Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout203-206• • ~~- MICROFILMED 03/01/2008 DO NOT PLACE ~, , ~_ . , _~. ANY NEW MATERIAL UNDER THIS PAGE F:\I,aserFiche\CvrPgs_Inserts\Microfilm Marker.doc . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: /'Î I \"1 Jim Regg,. . '~êdtJ b'Z;\' \J P.I. Supervisor U DATE: June 12, 2007 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Pioneer (Evergreen) Houston Pit #1 PTO 203-206 Tuesdav. June 12. 2007; I traveled to the Pioneer (Evergreen) coal bed methane exploration wells Little Su #1 ,Houston Pit #1, Sheep Creek #1, Kashwitna Lake #1 and Slats #1 to verify location clearance. The exploratory locations were clean with no evidence of past drilling activity. SUMMARY: I recommend the above mentioned 5 locations be given final clearance approval Attachments: Houston Pit #1.JPG SCANNED JUL 2 0 2007 2007 -0612_Location_ Clearance_Pioneer _Houston-1_cs.doc Location Clearance Inspection - Houston Photos Scheve June 12, 2007 2007 -0612_Location_ Clearance_Pioneer_Houston-1_cs.doc /9 /J.¡1rd .zò ~ i,ð DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2032060 Well Name/No. HOUSTON PIT NO.1 ~¿ / FJl,...~ '1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20028-00-00 MD 1604 / TVD 1604 / Completion Date 3/19/2004../ UIC N Completion Status P&A Current Status P&A REQUIRED INFORMATION ~-~-- Mud Log No Samples No Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Gamma Ray, Spontaneous Potential, Caliper, Array Induction, Compe Well Log Information: Electr Digital Dataset Log Log Run Interval OH/ Number Name Scale Media No Start Stop CH 12508 I nd uction/Resistivity 40 1610 Open Density 25 Blu 58 1608 Open Sonic 25 Blu 45 1608 Open I~ L Well Cores/Samples Name L~ (data taken from Logs Portion of Master Well Data Maint . Induction/Resistivity Received Comments SoniclNeutron/Porosity/Den 1 sityGR ARRAY INDUCTION, COMP SONIC ARRAY INDUCTION,PHOTO DENSITY, DUAL SPACED NEUTRON PHOTO DENSITY, DUAL SPACED NEUTRON, COMPENSATED SONIC 2 IN.=20 FT. 25 Blu 45 1607 Open Lithology 25 Col o 1604 Open Information: Interval Start Stop Sample Set Number Comments Cores and/or Samples are required to be submitted. This record automatically created from Permit to Drill Module on: 12/11/2003. . Sent Received -~ ADDITIONAL INFORMATION Well Cored? ~ N Chips Received? Analysis Received? Comments: Daily History Received? ~/N ~N -¥-I-'N" yG) f....\\. toY'.\; Formation Tops -- DATA SUBMITTAL COMPLIANCE REPORT 3/2/2006 Permit to Drill 2032060 Well Name/No. HOUSTON PIT NO.1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20028-00-00 MD 1604 TVD 1604 Completion Date 3/19/2004 Completion Status P&A Current Status P&A UIC N Compliance Reviewed By: fL Date: ¡r¡ ~~ . . . . January 13, 2005 PIONEER NATURAL RESOURCES ALASKA, INC Howard Okland Petroleum Geologist Assistant Alaska Oil & Gas Conservation Commission 333 W. ih Ave., Suite 100 Anchorage, Alaska 99501 Re: Letter of Transmittal Subj: Evergreen Resources Alaska Corp's 2004 Five-Hole Core Program Dear Mr. Okland, I am enclosing with this correspondence, both an inventory of the continuously cored exploratory wells that were drilled in early 2004 by Evergreen Resources Alaska Corporation (Evergreen) and a data CD, per your request. The wells drilled include the Sheep Creek #1, Kashwitna Lake #1, Houston Pit #1, Little Su #1, and the Slats #1. Total well depths and cored footage (in parentheses) of these exploratory wells are as follows: Sheep Creek #1 - 1,369' (1,034'); Kashwitna Lake #1 - 1,750' (878.5'); Houston Pit #1 - 1,604' (1,548'); Little Su #1 - 2,125' (2,010'); and Slats #1 - 3,095' (2,685'). Total cored footage equates to 8,155.5 feet. Core from the five Evergreen exploratory wells is presently in a container at the Alaska Geologic Materials Center in Eagle River. If you have any additional questions or requests, please feel free to contact me. Sincerely, -/Jf~/ð~ Michael A Belowich Coal Geologist Pioneer Natural Resources Cc: Robert Crandall - Alaska Oil & Gas Conservation Commission Matt Rader - Alaska Division of Oil and Gas John Reeder - Alaska Geologic Materials Center 1075 CHECK STREET, STE. 202 . WASILLA, ALASKA 99654 . MAIN: (907)357-6130 . FAX: (907)357-8340 . . Well Name: Houston Pit #1 .}... 0 -!>.- À a Ie - Box Depth Box Depth Numbers Column Shelf Top Bottom Numbers Column Shelf Top Bottom (ft) (ft) (ft) (ft) 1 14 D 56.0 64.9 51 14 A 549.1 558.0 2 14 D 64.9 74.2 52 14 A 558.0 567.4 3 14 D 74.2 83.0 53 14 A 567.4 576.4 4 14 D 83.0 93.5 54 14 A 576.4 585.9 5 14 D 93.5 103.3 55 14 A 585.9 595.4 6 14 D 103.3 113.0 56 14 A 595.4 605.1 7 14 D 113.0 123.7 57 14 A 605.1 615.0 8 14 D 123.7 132.4 58 14 A 615.0 625.0 9 14 D 132.4 141.5 59 14 A 625.0 632.6 10 14 C 141.5 151.0 60 14 A 632.0 642.0 11 14 C 151.0 161.0 61 14 A 642.0 652.0 12 14 C 161.0 172.0 62 14 A 652.0 662.0 13 14 C 172.0 181.5 63 14 A 662.0 672.0 14 14 C 181.5 191.0 64 15 D 672.0 681.0 15 14 C 191.0 206.5 65 15 D 681.0 691.0 16 14 C 206.5 218.8 66 15 D 691.0 701.0 17 14 C 218.8 227.9 67 15 D 701.0 710.0 18 14 C 227.9 237.6 68 15 D 710.0 723.2 19 14 C 237.6 246.5 69 15 D 723.2 732.0 20 14 C 246.5 256.0 70 15 D 732.0 742.0 21 14 C 256.0 266.0 71 15 D 742.0 752.0 22 14 C 266.0 276.0 72 15 D 752.0 764.8 23 14 C 276.0 285.0 73 15 C 764.0 773.0 24 14 C 285.0 297.0 74 15 C 773.0 785.0 25 14 C 297.0 306.0 75 15 C 785.0 795.4 26 14 C 306.0 316.0 76 15 C 795.4 809.2 27 14 C 316.0 327.0 77 15 C 809.2 816.8 28 14 B 327.0 335.0 78 15 C 816.8 826.0 29 14 B 335.0 344.0 79 15 C 826.0 837.0 30 14 B 344.0 354.4 80 15 C 837.0 848.0 31 14 B 354.0 363.4 81 15 C 848.0 860.0 32 14 B 363.4 372.9 82 15 C 860.0 871.0 33 14 B 372.9 382.5 83 15 C 871.0 882.0 34 14 B 382.5 391.6 84 15 C 882.0 890.6 35 14 B 391.6 401.0 85 15 C 890.6 901.0 36 14 B 401.0 410.4 86 15 C 901.0 909.8 37 14 B 410.4 419.4 87 15 C 909.8 919.5 38 14 B 419.4 429.4 88 15 C 919.5 928.5 39 14 B 429.4 439.0 89 15 C 928.5 937.0 40 14 B 439.0 450.0 90 15 C 937.0 947.2 41 14 B 450.0 460.0 91 15 B 947.2 956.4 42 14 B 460.0 471.0 92 15 B 956.4 966.0 43 14 B 471.0 480.0 93 15 B 966.0 975.0 44 14 B 480.0 490.0 94 15 B 975.0 984.0 45 14 B 490.0 500.0 95 15 B 984.0 994.0 46 14 A 500.0 510.0 96 15 B 994.0 1003.0 47 14 A 510.0 520.0 97 15 B 1003.0 1013.0 48 14 A 520.0 530.0 98 15 B 1013.0 1022.0 49 14 A 530.0 539.7 99 15 B 1022.0 1030.0 50 14 A 539.7 549.1 100 15 B 1030.0 1040.0 / (, J e,^- ).Ju"\J:> . . - - Box Column Shelf Top Bottom Box Column Shelf Top Bottom Numbers (ft) (ft) Numbers (ft) (ft) 101 15 B 1040.0 1050.0 150 16 C 1520.0 1530.0 102 15 B 1050.0 1060.0 151 16 C 1530.0 1539.0 103 15 B 1060.0 1069.0 152 16 C 1539.0 1548.0 104 15 B 1069.0 1077.0 153 16 C 1548.0 1557.0 105 15 B 1077.0 1085.8 154 16 B 1557.0 1567.0 106 15 B 1085.8 1096.0 155 16 B 1567.0 1579.0 107 15 B 1096.0 1106.4 156 16 B 1579.0 1589.0 108 15 B 1106.4 1116.4 157 16 B 1589.0 1597.7 109 15 A 1116.4 1129.5 158 16 B 1597.7 1604.0 110 15 A 1129.5 1134.4 159 111 15 A 1134.4 1144.3 160 112 15 A 1144.3 1154.2 113 15 A 1154.2 1163.8 113A 15 A 1163.8 1172.4 114 15 A 1172.4 1181.6 115 15 A 1181.6 1192.0 116 15 A 1192.0 1201.0 117 15 A 1201.0 1210.0 118 15 A 1210.0 1220.0 119 15 A 1220.0 1230.0 120 15 A 1230.0 1239.0 121 15 A 1239.0 1251.1 122 15 A 1251.1 1260.5 123 15 A 1260.5 1271.0 124 15 A 1271.0 1281 .0 125 15 A 1281.0 1290.6 126 16 D 1290.6 1302.8 127 16 D 1302.8 1312.2 128 16 D 1312.2 1322.0 129 16 D 1322.0 1332.0 130 16 D 1332.0 1343.0 131 16 D 1343.0 1353.0 132 16 D 1353.0 1363.0 133 16 D 1363.0 1373.0 134 16 D 1373.0 1382.0 135 16 C 1382.0 1391.0 136 16 C 1391.0 1401.0 137 16 C 1401.0 1410.0 138 16 C 1410.0 1418.0 139 16 C 1418.0 1429.0 140 16 C 1429.0 1436.6 141 16 C 1436.0 1445.5 142 16 C 1445.5 1455.5 143 16 C 1455.5 1465.0 144 16 C 1465.0 1474.3 145 16 C 1474.3 1483.0 146 16 C 1483.0 1492.0 147 16 C 1492.0 1501.5 148 16 C 1501.5 1310.0 149 16 C 1310.0 1520.0 . > =\'=I~GI~==I'. RESOURCES (ALASKA) COR~ A SUDs/diary of Evergreen Resources, Inc. e June 17, 2004 ~ {)3 -"blð b Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Evergreen Resources (Alaska) Corp.'s 2004 Core Program Dear Mr. Crandall: The purpose of this letter is to fulfill the reporting requirements of Evergreen Resources (Alaska) Corp. as stipulated by 20AAC25.070 and 20AAC25.071 for the completed core drilling project. Attached are the drilling summaries, logs and other pertinent information for the Houston Pit#1, Little Su #1, Sheep Creek #1 and Slats #1. The acquired core is currently being slabbed and photographed. The desorption analysis is also ongoing. Hard and soft copies of these studies will be made available upon their completion. Wireline logs were not run on the Sheep Creek prior to abandonment of the hole; consequently, a gamma ray log will be generated from the core and provided when available. Once the studies are complete the core will be donated to the Alaska Oil and Gas Conservation Commission and housed in a State facility. The Willow Fishhook is currently suspended; drilling operations may resume at a later date. The six foot cellar has been constructed and six inch surface casing has been set at 335'. A plate has been welded over the casing to prevent vandalism. All information submitted concerning the above listed wells are subject to the two year confidentiality stipulation. If you have any questions, please feel free to contact me at 907-357-8130 or shaneq@everqreenqas.com. Sincerely, A Shane Gagliardi Petroleum Engineer " OR\G\\~AL RECEIVED JUN 2 J 2004 Alaska Oil & Gas Co C '. . os. ornmlS$/on AnChorage 1075 Check Street, Suite 202 . Wasilla AK 99654 D() Qnv R7HMt::. . W':lci/b t1K Qa~R7 . T~I an7 ':l&\7 R1~n . f:",4}( Qn7 .'{1:;7 R.'i4n Hi:: . .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION M~ska ml f~ WELL COMPLETION OR RECOMPLETION REPORT AND LØ6'Y'/' - e JUN'ì~ 1 2004 1a. Well Status: OilD GasD PluggedD Abandoned[81 SuspendedD WAGD 1 b. Well Class: 20AAC 25.105 20AAC 25.110 Development 0 Exploratory D GINJD WINJD WDSPLD No. of completions Other Service D Stratigraphic Test [81 2. Operator 5. Date Comp., Susp., 12. Permit to Drill Number: Name: Evergreen Resources Alaska Corp. or Aband.: 3/19/04 fJ_./ 203-206 3. Address: P.O. Box 871845 6. Date Spudded: 13. API Number: Wasilla, AK 99687 2/1/04 50- 009-20028 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Sec 20, TWN 18N, RNG 3W 3/17/04 Houston Pit #1 Surface: 1022' FNL and 797' FEL Top of Productive 8. KB Elevation (ft): 15. Field/Pool(s): 304' Wildcat Horizon: Same as Above 9. Plug Back Depth (MD + Total Depth: 1604' MD TVD): Surface (abd) 4b. Location of Well (State Base Plane Coordinates): (NAD 27) 10. Total Depth (MD + TVD): 16. Property Designation: 1604' City of Houston Surface: x- 526782.80 y- 2791671.87 Zone- 4 11. Depth where SSSV Set: 17. Land Use Permit: TPI: x- 526782.80 y- 2791671.87 Zone-4 AK 550.184.09382 N/A feet MD TotalDepth: x- 526782.80 y- 2791671.87 Zone-4 19. Water Depth, if Offshore: 20. Thickness of 18. Directional Survey: Yes [81 NoD Permafrost: N/A N/A feet MSL 21. Logs Run: Gamma Ray, Spontaneous Potential, Caliper, Array Induction, Compensated Neutron Density, Sonic, Inclination Survey 22. CASING, LINER AND CEMENTING RECORD CASING WT. SETTING DEPTH MD SETTING DEPTH TVD AMOUNT SIZE PER GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED FT. 6" 17 LP 0 37 0 37 6.125 None 4.5" 14.4 X42 0 57 0 57 5.5 5 sx Portland cmt 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 N/A N/A N/A N/A N/A N/A : 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. c AMOUNT AND KIND OF MATERIAL USED DEPTH INTERVAL (MD) None None 26. PRODUCTION TEST Date of First Production: Abandoned Method of Operation (Flowing, Gas Lift, etc.): Abandoned Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: N/A Test Period .. Flow. Tubing Casing Pressure: Calulated .. Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press: 24-Hour Rate 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". rr;,~·,;;c;:··...$eparate core analysis will be submitted. i,!-Ui'~';'iï>!: I iOfJ ; ':t ~TJž_ /¡ . Form 10-407 Revised 4/2003 ~ 7 CON1N~' ~Rt\rE SIDE.. . , OR RBDMSBfL JUN 2 ') ""' - .., GY ?nOll 28. GEOLOGIC MA , NAME MD Tyonek 27' - 1343' Arkose Ridge 1343' - 1560' Volcanics 1560' - TD (Andecite) TVD 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 27' -1343' None 1343' -1560' 1560' - TO RECE~VED JUN212004· l\Îas\(a O\! [í" 30. List of Attachments: Daily reports, wireline logs, mud logs, inclination survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane Gaaliardi Title Petroleum Enaineer Signature \. Phone 907-355-8569 Date 3/22/04 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 1 a: 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 4/2003 Well Name Houston Pit #1 12/10/04 01/31/04 02/01/04 03/06/04 03/07/04 03/08/04 03/09/04 03/10/04 03/11/04 03/12/04 03/13/04 03/14/04 03/15104 03/16/04 03/17/04 03/18/04 03/19/04 e Daily Drilling Summary Location I API I QTR I Sec I Twn I Rnll I Number NE NE I 20 I 18N I 3W I 50-009-20028 I Dig cellar and install culvert. Make cellar covers and plow snow. MIRU Denali Drilling from Willow Fishhook Drive 6" csg to 37". Drill and drive 4.5" csg to 57'. RU cement equipment Cement with 50 gal, circulate 30 gal cement to cellar MIRU Layne Christiansen Rig. Repair well head install BOPE. Test csg to 1500psi;held. Test BOPE to 1500psi:held. TIH w/ core bit & BBL. Tag something hard at 15' Fish core bit and reamer shell. TIH w/ core bit & BBL. Tag cmt @43'. Clean to 57'. TIH w/core bit and reamer. On bottom ready to begin coring. Core from 57' to 236'. Recover 161.6' core, 90% Core from 236' to 259', recover 17.2', recovery 74.8% Core from 259' to 306', recover 49', recovery 100% Core from 306' to 326', recover 19' recovery 95% Core from 326' to 438', recover 114.4', recovery 100% Core from 438' to 616', recover 174', recovery 98% Core from 616' to 661', recover 44.3', recovery 98% Core from 661' to 671', recover 14', recovery 100% Core from 671' to 736', recover 60.2', recovery 93% POOH Repair Drive head Core from 736' to 809', recover 59.8, recovery 82% POOH Replace bent core tube. Core from 809' to 860', recover 49', recovery 96% Core from 860' to 951', recover 93', recovery 100% Core from 951' to 971', recover 20.8', recovery 100% Core from 971' to 1159', recover 182.1', recovery 97% Core from 1159' to 1236', recover 74', recovery 96% Core from 1236' to 1251', recover 11.4, recovery 76% Core from 1251' to 1293', recover 38.2, recovery 91% Core from 1293' to 1495', recover 197.6', recovery 98% Core from 1495' to 1604', recover 114', recovery 100% POOH and LD DP, core bit and bbl Wait on Reeves Wireline MIRU Reeves Wireline Log holes with Gamma, Sonic and dual induction. Loggers TD 1608. Log holes with Gamma, caliper, and comp ND RDMO Reeves Wireline Survey hole @ 500 - 0 degrees, 1000 - 1 degree and 1500' - 0 degrees. Cmt hole w/24 bbls, 74 SX, class G cmt. Circulate 1 bbl cmt to cellar. RDMO Layne Christiansen and Swaco to Little Suo Permit to I Drill 203-206 I Page 1 of 1 Spud Date 1/31/2004 e I I Total Depth 1604' ~ 2? ~ Slats # I Core Disposition e e Subject: . Core Disposition· From:S liardi <shaneg@evergreen Date: Thu, 20 May 200409:33:35 -0800 Bob, >From this year's core program, we have extracted approximately 8,000' of core. Of this core about 3,000' will be slabbed. Evergreen Alaska will donate all of the core to the state to fulfill the AOGCC requirements of 20 AAC 25.071 (b) (4). We understand that the donated core will be kept confidential for a minimum of two years. The slabbing and photographing process is lengthy; the anticipated approximate date for completion of the process and transferring the core to the state is March 05. If you have any further questions, please contact me @ 907-355-8569. Thanks, Shane of I 5/20/2004 9:40 AM Nad 27 Coords for Core Wells . . Bob, Here are the coords (in NAD 27) for the core wells. Little Su - N = 2813373.15 E = 633118.22 Houston Pit - N = 2791671.87 E = 526782.80 willow Fishhook - N = 2838106.12 E = 504445.60 Kashwitna Lake - N = 2866054.57 E = 487747.09 Sheep Creek - N = 2918957.46 E = 489689.87 ç \) ",... t ~ 'i S tÀ V" V U- \ô) y- I think that most internet converters can convert Lat Long coords to NAD 27 without a problem. I have found several free programs that can do this. At this point, the standard has become NAD 83 due to the increasing number of handheld GPS tools. Thanks, Shane 1 of 1 12/16/2003 8:48 AM . . r-:.-"\ In \ lW FRANK H. MURKOWSKI, GOVERNOR AI4ASIiA. OIL AND GAS CONSERVATION COMMISSION Shane Gagliardi Petroleum Engineer Evergreen Resources (Alaska), Corp. PO Box 871845 Wasilla, AK 99687 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Houston Pit #1 Evergreen Resources (Alaska), Corp. Permit No: 203-206 Surface Location: 1022' FNL and 797' FEL, Sec. 20, T18N, R3W, SM Bottomho1e Location: 1022' FNL and 797' FEL, Sec. 20, T18N, R3W, SM Dear Mr. Gagliardi: Enclosed is the approved application for permit to drill the above referenced development well. 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 North Slope petroleum field inspector at 659-3607 (pager). //2L' Sincerely, Sarah Palin Chair BY ORDER OF THE COMMISSION DATED this..J..Q. day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. lA.JúA- n-, O t ¿.co s . STATE OF ALASKA - ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of Work: Drill[8J Redrill D 1 b. Current Well Class: ExploratoryD Development Oil 0 Multiple Zone D Re-entry D Stratigraphic Test ø Service 0 Development GasO Single ZoneD 2. Operator 5. Bond; [8JBlanke~ DSingle Well 11. Well Name and Number: Name: Evergreen Resources (Alaska) Corp. Bond No. RLBOO03430 Houston Pit #1 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 871845, Wasilla, AK 99687 MD: 3000 ft TVD: 3000 ft Wildcat 4a. Location of Well (Governmental Section): 7. Property Designation: Sec 20, TWN 18N, Rng 3W '1 ~;-~I Health Trust Surface: 1022' FNL and 797' FEL ;2..oCl O-"(/h':.. 8. Land Use Permit: 13. Approximate Top of Productive AK 550.184.09382 Spud Date: 10 Dee 03 Horizon: Same as above 9. Acres in Property: 14. Distance to Total Depth: Same as above 64 acres Nearest Property: 640 feet 4b. Location of Well (State Base Plan~co~rdinate~: NAD 831).7 10. KB Elevation 15. Distance to Nearest Vt-' ~r.~~' ro z ~~2'/. 7/f1¡4.i) (Height above GL): 303.7' feet Well within Pool: 580 feet Surface: x- 166 1. y- 2 428.91 Zone- 4 16. Deviated Wells: N/A 17. Anticipated Pressure (see 20 MC 25.035) I '~ ~o Kickoff Depth: N/A ft. Maximum Hole Angle: N/A Max. Downhole Pressure: 1- sig. Max.Surface Pressure' psig. 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c.f. or sacks. Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Including Stage Data) 6 4.5 10.8 LP LP 50 0 0 54 54 4.3 cu. Ft. 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD(ft): Plugs (measured): Junk (measured): Casing Length Size Cement Volume MD TVD Structural -- 1__." ___ Conductor ~r ..t:.IVt:U Surface Intermediate UI: I~ - D lUUj Production ^ Liner AlaSKa un 0 . "it;) \.lUll;). Perforation Depth MD (ft): None Perforation Depth TVD (ft): None Ancnorage 20. Attachments: Filing Fee ø BOP Sketch 1:81 Drilling Program 1:81 Time v. Depth Plot 0 Shallow Hazard Analysis 0 Property Plat[2J Diverter SketchO . Seabed ReportO Drilling Fluid program[2J 20 MC 25.050 Requirements 0 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Shane GaQliardi Printed Name Shane Gar liardi Title Petroleum EnQineer Signature -a cL""I 912·, Phone 907-355-8569 Date lz15/63 , Commission Use Only Permit to Drill 6" I API Number: Permit APpro~t'( .. b '7 See cover letter for Number:20.~ ~2..C> 50- 009 - 200 Z- ~ Date: 12 (/I'? other requirements. Conditions of approval: Samples requireq I8!Yes DNo Mud log requiréd. ' DYes aNo Other: L. ~ to Hydrogen sulfide me~sur~s DYes ~No a..1. Directional survey requireq DYes JXlNo CLt{-o.¿k¿d c.~..t:to\'\-~ oe Appro" . Ori~~~~i~~~~MISSIONER BY ORDER OF /J//t2/cr~ Approved by: THE COMMISSION Date: Form 10-401 Revised 3/2l!ro' I S)<fbmit in duplicate IIJ4.It- Core Program 2003 APD O()lh! !\~\.¡ . . Conditions of Approval Evergreen Resources (Alaska) Corp. Houston Pit #1 (PTD 203-206) 1. Per 20 MC 25.030 (g), the formation integrity test requirement is waived. 2. Per 20 MC 25.033 0), the drilling fluid system requirements are waived. 3. Per 20 MC 25.035 (h) (1) and (2), the BOPE and diverter requirements are waived. 4. Per 20 MC 25.050 (h), alternate well bore directional survey intervals are approved. 5. Per 20 MC 25.061 (c), the near surface survey requirement is waived. 6. Test BOPE to 1500 psi. 7. Abandonment plug cement volumes may be adjusted dependent upon actual subsurface conditions. Dee 05 03 OS:56p Dit NOTES: 1. COORDINATES SHOWN ARE NAD83 ALASKA STATE PLANE ZONE 4 BASED ON PRQ1RACTED VALUES. 2.. GEOGRAPHIC COORDINATES ARE NAD 8:5 BASED ON PROlRACTEO VAlUES. 3. ALL DISTANCES ARE GROUND IN U.S. SUR\IEY FEET. 4. VERllCAl DATUM IS NG\{) 29 BENCHMARK 5102. EL == 307,Ot HOUSTON PIT #1 LOCATED 1022.' FROM 11iE NORJH UNf OF SECTION 20 AND 797 FROM 1HE EAST UNE OF SECTICN 20 T 18 N. R ~ 1'/, SEWARD MERIDIAN AT LAT. 61'3B'24,304-'N LONG. 149'SO'53.656·W ÞS? ZONE 4 1'1==279141.8.91 E=1666810.6B7 (NM> 83) GROUND ELEVATiON ~ JO}.7' N SCALE ,. - 600' SECTION 20 T18N, R3W, S.M., ALASKA Houston Pit #1 PERMIT DRAWING ORA'M'-I KWA SCALE l' :: 500' CHECKED KWA SOW57.8340 17 19 ~ ,.., a::: p.S ~. 15 ~ l:j. 22 118N VICINTY MAP SCALE 1" = E 1/18 N a9·53'~· E 131a.n' ¡.... LXJ Ñ o 796.62' Houston Pit #1 1716 2021 ~~ I 't2~ bID QU> II) I~ u:> lID ;; \w ~ ,.... ~ § I~ 1/~ 21 @LOUNSBURY & ASSOCIATES, INC. SURVEYORS-ENGiNEERS-PLANNERS . 723 W. 6th AVE. ANCHORAGE, ALASKA 99501 (907) 272-54-51 FAX (907) 272-9065 November 24. 200J DWG NAME OJ-OJ1-7.DWG · Proposed Drilling procedU! Core Program 2003 Matanuska-Susitna Borough, Alaska Objective The objective of this operation is to core the intended wells for geologic study to determine coal bed methane exploration potential and begin to describe the Mat Su Basin Casing Program Surface casing will be run from surface through the glacial gravels to protect fresh water. The surface hole will be 6 inch d iameter and the surface casino will be X-42 4 inch nominal schedule 40 line Di )e. Hole Size Casing Size Casing Weight Casing Casing Approx Casing Cement (in) OD (in) (Ibs/ft) Grade Connection Depth Interval (ft) Surface 6 4.5 10.8 LP LP 200 to surface Mud Program Water will be the primary drilling fluid used. Bentonite and EZ-Mud DP or other fresh water polymer may be used if hole conditions warrant. After the well has reached TO, this mud will be conditioned and transported to the next site. The cuttings will be tested and either spread on location, sent to an off site disposal facility or placed back in the hole as part of the abandoning process. Open Hole Logging Program Memory tools will be latched into the landing sub above the core barrel. The hole will be logged as the drill pipe is being pulled out of the hole. Log Interval Single Induction TO to ± 20 ft in Surface Casing Sonic Porosity TO to + 20 ft in Surface CasinQ Gamma Rav TO to± 20 ft in Surface Casino Caliper TO to ± 20 ft in Surface CasinQ Compensated Density TO to ± 20 ft in Surface Casing Neutron Porosity TO to ± 20 ft in Surface Casing Formation Tops Formation Estimated Tops (ft KB) I Quarternary Gravel Surface Tertiary Tyonek 50-200 General Information All information not publicly available is considered Tight Hole and confidential. Spill Prevention Plan and Bear Mitigation measures must be adhered to at all times. Core Program 2003 APD e e Proposed Drilling Procedure Core Program 2003 Matanuska-Susitna Borough, Alaska SURFACE AND CORE HOLE 1. MIRU DJ excavation. Make any necessary changes to location to accommodate core drilling rig. a. Dig 6' cellar wI 6' diameter and place culverts. 2. MIRU Discovery Drilling. 3. Drill 6" hole through base of gravel (50'-200' anticipated) and set 4" casing to bottom. a. Evergreen person~e. ill call TD on surface hole. 4. Cement casing in place w/- bbl cmt wI cmt wt @ 15.6 ppg a. Water requiremen .:... 5.2 gallsk b. Slurry volume - 1.18 cu tusk c. Leave 1" to 2" of cement in cellar for seal 5. RDMO Discovery drilling to next well. 6. MIRU Layne Christiansen CS 4000 core drilling rig. 7. Fill mud tanks wI city water. Make sure there is enough mud on site to mix kill wt mud if necessary. 8. WOC for 6 hours. 9. NU and test BOP. 10. Pressure test casing to 1500 psi. 11. Drill cmt and csg shoe. Drill 20 feet into new formation and POOH. 12. RIH with HQ core bit and barrel. 13. Core to Arkose Ridge formation. The well will be TD'd above this level if significant hole problems occur. a. Arkose Ridge formation: Fluvitile and alluvial feldsparic sandstone, conglomerate, siltsone and shale containing abundant plant fragments. b. The core will be described on site by Evergreen personnel or contractors in the following manner: i. Apparent texture variations . 1. Fractures 2. Bedding plane attitudes ii. Apparent fluid variations 1. Presence of hydrocarbons iii. Apparent lithologic variations 1. Rock type 2. Porosity 3. Sedimentary structure 4. Grain size 14. Evergreen personnel will call final TD. POOH wI last core inner tube. 15. Condition hole. 16. PU 30 ft off of bottom to make room for logging tools. 17. MIRU Reeves Wireline. Drop memory tools consisting of Gamma Ray, Sonic Porosity, Array Induction, Compensated Neutron Density and Caliper. 18. POOH anC LD drill pipe, rods, core barrel and core bit and logging tools. 19. TIH wI "B" rods to TD. (Cmt calculations are based on TD=2500' and surface csg @ 200') a. Surface casing - (0.01574bbls/ft)(200') = 3.14 bbls b. HQ Hole - (0.01440 bbls/ft)(2300') = 33.12 bbls c. Total fluid required to fill hole - 36.26 bbls 20. Pump 3 bbls cmt and POOH 210 ft. ./ 21. Pump 18 bbls (1250ft~f mud and cuttings and POOH to 1000 ft. 22. Pump 15.1 bbls cmt 23. POOH wI uB" rods. 24. Clean-up well site. 25. RDMO Layne Christianson to next hole. 26. WOC 24 hours. . J.f 1 vJ(¡þt- 27. MIRU DJ Excavation. 1~ 1 ut&LH-Le/re7" a. Cut 4" casing 3' below 9rl9inal ground level. b. Weld~" thick plate w/Kdiameter onto 4" casing. c. Plate must have the following bead welded information: i. Evergreen Resources ii. Permit to drill number (Number will be provided as soon as it is issued by AOGCC) Core Program 2003 APD e e iii. Well number iv. API number (Number will be provided as soon as it is issued by AOGCC) d. Remove culvert and back fill cellar. 28. RDMO DJ Excavation. Core Program 2003 APD e e Proposed Drilling Procedure Core Program 2003 Matanuska-Susitna Borough, Alaska Core Hole Diagram 6" Hole to ± 100' 4" LP (4.5" aD, 4,026" 10, 3320 psi) @ ± 200' Cemented wI 25 sx Portland cmt Tyonek Formation HQ Diameter Hole (3.850") to 1800' 2.5" core. Log hole using memory tools latched into landing sub while pulling drill pipe. Rig Layout Diagram R' 9' 23' Core Solids Drill Control Van 40' I ";::~ I 20' Rods '--- D Parts Trailer Water Truck De-~asser Vehicle Parking 60' .. 45' ~ Core Program 2003 APD e . a anus a- us. na orougl , as a Company Address Name Telephone Evergreen Resources Inc. Suite 1200 Dennis Carlton Office: 303-298-8100 1401 Seventeenth Street Senior Vice President of Fax: 303-298-7800 . Denver, Colorado 80202 Operations Evergreen Resources Inc. Suite 1200· Scott Zimmerman Office: 303-298-8100 1401 Seventeenth Street Vice President of Operations Cell: 303-981-3314 Denver, Colorado 80202 and Engineering Fax: 303-298-7800 Evergreen Resources Alaska P.O. Box 871845 Shane Gagliardi Office: 907-357-8130 Wasilla, AK 99687 AK Project Engineer Cell: 907-355-8569 Fax: 907-357-8340 Evergreen Resources Alaska P.O. Box 871845 Mike Bellowich Office: 907-357-8130 Wasilla, AK 99687 AK Project Geologist Cell: 907-232-9538 . Fax: 907-357-8340 Evergreen Resources Inc. Suite 1200 Jerry Jacobs Office: 303-298-8100 1401 Seventeenth Street Environmental Manager Fax: 303-298-7800 Denver, Colorado 80202 Hampton & Waechter Suite 300 Noel Waechter Office: 303-825-7140 1645 Court PI. Denver, Colorado 80202 Layne Christiansen 2370 Steese Hwy. Shane Crum Office:918-322-3095 Fairbanks, AK 99712 Mobil 918-625-1668 Fax: 918-322-3829 MI Swaco 721 West 1st Ave. Dennis Jackson Office: 907-274-5501 Anchorage, AK 99501 Reeves Wireline 121 South Country Estates Bob Gales Office: 785-331-2933 Road, Liberal, KS 67901 Proposed Telephone Contact List Core Program 2003 M t k S "t B h AI k Core Program 2003 APD Manufacturer: Size: Rating: Usage: e e Well Control Diagrams Core Program 2003 Matanuska-Susitna Borough, Alaska Cavins Oil Well Tools 4" 3000 psi Used for mineral exploration core drilling in Nevada. . ...... IIi.1IIiiiW'j if . JØU ..1..... f't1Jtm1U __!'OCJOOIJ! tFI ...... -. -r Cavins Annular BOP ~.... Cavins Annular BOP Schematic The combination Blowout Preventer and Sucker Rod Stripper combines safety and economy in a tool designed to perform the necessary function of line wiping. It can be operated from anywhere on the derrick floor utilizing pressure from bottled nitrogen, an optional hand operated hydraulic pump, or the optional BOP control system. When swabbing, a short lubricator the length of the swab between the master gate and the Blowout Preventer is all that is required. Pressure connection is for 1/4" A.P.I. pipe. The units are testèd to give full closure up to 3000 psi well pressure with no leakage. The full closure feature of the Blowout Preventer will give a temporary seal, allowing ample time to close the master gate should a well blowout occur. BALL LOCK OIL SAVER The use of the Ball Lock Oil Savers by drilling and production departments has earned this service proven tool a reputation for trouble-free operation with simplicity. The CAVINS Ball Lock Oil Savers are made of high carbon steel and precision machined for demanding dependability and safety in a wide range of service applications. Exhaustive testing in the excess of 3000 psi is further assurance against failure or leakage. Incorporated in its design, which affords a cleanly wiped wire line, is its safeguard against blowout. One important feature of the Oil Saver is its automatic ball release design. Hardened Steel Balls hold the traveling assembly securely in the body until released by the upward travel of the Rope Socket. The Rubber Packing unit with its internal fins provide the ultimate in wire characteristics with only a normal pressure, or drag, on the line. The Packing Rubber is compounded of special abrasive and oil .. resistant properties to give the rubber longer wear. A tough spark-proof die cast alloy is utilized in the top and bottom line guides and enhances Hydraulic Pump and Hose reduced wear in the rubber packing unit. A high quality leather hydraulic packing ring wards against leakage in the area between the body and the traveling assembly. The Hydraulic Bonnets provide an even greater degree of wiping efficiency. The wire line can be completely stripped of all oil, or water and an Oil Saver outfitted with a Hydraulic Bonnet foregoes the necessity of tools for ·taking up' wear in the packing element. The one hand operation requires only a few strokes of the pump handle to give complete wiping action or turn the release valve when no wiping is Ball Lock Oil required. The Hydraulic action affords a greater rubber contact surface as the packing rubber is compressed Saver around the line. The line is completely surrounded and sealed from blow-out leakage by the action of the Hydraulic unit. There is no danger of packing rubber or other elements falling into ttie well. Core Program 2003 APD e e Well Control Diagrams Core Program 2003 Matanuska-Susitna Borough, Alaska BOPE Diagram 1. Oil saver fitted with stripping rubbers to fit 3/16" slick line. Can be operated 2 manually andlor hydraulically. 3 2. Cross over from drill pipe thread to 4" API LP thread. 4 3. Relief valve for lubricator. 4. Lubricator made of HQ drill pipe. Rated to 4600 psi. 5. TIW (stabbing valve). Rated for 3000 psi. Used for shutting in drill pipe ID to rig up for pulling core. 5 6 7 8 9 Kill Line 10 6. Drill pipe sitting in foot clamps during coring operation. Rig Floor 18-5/8 Inches 7. Cavins 4" 3000 psi Annular BOP. BOP can be operated manually or hydraulically. Will be fit with rubbers to provide pressure control on the outer tube of the coring assembly. 8. 4" Full port 3000 psi valve. 13/nches 9. Standard spool threaded to fit 4" line pipe connections wI two 2" ports that will be fitted wI 3000 psi full port ball valves. 10. 4" API line pipe surface casing. Choke Line NOTE: ALL CONNECTIONS ARE THREADED Core Program 2003 APD e e . Tubular Information Core Program 2003 Matanuska-Susitna Borough, Alaska Drill Pipe (HQ) Size Pipe Weight 10 Drift Collapse Burst Tensile Capacity Capacity 6" Hole 6" Hole Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (k~lbs) (bbllft) (ftIbbl) (bbllft) (ftlbbl) 3.5 HMQ 4.5 3.188 3.188 3910 4600 88.46 0.00911 109.7 0.02307 43.35 u ace asmg Size Pipe Weight ID Drift Collapse Burst Tensile Capacity Capacity 6" Hole 6" Hole Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (k-Ibs) (bblslft) (ftlbbl) (bbllft) (ftIbbl) 4.5" LP X42 10.8 4.026 4.026 2650 3320 0.01574 63.51 0.0153 65.36 Sch 40 5 rf C Core Program 2003 APD e . Core Program 2003 Matanuska-SusitnaBorough, Alaska Exception #1 Regulation 20 AAC 25.030 - CASING AND CEMENTING. (f) Except for through-tubing drilling, a formation integrity test must be performed if BOPE is installed on a casing. The test must be performed to a predetermined equivalent mud weight, leak-off, or fracture pressure as specified in the application for the Permit to Drill. The test must be conducted after drilling out of the casing shoe into at least 20 feet but not more than 50 feet of new formation. The test results must demonstrate that the integrity of the casing shoe is sufficient to contain anticipated wellbore pressures identified in the application for the Permit to Drill. The test procedure followed and the data from the test and any subsequent tests of the formation must be recorded as required by 20 MC 25.070 (1). List of Exceptions For Drilling Authority 20 AAC 25.030 - CASING AND CEMENTING. (g) Upon request of the operator, the commission will, in its discretion, approve variances from the requirements of (b) - (f) of this section to allow for special or unusual conditions if the design requirements of (a) of this section are satisfied. Justification No intermediate casing will be set and surface casing will be set relatively close to surface; therefore, a formation integrity test is not valid. Exception #2 Regulation 20 AAC 25.033 - PRIMARY WELL CONTROL FOR DRILLING: DRILLING FLUID PROGRAM AND DRILLING FLUID SYSTEM. c) A drilling fluid system intended to maintain the wellbore in overbalanced condition must include (1) a recording drilling fluid pit level indicator with both visual and audible warning devices located in the immediate area of the driller's station; (2) a drilling fluid measuring system or trip tarik for accurately determining drilling fluid volumes required to fill the wellbore on trips; (3) a drilling fluid flow sensor with a readout convenient to the driller's station to enable the operator to determine whether drilling fluid returns equal drilling fluid pump discharge rates; Authority 20 AAC 25.033 - PRIMARY WELL CONTROL FOR DRILLING: DRILLING FLUID PROGRAM AND DRILLING FLUID SYSTEM. 0) Upon request by the operator, the commission will, in its discretion, approve a waiver of the requirements of (c) - (g) of this section if the alternative drilling fluid program and drilling fluid system meet the design criteria of (b) of this section and the corresponding equipment and procedures are at least equally effective in preventing the loss of primary well control. Justification The steel mud tank will be placed next to the drillers console in plain sight. There will be constant circulation of drilling fluids taking returns into the cellar. The mud system will have adequate volumes for maintaining the fluid level in the hole while tripping. For this process a couple of bit trips are anticipated per hole. Lost circulation is not anticipated as indicated by the previous drilling in the area. Other wells drilled in the area were drilled using air; during that drilling operation, gas influx was not an issue. There is no indication from past drilling that hydrogen sulfide gas will be encountered. Exception #3 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (c) (1) (A) of at least 16 inches, unless a smaller diameter is approved by the commission to account for smaller hole size, geological conditions, rig layout, or surface facility constraints. (B) the actuating mechanism for the vent line valve must be integrated with the actuating mechanism for the annular pack-off device in a fail-safe manner so that the vent line valve automatically opens before full closure of the annular pack-off; (C) the vent line must extend to a point at least 75 feet Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. Core Program 2003 APD e e Justification The largest hole size being cored is only 3.8S inches. A 16 inch diverter vent line is not necessary. Due to the size of the location, manual valves and adjustable chokes would be sufficient to provide pressure control. The DNR states that the locations should be placed such that minimal surface damage is caused; therefore, the proposed location sizes are 4S' x 6S'. The location size is smaller than the required length of the vent line. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Exception #4 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (1) (A) for an operation requiring a BOP stack equal to or less than API SK, BOPE must have at least three preventers, including (i) one equipped with pipe rams that fit the size of drill pipe, tubing, or casing being used, except that pipe rams need not be sized to bottom-hole assemblies (BHAs) and drill collars; (ii) one with blind rams, except that a subsea BOPE assembly must have blindlshear rams in place of blind rams; and (iii) one annular type Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary Justification Being a mineral exploration rig, this equipment is not set up to easily accommodate blowout prevention equipment. The size of the rig and the size of the surface casing indicate that a small bore BOP is required. A Cavins 3000 psi annular BOP is requested to satisfy this portion of the secondary well control requirements. There will be no pipe rams and the blind rams will consist of a full port valve placed below the annular preventer. The annular can be closed either manually using a hand pump or by using rig hydraulics. Exception #5 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (4) (A) a hydraulic actuating system with (B) locking devices on the ram-type preventers; (D) in rotary drilling rig operations, one complete set of operable remote BOPE controls on or near the driller's station, in addition to controls on the accumulator system (F) a kill line and a choke line each connected to a flanged or hubbed outlet on a drilling spool, the BOP body, or the tree, with two full-opening valves on each outlet, conforming to the following specifications: ii) the outer valve on the choke side must be a remotely controlled hydraulic valve; (H) a choke manifold equipped with (i) two or more adjustable chokes, one of which must be hydraulic and remotely controlled from near the driller's station if the operation requires a BOP stack equal to or greater than API SK; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and . (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Core Program 2003 APD e e Justification The proposed BOP does not have rams. This rig is not configured to have an additional set of BOP controls near the driller's console, this rig does not use BOPE on a regular basis when conducting mineral exploration. This rig is not equipped to run hydraulically operated chokes; therefore, manual adjustable chokes are requested. Due to anticipated low pressure, threaded connections are requested for the entire operation. Exception #6 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (10) (F) be assembled without hammer unions or internally clamped swivel joints, except that hammer unions and internally clamped swivel joints may be used on the kill line upstream of the valves that are flanged to the wellhead or tree. (e) (9) connections directly to the BOPE, other than connections described in (8) of this subsection, must be flanged or hubbed. except that suitably pressurerated quick connects may be used if a positive seal manual valve, hydraulic valve, or BOPE blind ram and an annular type preventer or sealing ram are flanged to the wellhead or tree below the quick connection; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification The proposed BOP does not have rams. Request that all connections be threaded and hammer unions be approved. Anticipated suñace pressure will be well within the pressures ratings of all BOPE. This well head is not intended to be a permanent fixture for production. Exception #7 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (6) (F) be assembled without hammer unions or internally clamped swivel joints, unless the commission determines that those joints do not compromise maintenance of well control; (e) (8) connections attached directly to the wellhead, tree, or BOPE must be flanged or hubbed; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification Request that all connections be threaded and hammer unions be approved. Hammer unions to be used are rated for 5,000 psi. Anticipated suñace pressure will be well within the pressures ratings of all BOPE. This well head is not intended to be a permanent fixture; and intended annular BOP is threaded. Exception #8 Regulation 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (e) (9) (A) an inside BOP and a full-opening drilling assembly safety valve in the open position on the drill rig floor to fit all connections that are in the drilling assembly; Authority 20 AAC 25.035 - SECONDARY WELL CONTROL FOR PRIMARY DRILLING AND COMPLETION: BLOWOUT PREVENTION EQUIPMENT AND DIVERTER REQUIREMENTS. (h) Upon request of the operator, the commission will, in its discretion, approve a variance (1) from the BOPE requirements in (e) of this section if the variance provides at least an equally effective means of well control; and Core Program 2003 APD e e (2) from the diverter system requirements in (c) of this section if the variance provides at least equally effective means of diverting flow away from the drill rig or if drilling experience in the near vicinity indicates that a diverter system is not necessary. Justification The use of a continuous core system prevents the use of internal check valves. A lubricator system will be employed when the core is to be retrieved. Exception #9 Regulation 20 AAC 25.050 WELLBORE SURVEYS. (a)(3) surveyed by a complete continuous directional survey if a portion of the well path is less than 500 feet from a property line where the ownership by owner or landowner is not identical on both sides of the line, or if a portion of the well path is less than 200 feet from any other vertical or deviated well; the survey must be taken at intervals not more than 100 feet apart, beginning within 100 feet of the surface. Authority 20 AAC 25.050 WELLBORE SURVEYS. (h) Upon application, the commission will, in its discretion, waive all or part of the directional survey requirements of this section or approve altemate means for determining the location of a wellbore if the variance at least equally ensures accurate surveying of the wellbore to prevent well intersection, to comply with spacing requirements, and to ensure protection of correlative rights. Justification Request that inclination surveys every 500 feet as stipulated in 20 MC 25.050 (a) (2) be adequate for this operation. There will be no production from these wells; therefore, spacing requirements and correlative rights should not be an issue. Exception #10 Regulation 20 AAC 25.055 - DRILLING UNITS AND WELL SPACING. (a)(2) for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line Authority 20 AAC 25.055 - DRILLING UNITS AND WELL SPACING. (d) The commission will review an application for an exception to the provisions of this section in accordance with 20 MC 25.540. The applicant for an exception shall send notice of the application by certified mail to the owners, landowners, and operators described in (1) of this subsection and shall furnish the commission with a copy of the notice, the date of mailing, and the addresses to which the notice was sent. The application must include (1) The names of all owners, landowners, and operators of all properties within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) A plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells; and (3) An affidavit by a person acquainted with the facts, verifying that all facts are true and that the plat correctly portrays pertinent and required data. Justification These wells are intended for stratigraphic testing only; therefore, no gas production or sales will result from any of these wells. The above listed requirements will be met. Exception #11 Regulation 20 AAC 25.061 (a) - Well Site Surveys For an exploratory or stratigraphic test well, near surface strata to a depth of 2,000 feet in the vicinity of the well must be evaluated seismically by common depth point refraction or reflection profile analysis, or by another method approved by the commission, to identify anomalous velocity variations indicative of potential shallow gas sources. Analysis results must be included with the application for the Permit to Drill (Form 10-401). Authority 20 AAC 25.061 (c) - Well Site Surveys Upon request by the operator, the commission will, in its discretion, waive the requirements of this section if the operator can identify, by other equally effective means, the likelihood of encountering potential shallow gas or seabed hazards or if the commission already has information that substantiates the presence or absence of shallow gas or seabed hazards. Core Program 2003 APD e e Justification Several wells have been drilled in the area through the intended formations without incident. Drilling history in the area indicates that over pressured shallow gas is not going to be a problem; therefore,seismic data collection and interpretation would be an unnecessary expense. Core Program 2003 APD =\I=I~GI~==I'tt RESOURCES(ALASKA)COR~ A Subsidiatyof Evergreen Resources, Inc. . December 5, 2003 Ms. Sara Palin, Chair Alaska Oil and Gas Conservation Commission 333 West Ave., Suite 100 Anchorage, Alaska 99501 RE: Application for Permit to Drill: Core Program 2003 Target: Tertiary Tyonek Proposed TD: 3000 Feet Proposed Spud Date: 10-December-2003 Dear Ms. Palin, Evergreen Resources Alaska Corporation hereby applies for a Permit to Drill for the subject core wells located approximately 30 miles north of Anchorage. The wells are planned as a shallow, straight holes drilled to evaluate the producibility of the Tyonek Coals. A core drilling company currently operating in the Fort Knox gold mine will be used to provide a continuous wireline coring operation. The rig to be used is a CS-4000 that is typical for mineral exploration. A six inch hole will be drilled through the glacial gravel section and a string of 4.5 inch line pipe will be cemented in place. Once the cement has hardened and the appropriate test has been conducted for casing integrity, an HQ hole (3.875" diameter) will be drilled to TO. A logging suite consisting of gamma ray, array induction, compensated neutron density, caliper and sonic porosity tools will be run. After all cores have been retrieved and logs run, the hole will be permanently abandoned. Attached is information required by 20 AAC 25.005 (a) and (c) for your review. Due to the differences in equipment and methods used for mineral core drilling, Evergreen requires several variances from current AOGCC regulations. The designated contact for reporting responsibilities to the Commission is Shane Gagliardi, Alaska Projects Engineer, office: 907-357-8130 or cell: 907-355-8569. Sincerely, Evergreen Resources (Alaska) Corporation ß 4tl2-::- Shane Gagliardi Alaska Projects Engineer enclosures RECEIVED DEC - 5 2003 Alaska Oil & Gas Cons. Commission Anchorage nQ!ru\1 Core Pr gram 2003.APD 1075 Check Streel, Suite 202 . Wasilla AK 99654 P.O. Box 871845 . Wasil/a, AK 99687 . TEL 907.357.8130 . FAX 907.357.8340 Dee 17 03 04:22p DH . 907.357.8340 p.10 . @Cß-!9-0(ç December 3, 2003 The TRUST LAND OFFICE Scott Zimmerman, Alaska Projects Manager Evergreen Resources Alaska Corporation P.O. Box 871845 Wasilla, Alaska 99687 ) Re: Proposed Core Drilling on Lease MHT 9200180 Dear Mr. Zimmerman: The Trust Land Office (TLO) has reviewed the Plan of Operations that dc:>cribes your proposed mineral core-drilling program on the above referenced Mental Health Trust oil and gas lease. As proposed, this drilling operation is to take place on a portion of the referenced lease located in the NEl/4 Section 20, Township 18 North, Range 3 West, S.M., on a parcel described by Evergreen as the Houston Pit #1 core site. Note that the Trust owns only the hydrocarbon (Oil and Gas) estate in this parcel. Pursuant to Section 6 of Oil and Gas Lease MHT 9200180, the TLO approves your Plan of Operations subject to your providing a schedule of the operations to be conducted on the Leased Area, including the date operations are proposed to begin and their proposed duration. This schedule must be provided before activities begin on the Lease. Note that approval of your Plan by the TLO does not relieve you of your obligations to adhere to all applicable provisions of the referenced Lease or to obtain all approvals or pennits required by governmental agencies having regulatory authority over the proposed operations. It does not address your requested exemption of certain mitigation measures that are part of MHT 9200180, since these measures are covered by the regulatory authority of specific agencies. Note also that the TLO approval applies only to the Trust ownership interest in the oil and gas estate. You must obtain approval for use of the surface estate andresolve any surface use issues or conflicts with the surface estate owner of this parcel. Let me know if you have any questions regarding this letter. Mike Franger Senior Resource Manager Cc: Stephen C. Planchon Matt Rader Alaska Mental Health Trust Land Office . Department of Natural Resources 550 West 7th Avenue, Suite 1430 . Anchorage, Alaska 99501 . Telephone: (907) 269-8658 . Fax; (907) 269-8905 Dee 17 03 04:22p OCT-22-Ø3 01:17 PM DH ceOF 907.357.8340 90799~. HOUSTOH A , DALE ADAMS. MAYOR ---.- -------- P.o. Box 940027 Houston. AK. 99694 907-892-6869 907-892-7677 Fox cityh all@mtoonline.net .net October 22, 2003 John Tanigowo. Projects Manager Evergreen Resources P.O. BOX 871845 Wosilla. AK 99687 Deor Mr. Tanigawa. On October 22. 2003 the council for the City of Houston, Alaska voted to allow Evergreen Resources to drill 0 core well on its property in the vicinity of the old Houston strip pit. Sincerley. , ((;J:X<~é~~ Dale AdoJ;:-;;ayor _._...._;;.-~._-_._-_.. - p.11 P_01 Alaska Department of Natural Resources Recorder's Office Imaging System e e Page 1 of5 Administration Case Abstract Information Fil.e Type: 9200180 http://www.dnr.state.ak.us/las/Case _ Abstract.cfm?FileType=MHT &FileNumber=9200 180LJ 12/9/2003 Alaska Department of Natural Resources Recorder's Office Imaging System e e Page 2 of5 http://www.dnr.state.ak.us/las/Case _ Abstract.cfm?FileType=MHT &FileNumber=9200 180<'.J 12/9/2003 Alaska Department of Natural Resources Recorder's Office Imaging System e e Page 3 of5 http://www.dm.state.ak.us/las/Case _ Abstract.cfm?FileType=MHT &FileNumber=9200180¿.J 12/9/2003 Alaska Department of Natural Resources Recorder's Office Imaging System e e Page 4 of5 http://www.dnr.state.ak.us/las/Case _ Abstract.cfm?FileType=MHT &FileNumber=9200 180'-.J 12/9/2003 TOWNSHIP 18 N RANGE 3W OF THE SEW ARD MERIDIAN, ALASKA .......~_.;.t:"'!" "'0" ....00. ,...""" '.~.. "":"'l ....'.. ~ Iii ti -- ,~ .!. 1 .1 ,~ .J. ..J. J. .J... ~l.. .. I '! '~\\ ..- ,~ r 'I Ii " I "'-c I' LSE08S '"' J,', .3892fi~ 1 ~s .. II 12 ¡ " 32 " I';' suP"'~:OA< pm ¡ ~~~ : 4-mlll-' /ff~"'! Iff,; I. L SC4t.£ ~,~~- 4.,;,~;;æ;;æ,:'-''-~ STATE OF ALASKA O(P1'O"U,TUIIAJ,. IIkSOUACE'J O"I'SIOHOFLANOS ~~Ji~~:i~:; ..MJ.iiEHALES IiI T ¡;: ~. ~; I, :t ,; ,.,:~~:. ~~:.',~' ¿t'i~~'·.n:"":'i~~:::'-:' ," I. -. . ,. ..,~,-.-.. e .......i.:",\f.' ,.1~~!'!!U.~ ..:.. _._~_,,_ '" __.~. . '.'.~'" ~'.~' _.:.:...."':.,-S.?!!.!:f:.:..'0.....' .;!.r.- f'tAr M"C";¡".y r'~(:. 12/f/'6 ~-If;;:;:i-~~<~;Z:~ . --¡;;¡~~;;.-;¡;m.;-~;-:;:'::;:---- '_!9;:,_~_~:~e~~~' ---.--. _.._.._..___ _u'___'_"'_' , '''',£IIn'.'·'''''·I!Y'''. J . __,'__ ._'__n___.. _..n._ .?c>......_ '-,J -. -..... . . -..---- --.-... .-,---..--.--.----"..,. u. __^._",,-_.___.__.,__,__~__._ .,. .-.---...----.---- .-._-~-_.__.. .---.---.--.--. -.----..--....-, _._.-._."._..~--- e ----------".- ---'--"--~-- - ~_.' - ---_._~--- ---.-.------ E,f-fi~~... C~"ilJ.' ~:1 ~~~~l~~-~~=J ~~.:.:_.~:_= j ~, ----~.--...._---_. -.._~-:~r--\-;.:: ~. ., TU. , OW 'M ^PLEASE DETACH AT PERFORATION ABOVE^ ^PLEASE DETACH AT PERFORATION ABOVE' Evergreen Resources (Alaska) Corp 1401 17th Street Suite 1200 Denver CO 80202 303-298-8100 112403SG5 11/24/2003 12 month permit fee Houston Pit 1 100.00 0.00 100.00 ECE/V 0 DEC - 9 13 Alaska Oil & Gas Cons C '. . mrJ1Iulon Anchorage I 009195 I ~ Vendor Check Date: 12/08/2003 Check Amount ~ I 100.00 I e e TRANSMIT AL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERIP ARA GRAPH S TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing weD . 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(1), all (PH) records, data and logs acquired for the pilot hole must be dearly differentiated in both name (name on permit plus PH) . and API Dumber (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 is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. DRY DITCH An dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07110/02 C\jody\templates Well Name: HOUSTON PIT No. 1 Program STR Well bore seg PTD#: 2032060 Company EVERGREEN RESOURCES (ALASKA) CORPORATION Initial ClasslType STR /INFO GeoArea Unit On/Off Shore On Annular Disposal 1 P~rmitfee attaçhe~. . . . . . . . . . . . . .. .................. Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 .Leas~.numberappropri<lte............................. . . . . . Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ...... . . . . . .. ...... 3 .U.nique well.n.arn~.aod oumb.er ..................................... Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 WellJoc<lt~d in.ad.efil1e~.pool. . . . . . . . . . . . . . . . . . No . . . . . Thi$. is <I~on.tioouscore.straUest . . . . . . . . . . . . . . . . . 5 WellJoc<lt~d proper .distance from driJling ul1itb.oUl1d.ary. . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . There wilJ be 110.te$.ts of.this well . . . . . . . . . . . . . . . . . . . .. ...... 6 WellJoc<lt~d pr9per .distaoce. from otber wells. . . . . . . .. .......... 'yes. . . . . . . and no .correlatiye rjghtsissue$.. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 .S.uffiçiel1taçreage.ayail<lble [ndrilJiog unjt . . . . . . . . . . . . . . . . . . . . . . Y~s .. ............................. ....... . . . . . . . . . . . . . . .. .......... 8 Jf.d~viated, js. weJlbore platil)cJuded . . . . . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . .. ......... . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 .Operator only affected party. . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ ................. ...... 10 .Operator bas.apprppriate.b.ood inJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . 11 P~rmit cao be issued wjtbout conserva.tiOI1 order. . . . . . . . . . . . . . . . . . . . . . . . . . . . Y.es . . . . . . . See. above. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 12 P~rmitc.all be issuedwjtbout ad.mil)istrative.apprpvaJ. . . . . . . . . . . . . . . . Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . .. ...... . . . . . . . . . . . . . . . RPC 12/9/2003 13 Can permit be approved before 15-day wait Yes 14 WellJocat~d within area and strata .authorized by.llljectipo Ord~r # (puUO# in.comrn~llts)(For .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ...... . . . . . . . . . . . . . 15 .AJI wells.wit!1inJI4.rtlile.area.of review jd~otifjed (Fpr $.ervj~.w.ell only). . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 Pre-produ.ced iojector; ~ur<llionof pre-pro.ductiOI) tess. than:3 montbs. (For.service well onJy) . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............... . . . . . . . 17 ACMP.F'inding.ofCon$islellcy.h.as bee.ni$.sued.for.tbis projeçt . .. ........ .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 .C.ollduclor string. provided . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 19 .S.urfaceca$.il)g.p.rotects. all.known. USDWs . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . .. ...... ................ ................... 20 .CMTv.otadequate.to çirc.utate.oncOl)duçtor.& surf.csg . . . . . . . . 'yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ . . . . . . . 21 .CMT v.ol adequ.ate.to tie-in Jong .strillg losurf C$.g. .. ........ .............. .NA . . . . . . NO ca.sing below surl'açe. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 22CMTwill coyer all kl)own.pro.ductiye borizon.s. . . . . . . . . . . . . . . . . . . . . . . No. . . . . . . . Stra.tigraphic test.. . . . . . . . . . . . . .. ....... .. . . . . . . . . . . 23 .C.asillg desiglls adequa.te fpr C,.l", B.&.p-ermafrost . . . . . . . . . . . . . . . . . . . . . . . . . . Y~s . . . . . . . .. ............. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24A~equ<lle.tan.kage.o.r re.serve pit. .. ...... . . . . . . . . . .Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 25 Jf.a.re-~rilt has.a. lOA-03 for abandonment be~o app.roved . . . . . . . . . . . . . . . . . . . . . . .NA . . . . . .. ....... ................... . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .Mequale.wellbore$.epar<ltjo.n.proposed................................. Y~s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 27 Jf.djverter .required, does it.meel reguJatiol)s. . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA . . . . W<liyed. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ Appr Date 28 .D.riUiog fluid. program schematic&eq.uipJistadequ<lte. . . . . . . . . . . . . . . . . . . . . . . . . Y~s. . . . . . . .. .............. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WGA 12/10/2003 29 .BOPEs,d9.they meelreguJatiol) . .. ................... ............ .NA . Waiyed... . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................................. 30 .BOPE.Pfessratillgappropriate;testlo.(pu.tpsigin.commel)ts)................... .Yes..... .TestloJ5QO.psi..MS~10.80psi................................................ 31 .C.hoke.rtlanjfold çompJies. w/APtR~-5:3 (May 84) . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 Work will occur withpytoperation .shutdown. . . . . . . . . . . . .. .... Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 33 J$. pre$.ellce of H2S gas. probable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . No.. ............. ...................... . . . . . . . . . . . . . . . . . . . . . . . . . . . 34 Mecba.nical.cPl)ditioll9f wells within .ð.OR verified (For.s.ervice welJ onJyj. . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Administration Engineering Geology Appr RPC Date 12/9/2003 Field & Pool . . . . offsetweJls indicate 1)01:125. . . . . . . . . . . . . . . . . . . . . . . . . _ . . offsetwells sh.ow.normal pre$.sur.e. . . . . . . . . . . . . . .. ......... 35 P~rmit call be issued w!o. hydrogen sulfide meaSJJres. . . . . . . . . . . . . . . . . . . . . . 36 .D.ata.presel)ted on. pote.ntial pve.rpre$.sure .zones. . . . . . . . . . . . . . . . . . . . . . . 37 .S~ismic.analysjs. of sbaJlow gaS.Z90es . . . . . . . . . . . . . .. ....... 38 .S~abedconditipo survey (if off-sh.ore) ........... 39 . Conta.clnam.elp!1on.e.for.weekly progre$.s.reports [exploratory .ollly). . . . . . . . . . . . . . . . . Y~s. . . . . . . Shane G<lgliardi (907) .355-8569. . . . . .Yes. . . . Y~s. . .No. .NA........ . - - - - - - - - ~ - - - - - - - - - D D .. . Geologic Commissioner: Þ/S - - - ~ - - - ~ - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Public ~ Commissioner~ .-:>Da~ /7/0 Date /2/ {O 3 e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the me under APPENDIX. No special effort has been made to chronologically organize this category of information.