i ~ ~,'~, •.M. SCOTT McLANE:' ~ ~ `" ~'•. 4928-S .•' ~i ,•o~'~•........ "`~`~ESS I ONP~ ~'P~~` PROTRACTED SECTION 26 TOWNSHIP 11 NORTH RANGE 12 WEST SEWARD MERIDIAN ALASKA WITHIN U.S. SURVEY N0. 1865 AS BUILT z KOLOA N0. 2 ~ SURFACE LOCATION 1- NORTHING: 2566864.64 L` EASTING:260774.49 a LAT: 61°01'08.478"N LONG: 151 °20'54.851 "W / ELEV:197.4 1706 FT. FEL AS BUILT KOLOA N0. 1 SURFACE LOCATION NORTHING: 2566877.080 EASTI N G: 260693.06 LAT: 61°01'08.584"N LONG: 151 °20'56.508"W SCALE 1 inch = 500 ft. o soa 7so ~ooo ~ ~ NOTES 1) BASIS OF COORDINATES: NGS CORS STATION "KEN 1 ". 2) ELEVATION DATUM: MLLW NOAA BM5869H 3) SECTION LINE OFFSETS DERIVED FROM THEORETICAL BLM PROTRACTED SECTION CORNER VALUES 4) ALASKA STATE PLANE ZONE 4 NAD27 S23 S24 S26 S25 KOLOA N 2 Consulting C~'roup SURFACE LOC ION 1v~cLane Testing APPLICANT: ENGINEERING/MAPPING/SURVEYING/TESTING •~"~•• P.O. BOX 468 SOLDOTNA, AK. 99669 :==~,4~:~~~v~: VOICE: (907) 283-4218 FAX: (907) 283-3265 -~~~ ~~ EMAIL: msmclane®mclanecg.com NORTHING: 2568137.490 FASTING: 262506.440 LAT: 61°01'21.360"N LONG: 151 °20'20.242"W PROJECT NO. DRAWN BY: DATE: OFFSETS: LOGATIUN: June 21, 2ooa 1706' FEL PROTRACTED SECTION 26 033008 MSM 1308' FNL TOWNSHIP 11 NORTH RANGE 12 WEST SEWARD MERIDIAN ALASKA Aurora Gas, LLC. Kaloa No. 4 Drilling Program Drilling Program: Kaloa No. 4 1. File and insure all necessary permits and applications are in place. 2. Mob in rig and RU. 13 3/8" conductor has been pre-installed. Install 13 5/8" 5M starter head. 3. Rig up diverter and mud loggers. Test and-calibrate all PVT and gas sensor equipment. Provide 24 hr notice to AOGCC inspectors for ~ chance to witness diverter test. 4. Notify AOGCC and pertinent agencies when ready to start drilling operations. 5. Prepare spud mud system using recycled mud from previous drilling project, weight up to ~10 ppg.' Load, strap and drift 9 5/8" surface casing. 6. PU 7 7/8" bit and drill ilk of hole to 640 ft, using 6 1/4" stabilized BHA. Watch for gas in shallow coals and sands. Attempt to TD casing landing point in sil#stone or claystone, i.e. avoid surface TD in coal bed. If possible, plan TD to correlate with casing tally so when landed, cementing head is at floor level. Increase mud weight as needed. 7. POOH LD 7 7/8" pilot hole BHA and PU 12'/4" stabilized BHA. Open 7 7/8" surface hole to 12 '/4" to TD achieved in step 6. 8. Condition .hole for running 9 5/8" surface casing, POOH, LD 12 1/4" BHA. 9. Run and cement (new) 9 5/8" 36 #/ft, J-55 BTC surface casing at 640' installing 1 centralizer /joint centered on 1St 4 joints above shoe, and 1 centralizer every 2"d joint thereafter, cement to surface. Shoe joint _____-- connection at#loat shoe and float collar must be Baker-Locked. Cementing will be single stage using 14.5 ppg cement at 100% excess volume. 10. RU and test 11" 3M BOP!t ck and 5M choke manifold. Test stack and surface equipment to 00 psi. Pressure test casing to 1500 psi or as required on approved, mit. 11. PU 8 %2" bit, bit sub and RIH w/ 6'/" collars, drill out float equipment and shoe. Condition. /treat mud as needed for cement contamination, drill ~20' OH. Pull back into shoe and perform FIT to 15.0 ppg MWE. Record ~' .results. TOH, LD 6'/4" collars while POOH. 12. PU 4 3/" directional drilling assembly w/ 7 7/8" bit, motor and DIR MWD assembly, non-mag DC's, jars and HWDP as specified by directional hand. ,~Jsg.~,.~s'" 13. RIH and directionally drill 7 7/8'~p+l6f~hole to 4730 ft MD (4000 ft TVD} TD j per directional plan, or other as decided by Aurora Gas geologist. While drilling, load tally and drift load 5'/s" casing on racks. Attempt to TD 7 7/8" production hole to correlate with casing tally so when landing pipe, cementing head is at floor level. 14. While drilling,monitortyell and volumes carefully. Be prepared to shut well in and weight up immediately if flow or excessive g wild up in mud is noticed. Anticipated mud weights required are 9.5 - pg. Do not - exceed fracture gradient determined in step 11. 15. Condition hole, short trip and prepare for running wireline logs. Aurora Gas LLC. Page 1 of 11 Rev. 1.0 8/26/2005 Aurora Gas, LLC. • Kaloa No. 4 Drilling Program 16. POOH, rack back drillstr-ing and RU wireline BOP's and lubricator and logging tools. Log cased hole section w/gamma ray sensor, Log OH section with logging suite as indicated by Aurora Gas. 17. RD wireline, RIH w/ 7 7/8" drilling assemblyto TD and condition hole for running 5'/2" casing. Insure cementing head has proper connections or proper cross-over is available for quick rig up. 18. POOH while laying down drillpipe and BHA, RU to run casing. Insure cementers equipment is ready. 19. Change out pipe rams for 5'/2" casing. 20. Run 5 %2" 15.5# BTC J-55 casing installing 1 centralizer /joint centered on 1St 4 joints above shoe, and 1 centralizer every 2"d joint there after to 1 jt inside surface casing shoe. Install centralizers every 3rd joint there-after to surface. Shoe joint connection at float shoe and float collar must be Baker-Locked. While running casing, fill every 3rd joint. Be prepared to RU and wash to bottom. 21. RU cementers, cement per attached cementing program from TD back to surface. A 13.5 ppg lead and 15.8 ppg tail cement system will be used. Ta- i slurry to be of sufficient volume to cover 5'/2" CH x_7 7/8". OH annulus _ to 100f0 ~tw` See attached cementing info for preliminary volume estimates. While pumping cement, reciprocate pipe a minimum of 20 feet until cement goes around the shoe. Land casing within 2 - 5 ft of bottom if possible. Displace cement w/ brine to minimize contamination on clean- out. When displacement is finished, bump plug, check floats, drain and wash down stack, check annulus for flow, center casing w/ annular preventer and WOC. 22. RD cementers, nipple down stack, land casing in slips and cut casing. 23. Install 11" X 7 1/16" tubing spool, 7 1/16" X 11" DSA, mud cross and reinstall BOP stack. Pressure test BOP and surface equipment to 3000 i psi. Pressure test casing to 2000. psi and record results. 24. C/O 5 %2" rams to 2 7/8" for workstring. PU bit and casing scraper and RIH with tbg to top of float collar. After circulating out cement debris, clean brine for perforating by running through centrifuge and filtering. POOH LD bit. and casing scraper. Strap tubing on TOH to validate tally. 25. PU wireline BOP's, lubricator, pressure test all. PU perforating guns, RIH to depth as determined from OH logs and perforate. Watch for pressures in casing after shooting. POOH, LD perf gun. 26. RU and RIH with test packer assembly on workstring. Connect to surface .flow west equipment. Swab in well for flow test, record results. Kill well 27. Repeat steps 24 and 25 until sufficient intervals have been penetrated for production. 28. POOH, RD wireline. 29. Pickup and assemble completion assembly which will use retrievable type packers, sand exclusion screen, sliding sleeves and other. Exact configuration to be determined by test results. Please see Figure 1 for proposed completion scenario. Packer is to be 75 ft minimum above upper-most screen. RIH and hang off (depth to be determined by depth of Aurora Gas LLC. Rev. 1.0 .Page 2 of 11 8/26/2005 • Aurora Gas, LLC. • Kaloa No. 4 Drilling Program perforations).. POOH with workstring, RIH with 2 7/8" 6.5# EUE 8rd production tubing, space out and stab into packer, hang off in tubing head and lock down. Install blanking plug. in profile nipple, Pressure test tubing to 2000 psi, pull blanking plug. 30. RU and swab in well, allow to clean up, record rates and pressures then shut in. 31. Install BPV at surface, nipple down and remove BOP stack. Install wellhead tree. RD and remove. all rig equipment. 32. Prepare site for well testing and surface production facilities. ~ 33. File completion reports with proper agencies. Site Access:Kaloa No. 4 will be accessible via existing gravel road. originally built to support early exploration activities in the region and now being used to support ongoing operations at the Kaloa No. 2 site, an active producing facility. Rig.: Aurora Well Service, Rig No. 1 (AWS 1) will be used to drill the Kaloa No..- 4 well. The Alaska Oil and Gas Conservation Commission has information on this equipment as it has been in use for the last (3) years on other- Aurora Gas operations. The pits, BOP system and mud equipment configuration will be similar to that used for previous work. Survey Program: The 12'/" surface hole will be drilled vertically and the survey program will consist of inclination only single-shot surveys to be obtained. at 500' intervals in accordance with rules laid out in 20 AAC 25.050 (a) (1) & (2). .The surveys will be acquired while drilling the 7 7/8" pilot hole. The? 7/8" production hole will be drilled directionally. For all directional work, wellbore surveys will be , taken at maximum of 100 ft intervals, per AAC 25.050 (a)(1) with intervals likely to be surveyed more frequent while steering. Logging Program: Aurora will have mud loggers on site for the duration of '~ drilling .activities. Schlumberger will provide wireline logging services and will run their Platform Express suite in open-hole o A gamma ray log will be obtained to surface while logging out of the~e on one of the Platform ..Express runs. Proposed logs at this time are: ~. ~~ ,U~ Kaloa #4 Proposed Logging Program Well Section De the ft OH CH Lo T e 12 1/4" Surface 0 - 640 ,~ N/A: No open-hole logs planned for surface at this time. 9 5/8" Surface 0 - 640 ,~ GR Cs 7 7/8" 640 - 4730 ~ Platform Express: Array Induction, .Compensated. Production Neutron, Litho-Density, SP, GR, DSI and FMI. Also Hole MDT and Sidewall cores. 5 1/2" Int. Cs 640 - 4730 ~ GR/CBUCCL Surface - TD 0 - 4730 ~( Mud Lo ing Services Aurora Gas LLC. Page 3 of 11 Rev. 1.0 8/26/2005 ~ ~ Aurora Gas, LLC. Kaloa No. 4 Drilling Program BOP Equipment: Aurora Gas, LLC will use the same BOP system they. have been using for the last (3) years which will consist of the following: 12 1/4" surface hole: While dri ' the 12 1/4" surface hole, a 13 5/8" 5M annular w/ 13 5/8" diverter spool and 0" iverter line will be used. Information on this system is already on file at t AOGCC. Per 20 AAC 25.035 (c)(1)(A) there is a requirement that the diverter line outlet size be at least 16" in diameter or (B) at ..least as large as the hole size being drilled. Since Aurora does not have acc to a diverter spool with an outlet line ID which fulfills this requirement, a 7/ ' pilot hole will be drilled to 640 ft and then opened to 12 '/" prior to runnin 8" casing. 7 7/8" Production Hole: An 11" (3M) Schafco (Shaffer. Equivalent) BOP system will be used which is configured with an 11" 3M annular preventer, (1) 3M double gate with a set of pipe rams installed sized to fit the pipe being run and a set of blind rams and (1) 11" 3M rated drilling spool. BOP tests will be performed to 3000 psi. The annular preventer will be tested to 1500 psi. Again, this is the / same equipment Aurora has been using all along and information on the system is on file at the AOGCC. Pressure Considerations: .Based on records from the original Albert Kaloa No. 1 and nearby offset well Kaloa No. 2, a pressure gradient of .46 psi/ft ~ can be expected. Using this information, the maximum anticipated bottom-hole pressure to be encountered would be expected at TD, or 4730 ft MD (4000 ft TVD) .with potential pressures approaching 1840 psi. " Maximum anticipated surface pressures "MASP" can be calculated by subtracting the gas gradient of .11 psi/ft from pore pressure gradient of .46 psi / ft and .multiplying by the total TVD depth. =>MASP = (.46 - .11) * 4000 = 1400 psi ~ ~ Drilling Fluids: The drilling fluids are being furnished by Baroid Drilling Fluids. Baroid has extensive experience with drilling activities in this area. An experienced mud engineer will be on site at all times while drilling to monitor rheologies and make recommendations. Surface Hole Recommendations Mud Type: 6%KCI, EZ Mud, or recycled mud from previous wells. Pro erties: Density Viscosity Plastic Viscosity Yield Point API FL pH 0 - 640' 10.0 45 - 65 16 - 23 20 - 30 <5 $.5-9.5 System Formulation: 6%KCI, EZ Mud if no used mud is available) Product Concentration Aurora Gas LLC. Page 4 of 11 Rev. 1, 0 8/26/2005 Aurora Gas, LLC. • Kaloa No. 4 Drilling Program Water 0.905 bbl KCI 19.8 ppb (30K chlorides). KOH 0.2 ppb (9 pH) BARAZAN D 1.25-1,5 ppb (as required 25 YP) EZ MUD DP 0.75 ppb (begin with .2 ppb) PAC-L or DEXTRID LT 1.5 to 2.0 ppb ALDACIDE G 0.1 ppb Barite As/if needed BARACOR 700 1 ppb BARASCV D 0.5 ppb (add as the well spuds) • Mix in order as listed • Add polymers slowly to minimize fisheyes Recycle fluids as appropriate. No over pressured zones were encountered nor any major hole problems were seen on Kaloa #2. Some tight hole was seen. on a trip at 3022'. Occasional short trips are suggested to help alleviate this problem. Production Hole Recommendations Mud Type: 6%KCI, EZ Mud Properties: Den Viscosit Plastic Viscosity Yield Point API FL pH 640 - 4730' 9.8 10. 40-50 6 - 15 13 - 25 <5 8.5-9.5 ~~ System Formulation: 6%KCI, EZ Mud Product Concentration Water 0.905 bbl KCI 19,8 ppb (30K chlorides) KOH 0.2 ppb (9 pH) Barazan D 1.25 ppb (as required 13-20 YP) Dextrid 2-3 ppb EZ Mud DP 0.75 ppb Aldacide G 0.1 ppb. Baroid as/if needed Baracor 700 1 ppb Barascav D 0.5 b maintain er dilution rate Drilling Fluid Handling System: Shale Shaker, Mud Cleaner, Centrifuge, PVT monitors Casing /Cementing Program: All casing is new. Analysis (attached.) indicates casing program as designed provides adequate safety factors for this well. All casing strings with. the exception of the 13 3/8" conductor will be cemented in place using industry standard casing cementing. techniques utilizing a casing shoe, float equipment and wiper plugs and centralizers installed as needed.. Kaloa No. 4, 13 3/8" 72# N-80 Conductor Analysis and Cementing Program The .conductor for Kaloa No. 4 has been installed by driving the 13 3/8" pipe to refusal at 94 ft. Joints were welded and a drive shoe was welded to the bottom Aurora Gas LLC. Page S of 11 Rev. 1.0 8/26/2005 • Aurora Gas, LLC. Kaloa No. 4 Drilling Program joint. No cementing is required. Please see attached Conductor Analysis with specifications. Kaloa No. 4, 9 5/8" 36# J-55 BTC Surface Casing Analysis and Cementing Program The 9 5/8" surface casing will be cemented in fully from the proposed set depth of 640' to surface with a 14.5 ppg "G" tail cement system. Where: 12 7/4" OH Capacity =.1458 bbl/ft 9 5/8" 36# Csg x 12 1/4" OH capacity = .0558 bbl / ft 9 5/8" 36# Csg capacity = .0773 bbl/ft v OH x Csg: 640 ft x .0558 bbl / ft x 2 (100 % excess) = 71.5 bbls Shoe Jt: 38ft x .0773 bbl/ft = 2..94 bbls Actual volumes to be re-calculated at time of running casing due to potential variation in actual depth from planned. The surface cement system to utilize alias-Block type additive to minimize potential for gas entrainment and or channeling. Cement System Weight (ppg) Volume Required Gas-Block enhanced 14.5 74.5 bbls @ 100% ~ Please see attached 9 5/8"surface casing analysis and specifications. Kaloa No. 4, 5 1/2" 15.5# J-55 BTC Production Casing Cementing Program The 5 112" production casing .will be cemented in fully from the proposed. set --~ depth of 4730' to surface. A 13.5 ppg. lead "G" cement followed with a 15.8 ppg "G" tail cemen system will be used. This program is designed to insure the intended perforating /production intervals are isolated with 15.8 ppg "G" cement. Where: 5 %" 15.5# csg capacity = .0238 bbl/ft 5 %"15.5# csg X 7 7/8" OH capacity = ..0309 bbl/ft 5 %" 15.5# csg X 9 5/8" 36# annular capacity = .0479 bbl/ft 5 %" 15.5# csg displacement = .0056 bbl/ft Lead System: 9 5/8" CH x 5 %"Csg: = 640 ft 640 ft x .0479 bbls/ft x 1 (0% excess= 30..7 bb/s 7 7/8" OH x 5 %" CSG: 1000 ft - 640 ft = 360 ft 360 ft x .0309bbI/ft x 1.25 (25% excess) = 13.9 bb/s Total Lead System = 44.6 bb/s Aurora Gas LLC. Page 6 of 11 Rev. 1.0 8/26/2005 • Aurora Gas, LLC. Kaloa No. 4 Drilling Program Tail System: 7 7/8" OH x 5 %" Csg: 4730 ft - 1000 ft = 3730 ft 3730 ft x .0309 bbl/ft x 1.25(25% excess= 144 bb/s Shoe Joint = 38' x .0238 bbl/ft = .9044 bbls Total Tail Cmt Volume = 145 bbls Cement System Type Cement Weight (ppQ) Volume(c~% Excess Lead "G" 13.5 45 bbls@ 25% OH ~ Tail "G" 15.8 145bb1s @ 25% OH ~ Please see attached 5 1/2" production casing analysis .and specifications. Drilling Hazards: Drilling in the South Central Region of .Alaska offers its own challenges. Common known hazards are as follows: Shallow gas: Shallow gas is a known hazard which exists throughout the area. The northwest side of Cook Inlet is noteworthy for its shallow gas hazard. All responsible personnel will be made aware and a notice of such hazards will be posted in the rig doghouse. There is no record of H2S in the region, however; a gas detection system capable of detecting - /' H2S as well as methane will be installed on the rig with detectors at the floor level, the shale shaker and in the cellar. Coal Seams: The Cook Inlet region is rich in coal seams, inter-bedded between the sands, gravels and shale's that make up the Beluga. and Tyonek formations. Drilling into a coal seam will appear to be a drilling break when drilled with a tri-cone bit. The major hazard of drilling into a coal seam without observing the proper response is the risk of stuck pipe. The proper course of action for preventing stuck pipe is two-fold. First, prior to drilling, insure the drilling fluid system is up to par,. per recommendations from the on-site mud engineer. The second step to successfully drilling through coals in the Cook Inlet area is to not get greedy when coals are encountered. When a coal has been encountered, pull back above coal after drilling into it, and circulate, allowing the coal to stabilize. Re-enter, drill .some more, and pull back out again. Continue in this fashion .until successfully through the coal bed. The key .word irr successfully drilling the coal beds is patience. It should be remembered that coals behave plastically, and will flow under the weight of the overburden. The deeper the coal, the more pronounced this tendency becomes. For this reason it is critical to maintain the proper weight and viscosity of your drilling fluid to properly remove the coals drilled up, and. to hold flowing coals in place. Again, heed the recommended drilling fluid program and advice offered. by the on-site Mud Engineer. Aurora Gas LLC. Page 7 of 11 Rev. 1.0 8/26/2005 Aurora Gas, LLC. Kaloa No. 4 Drilling Program Nearby Well's: There is one producing well in close proximity to .the proposed Kaloa No. 4, that is the Kaloa No. 2. The Kaloa 4 conductor will be approximately 127 ft north by northeast of the Kaloa 2 surface location. Since we will be kicking off in a northeast direction after drilling surface, proximity issues should be manageable. Other: Sticky bentonitic clays, boulders, lost returns & differential sticking w/ overbalanced muds and gas influx while cementing. Aurora Gas LLC. Rev. 1.0 Page 8 of 11 8/26/2005 Aurora Gas, LLC. • Kaloa No. 4 Drilling Program Kaloa No. 4 Summary of Drilling Hazards POST THIS NOTICE IN DOGHOUSE There is potential for abnormal pressured shallow. gas. ~ There is potential for stuck pipe in coals encountered while drilling from surface to TD. Be extra vigilant while performing hole opener run. Short trip to be performed every 600 ft or 24 hrs, whichever comes first. ~ There is no H2S risk anticipated for this well. ~ Due to potential for shallow gas kick, very little response time will be afforded to respond.. PVT and gas detection systems. must be fully operational and functioning at all times, visual. flow.checks and pit level monitoring are critical. CONSULT THE "KALOA No. 4" WELL PLAN FOR ADDITIONAL INFORMATION. Aurora Gas LLC. Page 9 of 11 Rev. 1.0 8/26/2005 Aurora Gas, LLC. Kaloa No. 4 Drilling Program _ ~~ CBS, ZLrr Kaloa No. 4 Days vs. Depth Days From Spud . _,. _. _ _ _ _ _ _ u 1 _ __ ___ _ . _ ,_. _ ~ . 00 200 300 400 500 600 700 800 12 1/4" Hole to 640', Set /cement 9 5/S" surface casing at 640. NU BOPS, Rtest, Drill out and FR to 15 ppg MVVE 900 1000 1100 ' ~ 1 200 1 0 ' 30 14 00 1500 1600 1700 1 TD @ 4730', Condition hole, run OH logs, Run 5 1/2"casing and cement. Perforate, test and comple well. 800 1900 2000 2100 ~ 22 ~ 00 2 300 4 ~ 2 00 g 2500 ~ 2 ~ 600 ~ 2700 p 2800 2 00 9 ~ ~ 3000 1 ' 3 00 3200 3300 4 3 00 3500 3600 3700 3800 3900 4 000 4100 4200 4300 4400 ~ 4500 4 0 60 47 ~ 00 4 0 i 80 4900 5000 Aurora Gas LLC. Page 10 of I1 Rev. 1.0 8/26/2005 Aurora Gas, LLC. Kaloa No. 4 Drilling Program 2 7/8 6.5# 8rd EUE J-55 Tubing -.y Aurora Gas, LLC Kaloa No. 4 Proposed Configuration 2 7/8" X 5 '/_" annulus to be displaced over to inhibited packer fluid following completion. 13 3/8" 61# LSS Conductor driven to 80+ ft or refusal. 9 5/8" 36# J-55 LTC Surface Csg to 640' MD Sliding sleeve to be installed 1 jt above packer. Top Tyonek Carya 2-4-2 Estimated at 3315ft MD 2750 ft TVD(2750 ft TVD. Attachment I 5 '/:" 15.5# J-55 BTC Product Csg to 4730' MD (4000' TVD Cemented back to surface. Est PBTD @ 4690' MD. Aurora Gas LLC. Rev. 1.0 retrievable type packer to be set _ 75ft bove shallowest perforations. Completion gill consist of sand exclusion screen and pacer jts as needed, to be determined by 7 5/8" OA Drilled to TD at 4730 ft MD (4000 ft TVD). Page 11 of 11 8/26/2005 Well ID Aurora Gas, LLC: Kaloa No. 4 / Min. Safety Factors To Be Used: Body Yield: 1.5 Jt. Strength: 1.8 Collapse 1.5 Collapse While Cementing 1.5 Top Burst 1.1 Bottom Burst 1.1 Properties: Size OD: 13 3/8 Grade: LSS Weight ppf: 54.50 Coupling: BTC Set Depth ft 90.00 (ft)MD Next Casing Depth 640.00 (ft)MD FIT TEST OR TD DEPTH N/A (ft)MD Collapse Resistance (psi) Internal Yield (psi) Joint Strength (psi) x 1000 Body Yield (psi) x 1000 API Drift Diameter (in) 12.459 Wall Thickness (in) 0.38 13 3/8" Conductor 90.00 (ft)TVD 640.00 (ft)TVD N/A (ft)TVD 1130.00 2730.00 909.00 853.00 ormation 8~ Fluid Properties: al 909,000.00 "Tensile Limits 853,000.00 "Tensile Limits Weight ppg Gradient psi/ft Mud Weight 9.00 0.468 psi/ft Anticipated Mud Wt Next Csg Pt. 10.00 0.520 psi/ft Calculated Bouyancy Factor @ Mud Wt: 0.86 Anticipated Cement Weight (ppg) 14 0.728 psi/ft i Sea Water Gradient (ppg) 8.94 0.465 psi/ft 'Frac Gradient at Shoe(ppg) 13 0.676 psi/ft Frac Gradient at Next Casing Point 16 0.832 Est. Pore Pressure Gradient @ Shoe 8.4 0.437 Est. Pore Pressure Gradient @ Next Csg Pt. 9 0.468 Gas Gradient (psi/ft) 0.110 Mud Backup Gradient ppg 8. ~ 0.465 °ia Fluid Drop for Collapse Calculation (Enter #). ~ 0.55 ~ • Tensile Calculations: Weight in Air (Ibs) 4,905.00 Bouyant Weight in Mud (Ibs) 4,230.00 Maximum setting depth (ft) 15,651.38 In Air: = Jt Strength / Wt.ppf Joint Strength Safety Factor 185.32 In Air: = Jt Strength / (Wt ppf * set depth) (At proposed depth) Body Yield Safety Factor 173.90 In Air: =Body Yld / (Wt ppf "set depth (At proposed depth) Collapse Calculations: Collapse Safety Factor 64.23 Collapse Res / (Depth ND' % Fluid Drop '(Mud B-up Grad -Gas Grad)) Collapse SF while cementing 47.81 Collapse Res /Depth ND * (Cmt Grad - B-up Mud Grad) No lost Circulation/Evacuation occurs Burst Calculations: Assume seawater backup gradient .465 psUft for burst design purposes Assume worst case by using anticipated frac gradient for TD of next hole section (ND) for MASP calculations MASP (Maximum Anticipated Surface 462.08 (Prat Grad -Gas Grad)' Next Casing Set Depth (ND) Pressure) Top Burst Safety Factor 5.91 Tube burst rating /ASP Bottom Burst Safety Factor 6.00 (Int. Yld + Depth ND * Seawater Grad)! ASP Summary of: 13 3/8 Safety Factors / Body Yield 173.90 in air "Tensile" OK Joint Strength 185.32 in air "Tensile" OK Collapse 64.23 OK Collapse 47.81 while cementing OK Top Burst 5.91 OK Bottom Burst 6.00 OK ~ • ~~ ~~ Aurora Gas, LLC: Kaloa No. 4 Min. Safety Factors To Be Used: Body Yield: 1.5 Jt. Strength: 1.8 Collapse 1.5 Collapse While Cementing 1.5 Top Burst 1.1 Bottom Burst 1.1 ing Properties: Size OD: 9 5/8 Grade: J-55 Weight ppf: 36.00 Coupling: BTC Set Depth ft 640.00 (ft)MD Next Casing Depth. 4730.00 (ft)MD FIT TEST OR TD Depth 660.00 (ft)MD Collapse Resistance (psi) Internal Yield (psi) Joint Strength (psi) x 1000 Body Yield (psi) x 1000 API Drift Diameter (in) 8.765 Wall Thickness (in) 0.352 Formation &Fluid Properties: 9 5/8" Surface Casing 640.00 (ft)TVD 4000.00 (ft)TVD 660.00 (ft)TVD 2020.00 3520.00 639.00 564.00 639,000.00 * Tensile Limits 564,000.00 * Tensile Limits Weight ppg Gradient psi/ft Mud Weight 10.00 0.520 psi/ft Anticipated Mud Wt Next Csg Pt. 9.80 0.510 psi/ft Calculated Bouyancy Factor @ Mud Wt: 0.85 Anticipated Cement Weight (ppg) 15.8 0.822 psi/ft Sea Water Gradient (ppg) 8.94 0.465 psi/ft Frac Gradient at Shoe(ppg) 16 0.832 psi/ft Frac Gradient at Next Casing Point 16 0.832 Est. Pore Pressure Gradient @ Shoe 9 0.468 Est. Pore Pressure Gradient @ Next Csg Pt. 9.1 0.473 Gas Gradient (psi/ft) 0.110 Mud Backup Gradient ppg 8.9 0.465 °~ Fluid Drop for Collapse Calculation (Enter #). 55; 0.55 • n Tensile Calculations: Weight in Air (Ibs) 23,040.00 Bouyant Weight in Mud (Ibs) 19,517.06 Maximum setting depth (ft) 15,666.67 In Air: = Jt Strength / Wt.ppf Joint Strength Safety Factor 27.73 In Air: = Jt Strength / (Wt ppf * set depth) (At proposed depth) Body Yield Safety Factor 24.48 In Air: =Body Yld / (Wt ppf * set depth (At proposed depth) Collapse Calculations: Collapse Safety Factor 16.15 Collapse Res / (Depth TVD • % Fluid Drop `(Mud 8-up Grad -Gas Grad)) Collapse SF while cementing 8.86 Collapse Res /Depth TVD' (Cmt Grad - B-up Mud Grad) No lost CirculatioNEvacuation occurs Burst Calculations: Assume seawater backup gradient, .465psi/Rforburstdesignpurposes Assume worst case by using anticipated hac gradient and pore press gradients at shoe with TD(TVD) of next hole section for MASP calculations MASP (Maximum Anticipated Surface 2,888.00 (Frac Grad -Gas Grad)` Next Casing Set Depth TVD Pressure using Frac Grad) MASP (Maximum Anticipated Surface 1,432.00 (Pore Press Grad -Gas Grad)' Next Casing Set Depth TVD Pressure Using Known Area Pore P) Top Burst Safety Factor 2.46 Tube burst rating /ASP (Based on most realistic MASP above) Bottom Burst Safety Factor 1.32 (Int. Yld + Depth TVD `Seawater Grad) /ASP Summary of: 9 5/8 Safety Factors Body Yield 24.48 in air'Tensile" OK Joint Strength 27.73 in air "Tensile" OK Collapse 16.15 OK Collapse 8.86 while cementing OK Top Burst 2.46 OK Bottom Burst 1.32 OK • • ~~ Aurora Gas, LLC: Kaloa No. 4 51/2" Production in. Safety Factors To Be Used: ~dy Yield: 1.5 Strength: 1.8 ~Ilapse 1.5 ~Ilapse While Cementing 1.5 ~p Burst 1.1 ~ttom Burst 1.1 Casing Properties: Size OD: 5 1 /2 Grade: J-55 Weight ppf: 15.50 Coupling: BTC Set Depth ft 4730.00 (ft)MD 4000.00 (ft)TVD Next Casing Depth 4730.00 (ft)MD 4000.00 (ft)TVD FIT Test Depth 660.00 (ft)MD 660.00 (ft)TVD Collapse Resistance (psi) 4040.00 Internal Yield (psi) 4810.00 Joint Strength (psi) x 1000 300.00 300,000.00 * Tensile Limits Body Yield (psi) x 1000 248.00 248,000.00 "Tensile Limits API Drift Diameter (in) 4.825 Wall Thickness (in) 0.275 ~~Formation ~ Fluid Properties: IlMaterial Weight ppg Gradient psi/ft Mud Weight 10.00 0.520 psi/ft Anticipated Mud Wt Next Csg Pt. 10.00 0.520 psi/ft Calculated Bouyancy Factor @ Mud Wt: 0.85 Anticipated Cement Weight (ppg) 15.8 0.822 psi/ft Sea Water Gradient (ppg) 8.94 0.465 psi/ft Frac Gradient at Shoe(ppg) 16 0.832 psi/ft Frac Gradient at Next Casing Set Point 20 1.040 psi/ft Est. Pore Pressure Gradient @ Shoe 9.1 0.473 psi/ft Est. Pore Pressure Gradient @ Next Csg Pt. 18.5 0.962 psi/ft Gas Gradient (psi/ft) 0.110 psi/ft Mud Backup Gradient ppg 8.95 0.465 psi/ft Fiuid Drop for Collapse Calculation (Enter#}. ~5 0.55 • • Tensile Calculations: Weight in Air (Ibs) 73,315.00 Bouyant Weight in Mud (Ibs) 62,104, 76 Maximum setting depth (ft) 16,000.00 In Air: = Jt Strength / Wt.ppf Joint Strength Safety Factor 4.09 In Air: = Jt Strength / (Wt ppf" set depth) (At proposed depth) Body Yield Safety Factor 3.38 In Air: =Body Yld / (Wt ppf "set depth (At proposed depth) Collapse Calculations: Collapse Safety Factor 5.17 Collapse Res / (Depth ND ` % Fluid Drop'(Mud B-up Grad -Gas Grad)) Collapse SF while cementing 2.84 Collapse Res /Depth ND ` (Cmt Grad - B-up Mud Grad) No lost Circulation/Evacuation occurs Burst Calculations: Assume seawater backupgredient,.465psi/Itforburstdesignpurposes Assume worst case by using anticipated frac gredient and pore press gradients at shoe with TD (ND) of next hole section for ASP calculations MASP (Maximum Anticipated Surface 2, 888.OO (Frac Grad -Gas Grad)' Next Casing Set Depth (ND) Pressure Using Frac Gradient @ TD) MASP (Maximum Anticipated Surface 1,452.80 (Pore Press Grad -Gas Grad)` Next Casing Set Depth (ND) Pressure Using Known Area PP) Top Burst Safety Factor 3.31 Tube burst rating /ASP 2.78 Using PP (Based on Most Realistic MASP above) Bottom Burst Safety Factor 2.31 (Int. Yld + Depth ND 'seawater Gr 4.59 Using PP Summary of: 5 1/2 Safety Factors ~ Body Yield 3.38 in air "Tensile" OK Joint Strength 4.09 in air "Tensile" OK Collapse 5.17 OK Collapse 2.84 while cementing OK Top Burst 3.31 OK Bottom Burst 2.31 OK • • HALLIBURTON Sperry Drilling Services Aurora Gas, LLC Cook Inlet Kafoa Kaloa #4 Kaloa #4 Plan: Kaloa #4 wp04 Proposal Report 25 August, 2005 • HALLIBURTON $p:elr~ry Dri00ilrng 'S~ra~ri~oaes 1 f R A _ .... 0 ~0 ~ 500 9 5/8" I `~ 0° Start Build 4.29 5° Start Build 5.00 Start DLS 5.50 TFO 0.00 11)00 1000 Start DLS 6.00 TFO 15.15 25< Start Hold 1745.5 35° ,500 1500 2p00 c_ u~i 2000 r 43 25p0 a d O 2500 3~0 ~ Start DLS 2.00 TFO 167.70 I` Start DLS 2.00 TFO 180.00 Kaloa-4 wp04 3000 ~° 4000 3500 • WELL DFi,111S Kaloa d-1 Ground [xvel 185.0 +N/-S +E-W Northing Fasting Latittude Longitude Slot 0.0 0.0 2566987.73 260742.00 61' I'9.684N 151°20'55.561 W COMPANY DEiAB.S..Aurora Gas, LLC REFERENCE INFORMATION Drilling Co-ortlinate (N/E) Reference: Well Kaloa #4, Gritl North Vertical (TVD) Reference: WELL @ 198.Ofl (Original Well Elev) Measuretl Depth Reference: WELL @ t98.Ofl (Original Well Elev) Calculation Method: Minimum Curvature Calculatbn Methotl~ Minimum Curvature Emor System: ISCWSA Scan Method: Trav. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based WELLBORE TARGET DETAILS Name TVD +W-S +E/-W Shape Kaloa-0wp04 2750.0 712.3 1358.0 Pdnt SECTION DETABS Sec MD Inc Aa TVD +N/-S +E/-W DLeg TFace VSec Target 1 0 0 0.00 57.00 0.0 0.0 0.0 0.00 000 0.0 2 660.0 0.00 5700 660.0 0.0 0.0 0,00 57.00 0.0 3 800.0 6.00 57.00 799.7 4.0 6.1 4.29 57.00 4.0 q 900.0 11.00 57.00 898.6 12.0 18.5 5.00 000 12 0 5 1200.0 27.50 5700 1180.9 65.7 101.2 5.50 0.00 65.7 6 1465.1 43.04 63.02 1396.7 140.6 234.0 6.00 15.15 140.6 7 8 3210.5 3314.9 43.04 41.00 63 02 63.70 2672.5 2750.0 681.0 1295.6 0.00 7123 1356.0 2.00 000 167.70 681.0 712.3 Kaloa~wp04 9 4730.3 12.69 63 70 4000.0 992.6 1925.2 200 180.00 942 6 CASING DETAILS No TVD MD Name Size 1 620.0 620.0 9 5/8" 9-5/8 2 3999.9 4730.2 51/2" 5-1/2 LEGEND -e- Kaloa #2, Kaloa #2, Kaloa #2 VO -~ Kaloa #4 wp04 Aurora Gas, LLC 20° 4500 ,v~ 15° ~aP' 1000 4000 ~...`>'4730 Ap1~,~~'r 5112" ~~ .r o Start DLS 2.00 TFO 180.00 ~ ~?~ S O Kaloa #4lKaloa #4 wp04 ~ 750 Start DIS 2.00 TFO (67.70 _ ~ 7 i:aloa-3 up(r! j 4500 - 2s o 0 500 1000 1500 $ --500 ~`:'r .+. 0 `~ G Azimuths to Grid North O T True North: 1.18° o ~~ MMagneticNorth:21.04° -250 ~' Start DLS 5.50 TFO 0.00 !r Magnetic Field `~ Q~ SVength:55554.9nT i - Dip Angle: 73.77° Start Build 5.00 y',ro Start Hdd 1745 5 Date: 8/12/2005 0 o Model: BGGM2005 Start Build 4.29 Start DLS 6.00 TFO 15.15 -250 0 250 500 750 1000 1250 1500 1750 2000 West(-)/East(+) (500 fi/in) • • }.~q~„(,,,~Br„~~°'~-pN Halliburton Energy Services Planning Report -Geographic Sperry IDrilliing Services Databas®: EDM 2003.11 Single. User Db Local Co-ordinate Reference: Well Kaloa 1x4 Company: Aurora Gas, LLC TVD Reference: WELL Q 196.Oft (Original Weq Elev) Project: Cook Inlet MD Reference: WELL @ 196.Oft (Original WeII Elev) Site: Kaloa North Reference: Grid Well: Kaloa #4 Survey Calculation Method: Minimum Curvature Wellbore: Kaloa #4 Design: Kaloa #4 wp04 Project Cook Inlet, USA Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well Kaloa #4 -- - -- - Well Poskion +N/-S 0.0 ft Northing: 2,568,987.73 ft Latkude: 61 ° 01' 09.684" N ', +E/-W 0.0 ft Easting: 260,742.00 ft Longitude: 151 ° 20' 55.561" W ~, Position Uncertainty 0.0 ft Wellhead E levation: ft Ground Level: 185.0 ft Wellbore Kaloa #4 __ _ __ Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 8/12/2005 19.86 73.77 55,555 Design Kaloa 1k1 wp04 _ ___ _ - ', Audit Notes: i ~I Version: Phase: PLAN Tie On Depth: t 0.0 Vertical Section: Depth From (TVD) +Ni-S +Ei-W Directio n (ft) Ift) (ft) (°) 0.0 0.0 0.0 279.11 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/.yy Rate Rate Rate TFO Ift) (°) 1°) lftl (ft) (ft) (°t100ft) (°/100ft) (°l100ft) (°) 0.0 0.00 57.00 0.0 0.0 0.0 0.00 0.00 0.00 0.00 660.0 0.00 57.00 660.0 0.0 0.0 0.00 0.00 0.00 57.00 800.0 6.00 57.00 799.7 4.0 6.1 4.29 4.29 0.00 57.00 900.0 11.00 57.00 898.6 12.0 18.5 5.00 5.00 0.00 0.00 1,200.0 27.50 57.00 1,180.9 65.7 101.2 5.50 5.50 0.00 0.00 1,465.1 43.04 63.02 1,396.7 140.6 234.0 6.00 5.86 2.27 15.15 3,210.5 43.04 63.02 2,672.5 681.0 1,295.6 0.00 0.00 0.00 0.00 3,314.9 41.00 63.70 2,750.0 712.3 1,358.0 2.00 -1.95 0.65 167.70 4,730.3 12.69 63.70 4,000.0 992.6 1,925.2 2.00 -2.00 0.00 180.00 8/25/2005 7:18:06AM Page 2 of 4 COMPASS 2003.118ui1d 48 HgLL,~B(„~~";"~~ Hallibu rton Energy Services Planning Report - Geograph ic Sperry Drilling Services Database: EDM 2003.11 Single Userbb Loc al Co-ordinate Reference: Well Kaloa #4 Company: Aurora Gas, LLC ND Reference: WELL @ 196:Oft (Original Well Elev) Project: Cook I nlet MD Reference: WELL @ 196.Oft (Original Well Elev) Site: Kaloa North Reference: Grid Well: Kaloa #4 Survey Calculatio n Method: Minimum Curvature Wellbore: Kaloa #4 Design: Kaloa #4 wp04 Planned Survey Kaloa #4 wp 04 Map Map MD Inclination Azimuth ND SSND +N/-S +E/-W Northing Easting DLSEV Vert Section (ft! (°) (°) Iftl (ft) (ft) (ftl (ftl (ftl (°/100ft) (ftl 0.0 0.00 57.00 0.0 -196.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 100.0 0.00 57.00 100.0 -96.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 ', ', 200.0 0.00 57.00 200.0 4.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 300.0 0.00 57.00 300.0 104.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 400.0 0.00 57.00 400.0 204.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 500.0 0.00 57.00 500.0 304.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 600.0 0.00 57.00 600.0 404.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 620.0 0.00 57.00 620.0 424.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 ', 95!8" I 660.0 0.00 57.00 660.0 464.00 0.0 0.0 2,566,987.73 260,742.00 0.00 0.00 Start Build 4.29 700.0 1.71 57.00 700.0 503.99 0.3 0.5 2,566,988.06 260,742.50 4.29 -0.44 800.0 6.00 57.00 799.7 603.74 4.0 6.1 2,566,991.72 260,748.14 4.29 -5.43 ', start B~ila s.oo 900.0 11.00 57.00 898.6 702.61 12.0 18.5 2,566,999.77 260,760.53 5.00 -16.39 Start DLS 5.50 TFO 0.00 ', 1,000.0 16.50 57.00 995.7 799.71 25.0 38.5 2,567,012.71 260,780.46 5.50 -34.02 ~~ 1,100.0 22.00 57.00 1,090.1 894.08 42.9 66.1 2,567,030.65 260,808.10 5.50 -58.46 1,200.0 27.50 57.00 1,180.9 984.86 65.7 101.2 2,567,053.45 260,843.20 5.50 -89.51 Start DLS 6.00 TFO 15.1 5 1,250.0 30.40 58.55 1,224.6 1,028.61 78.6 121.7 2,567,066.34 260,863.67 6.00 -107.69 1,300.0 33.33 59.85 1,267.1 1,071.07 92.1 144.4 2,567,079.84 260,886.35 6.00 -127.94 ', 1,350.0 36.26 60.96 1,308.1 1,112.12 106.2 169.2 2,567,093.92 260,911.15 6.00 -150.20 1,400.0 39.20 61.93 1,347.7 1,151.67 120.8 196.0 2,567,108.53 260,938.03 6.00 -174.42 1,450.0 42.15 62.78 1,385.6 1,189.58 135.9 224.9 2,567,123.64 260,966.89 6.00 -200.53 1,465.1 43.04 63.02 1,396.7 1,200.70 140.6 234.0 2,567,128.29 260,975.99 6.00 -208.77 ', Start Hold 1745.5 ~, 1,500.0 43.04 63.02 1,422.2 1,226.21 151.4 255.2 2,567,139.10 260,997.22 0.00 I -228.02 1,600.0 43.04 63.02 1,495.3 1,299.30 182.3 316.0 2,567,170.06 261,058.04 0.00 -283.17 1,700.0 43.04 63.02 1,568.4 1,372.39 213.3 376.9 2,567,201.02 261,118.86 0.00 -338.32 1,800.0 43.04 63.02 1,641.5 1,445.48 244.3 437.7 2,567,231.98 261,179.67 0.00 -393.47 1,900.0 43.04 63.02 1,714.6 1,518.57 275.2 498.5 2,567,262.94 261,240.49 0.00 -448.62 2,000.0 43.04 63.02 1,787.7 1,591.66 306.2 559.3 2,567,293.90 261,301.31 0.00 -503.77 II 2,100.0 43.04 63.02 1,860.8 1,664.75 337.1 620.2 2,567,324.85 261,362.13 0.00 -558.91 ', 2,200.0 43.04 63.02 1,933.8 1,737.84 368.1 681.0 2,567,355.81 261,422.95 0.00 -614.06 2,300.0 43.04 63.02 2,006.9 1,810.93 399.1 741.8 2,567,386.77 261,483.77 0.00 -669.21 2,400.0 43.04 63.02 2,080.0 1,884.02 430.0 802.6 2,567,417.73 261,544.59 0.00 -724.36 2,500.0 43.04 63.02 2,153.1 1,957.11 461.0 863.4 2,567,448.69 261,605.41 0.00 -779.51 ~~ ~' 2,600.0 43.04 63.02 2,226.2 2,030.20 491.9 924.3 2,567,479.65 261,666.23 0.00 -834.66 2,700.0 43.04 63.02 2,299.3 2,103.29 522.9 985.1 2,567,510.61 261,727.04 0.00 -889.81 '~ 2,800.0 43.04 63.02 2,372.4 2,176.38 553.9 1,045.9 2,567,541.57 261,787.86 0.00 -944.95 ~' 2,900.0 43.04 63.02 2,445.5 2,249.47 584.8 1,106.7 2,567,572.53 261,848.68 0.00 -1,000.10 ~ 3,000.0 43.04 63.02 2,518.6 2,322.56 615.8 1,167.5 2,567,603.48 261,909.50 0.00 -1,055.25 !I 3,100.0 43.04 63.02 2,591.7 2,395.65 646.7 1,228.4 2,567,634.44 261,970.32 0.00 -1,110.40 ', 3,200.0 43.04 63.02 2,664.7 2,468.75 677.7 1,289.2 2,567,665.40 262,031.14 0.00 -1,165.55 ', 3,210.5 43.04 63.02 2,672.5 2,476.46 681.0 1,295.6 2,567,668.67 262,037.56 0.00 -1,171.37 Start DLS 2.00 TFO 167070 8/15/2005 7:18:O6AM Page 3 of 4 COMPASS 2003.11 Build 48 ! • ~q~,,,,Lrg ~„~R°~'jpN Halliburton Energy Services Planning Report -Geographic Sperry ©rill+ng Services Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Kaloa #4 Company: Aurora Gas, LLC TVD Reference: WELL @ 196.Oft (Original Well Elev) Project: Cook Inlet MD Reference: WELL @ 196.Oft (Original Well Elev) Site: Kaloa North Reference: Grid Well: Kaloa #4 Survey Calculation Method: Minimum Curvature Wellbore: Kaloa #4 Design: Kaloa #4 wp04 __ Planned Survey Kaloa #4 wp04 Map Map MD In clination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section Ift1 (°1 1°1 Ift1 lft1 Ift- Ift) Iftl Ift1 (°/looft) Iftl 3,300.0 41.29 63.60 2,738.8 2,542.76 707.9 1,349.2 2,567,695.64 262,091.20 2.00 -1,220.06 3,314.9 41.00 63.70 2,750.0 2,554.00 712.3 1,358.0 2,567,700.00 262,100.00 2.00 -1,228.06 Start DLS 2.00 TFO 180.00 - Kaloa-4 wp04 ', 3,400.0 39.30 63.70 2,815.0 2,619.02 736.6 1,407.2 2,567,724.30 262,149.17 2.00 -1,272.76 3,500.0 37.30 63.70 2,893.5 2,697.50 764.1 1,462.8 2,567,751.76 262,204.72 2.00 -1,323.27 3,600.0 35.30 63.70 2,974.1 2,778.09 790.3 1,515.8 2,567,777.99 262,257.79 2.00 -1,371.51 3,700.0 33.30 63.70 3,056.7 2,860.69 815.2 1,566.4 2,567,802.95 262,308.30 2.00 -1,417.43 3,800.0 31.30 63.70 3,141.2 2,945.21 838.9 1,614.3 2,567,826.62 262,356.20 2.00 -1,460.98 ~, 3,900.0 29.30 63.70 3,227.6 3,031.55 861.3 1,659.5 2,567,848.97 262,401.43 2.00 -1,502.09 4,000.0 27.30 63.70 3,315.6 3,119.59 882.3 1,702.0 2,567,869.98 262,443.92 2.00 -1,540.72 4,100.0 25.30 63.70 3,405.2 3,209.24 901.9 1,741.7 2,567,889.61 262,483.64 2.00 -1,576.83 4,200.0 23.30 63.70 3,496.4 3,300.38 920.1 1,778.6 2,567,907.84 262,520.52 2.00 -1,610.36 4,300.0 21.30 63.70 3,588.9 3,392.89 936.9 1,812.6 2,567,924.65 262,554.54 2.00 -1,641.28 ', 4,400.0 19.30 63.70 3,682.7 3,486.68 952.3 1,843.7 2,567,940.02 262,585.63 2.00 -1,669.56 ', 4,500.0 17.30 63.70 3,777.6 3,581.61 966.2 1,871.8 2,567,953.93 262,613.78 2.00 -1,695.14 4,600.0 15.30 63.70 3,873.6 3,677.59 978.7 1,897.0 2,567,966.36 262,638.94 2.00 -1,718.01 4,700.0 13.30 63.70 3,970.5 3,774.49 989.6 1,919.1 2,567,977.30 262,661.08 2.00 -1,738.14 4,730.2 12.70 63.70 3,999.9 3,803.90 992.6 1,925.2 2,567,980.31 262,667.16 2.00 -1,743.67 5 1/2" 4,730.3 12.69 63.70 4,000.0 3,804.00 992.6 1,925.2 2,567,980.32 262,667.18 2.00 -1,743.69 ', TD at 4730.3 Geologic Targets Kaloa #4 - _ __ _ _ __ TVD Ta rget Name +N/-S +E!-W Northing Easting Ift) -Shape ft ft (ft) (ft) 2,750.0 Kaloa-4 wp04 712. 3 1,358.0 2,567,700. 00 262,100.00 -Point I Prognosed Casing P oints Measured Vertical Casing Hole Depth Depth Diameter Diameter lftl Ift) 1") (") 620.0 620.0 9-5/8 12-1/4 !, 4,730.2 3,999.9 5-112 6 8/22005 7:18:06AM Paqe 4 of 4 COMPASS 2003.11 Build 48 • • ~ ~ .~ Sperry L7riling Services Aurora Gas, LLC Cook Inlet Kaloa Kaloa #4 Kaloa #4 Kaloa #4 wp04 Anticollision Risk Report 25 August, 2005 • • Sl R\'F.\ PROGR.~\I Date:2005-08-257011:00:011 Validated:l'es Version: Depth From Depth To Survey/Plan Tool 0.0 0.0 Kaloa #4 wp04 BLIND 650.0 4729.5 Kal°a H4 wp04 1\VD zoo so :olour To 250 500 Aurora Gas, LLC 180 Travelling Cylinder .azimuth (TFO+AZI) [°[ vs Centre to Centre Separation [100 ft/in[ NAD 27 ASP Zone 4 : WELL DETAILS: Kaloa ff4 +NI-S +EI-W Northing 0.0 0.0 2586987.73 SECTION DETpll9 Sac MD Inc pzi T/0 •W-5 •EI-W DLe9 TFaca Veac Tagal 1 ao 00o szao as o0 o.a a o.ao 00 2 eaoo 009 s)m eaoo 0o aoo s]ao o.a 3 aooo aao s)m ]w.] a.o sl a29 s>oo ao goon nao szoo ewe ua ins Sao o.oo I2.o 5 1200.0 2)50 9].00 11e0.9 ~-] 101.3 5'A 000 w.) e I~nsl oa eaoz law.] I~o.e z3ao em Is.ls leo.e ] 32109 aJ.d e302 28729 win t2%.8 O.OO Ow w10 9 3a1~9 a100 43. h1 2]900 )12.3 tYdn I.001e].)0 ]12.3 Ktloa~+g0a 9 0]0312 fig 83]0 a0W0 9918 19292 in01e000 9925 ANTI-COLLISION SETTINGS REFERENCE INFORMATION 750 750 --- - 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 5000 Coordinate (WE) Reference: Well Kaloa k4, Grld North Vertical (TVD) Reference: WELL ~ 196.OR (Original WNI Elev) Section (VS) Reference: Slot - (O.ON, O.OE) Measured Depth Reference: WELL ~ 198.OR (Original WNI Elev) Calculation Method: Minimum Curvature Ground Level: 185.0 Fasting Lathtude longitude Slot 0742.00 61°1'9.684N 151°20'55.561W Drilling Interpolation Method: MD Interval: 100Stations Depth Range From: 0.0 To 4730.3 Calculation Method: Minimum Curvature Maximum Range:673.026963575127 Error System: ISCWSA Reference: Plan: Kaloa #4 wp04 Scan Method: Trav. Cylinder North Error Surtace: Eiliptlcal Conic Warning Method: Rules Based 0 HALLlBURTON Spaarry Orillnag t38rviices Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Error: O.Oft Reference Well: Kaloa #4 WeIF Error: O.Oft Reference Wellbore Kaloa #4 Reference Design: Kaloa #4 wp04 Halliburton Energy Services Anticollision Risk Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Kaloa #4 WELL @ 196.Oft (Original Well Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Kaloa i'f4 wp04 type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer ~olation Method: MD Interval 100.Oft Error Model: ISCWSA i Range: Unlimited Scan Method: Trav. Cylinder North is Limited by: Mabmum center-center distance of 673.Oft Error Surface: Elliptical Conic ng Levels Evaluated at: 0.00 Sigma Risk Settings Vertical Depth for Analysis: ft (Below TVD Reference Datum) Level of Acceptable Risk (1 in): Minimum Separation: 0 ft Survey Tool Program Date 8/25/2005 From To (ft) (ft) Survey (Wellbore) Tool Name Description ~ 0.0 0.0 Kaloa #4 wp04 (Kaloa #4) BLIND Blind drilling 650.0 4,729.5 Kaloa #4 wp04 (Kaloa #4) MWD MWD -Standard Summary Reference Offset Distance Measured Measured Between Between Separation Warning Site Name Depth Depth Centres Ellipses Factor Offset Well - Wellbore -Design Ift) (ftl (ftl (ftl Kaloa Kaloa #1 - Kaloa #1 - Kaloa #1 0.0 0.0 121.1 121.1 10,000.000 CC Kaloa #1 - Kaloa #1 - Kaloa #1 697.0 700.0 128.7 63.5 1.974 ES, SF Kaloa #1 - Kaloa #1 ST1 - Kaloa #1 ST1 0.0 0.0 121.1 121.1 10,000.000 CC Kaloa #1 - Kaloa #1 ST1 - Kaloa #1 ST1 697.0 700.0 128.7 63.5 1.974 ES, SF Kaloa #1 - Kaloa #1 ST2 - Kaloa #1 ST2 0.0 0.0 121.1 121.1 10,000.000 CC Kaloa #1 - Kaloa #1 ST2 - Kaloa #1 ST2 697.0 700.0 128.7 63.5 1.974 ES, SF Kaloa #2 - Kaloa #2 - Kaloa #2 796.3 800.0 108.7 19.6 1.220 ES, SF Kaloa #2 - Kaloa #2 - Kaloa #2 892.2 900.0 108.7 21.9 1.253 CC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/"15/2005 7:20:20AM Page 2 of 7 COMPASS 2003.11 Build 48 HAL.L.IBURT©N Sperry Drilling Services Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Ercor: O.Oft Reference Well: Kaloa #4 Well Error: O.Oft Reference Wellbore Kaloa #4 Reference Design: Kaloa #4 wp04 Halliburton Energy Services Anticollision Risk Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Datab~e: Offset ND Reference: Well Kaloa #4 WELL @ 196.Oft (Original Well Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Offset Design Kaloa - Kaloa #1 - Kaloa #1 - Kaloa #1 onset Ske Error. o.oft Survey Program: 653-C&MAGSS Offset Well F.nor: O.Oft Reference Offse t Semi Major Axis Distance Measured Vertical Measured Vertlcal Reference Offset Highside Betxreen 9etvvten MlMmum Separation Risked Probabil~r Warning. Depth Depth Depth Depth Toolface Centres Ellipses Separatfon Factor Separation of Collision tftl tnl Ift- tR) (ft) (ft) 1°I !n) IR- (frl Factor 0.0 0.0 0.0 0.0 0.0 0.0 -156.16 121.1 121.1 0.00 10,000.000 CC 100.0 100.0 100.0 100.0 0.4 0.3 -156.26 121.2 118.4 2.80 43.219 200.0 200.0 200.0 200.0 1.9 0.6 -156.59 121.6 113.2 8.45 14.398 300.0 300.0 300.0 300.0 4.4 1.0 -157.12 122.3 105.5 16.83 7.267 400.0 400.0 400.0 400.0 8.0 1.3 -157.86 123.3 95.4 27.96 4.410 499.9 499.9 500.0 499.9 12.7 1.6 -158.78 124.7 82.8 41.84 2.980 599.9 599.9 600.0 599.9 18.4 1.9 -159.89 126.3 67.9 58.45 2.161 697.0 697.0 700.0 699.8 20.3 2.3 -160.99 128.7 63.5 65.23 1.974 ES, SF 789.6 789.4 800.0 799.8 20.3 2.7 -160.57 135.7 68.6 67.14 2.021 879.8 878.8 900.0 899.7 20.3 3.2 -158.19 148.0 79.2 68.78 2.152 966.7 963.7 1,000.0 999.7 20.3 3.7 -154.44 166.8 96.8 70.01 2.383 1,049.5 1,042.8 1,100.0 1,099.7 20.4 4.1 -150.46 194.5 123.8 70.70 2.752 1,127.6 1,115.5 1,200.0 1,199.6 20.4 4.5 -146.72 230.3 159.4 70.91 3.248 1,200.0 1,180.9 1,300.0 1,299.5 20.4 5.0 -143.58 273.7 202.9 70.78 3.867 1,268.0 1,240.1 1,400.0 1,399.4 20.4 5.4 -140.57 324.0 253.6 70.40 4.603 1,329.5 1,291.4 1,500.0 1,499.2 20.5 5.7 -137.67 380.8 311.2 69.58 5.473 1,385.4 1,336.3 1,600.0 1,599.0 20.5 6.2 -135.36 442.9 374.1 68.76 6.441 1,436.3 1,375.4 1,700.0 1,698.7 20.5 6.6 -133.38 509.2 441.3 67.89 7.500 1,493.3 1,417.4 1,800.0 1,798.5 20.6 7.1 -131.83 577.8 509.9 67.97 8.502 1,564.5 1,469.4 1,900.0 1,898.4 20.7 7.6 -130.69 647.1 577.6 69.46 9.316 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/25/2005 7:20:20AM Page 3 of 7 COMPASS 2003.11 Build 48 HAL.L.IBURT©N Sperry ®rling Services Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Error: O.Oft Reference Well: Kaloa #4 Well Error: O.Oft Reference Welibore Kaloa #4 Reference Design: Kaloa #4 wp04 • Halliburton Energy Services Anticollision Risk Repoli Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Datattase: Offset ND Reference: Well Kaloa #4 WELL @ 196.Oft (Original Well Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Offset Design Kaloa - Kaloa #1 - Kaloa #1 ST1 - Kaloa #1 ST1 onset sloe error. o.oft Survey Program: 653-C&MAGSS, 6590-CB-MAGSS OffaeE Well Ertor. 0.0 ft Reference Onset Semi Major Axis DhNaru:e Measured Vertical Measured Vertical Reference Ortset Highside BetNreen Between Minimum Separation tasked Probability Warning Depth Depth Deplh Depth TooHace Centres Ellipses Separation Factor Separation of Cogision (n- (nl In1 (ft) (nl (RI l°i (ft- In1 (ft) Factor a.o a.o o.o o.o o.o o.o -15s.1s 121.1 121.1 0.00 10,000.000 CC 100.0 100.0 100.0 100.0 0.4 0.3 -156.26 121.2 118.4 2.80 43.219 200.0 200.0 200.0 200.0 1.9 0.6 -156.59 121.6 113.2 8.45 14.398 300.0 300.0 300.0 300.0 4.4 1.0 -157.12 122.3 105.5 16.83 7.267 400.0 400.0 400.0 400.0 8.0 1.3 -157.86 123.3 95.4 27.96 4.410 499.9 499.9 500.0 499.9 12.7 1.6 -158.78 124.7 82.8 41.84 2.980 599.9 599.9 600.0 599.9 18.4 1.9 -159.89 126.3 67.9 58.45 2.161 697.0 697.0 700.0 699.8 20.3 2.3 -160.99 128.7 63.5 65.23 1.974 ES, SF 789.6 789.4 800.0 799.8 20.3 2.7 -160.57 135.7 68.6 67.14 2.021 879.8 878.8 900.0 899.7 20.3 3.2 -158.19 148.0 79.2 68.78 2.152 966.7 963.7 1,000.0 999.7 20.3 3.7 -154.44 166.8 96.8 70.01 2.383 1,049.5 1,042.8 1,100.0 1,099.7 20.4 4.1 -150.46 194.5 123.8 70.70 2.752 1,127.6 1,115.5 1,200.0 1,199.6 20.4 4.5 -146.72 230.3 159.4 70.91 3.248 1,200.0 1,180.9 1,300.0 1,299.5 20.4 5.0 -143.58 273.7 202.9 70.78 3.867 1,268.0 1,240.1 1,400.0 1,399.4 20.4 5.4 -140.57 324.0 253.6 70.40 4.603 1,329.5 1,291.4 1,500.0 1,499.2 20.5 5.7 -137.67 380.8 311.2 69.58 5.473 1,385.4 1,336.3 1,600.0 1,599.0 20.5 6.2 -135.36 442.9 374.1 68.76 6.441 1,436.3 1,375.4 1,700.0 1,698.7 20.5 6.6 -133.38 509.2 441.3 67.89 7.500 1,493.3 1,417.4 1,800.0 1,798.5 20.6 7.1 -131.83 577.8 509.9 67.97 8.502 1,564.5 1,469.4 1,900.0 1,898.4 20.7 7.6 -130.69 647.1 577.6 69.46 9.316 CC -Min centre to center distance or wvergent point, SF -min separation factor, ES -min ellipse separation 8/25/2005 7:20:20AM Page 4 of 7 COMPASS 2003.11 Build 48 HALLIE3URTON Sperry drilling Services Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Error: O.Oft Reference Well: Kaloa #4 Well Error: O.Oft Reference Wellbore Kaloa #4 Reference Design: Kaloa #4 wp04 Halliburton Energy Services Anticollision Risk Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Kaloa #4 WELL @ 196.Oft (Original Wetl Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Offset Design Kaloa - Kaloa #1 - Kaloa #1 ST2 - Kaloa #1 ST2 oesetsi<e Error: o.oft Survey Program: 653-C&MAGSS, 6590&MAG-SS, 7120-C&MAG-SS Otrset Welf Flror. 0.0 ft Reference Offset SerN Major Axis Distance Measured Vertical Measured VeMcel Reference Offset Highside Between Betvreen Minimum Separatlon. Risked Probability Warning Depth Depth Depth Depth Toolface Centres Ellipses Separatlon Factor Separatlon of Collision (~1 lKl (rtl (n1 Iftl Iftl 1°1 Irt- In) (ft) Factor o.o o.o o.o o.o o.o o.o -15s.1s 121.1 121.1 0.00 10,000.000 CC 100.0 100.0 100.0 100.0 0.4 0.3 -156.26 121.2 118.4 2.80 43.219 200.0 200.0 200.0 200.0 1.9 0.6 -156.59 121.6 113.2 8.45 14.398 300.0 300.0 300.0 300.0 4.4 1.0 -157.12 122.3 105.5 16.83 7.267 400.0 400.0 400.0 400.0 8.0 1.3 -157.86 123.3 95.4 27.96 4.410 499.9 499.9 500.0 499.9 12.7 1.6 -158.78 124.7 82.8 41.84 2.980 599.9 599.9 600.0 599.9 18.4 1.9 -159.89 126.3 67.9 58.45 2.161 697.0 697.0 700.0 699.8 20.3 2.3 -160.99 128.7 63.5 65.23 1.974 ES, SF 789.6 789.4 800.0 799.8 20.3 2.7 -160.57 135.7 68.6 67.14 2.021 879.8 878.8 900.0 899.7 20.3 3.2 -158.19 148.0 79.2 68.78 2.152 966.7 963.7 1,000.0 999.7 20.3 3.7 -154.44 166.8 96.8 70.01 2.383 1,049.5 1,042.8 1,100.0 1,099.7 20.4 4.1 -150.46 194.5 123.8 70.70 2.752 1,127.6 1,115.5 1,200.0 1,199.6 20.4 4.5 -146.72 230.3 159.4 70.91 3.248 1,200.0 1,180.9 1,300.0 1,299.5 20.4 5.0 -143.58 273.7 202.9 70.78 3.867 1,268.0 1,240.1 1,400.0 1,399.4 20.4 5.4 -140.57 324.0 253.6 70.40 4.603 1,329.5 1,291.4 1,500.0 1,499.2 20.5 5.7 -137.67 380.8 311.2 69.58 5.473 1,385.4 1,336.3 1,600.0 1,599.0 20.5 6.2 -135.36 442.9 374.1 68.76 6.441 1,436.3 1,375.4 1,700.0 1,698.7 20.5 6.6 -133.38 509.2 441.3 67.89 7.500 1,493.3 1,417.4 1,800.0 1,798.5 20.6 7.1 -131.83 577.8 509.9 67.97 8.502 1,564.5 1,469.4 1,900.0 1,898.4 20.7 7.6 -130.69 647.1 577.6 69.46 9.316 CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/25/2005 7.•20:20AM Page 5 of 7 COMPASS 2003.11 Build 48 HQ~..ILIBURTEaN Sperry Drilling Services Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Error: O.Oft Reference Well: Kaloa #4 Well Error: O.Oft Reference Wellbore Kaloa #4 Reference Design: Kaloa #4 wp04 • Halliburton Energy Services Anticollision Risk Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Datab~e: Offset ND Reference: Well Kaloa #4 WELL @ 196.Oft (Original Well Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Offset Design Kaloa - Kaloa #2 - Kaloa #2 - Kaloa #2 Olfset Site Error. o.o ft Survey Program: 510-INC Offset Well Ertor. 0.0 ft Reference OtFs et Semi Major Axis Distarrce Measured Vertical Measured Vertical Reference Onset Highside Between Between Minimum Separation Risked Probabghy Warning Depth Depth Depth Depth Toolface Centres Ellipses Separation Factor Separation of Collision (Rl (R- Iftl IftI Ift1 (R) (°- jrt) (R) (ft) Factor 0.0 0.0 0.0 0.0 0.0 0.0 165.21 127.3 127.3 0.00 10,000.000 100.0 100.0 100.0 100.0 0.4 2.6 165.17 127.0 122.7 4.31 29.458 200.0 200.0 200.0 200.0 1.9 5.3 165.05 126.0 114.5 11.48 10.976 300.0 300.0 300.0 300.0 4.4 7.9 164.85 124.3 102.9 21.43 5.802 400.0 400.0 400.0 400.0 8.0 10.6 164.56 122.0 87.8 34.19 3.569 499.9 499.9 500.0 499.9 12.7 13.2 164.16 119.1 69.3 49.78 2.392 599.8 599.8 600.0 599.8 18.4 20.9 163.66 115.5 43.6 71.91 1.606 698.8 698.8 700.0 699.7 20.3 29.2 163.32 111.5 26.8 84.74 1.316 796.3 796.0 800.0 799.6 20.3 37.5 165.89 108.7 19.6 89.12 1.220 ES, SF 892.2 890.9 900.0 899.5 20.3 45.8 172.32 108.7 21.9 86.80 1.253 CC 985.2 981.4 1,000.0 999.3 20.3 54.1 -177.70 114.2 29.6 84.52 1.351 1,074.3 1,066.1 1,100.0 1,099.1 20.4 62.4 -166.10 128.2 26.0 102.15 1.255 1,158.7 1,143.9 1,200.0 1,198.8 20.4 73.4 -155.36 152.7 21.4 131.31 1.163 1,238.0 1,214.3 1,300.0 1,296.6 20.4 84.4 -146.65 187.5 27.5 160.01 1.172 1,311.5 1,276.7 1,400.0 1,398.3 20.4 95.4 -139.66 231.2 46.2 185.03 1.250 1,378.6 1,330.9 1,500.0 1,498.1 20.5 106.4 -134.28 282.6 77.2 205.39 1.376 1,439.4 1,377.7 1,600.0 1,597.8 20.5 117.4 -130.15 340.5 118.9 221.58 1.537 1,506.1 1,426.7 1,700.0 1,697.6 20.6 128.4 -127.09 403.2 161.9 241.33 1.671 1,581.2 1,481.5 1,800.0 1,797.4 20.7 139.4 -124.92 467.2 202.0 265.21 1.762 1,656.2 1,536.4 1,900.0 1,897.1 20.9 149.9 -123.28 531.7 244.3 287.48 1.850 1,731.0 1,591.1 2,000.0 1,996.9 21.0 158.2 -122.09 597.1 291.8 305.31 1.956 1,8054 1,645.4 2,100.0 2,096.8 21.1 166.4 -121.24 663.3 341.1 322.21 2.059 CC - WGn centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/25/2005 7:20:20AM Page 6 of 7 COMPASS 2003.11 Build 48 • HALiLIBURTON f3pearry I©riling Saervic~e~ Company: Aurora Gas, LLC Project: Cook Inlet Reference Site: Kaloa Site Error: O.Oft Reference Well: Kaloa #4 Well Error: O.Oft Reference Welltwre Kaloa #4 Reference Design: Kaloa #4 wp04 • Halliburton Energy Services Anticollision Risk Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset ND Reference: Well Kaloa #4 WELL @ 196.Oft (Original Well Elev) WELL @ 196.Oft (Original Well Elev) Grid Minimum Curvature 1.00 sigma EDM 2003.11 Single User Db Offset Datum Reference Depths are relative to WELL @ 196.Oft (Original Well Elev) Coordinates are relative to: Kaloa #4 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927 (Exact solution), Alaska Zone 04 Central Meridian is -150.00000000 ° Grid Convergence at Surface is: -1.18° CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 8/2512005 7:20:20AM Page 7 of 7 COMPASS 2003.11 Build 48 Subjects Kal~~a -_a From: ~luan~ ~~iu~_cu ~_~lu~in~u l~iim.cathrr.c~,iri~ Date: Snn_ ~S ~u~ ?UU~ I (,3G~ 13 -U~~ii(i fo: iom rn~undci~"u s~lmin.,tatcah.ut. b~~int~,n .lubcrt ~-~~ imon ,uihcrtzi ~~lmin.~rat ~.a4:.us~,_ slc~~ ~I.~, isn ;~~lmin.~l;u~.,ik.us I submitted a PTD application on Friday the 26th on behalf of Aurora Gas, LLC for the drilling of Kaloa No. 4. I forgot to include the directional plan for that well. Please see the attached. Regads Duane Vaagen Project Engineer Fairweather E&P Services, Inc. • duane(c~fairweather.com Office: (907)258-3446 Cell: (907)240-1107 Cook Inlet Kaloa #4 MD, Inc, Azim. , SSTVD, TVD, N/S „ E/W „ Y „ X „ DLS, V.S., Comments, E/W, N/S (°/100ft) , (ft) , (Deg) , (Deg) , (ft) , (ft) , (ft ) „ (ft) „ (ft) „ (ft) „ °/100ft , (ft) , (ft) , (ft) 0.00, 0 .00, 57. 00, -196. 00, 0. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 100.00, 0 .00, 57. 00, -96. 00, 100. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, O .OO,BLIND (1) 200.00, 0 .00, 57. 00, 4. 00, 200. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 300.00, 0 .00, 57. 00, 104. 00, 300. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 400.00, 0 .00, 57. 00, 204. 00, 400. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 500.00, 0 .00, 57. 00, 304. 00, 500. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 600.00, 0 .00, 57. 00, 404. 00, 600. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00, 620.00, 0 .00, 57. 00, 424. 00, 620. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, 0 .00,9 5/8 " - MWD (2) 660.00, 0 .00, 57. 00, 464. 00, 660. 00, O. OO,N, O. OO,E, 2566987 .730, N, 260742 .000,E, 0.000, O .OO,Start Build 4.29 700.00, 1 .71, 57. 00, 503. 99, 699. 99, 0. 33,N, 0. 50, E, 2566988 .056, N, 260742 .502,E, 4.286, 0 .33, 800.00, 6 .00, 57. 00, 603. 74, 799. 74, 3. 99, N, 6. 14,E, 2566991 .719,N, 260748 .142,E, 4.286, 3 .99,Start Build 5.00 900.00, 11 .00, 57. 00, 702. 61, 898. 61, 12. 04,N, 18. 53,E, 2566999 .766,N, 260760 .534,E, 5.000, 12 .04,Start DLS 5.50 TFO 0.00 1000.00, 16 .50, 57. 00, 799. 71, 995. 71, 24. 98, N, 38. 46,E, 2567012 .705,N, 260780 .459, E, 5.500, 24 .98, 1100.00, 22 .00, 57. 00, 894. 08, 1090. 08, 42. 93, N, 66. 10,E, 2567030 .654,N, 260808 .097,E, 5.500, 42 .93, 1200.00, 27 .50, 57. 00, 984. 86, 1180. 86, 65. 72,N, 101. 20,E, 2567053. 447, N, 260843 .195,E, 5.500, 65. 72,Start DLS 6.00 TFO 15.15 1250.00, 30 .40, 58. 55, 1028. 61, 1224. 61, 78. 61, N, 121. 68,E, 2567066. 337,N, 260863 .672,E, 6.000, 78. 61, 1299.99, 33 .33, 59. 85, 1071. 07, 1267. 07, 92. 11, N, 144. 35,E, 2567079. 840,N, 260886 .347,E, 6.000, 92. 11, 1349.99, 36 .26, 60. 96, 1112. 12, 1308. 12, 106. 19, N, 169. 16,E, 2567093. 918, N, 260911 .155,E, 6.000, 106. 19, 1399.99, 39 .20, 61. 93, 1151. 67, 1347. 67, 120. 81, N, 196. 04,E, 2567108. 532,N, 260938 .029, E, 6.000, 120. 81, 1449.99, 42 .15, 62. 78, 1189. 58, 1385. 58, 135. 92, N, 224. 90,E, 2567123. 642,N, 260966 .894,E, 6.000, 135. 92, 1465.09, 43 .04, 63. 02, 1200. 70, 1396. 70, 140. 57, N, 234. OO,E, 2567128. 295,N, 260975 .988, E, 6.000, 140. 57,Start Hold 1745.5 1499.99, 43 .04, 63. 02, 1226. 21, 1422. 21, 151. 38, N, 255. 23,E, 2567139. 1O1,N, 260997 .217,E, 0.000, 151. 38, 1599.99, 43 .04, 63. 02, 1299. 30, 1495. 30, 182. 34, N, 316. O5,E, 2567170. 060, N, 261058 .036,E, 0.000, 182 .34, 1699.99, 43 .04, 63. 02, 1372. 39, 1568. 39, 213. 30,N, 376. 87,E, 2567201 .019, N, 261118 .SSS,E, 0.000, 213 .30, 1799.99, 43 .04, 63. 02, 1445. 48, 1641. 48, 244. 26,N, 437. 69,E, 2567231 .978, N, 261179 .674,E, 0.000, 244 .26, 1899.99, 43 .04, 63. 02, 1518. 57, 1714. 57, 275. 22, N, 498. S1,E, 2567262. 937, N, 261240 .493,E, 0.000, 275 .22, 1999.99, 43 .04, 63. 02, 1591. 66, 1767. 66, 306. 16, N, 559. 33,E, 2567293. 895, N, 261301 .312,E, 0.000, 306 .18, 2099.99, 43 .04, 63. 02, 1664. 75, 1860. 75, 337. 14, N, 620. 15,E, 2567324. 854,N, 261362 .131,E, 0.000, 337. 14, 2199.99, 43 .04, 63. 02, 1737. 84, 1933. 84, 368. 10, N, 680. 97,E, 2567355. 813,N, 261422 .950,E, 0.000, 368. 10, 2299.99, 43 .04, 63. 02, 1810. 93, 2006. 93, 399. 06, N, 741. 79,E, 2567386. 772,N, 261483 .769, E, 0.000, 399 .06, 2399.99, 43 .04, 63. 02, 1884. 02, 2080. 02, 430. 02, N, 802. 62,E, 2567417. 731,N, 261544 .588, E, 0.000, 430 .02, 2499.99, 43 .04, 63. 02, 1957. 11, 2153. 11, 460. 98, N, 863. 44,E, 2567448. 690, N, 261605 .407,E, 0.000, 460. 98, 2599.99, 43 .04, 63. 02, 2030. 20, 2226. 20, 491. 94, N, 924. 26,E, 2567479. 649,N, 261666 .226,E, 0.000, 491 .94, 2699.99, 43 .04, 63. 02, 2103. 29, 2299. 29, 522. 90, N, 985. OS,E, 2567510. 608,N, 261727 .045, E, 0.000, 522. 90, 2799.99, 43. 04, 63.02, 2176.38, 2372.38, 553.86, N, 1045.90,E, 2567541.567,N, 261787. 864,E, 0.000, 553 .86, 2899.99, 43 .04, 63.02, 2249 .47, 2445. 47, 584. 82,N, 1106.72,E, 2567572.525,N, 261848. 683,E, 0.000, 584 .82, 2999.99, 43 .04, 63.02, 2322 .56, 2518. 56, 615. 78, N, 1167.54,E, 2567603.484,N, 261909. 502,E, 0.000, 615 .78, 3099.99, 43. 04, 63.02, 2395 .65, 2591. 65, 646. 74,N, 1228.36, E, 2567634.443,N, 261970. 321, E, 0.000, 646 .74, 3199.99, 43 .04, 63.02, 2468 .75, 2664. 75, 677. 70, N, 1289.18, E, 2567665.402, N, 262031. 140, E, 0.000, 677 .70, 3210.55, 43 .04, 63.02, 2476 .46, 2672. 46, 680. 97, N, 1295.61,E, 2567668.671, N, 262037. 562,E, 0.000, 680 .97,Start DLS 2.00 TFO 167.70 3299.99, 41 .29, 63.60, 2542 .76, 2738. 76, 707. 93, N, 1349.24,E, 2567695.639,N, 262091. 196,E, 2.000, 707 .93, 3314.92, 41 .00, 63.70, 2554 .00, 2750. 00, 712. 29,N, 1358.OS,E, 2567700.000,N, 262100. 000,E, 2.000, 712 .29,Start DLS 2.00 TFO 180.00 - Kaloa-4 wp04 3399.99, 39. 30, 63.70, 2619 .02, 2815. 02, 736. 60, N, 1407.22,E, 2567724.301, N, 262149. 169, E, 2.000, 736 .60, 3499.99, 37. 30, 63.70, 2697. 50, 2893. 50, 764. O5,N, 1462.78, E, 2567751.758, N, 262204. 725, E, 2.000, 764 .05, 3599.99, 35. 30, 63.70, 2778. 09, 2974. 09, 790. 28, N, 1515.64,E, 2567777.985, N, 262257. 791,E, 2.000, 790 .28, 3699.99, 33. 30, 63.70, 2860. 69, 3056. 69, 815. 25,N, 1566.36,E, 2567802.950, N, 262308. 304,E, 2.000, 815 .25, 3799.98, 31. 30, 63.70, 2945. 21, 3141. 21, 838. 92,N, 1614.26,E, 2567826.623, N, 262356. 202,E, 2.000, 838 .92, 3899.98, 29. 30, 63.70, 3031. 55, 3227. 55, 861. 27,N, 1659.48,E, 2567848.974,N, 262401. 427,E, 2.000, 861 .27, 3999.98, 27. 30, 63.70, 3119. 59, 3315. 59, 882. 28,N, 1701.98,E, 2567669.977, N, 262443. 922,E, 2.000, 882 .28, 4099.98, 25. 30, 63.70, 3209. 24, 3405. 24, 901. 91,N, 1741.70, E, 2567889.606, N, 262483. 638,E, 2.000, 901 .91, 4199.98, 23. 30, 63.70, 3300. 38, 3496. 38, 920. 14,N, 1778.59, E, 2567907.836, N, 262520. 524,E, 2.000, 920 .14, 4299.98, 21. 30, 63.70, 3392. 89, 3588. 89, 936. 95,N, 1812.60, E, 2567924.646, N, 262554. 537, E, 2.000, 936 .95, 4399.98, 19. 30, 63.70, 3486. 68, 3682. 68, 952. 32,N, 1843.70, E, 2567940.016, N, 262585. 635,E, 2.000, 952 .32, 4499.98, 17. 30, 63.70, 3581. 61, 3777. 61, 966. 23,N, 1871.84,E, 2567953.926, N, 262613. 779, E, 2.000, 966 .23, 4599.98, 15. 30, 63.70, 3677. 59, 3873. 59, 978. 66,N, 1897.OO,E, 2567966.359, N, 262638. 937, E, 2.000, 978 .66, 4699.98, 13. 30, 63.70, 3774. 49, 3970. 49, 989. 61, N, 1919.14,E, 2567977.301,N, 262661. 076, E, 2.000, 989 .61, 4730.17, 12. 70, 63.70, 3803. 90, 3999. 90, 992. 61,N, 1925.23,E, 2567980.309, N, 262667. 162,E, 2.000, 992 .61,5 1/2" - BLIND (2) 4730.27, 12. 69, 63.70, 3804. 00, 4000. 00, 992. 62, N, 1925.25, E, 2567960.319, N, 262667. 182, E, 2.000, 992 .62,TD at 4730.3 Content-Description: Kaloa #4 wp04 -Preliminary Plan.pdf Kaloa #4 wp04 - Preliminary Plan.pdf Content-Type: application/octet-s tream Content-Encoding: base64 ', Content-Description: Kaloa #4 wp04.txt Kaloa #4 wp04.txt' Content-Type: text/plain Content-Encoding: base64 • • • 0 0 0 0 f F ~ .-. m o H F N N O 111 `- o o w o 0 ~ In u1 o r o 0 q rl a ro ro ~; ~ N N ~~ ~ v •~ •.~ m m ,-, m m ~ l a ~a a o a a W PO q q x q q q mu a1 a.1 1.1 ~ ~ 1.1 H u1 r6 rt r6 rt rt rt rt a a.1 a.1 u a~ ~ ~ u w m cn ~ cn m ~ In m O O O O O O O O O M 41 d~ N M N r-I ri Ol ri N r W [M O l0 N 4D d~ O 1O N 4D d~ O ~D N CO d~ O r M 41 O 171 W N N r 00 rl ~ 111 N M ~O O O O O O O O O O M Ol 0 Ol . . . 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N ~O O l11 O H N M VI N ~O r CO 01 O O H N M d~ 171 10 r O r N 10 ~ O lf) W r-1 N r-I O l0 N l0 W H N d~ ~O r Ol O N M T l11 CO H dl r O M ~O Ol M ~0 01 N In W H d~ r OD O '-I M ~O 01 r-I M 10 N O N M 111 ~O r rl ri r-I ri rl rl N N N M M M M d~ d~ d~ Ifl N In l0 ~ ~ LD r r r r r OD OD W CO Ol Ol Ol Ol Ol Ol ` ~ ~ ~ ` 0 0 0 0 0 0 0 0 0 10 10 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O W N O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O N N O lfl l11 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 0 0 0 0 0 0 0 0 0 ~~ Lfl 111 N 171 ~O ~D ~D 1D ~O lD O O O O O O O O O O O O O O O O O O O N N N N N N N N N N N N N N N W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W ` . O O O O O O O O O N N d~ O1 r l11 N r lfl 01 <M OD r l0 111 d+ M N H O 01 w r l0 In d~ M N H O N ~O O O1 lfl r-I d~ N r N OD d~ r 171 O1 r 0 0 0 0 0 0 0 0 0 0 d~ M 171 01 Ol r d~ ll) N 01 W H M lf1 r Ol ri M l11 l0 CO O N d' l0 N O N d~ lD Ol O lb N Ol O O N N M N M M r M 0 0 0 0 0 0 0 0 0 111 H Lf1 d~ O H ~O M H O aD Ol N O OJ ~O d' M ~'-I Ol r 171 V~ N O N ~O N M H l!) H O H r r M N VI 01 ~D N L11 ~O r Ol d~ rt rl x yJ N ri C.' H X O 0 U N N N N N N N N N N CO O O 00 M M i0 H N ~O lf1 r OD CO Ol 0 H N N M [M IP LD r r O] Ol O H r H O Ol d~ r m ~O H M M O d~ Lf7 M W d~ d~ d~ d~ 'd~ d~ d~ d~ d~ d~ d~ 1D OD O d~ ~D OD rl M ~ r Ol lfl rl r d~ O ~D N ~ d~ O l0 N N d' O r M M 01 O d~ O l11 O ll) O W O N 171 O H M rrrrrrrrrrrrrrorommrnmololmoH.~NMM<r~ W ~iorrmrnmoooHNNNMM~w~Inlnln~~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 r-I rl ri rl rl ri r-I rl H H H H H H r-I ri N N N N N N N N N N N N N N N N N ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ LD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N zzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzzz 0 0 0 0 0 0 0 0 0 ~O Ol ~O l!) [M r r 0 OD N N L11 H O Ol m r lfl [M M N ri O 01 CO r N d~ M N H 41 O r-I OD 1f1 O M d~ r ~D ~O ~O 10 10 Ol M M M M M M M M M l71 ri ~O O N d~ M d~ H M d~ Ol O ~O •-I r M 01 N H r M Ol V' O l0 N Ql d~ O r M 0 0 l!) O In N r r O M d~ ri N N rrrrrrrrrorrr~od~MaD01In~DNrloommmaomrr~~o~oullnw rw~~oMrmm~oolrn~m~omM . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . r r r r r r r r r m '-I 01 N O M ~O Ol M W M 4D O1 O rl rl N M d~ lfl l0 r CO O1 O H N M d~ 171 W Ln O~ H r N ~O W Ol 01 r~ O M l0 aD OD OD OD 00 OD CO CO W O] Ol Ol H M N ~O r Ol O N N M r O M lD Ol N l11 CO H V~ r ri d~ r O M 10 l0 Ol O N In r O N d~ ~D OD O N d~ l11 l0 Ol Ol Ol Ol Ol Ol 01 01 Ol 01 Ol Ol O O O O O O rl ~-i r-I r-I H N N N N M M M d~ d~ ~ N Ifl L() ~O ~O ~O ~O 10 r r r r CO N N CO CO Ol Ol Ol Ol Ol ~ ~o ~o io io io io ~o ~ ~o ~~ r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ to ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ to ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ JJ lf1 N N N lP 111 N 171 Ifl In In In lP L/1 171 111 N 1.t1 171 lf1 N 111 In N 171 111 171 N N N V) lf) In In In to 171 Lfl N lf1 N N N In N lP In 171 tf1 171 171 In In lP 171 W N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N N ` ~ ` f!]rJ W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W W ` ~ ~ ` W ~/.~ ~ O O O O O O O O O O~ M l0 O O OD lf1 1O d~ 0 0 M lfl r O1 H M lf) r 01 N d~ \D 00 O N d~ ~O CO H <M In N W d~ ~O l0 N N O O1 O O al O ` 0 0 0 0 0 0 0 0 0 1.f) rl In ~ ri N ~O M r-I O 01 O N O W 10 IP M ri 01 r lD d~ N O Ol r lf1 M H 10 N O N r CO M N d~ 41 r lf1 l0 r OD O '$ J-1 0 0 0 0 0 0 0 0 0 0 ~O OD W ~O r-I ~-I [M O1 U) d~ [M ll) lp 10 r W 01 O O N N M V~ lf1 lf) ~O r N 01 lfl 01 W r N Ill l0 d~ 01 H H CO N M H r \ W r-I M l0 O N d~ ~O 01 N M 171 ri r M ~ 171 N OD d~ O 10 N c0 d~ O 10 N CO Ol d~ t11 O ~O H ~O rl lfl O ~ r '-I d~ r Ol W H H H H H N N N M M d~ d~ l11 ~O l0 r c0 N 01 01 O ri H N N N M M tl~ d~ In In 10 lD r r r d0 00 00 OD H H H (-I rl r-I r-1 rl N H r-i H ri H H H H H H H H ` JJ N W J-1 O {." 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'~'i Zi Zi Zi `~i 7r 7r7-~'Zi 'Ii ~ O O O O O O O O O M O1 d~ W M N H H O1 H N r OD ~ O ~O N N VI O l0 N W d~ O l0 N CO d~ O r M O1 O 171 W l/1 N r W r-I ~ l11 N M l0 U 0 0 0 0 0 0 0 0 O M 41 0 Ol 01 r ~O rl rl N Ol N M M M N N r-I ri r/ O O 01 01 01 of w r r r 01 Ol N 1p O N N 41 N N 01 ri Ol M N ~D ` 11 0 0 0 0 0 0 O O O O M N d~ N 171 00 N l0 O lfl O r-1 N M d~ 171 ~O r 00 Q1 O O H N M d~ Il) ~ r O r N ~D d~ O U1 00 rl N r-1 O W N ~D ~D • W H N d~ l0 r Ol O N M d~ lfl OD H d~ r O M l0 ~ M ~O 01 N 171 W H d~ r CO O H M ~O 01 H M ~O OJ O N M N ~O r U] ~-' ri rl rl rl ri r-I N N N M M M M d~ V~ d~ lf1 lf) lf) ~ ~ ~ ~ r r r r r 00 W N W O1 O1 01 01 O1 O1 rJ ` ` 11 U] W a q ~ 0 0 0 0 0 0 O O O Ol ~ H H N l0 H r N r aD O ri O 01 OD r ~D N d~ M N rl O 01 CO r ~D lf1 171 ~O l0 O N O Ol 01 r-I N 01 d~ d0 01 OD rl 01 ` 0 0 0 0 0 0 0 0 0 Ol r ~D r O W ~O O rl lD I.n r N M M d~ In ~ r OD Ol O H N N M d~ 171 ~D r d~ r 0 0 1.() O 10 N l71 171 N M aD 10 ~D 171 ..~ ` J.J 0 0 0 0 0 0 0 0 0 O1 O1 OD lf1 O O d~ r OD r 171 10 N lfl CO rl d~ r O M lp O M l0 41 N Ln ~ r-I d~ N CO O Ifl M <1' 10 r-I r lf) In 10 O N r M >C, W O O O O O O N ~O Ol Ol Ol 01 Ol OD N l0 O d~ aD Ol N 41 l0 d' ~-'I OD ~O M O W 171 N Ol r d~ H Ol l0 r M lfl N Ol r lfl d' N H O Ol CO OD r r `-' H N M~ lf1 ~D ~O 1D ~O r OD Ol O r-I N N M M M M d~ d~ In e r r OD Ol O O H N N M d~ 171 111 1D l0 r r N N Ol O H N M d~ d~ 111 ~D r OJ ` H H H .-1 H rl ri ~-I r-I r-1 rl ri rl r-I ri r-I N N N N N N N N N N N N N N N N M M M M M M M M M M ~ ^ ` ~ ~ ~ ~ ` J-1 ` W 0 0 0 0 0 0 0 0 0 O1 d~ rl H OD 10 H r N r 00 O H O O1 CO r ~O 111 V+ M N rl O 01 CO r ~O N 111 l0 ~O O N O O1 O1 H N 01 d~ 00 O1 00 H O1 0 0 0 0 0 0 0 0 0 Ol r 10 r O W l0 O H 1p lfl r N M M [M l11 ~O r 00 01 O r1 N N M In ~ r d~ r 0 0 In O l0 N In 111 N M W~~ In . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 'i$ ~- ~O ~O d~ ~ V~ d~ d~ d~ d~ M M N O1 d~ d~ c0 ri N H O1 O l0 T N N oD H ~'N r O d~ r O M ~O 01 N lJl CO ~ N d' lT r aD O 111 H 01 O1 O N l0 H r W .U Ol Ol O O O O N ~O O O O 01 Ol W N r rl 171 W O N~ r d~ rl 01 l0 M N CO 111 M O r d' N~ ~O r d~ In H Ol r l0 d~ M ~--I O O Ol OD OD r W H I H N M d~ d~ d~ 111 lD r r W Ol O O '-I H H N N N M d~ lf) lfl l0 r Op OD 01 O r-1 r-1 N M M 'cr ~ 111 In 10 1D r CO Ol O rl N M M d~ U) ~O ` I ri H H ri r-I r-I rl r-1 rl rl rl rl rl rl N H H N N N N N N N N N N N N N N N M M M M M M M M ~ ` ` ~ ~ ~ ~ ~ ` \ J-1 7., W 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Il) U1 10 M OD N N N N N N N N N N N N N N N N N N N N 0 0 0 0 0 0 0 0 0 0 0 O O O O `- o 0 0 0 0 0 0 0 0 0 0 0 0 0 o In ro m m r o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~o r r r r r r r r r r r r r r ` ` . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . q --~ r r r r r r r r r r r r r r r m Q1 O H N M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M M H O1 t11 If) t11 t11 In to 111 If1 to in 171 111 N N 111 111 111 l0 to lD l0 ~ ~ ~ l0 ~ l0 10 ~ ~ ~ ~ 10 10 ~ ~ ~ ~ ~ ~ ~ 10 10 ~ ~ 10 ~ ~ ~ ~ 10 l0 ~ l0 ~ q E tr1 000000000~0oooooM~ooul~~~wv~al~ww<r~w~~~al<r~rwwmooooo000000000 U1 N 0 0 0 0 0 O O O O r 0 0 Lfl O 111 d' M N N r-1 O O O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N O M M M M M M M M M M M M M . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ul q . `-' O O 0 0 0 0 0 0 O H ~O H l0 N r O M ~O 41 N M M M M M M M M M M M M M M M M M M M M r-I r-1 Ol r lf) M rl Ol r 111 M r-1 m r I71 ` .-1 r-I N N M M M M d~ d~ d~ d~ d~ d~ d~ ~M ~M d' <M d~ d~ d~ d~ d~ d~ d~ d~ d~ T ~M d' M M M M M N N N N N H H H E ~ •~1 w N `~ ~ ` O O O O O O O O O O O O O O O O O1 O1 Ol Ol Ol O1 O1 O1 01 01 Ol 01 O1 O1 01 01 O1 O1 O1 O1 O1 O1 O1 lf) Ol N Ol dl 01 T N OD CO N CO N aD OD OD ` i! O O O O O O O O O O O O O O O O Ol 01 01 Ol O Ol Ol Ol 01 Ol Ol Ol Ol Ol Ol Ol Ol Ol Ol Ol Ol Ol Ol lf7 Ol Ol Ol Ol Ol 01 01 Ol Ol 01 01 Ol Ol Ol Ol . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . U W Ci O O O O O O O O O O O O O O O O O O1 O1 O1 01 171 O1 O1 O1 O1 O1 O1 O1 O1 01 O1 O1 01 01 01 O1 O1 O1 O1 O O1 <T Ol ~ ~ (r T O1 01 01 O1 O1 T O1 O1 H O O O O O O O N ~O O O O O O O lfl 01 d' Ol ~ 10 Ol 01 Ol Ol Ol 01 Ol Ol 01 Ol Ol Ol Ol Ol Ol Ol Ol 01 rl Ol ri Ol Ol Ol Ol 01 Ol Ol Ol Ol Ol Ol Ol Ol H H N M~ N ~O ~O ~D r OD Ol O H N N N M M V~ d' [M 171 l0 r W Ol O rl N M I In ~ r c0 Ol O rl N N M M d~ Lf) ~O r aD Ol O ~-1 N M d~ 171 `~ r1 r-I r-1 H N r-I H H H H H H H H H N N N N N N N N N N M M M M M M M M M M M M d~ d~ d~ d~ ~~ q n. £ " 0 v-1 a, v-1 O N a1 N N W O ,--1 4699.98, 13.30, 63.70, 3774.49, 3970.49, 4730.17, 12.70, 63.70, 3803.90, 3999.90, 4730.27, 12.69, 63.70, 3804.00, 4000.00, 989.61,N, 1919.14,E, 2567977.301, N, 262661.076, E, 2.000, 989.61, 992.61,N, 1925.23,E, 2567980.309,N, 262667.162,E, 2.000, 992.61,5 1/2" - BLIND (2} 992.62,N, 1925.25,E, 2567980.319,N, 262667.182,E, 2.000, 992.62,TD at 4730.3 :~ 2 of 2 8/29/2005 9:50 AM Gas We11 Determination • • Subject: Gay ~Vclt Deterniinati~~n From: ~luanc ~-a<i<~cn ~~1u.~ne'~rl~airweatk~er.com> Date: Fri, ~(,,~u~~?~i~~ 1h:~1:~~ -i),~0~1 To: Lycji~~_mincrlrz~icc.~t~~te.ak.us CC: tot~n m~nn~~lei ~i;admin.a~~tc.~k.u;, Steve cl.n~ie5~a'~~clrnin.,t~~cak.u~, Lci lone, -_~ejone~ ~r;auroraj~o~i~er.com%, ~~nd~ (:liflord ~ ~~1CClifford~c~auri~r~~7x~wcr.cony= Lydia: Aurora Gas, LLC submitted a Permit To Drill application today (8/26/05) for the Kaloa No. 4 well. In the application we proposed to drill to 4730 ft MD (4000 ft TVDrkb). This well is being drilled as a step-out delineation well in the Kaloa Gas field and is being drilled from the same pad as the original Albert Kaloa No. 1 (now P&A'd but originally a gas well) and Kaloa No. 2, currently producing gas from the same zones expected to be encountered in the Kaloa No. 4. The Albert Kaloa No. 1 was originally drilled as a deep oil test and was plugged back when no oil was found and completed as a gas production well. If you need a determination letter for this well, please contact Steve Davies at the AOGCC for confirmation on our prognosis. We do not plan on filing a spill plan with the DEC for the above listed reasons. I hope this satisfactory with the DEC. Please contact myself or Jesse Mohrbacher if further information is required from our end. Thank You. Duane Vaagen Project Engineer Fairweather E&P Services, Inc. duane~fairweather,com Office: (907)258-3446 Cell: (907)240-1107 1 of 1 8/29/2005 10:16 AM 151 20 DOW 151 Kaloa No. 4 ~~ z~ ~~ Proposed 1-Gas C-061393 2051310 .~# p ~ ' ^ / n~- ~f ~r~~ ~~~M~~ ~"~t°` Confidential wells are red SFD 8!29!2005 ;~ + G ~, K4LP4 JPH - ry ~' ~ 4 g ~' °o KAL 3~~ ~ 0 Kaloa No.3 has not een drilled 3000' radius N iI Kaloa No. 4 BHL 25 ~ TPI K4L04 2X Na~dt /, Kaloa No. 2 Producer r,~ Feet 0 1 ,000 2,000 3,000 4,000 260,000 270,000 i• :~ ,~ . ~ . _:_ . __ __. ____ _ a Aurora Power 1400 WEST BENSON, SUITE 410 ANCHORAGE, AK 99503 PH: (907) 277-1003 PAY TO THE ? ORDER OF n J~ FIRST NATIONAL BANK ALASKA 2 2 9 7 ANCHORAGE, AK 99520 89-6/1252 `~ - ~ - a5 ~--- I ~ SOU o C~ DOLLARS 8 _ ~~ . , `~ ~ MEMO ~1 ~ `~~~ ~ ,J~ ~._.~. ,. 11'00 2 29 711' ~; 1 2 5 200060: 30 20 389 711' • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMIT/TAL LETT WELL NAME ~~---r PTD# ~ ~ ~'~ / CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (PH) records, -data and togs 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 The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a ~ spacing exception. L~ (Companv Name) assumes y~~j-~-~- , the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\jody\transmittal_checklist ELL PERMIT ECKLIST Field & Pool ALBERT KALOA, UNDEFINEDGAS-40500 Well Name: KALOA4 Program EXP Well bore seg ^ PTD#:2051310 Company AURORA GAS LLC Initial Classlfype EXP 1 PEND GeoArea 820 Unit ONOff Shore On Annular Disposal ^ Administration 1 Permikfeeatkached_________________________________ ____________Yes_ _____,-_-_______-__-_._____-__--______.__ -------------------------------- 2 Lezsenumberappropriake_____________________________ _______ _____Yes_ _____CI_RlLeaseC061393____.--...__--__-.--____-..-_-__- --------------------- 3 Uniquewell_nameandnumb_e[__________________________ ___--_-.--. Yes_ _____.__.--____..___.-__-_ 4 Welllocakedin_a_defned_pool___________________________ ____________N_o_- _-__Exploratorystep-out well----_,________--____.-_. ---------------------------- 5 Well Iocaked proper distance_from drilling onitbourldary_ _ - - - . - - No_ _ _ - _ Drilling unit is govt section: will be 2nd produce[ in S, 25. Nearby Kaloa 2 has been_ongas prod since 10!04 6 Well located proper distance_from other wells_ - - _ _ _ _ No_ _ -Reg. 25.055_stipulates_?3,000' to nea[est gas well in pool._ Thiswell-will be_ 1_,500'.f[om Kaloa_#2 producer._ 7 Sufficient acreageavail_ablein-drillingunit.__________________ ____...-___ No.- _____Willbe2ndprodu_cer_inS.-26,________--_____,-_--_____. - - - 8 If deviated,is_wellboreplat,included_______________________ ____________ Yes_ _____.._________.._ ------------------------------------------------------ 9 Ope[ator°nlyaffectedparty_______,_________________ ___________Yes_ ______-__.____- ----------------------------------------------------------- 10 Ope[atothasappropriate_bondinforce--------------------- ------------Yes- ------Letter of c[edit--------...-----------.----------------------------------- 11 Pe[mitcanbeissuedwithoutconseryationorder________________ ____________No_ ___.__-,______--__-__________-_______,-_-_________________--_____--__--_._ Appr Date 12 Pe[mit_canbeissuedwithoutadminist[alive-appr_ova_I--_.__--___ ____________Yes- ______.-___._______---______________-_____ ---------------------------- SFD 9/712005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthorizedby-InjectionOrde[#(put_1O# in_comments)_(For_NA_ _________________________-_________,-________--______-______.__--_____ 15 All wells within 114_mile area of review identified (For service well only) - - - - - - - - - - - - - - - NA- _ _ _ _ _ _ _ . _ - _ _ - _ _ _ - _ _ _ _ _ _ _ _ - - _ 16 Pre-produced injectgr duration of pre production less than_ 3 months_(For service well only) _ NA_ - - -- --- - 17 ACMP_Finding of Consiskency_has been issued_for_this project_ _ . - - - _ . - Yes . _ ACMP:_ No Review Required letter issued on Oct, 21, 2003.- _ _ _ - _ _ Engineering 18 Condu_clorst[ing-provided---------------------------- ---- Yes- ------13-3/8"_@90'.-________-_____ -----------------------------_----- 19 Surface casing-protects all known USDWs _ _ _ Yes Surface & production casing will be cemented back_tosurface, protecingany-freshwater sands._Sfd _ - - _ _ . _ _ 20 CMT_vol_adeguate_tocirculate-on conductor&&urf_csg-_____-____ ____-______Yes_ _____Adequateexcess______________________ 21 CMT_v_oladequate_totie-in long stringtosu_rfcsg_______ ________ ____________Yes_ ____.__.______..__________-_._______. 22 CMT-willccverallknow_nproductivehorizons__________________ ____________Yes- -________--________--_.________-____.-_-_______-______.________,-_-- 23 Casing designs adequate forC,TB&_permafrost--------------- -------- ---Yes- ---------------------------------------------------------------- -- -- 24 Adequate iankage_or reserve pit _ - - - -Yes AW$1, - - - - - - - - - 25 If_a_re-drill,has_a-10-403 for abandonment been approved__________ ____________ NA__ ___--_Newwell.--____________.__________-,______-__-______--_________________ 26 Adequatewellboreseparation_proposed_____________________ __-_---_.._Yes_ __--...--_____--._--._ 27 If diverterrequired,doesitmeet_regulations__________________ _____..-____Yes- ____Pilothole planned.___--______--__----,_____--_--.___.__-______.---- Appr Date 28 Drillingfluid_programschematic&equiplistadequate_____________ ______ __ __ Yes_ _____MaxMW_10,0_ppg.__-___._________-___-----______--_-_____-________--_- TEM 91712005 29 B_OPEs,_dotheymeetregu_lation - - - - - - - Yes - - - - - - - - - - - - - ~~w// ~~ 30 BOPE_pressratingappr_oprtale;testto_(putpsigincomments)________ ____________Yes_ ___Testto 3000psi._MSP1400psi.____________-.__.__.___-_--______-______,-_-._-_ ~~VV~~ 31 Choke_manifoldoomplieswlAPI_RP-53(May84)________________ ____________Yes- -________----______----_.-___ -------------------------------------------- 32 Work willoccurwithoutoperationshutdawn___________________ ____________Yes- -_______-___________--______ -------------------------------------------- 33 IspresenceofH2Sgasprobable- - - - - - - N0- - - - - - - - - - - - - - 34 Mechanical condition of wells within AOR yeri~ed For service well only _ _ _ _ - - .. _ NA_ _ _ - Geology 35 Permit_canbeissuedwlohydrogen_sulfidemeasures_____________ ____________Yes_ __.-.--.--_---_..----_--_...-..______.._--____-.._.-.__-.-______...-_-- 36 Data-presented on-potential overpressure zones- - . - - - _ _ .. _ - Yes - Recent, nearby Kaloa 2 indicates 0.46 psilft (8.9 ppg EMW)-gradient. Will be-drilled with 9,8-10,0_ppg mud.- _ _ Appr Date 37 Seismic analysis of shallow gas_zones- _ .. _ . - - . _ - - _ No_ _ - _ _ _ _ _ Mudloggers and H2$Igas dekection equipmenk will be used daring all drilling operations_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 8130!2005 38 Seabed condition survey_(if off_-shore) _ - - - NA-- - - -- - -- - -- 39 -Contact name/phone forweekly progressreports [exploratory only]_ - - _ _ _ _ _ . _ Yes . _ _ ... Duane Vaagen,-907-358-3446 _ - - - _ _ _ - - _ _ - _ _ Geologic Engineering Date: Date ' e SPACING EXCEPTION NEEDED. Mudlo and sam les not re wired as nearb Albert Kaloa 1 has mudlo and cuttin s g p q y 9 9 Commissioner: a ~ Commissioner: miss ~~8.~0~ ~ ~ r samples from 36' to 13600'. Nearby Kaloa 2 was recently mudlogged from 116' to 3720'. ~ ~ ~ ~~ ~ ~ •