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Home My WebLink About203-205• • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ~c~~ °~~ ~~ DATE: August 3, 2009 P. I. Supervisor ~~ FROM: Chuck Scheve, SUBJECT: Surface Abandonment Petroleum Inspector Little Su #1 PTD 203-205 •~~ ~L~#~i1•.4 3 !-~il.~~ ~~ .~~'. /!J`f~ BACKGROUND: Little Su`#1 was found during a location clearance inspection on May 11, 2009 to have a 6-foot surFace marker post with plate welded to top; refer to Inspection report same date. It is unclear why the marker post was installed following what the Commission witnessed (or was told was the Little Su #1 location) during a June 12, 2007 surface abandonment inspection. AOGCC instructed Pioneer on Jun 2, 2009 to remove the Little Su #1 marker post and replace it with a subsurface monument consistent with 20 AAC 25.120. Mondav, Auqust 3. 2009: I traveled to Pioneer's Little Su #1 exploratory location to inspect the casing cut off and abandonment of this well. The 4-1/2" casing was cut off at approximately 4' below ground level. No cement was evident in the casing. PVC pipe was run in the hole to 80' and tagged up solid. Cement was pumped from this point and a 3/8" thick marker plate was welded to the casing with the required information bead welded to it. The excavation was backfilled and the area graded smooth. SUMMARY: I inspected the casing cut off depth, cement top and the P&A marker plate on the Little Su #1 well and all was left in compliance with AOGCC requirements. The location was returned to original grade with no debris or other indication of past drilling activities. Attachments: Little Su #1 marker plate.JPG Little Su #1 cut off.JPG Little Su #1 finish grade.JPG ~ ~ SurFace Abandonment - Little Su #1 (Pioneer) Photos by AOGCC Inspector C. Scheve August 3, 2009 Little Su #1 casing cut- off 4 feet below surface Marker plate; note that well was drilled by Evergreen who was later purchased by Pioneer Well location backfilled and graded • • Page 1 of 2 Regg, James B (DOA) From Sent: To: Cc: Regg, James B (DOA) Tuesday, June 02, 2009 3:22 PM ~~ ~ ~ ~~-~~1 'Hoffman, Dale' ~~ ~o~-Z~ ~~~ Zee"~ -2~ ~ Davies, Stephen F (DOA); Foerster, Catherine P (DOA); Scheve, Charles M (DOA); Crisp, John H (DOA) Subject: RE: Willow Fishhook well inspection Attachments: 2007-0612_Location_Clearance_Pioneer_LittleSu-1_cs.pd Little_Su-1_plat _2009- 0511_cs.jpg; Little_Su-1_mkr_2009-0511_cs.jpg You will be contacted in next day or so from one of our Inspectors -John Crisp -about making arrangements to visit the Willow Fishhook #1 site. The Little Su #1 location surprised us. Chuck Scheve did a location clearance inspection there back in June 2007. The location was recommended for final clearance based on there being no evidence of past drilling activity (including no marker post). His 6/12/2007 inspection report with photo is attached. We would be interested in knowing what has transpired such that there is now a 6-foot marker post with a large square plate welded to the top as indicated in the photo from inspection done 5/11/2009 (photos attached). While 20 AAC 25.120 provides for the installation of a marker post that extends 4 to 6 ft above ground level, the Commission normally requires the marker plate to be installed directly on the cut casing stub -which is required to be least 3 feet below ground level (per 20 AAC 25.170(a)(1)) -and buried without any surface marker post. The AOGCC did not witness the surface P&A at Little Su #1, but surface abandonent of all other coalbed methane wells we witnessed in the Wasilla-Willow area were "marked" with a plate installed on the buried casing stub (no marker post). Based on the 6-12-2007 location clearance inspection (deemed acceptable), the marker post at Little Su #1 location needs to be removed before we can grant final location clearance and authorize releasing the bond. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Hoffman, Dale [mailto:Dale.Hoffman@pxd.com] Sent: Monday, June 01, 2009 8:12 AM To: Regg, James B (DOA) Subject: Willow Fishhook well inspection Jim, Please let me know when an inspector is available to examine the Willow fishhook site. I've pulled the plat from the archive and know right where it is. Sorry about the inconvenience on the last trip. Dale Hoffman, Senior Staff Landman Pioneer Natural Resources Alaska, Inc. 700 G St., Suite 600, Anchorage, AK 99501 6/2/2009 • • Page 2 of 2 907 343 2108 office, 907 830 2571 cell date.hoffman@pxd.com Statement of Confidentiality: This message may contain information that is privileged or confidential. If you receive this transmission in error, please notify the sender by reply e-mail and delete the message and any attachments. 6/2/2009 • • Location Clearance -Little Su #1 PTD 203-205 Photos by AOGCC Inspector C. Scheve 5/11 /2009 2009-0511 Location Clearance Pioneer LittleSu-1 cs.doc • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, ~ ~I2 ~'l.C~;~~ DATE: May 11, 2009 P.I. Supervisor ~~ FROM: Chuck Scheve, SUBJECT: Location Inspection Petroleum Inspector Pioneer (Evergreen) Little Su #1 PTD 203-205 Monday, May 11, 2009: The purpose of today's trip was to inspect the Willow Fishhook #1 (PTD 203-207) coalbed methane exploration location. I was shown to what was thought to be the Willow Fishhook location by Dale Hoffman with Pioneer Natural Resources. As shown in attached pictures a post approximately 6' tall with a marker plate on top indicating the well as the Little Su #1 (PTD 203-205) was found. Previous inspection of this location revealed no post or sign of past drilling activity. SUMMARY: Uncertainty exists in my mind and apparently Mr. Hoffman's as to which location was visited today. Positive identification of the well location and removal of the post should be completed prior to final location clearance for the Willow Fishhook #1 and Little Su #1 wells. Attachments: photos (2) 2009-0511 Location Clearance Pioneer LittleSu-1 cs.doc • • Location Clearance -Little Su #1 PTD 203-205 Photos by AOGCC Inspector C. Scheve 5/11 /2009 ~ r~ ~ _ ~"~ e , ~~~ .. ~ ' .~f t':v *> ~~ ~a~.~r~~ ''` ~ ~. `1'IW ~,e t 1 .~ ~ ;4 ~~~f ` lye . y' ~ e ~Tr„;~ w:~ ~.. .., - vF'v. .r ~ f , ~ -- v_ ~~.~~' ~^ .~Jf',.~ ' f - ~ ~,,, ~~~ ~'~ 4J `~i11 r~`d ~ 16 ~.~ ~ '' f •J~ * 'Ai~t'i1 _ ~. ' ;~:. ~...rr'.~i. ~~"'. ~.. ~'r~A~tCit. ~1~ "- ~.~ 2009-0511 Location Clearance Pioneer LittleSu-1 cs.doc r~ .. • • -_~° - ~`~ y. ter' ~~~ t MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, Ketí/'ll b\11\\ù1 P. I. Supervisor DATE: June 12, 2007 FROM: Chuck Scheve, Petroleum Inspector SUBJECT: Location Inspection Pioneer (Evergreen) Little Su #1 PTO 203-205 Tuesday. 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 driffing activity. SUMMARY: I recommend the above mentioned 5 locations be given final clearance approval Attachments: Little Su #1.JPG sCANNED JUL 20 Z007 2007 -0612_Location_ Clearance_Pioneer _littleSu~1_cs.doc Location Clearance Inspection - Little Su AOGCC Inspector Scheve 12, 2007 -0612_Location_ Clearance_Pioneer _littleSu-1_cs.doc Co Mj Â\ ~ r- DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2032050 Well Name/No. LITTLE SU NO.1 MD 2125'-- TVD 2125'/ Completion Date 4/6/2004 r- REQUIRED INFORMATION Mud Log Yes {q ~^Ò~3 J~ ~¿,. Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20027-00-00 Completion Status P&A Samples No DATA INFORMATION Types Electric or Other Logs Run: Gamma Ray, Spontaneous Potential, Caliper, Array Induction, Compe Well Log Information: Log/ Data c2 re; Electr Digital Dataset Med/Frmt Number Name C Las 12509 Induction/Resistivity j... t...." \.. .......Jt. Induction/Resistivity ~ Sonic ~ Density )4J Lithology Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? ~/ N Chips Received? Y / N \Y~ ~",", Analysis Y / ~ Received? Comments: Log Log Run Scale Media No 25 Blu 25 Blu 25 Blu Col Sent Received Daily History Received? Formation Tops Current Status P&A UIC N Directional SUNey No (data taken from Logs Portion of Master Well Data Maint Interval . OH/ Start Stop CH Received Comments 80 2126 Open SoniclNeutronlDensity/Por/ GR 80 2103 Open 6/21/2004 PHOTO DENSITY, DUAL SPACED NEUTRON, COMPENSATED SONIC 80 2125 Open 6/21/2004 PHOTO DENSITY, DUAL SPACED NEUTRON 80 2122 Open 6/21/2004 DUAL SPACED NEUTRON, COMPENSATED SONIC o 2125 Open 6/21/2004 5":20' Sample Set Number Comments Cores and/or Samples are required to be submitted, This record automatically created from Permit to Drill Module on: 12/12/2003, . ~~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2032050 Well Name/No. LITTLE SU NO.1 Operator EVERGREEN RESOURCES (ALASKA) API No. 50-009-20027-00-00 MD 2125 TVD 2125 Completion Date 4/6/2004 Completion Status P&A Current Status P&A Compliance Reviewed By: .~ Date: UIC N -~ 3~~ý ,. . . . . January 13, 2005 PIONEER NATURAL RESOURCES ALASKA, INC Howard Okland Petroleum Geologist Assistant Alaska Oil & Gas Conservation Commission 333 W. yth 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, ~;{~~ 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) 357-8130 ' FAX: (907) 357-8340 . . Well Name: Little Su #1 ). 03 -- ). 0 .>'- - Box De Jth Box De.Jth Numbers Column Shelf Top Bottom Numbers Column Shelf Top Bottom (ft) (ft) (ft) (ft) 1 10 D 115.0 123.5 51 10 A 580.0 589.0 2 10 D 123.5 133.6 52 10 A 589.0 598.0 3 10 D 133.6 142.7 53 10 A 597.0 607.0 4 10 D 142.7 152.0 54 10 A 607.0 616,0 5 10 D 152.0 161,0 55 11 D 616.0 626,0 6 10 D 161.0 170,6 56 11 D 626.0 635.0 7 10 D 170,6 179.8 57 11 D 635.0 644.0 8 10 D 179,8 189.0 58 11 D 644,0 654.0 9 10 D 189.0 198.0 59 11 D 654.0 663.0 10 10 C 198.0 207.0 60 11 D 663.0 673.0 11 10 C 207.0 216.0 61 11 D 673.0 682.0 12 10 C 216.0 226.0 62 11 D 682.0 691,0 13 10 C 226.0 235,0 63 11 D 691.0 700,0 14 10 C 235.0 244,0 64 11 C 700.0 708.7 15 10 C 244,0 254.0 65 11 C 708,7 717.8 16 10 C 254,0 265.0 66 11 C 717.8 727.2 17 10 C 265.0 274.0 67 11 C 727,2 736.4 18 10 C 274.0 283.0 68 11 C 736.4 745.5 19 10 C 283.0 291.0 69 11 C 745.5 764.3 20 10 C 291.0 300.0 70 11 C 764.3 774,0 21 10 C 300.0 310,0 71 11 C 774.0 783,0 22 10 C 310.0 318,0 72 11 C 783.0 792.0 23 10 C 318,0 327.0 73 11 C 782.1 801.4 24 10 C 327,0 338.0 74 11 C 801.4 810.8 25 10 B 338,0 347.0 75 11 C 810,8 821.0 26 10 B 347.0 355.0 76 11 C 821,0 830.0 27 10 B 355.0 365.1 77 11 C 830.0 839.0 28 10 B 365.1 375.0 78 11 C 839.0 848.0 29 10 B 375.0 384,0 79 11 B 848.0 857.0 30 10 B 384,0 393,3 80 11 B 857.0 867,0 31 10 B 393,3 402.8 81 11 B 867.0 876.0 32 10 B 402,8 412.0 82 11 B 876,0 885.0 33 10 B 412.0 421 .4 83 11 B 885,0 894.0 34 10 B 421.4 430.8 84 11 B 894.0 904.0 35 10 B 430.8 439.4 85 11 B 904.0 913.0 36 10 B 439.4 448.8 86 11 B 913.0 922.0 37 10 B 448.8 458,5 87 11 B 922.0 931,0 38 10 B 458,5 468,0 88 11 B 931.0 940,0 39 10 B 468,0 471.5 89 11 B 940.0 950.0 40 10 A 477.5 487.5 90 11 B 950.0 959.0 41 10 A 487.5 497.4 91 11 B 959,0 968.0 42 10 A 497.4 506.0 92 11 B 968.0 976.0 43 10 A 506.0 515.6 93 11 B 976.0 986.0 44 10 A 515.6 524.2 94 11 A 986.0 995.0 45 10 A 524.2 534,0 95 11 A 995.0 1004.6 46 10 A 534,0 543,1 96 11 A 1004,6 1014.0 47 10 A 543,1 551.6 97 11 A 1014.0 1023.0 48 10 A 551.6 561.6 98 11 A 1023.0 1032.9 49 10 A 561.6 571.0 99 11 A 1032.9 1042.0 50 10 A 571.0 580.0 .& 100 11 A 1042.0 1052.0 I '1 Jt.M.. ^ Ò ~ ç . . - e -- Box Column Shelf Top I Bottom Box Column Shelf Top I Bottom I Numbers (ft) (ft) Numbers (ft) (ft) 101 11 A 1052.0 1061,0 151 12 A 1524,0 1533,0 102 11 A 1061.0 1070,9 152 12 A 1533.0 1542.0 103 11 A 1070.9 1080.7 153 12 A 1542.0 1551.0 104 11 A 1080.7 1090.4 154 12 A 1551.0 1560.0 105 11 A 1 090.4 1099.5 155 12 A 1560.0 1569.0 106 11 A 1099.5 1109.0 156 12 A 1569.0 1578.0 107 11 A 1109,0 1118.7 157 12 A 1578.0 1588.0 108 11 A 1118,7 1128.2 158 12 A 1588.0 1597.0 109 12 0 1128,2 1137.5 159 12 A 1597.0 1606,0 110 12 0 1137.5 1147.4 160 12 A 1606.0 1615.4 111 12 0 1147.4 1157,0 161 12 A 1615.4 1625.0 112 12 0 1157.0 1166.0 162 12 A 1625.0 1634.8 113 12 0 1166.0 1175.0 163 13 0 1634.8 1644.0 114 12 0 1175.0 1185.0 164 13 0 1644.0 1653.6 115 12 0 1185.0 1195.0 165 13 0 1653.6 1663.2 116 12 0 1195,0 1204.0 166 13 0 1663.2 1672.5 117 12 0 1204,0 1213.0 167 13 0 1672.5 1681,7 118 12 C 1213.0 1222,0 168 13 0 1681.7 1690.6 119 12 C 1222.0 1231,0 169 13 0 1690,6 1700.0 120 12 C 1231.0 1241.0 170 13 0 1700.0 1709.2 121 12 C 1241.0 1253.0 171 13 0 1709.2 1718.9 122 12 C 1253.0 1262.0 172 13 C 1718.9 1728.0 123 12 C 1262,0 1270.0 173 13 C 1728.0 1738.0 124 12 C 1270,0 1279.0 174 13 C 1738.0 1747.0 125 12 C 1279,0 1289.0 175 13 C 1747.0 1758,0 126 12 C 1289,0 1298.0 176 13 C 1758.0 1768,0 127 12 C 1298.0 1308,7 177 13 C 1768,0 1777.0 128 12 C 1308.7 1316,8 178 13 C 1777.0 1786.0 129 12 C 1316.8 1327.0 179 13 C 1786.0 1796.0 130 12 C 1327.0 1336.3 180 13 C 1796.0 1805.0 131 12 C 1336.3 1345.2 181 12 C 1805.0 1814.0 132 12 C 1345,2 1354.3 182 13 C 1814.0 1823.0 133 12 B 1354,3 1364.6 183 13 C 1823.0 1832.0 134 12 B 1364.6 1374.0 184 13 C 1832.0 1842,3 135 12 B 1374.0 1383,0 185 13 C 1842.3 1851,5 136 12 B 1383.0 1392,3 186 13 C 1851,5 1860.7 137 12 B 1392.3 1402.9 187 13 B 1860.7 1870.5 138 12 B 1402.9 1411 .8 188 13 B 1870.5 1879.5 139 12 B 1411.8 1420.6 189 13 B 1879.5 1889.3 140 12 B 1420,6 1430.0 190 13 B 1889.3 1898.4 141 12 B 1430,0 1439.0 191 13 B 1898.4 1907.7 142 12 B 1439.0 1449.0 192 13 B 1907.7 1919.2 143 12 B 1449.0 1459,0 193 13 B 1919.2 1928.9 144 12 B 1459.0 1468,0 194 13 B 1928.9 1937,6 145 12 B 1468.0 1478.4 195 13 B 1937,6 1947.2 146 12 B 1478.4 1487.0 196 13 B 1947,2 1956.5 147 12 B 1487.0 1496.0 197 13 B 1956.5 1966.0 148 12 A 1496.0 1505.0 198 13 A 1966.0 1976.0 149 12 A 1505,0 1515.0 199 13 A 1976.0 1986.0 150 12 A 1515,0 1524.0 200 13 A 1986.0 1996.0 . . e __ Box Column Shelf Top I Bottom Numbers (ft) (ft) 201 13 B 1996.0 2005.0 202 13 A 2005.0 2015.0 203 13 A 2015.0 2024.0 204 13 A 2024,0 2033.2 205 13 A 2033,2 2044.7 206 13 A 2044.7 2054.0 207 13 A 2054.0 2063,2 208 13 A 2063.2 2072,5 209 13 A 2072.5 2082.0 210 13 A 2082.0 2091 .1 211 13 A 2091.0 2101.2 212 13 A 2102.2 2110.4 213 13 A 2110.4 2120.2 214 13 A 2120.2 2125.0 =\I=I~GI~==I~. RESOURCES (ALASKA) COR~ A Subsidiary of Evergreen Resources, fnc, e ~()8-~ð5 /'\ fJ '-I ,- C ":·:-7 .;;7<-.... J r) / 7._ ...., rJ =7" ç:,..., ¡j..) ,;.:"7'> ~, 03 .-c-~og' June 17,2004 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@everç¡reengas. com. Sincerely, A Shane Gagliardi Petroleum Engineer <." """c: ~~L(~ErVED J 1.· "004 f'--;· t ' ,í?; OR\G\NAL 1075 Check Street, Suite 202 . Wasil/a AK 99654 PO. Box 871845 . Wasil/a, AK 99687 . TEL 907.3578130 . FAX 907.357.8340 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION J\JN "J,1 '¿un(~ WELL COMPLETION OR RECOMPLETION R~jr,~~"[.:,~;~P ~QG:, 1a, Well Status: Oilo Gaso Pluggedo Abandoned[8J Suspendedo WAGo ~fj, ~eh cla~"~.:';'D":(" 20AAC25.105 20AAC25.110 D I . t"o'E' ··1· t D eve opmen xp ora ory Service 0 Stratigraphic Test 181 e GINJo WINJo WDSPLo No, of completions _ Other 5, Date Comp" Susp" or Aband,: 4/6/04 2. Operator Name: Evergreen Resources Alaska Corp. 3, Address: P.O. Box 871845 Wasilla, AK 99687 4a. Location of Well (Governmental Section): Sec 35, TWN 19N, RNG 1E Surface: 1191' FNL and 605' FWL Top of Productive Horizon: Same as Above Total Depth: Same as Above 4b, Location of Well (State Base Plane Coordinates): (NAD 27) Surface: x- 633118.22 y- 2813373.15 y- 2813373.15 Zone- 4 TPI: x- 633118.22 Zone- 4 TotalDepth: x- 633118.22 18, Directional Survey: Yes 181 y- 2813373.15 NoD N/A feet MSL 21, Logs Run: Gamma Ray, Spontaneous Potential, Caliper, Array Induction, Compensated Neutron Density, Sonic, Inclination Survey 20, Thickness of Permafrost: N/A Zone- 4 22, CASING WT, SIZE PER GRADE FT. 4.5" 14.4 X42 6, Date Spudded: 12/19/03 7, Date TD Reached: 4/4/04 8, KB Elevation (ft): 810.1' 9, Plug Back Depth (MD + TVD): 100 FFS (abd) e 12, Permit to Drill Number: 203-205 13, API Number.;. 0 50- 009-2002)(7 - ~ ~ 14, Well Name and Number: Little Su #1 15, Field/Pool(s): Wildcat 10, Total Depth (MD + TVD): 16, Property Designation: 2125' Private 11, Depth where SSSV Set: N/A feet MD 19, Water Depth, if Offshore: CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM HOLE SIZE o 117 23, Perforations Open to Production (MD + TVD of Top and Bottom Interval, Size, and Number; if none, state "none"): None 26, Date of First Production: Abandoned o 6 17, Land Use Permit: Private CEMENTING RECORD AMOUNT PULLED 117 13 sx 12.7 ppg Class G 24, TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A N/A N/A N/A N/A N/A 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED None None PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc,): Abandoned Date of Test: Hours Tested: Production for Oil-Bbl: N/A Test Period .. Flow, Tubing Casing Pressure: Calulated .. Oil-Bbl: 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", F'"" 10-407 R";,,d 412003?~ Sep."" "".. en.lysls will be submitted. Gas-MCF: Water-Bbl: Choke Size: I Gas-Oil Ratio: Oil Gravity-API (corr): o R ftjr~,l\ rVERSE SIDE Gas-MCF: Water-Bbl: J\JN 2 2 (9 Ý . ~ ~nnf. fml)MS Bft NAME GEOLOGIC MAIRS MD I TVD 29, 'RMATION TESTS Include and briefly summarize test results, List intervals tested, and attach detailed supporting data as necessary, If no tests were conducted, state "None", 28: Quaternary Gravel 0' -53' 0' - 53' None Tyonek 53' - 510' 53' - 510' Wishbone 510' - 896' 510' - 896' Chickaloon 896' - 1204' 896' - 1204' Wishbone (Repeat) 1204' -1625' 1204' -1625' JUN 'ì 12004 Chickaloon 1625' - 2125' 1625' - 2125' 30, List of Attachments: Daily reports, wireline logs, mud logs, inclination survey (included in daily reports) 31, I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Shane GaClliardi Printed Name ~ GaClliaYi/K) Title Petroleum EnQineer Signature /'~ ~?... Phone 907-355-8569 Date 4/19/04 - 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 Little Su #1 12/03/03 12/04/03 12/0S/03 12/19103 12/20/03 12/21/03 12/23/03 12/26/03 03/19/04 03/22/04 03/23/04 03/24/04 03/2S/04 03/26/04 03/27/04 03/30/04 03/31/04 04/01/04 04/02/04 04/03/04 04/04/04 04/0S/04 04/06/04 e e Daily Drilling Summary Location I API ¡Permit to Spud Total QTR Sec I Twn Rng Number Drill Date Depth NW NW 35 19N 1E 50-009-20024 203-205 12/19/2004 2125' Clear snow from MEA ROW. Clear snow from location and begin dirt work, No trees were knocked/cut down for cleaning Dig cellar Place culvert MIRU water well rig. Firstjt was 12.S Make first connection, weld 4.S" jts together Drill second rod, current depth 22.S Make second connection, weld 4,S" jts together Drill third rod, current depth 32.S' SOON Make connection, weld 4.S" jts together, Drill 1 0' rod down, current depth is 41' Make connection, weld 4.S" jts together. Drill 1 0' rod down, current depth is SO' POOH Drill 1 0' rod down, current depth is S1' Make connection, weld 8" pipe nipple and 9,67' csg jt Drill 10' rod down, current depth is 61' Make connection, weld 4,S" jts together. Drill 6', current depth is 66' SOON Drill rod down, current depth is 71' Make connection, weld 4.S" jts together. Drill rod down, current depth is 81' Make connection, weld 4.S" jts together. Drill rod down, current depth is 90' Make connection, weld 8" pipe nipple and 9,67' csg jt Drill rod down, current depth 100' Make connection, weld 4.S" jts together. Drill rod down, current depth 111' Drill 8" to put top of csg at convienient spot to weld, weld 4,S" jts together Drill 6' current depth is 117' POOH Clean and secure location for Holiday Break ROMO water well rig, Wait on Layne Christiansen Rig MIRU Layne Christiansen Rig Finish MIRU Layne Christiansen Rig Pressure test csg and BOP to 1S00 PSI. Replace nipple below annular BOP, test witnessed by John Spaulding TIH w/HQ OP, Core bbl and bit Core from 117' to 200', recover 84', recovery 99% Core from 200' to S19', recover 311.3', recovery 98% Core from S19' to 610', recover 87.8', recovery 96% Core from 610' to 79S', recover 183.1', recovery 99% POOH TIH w/10' tools Core from 79S' to 84S', recover SO', recovery 100% Core from 84S' to 112S', recover 280.1', recovery 100% Core from 112S' to 140S', recover 28S,9', recovery 99% Core from 140S' to 146S', recover 60', recovery 100% Core from 146S' to 147S, recover 10', recovery 100% Core from 147S' to 169S', recover 219,S', recovery 100% Core from 169S' to 1823', recover 12S.8', recovery 98% Core from 1823' to 1904', recover 80', recovery 99% Core from 1904' to 1915', recover 9', recovery 82%. Make bit trip, Repair BOPE, nipple above mud cross failed. Core from 1915' to 1945', recover 30', recovery 100% Core from 1945' to 1995', recover 48.9', recovery 98%. Can coal from 1970 - 1971. Core from 1995' to 2074', recover 79', recovery 100%, Can coal from 2000 to 2001 and 2039 to 2040, Core from 2074' to 210S', recover 30', recovery 97% Core from 210S' to 212S', recover 20" recovery 100%. POOH. MIRU Reeves wireline. Log hole wI gamma, SP, sonic, dual induction, caliper and Comp NO, Loggers TO - 2124', SOON. Cmt bottom 200' w/2.86 bbls class G cm!. Cmtfrom 1000' to 100' w/12.9 bbls class G cm!. Reverse out from 100'. Take inclination surveys @ SOO' - 1 degree, 1000' - 1.S degrees, 1S00' - 2 degrees and 2000' - 2 degrees, TIH. Tag cmt @ 112'. ROMO Layne Christiansen and Swaco, Will begin reclamation in the AM. .JJN 2.? 2OD4 Page 1 of 1 · ' Well Name Little Su #1 12/03/03 12/04/03 12/05/03 12/19/03 12/20103 12/21/03 12/23/03 12/26/03 03/19/04 03/22/04 03/23/04 03/24/04 03/25/04 03/26/04 03/27/04 03/30/04 03/31/04 04/01/04 04/02/04 04/03/04 04/04/04 04/05/04 04/06/04 e e =\'=I~GI~==I'I RESOURCES(ALASKA)COR~ A Subsidiary of Evergreen Reoources, Inc. Daily Drilling Summary Location I API I Permit to Spud Total aTR I Sec I Twn Rng Number Drill Date Depth NW NW 35 19N 1E 50-009-20024 203-205 12/19/2004 2125' Clear snow from MEA ROW,Clear snow from location and begin dirt work, No trees were knocked/cut down for cleaning Dig cellar Place culvert MIRU water well rig, Firstjt was 12.5 Make first connection, weld 4.5" jts together Drill second rod, current depth 22,5 Make second connection, weld 4,5" jts together Drill third rod, current depth 32.5' SDON Make connection, weld 4,5" jts together. Drill 10' rod down, current depth is41' Make connection, weld 4,5" jts together. Drill 10' rod down, current depth is 50' POOH Drill 1 0' rod down, current depth is 51 ' Make connection, weld 8" pipe nipple and 9,67' csg jt Drill 10' rod down, current depth is 61' Make connection, weld 4.5" jts together, Drill 6', current depth is 66' SDON Drill rod down, current depth is 71' Make connection, weld 4.5" jts together. Drill rod down, current depth is 81' Make connection, weld 4,5" jts together. Drill rod down, current depth is 90' Make connection, weld 8" pipe nipple and Drill rod down, current depth 100' Make connection, weld 4,5" jts together. Drill rod down, current depth 111' Drill 8" to put top of csg at convienient spot to weld, weld 4,5"jts together Drill 6' current depth is 117' . POOH Clean and secure location for Holiday Break RDMO water well rig, Wait on Layne Christiansen Rig MIRU Layne Christiansen Rig Finish MIRU Layne Christiansen Rig Pressure test csg and BOP to 1500 PSI. Repla~ nipple below annular BOP, test witnessed by John Spaulding TIH w/HQ DP, Core bbl and bit . Core from 117' to 200', recover 84', recoverw99% Core from 200' to 519', recover 311.3', recoVery 98% Core from 519' to 610', recover 87,8', rec¡)very 96% Core from 610' to 795', recover 183.1', (êcovery 99% POOH TIH w/1 0' tools Core from 795' to 845', recover 50',recovery 100% Core from 845' to 1125', recover ?ì30.1', recovery 100% Core from 1125' to 1405', recov.er 285.9', recovery 99% Core from 1405' to 1465', recqder 60', recovery 100% Core from 1465' to 1475, regtlver 10', recovery 100% Core from 1475' to 1695', r,ecover 219,5', recovery 100% Core from 1695' to 1823',fecover 125,8', recovery 98% Core from 1823' to 1904', recover 80', recovery 99% Core from 1904' to 1915', recover 9', recovery 82%. Make bit trip, Repair BOPE, nipple above mud cross failed. Core from 1915' to 1945', recover 3D', recovery 100% Core from 1945' to 1995', recover 48,9', recovery 98%, Can coal from 1970 - 1971, Core from 1995' to 2074', recover 79', recovery 100%, Can coal from 2000 to 2001 and 2039 to 2040. Core from 2074' to 2105', recover 30', recovery 97% Core from 2105' to 2125', recover 20', recovery 100%. POOH. MIRU Reeveifwireline. Log hole w/ gamma, SP, sonic, dual induction, caliper and Comp ND, Loggers TD - 2124', SDON. Cmt bottom 200' w/2,86 bbls class G cm!. Cmt from 1000' to 100' w/12.9 bbls class G cm!. Reverse out from 100'. TIH, Tag cmt @ 112', RDMO Layne Christiansen and Swaco, Will begin reclamation in the AM, D~ 'V 1.-; U/ t.. 0.~.//F> ~!Ö..,/ !1 ".- \I /.l'·" Q...J .i/ 967'",. t-/\,/ ¡ Page 1 of 1 Slats # 1 Core Disposition 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 1 of 1 5/20/2004 9:40 AM Mar 24 04 09:37a ="=líÇiI~F=I'1 A l. .Ä S ·\:,K" Ä ..- To: Fax: 907-276-7542 Date: 3-24-04 Phone: 907-279-1433 Pages: 3 including cover Re: 403 for LittleSu #1 cc: o Urgent 0 For Review 0 Please Comment 0 Please Recycle RECEIVED MAR 2 d ')u·'", .[ f.. 1.Ji1 NlMaOl&*,~ , Ad;;~ OR\G\Nþ..l Mailing PO Box 871845 Wasifla. AK 99687 Office 1075 Check Street, Suite 202 Wasilla. AK 99654 Yard 1900 Cottle Loop Drive Wasilla. AI< 99654 WWW.EvergreenGas.com NYSE: EVG ..__.~ 24 04 08:37a DH 807.357.8340 =\I=I~GI~==. RESOURCIOS (ALASKA) CORP.. A Si1bsiŒa¡y of Evetgreeo Re.50UT"",,, 'M . March 22, 2004 Winton Aubert Petroleum Engineer Alaska ()iJ and Gasyûf1servati0I1Commission (AOgCC) 333 West 7th Ave. #100 . ... '. .., ','. Anchorage, AK 99501-3539 RE: Request for Resuming Operations for the Little Su #1 Deaf Mr. Aubert: Attached is a·1 0-403 application for sundry approval requesting that operations be allowed to resume on the Little Su #1. The operational shut down was requested 1 'f/30/03 while waiting on the mineral coring rig. The well has 4,5 inch casingsetto 117' and has a full column òf cement and hammer shoe that needs to be drilled prior to core drilling. If you have any questions, please feel free to contact me at 907-355-8569 or shaneg@everQreenQas,com. Sincerely, :ß$ Shane Gagliardi Petroleum Engineer OQ!('!NAL í \ ~ oL ' 1075 Check Street, Suite 202 . Wi/sìßa AK 99$54 P.O, Box 871845 . Wasilla, AK 99687 . TEL 907,357.8130 . FAX 907.357,8340 ~- -"-- ....- Mal'" 24 04 09;3?a DH 90?357.8340 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operaticn Shutdovm 0 Plug Perforations 0 Perforate New Pool 0 4, Current Well Class: Development 0 Exploratory 0 Stratigraphic i8l Service 0 Perforìlte 0 Stimulate 0 Time Extension 0 Re-enter Suspended WeD 0 5, Permit to Drill Number: / 203-205 6, API Number: / so.. 009-20027 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 2, Operator Name: Evergreen Resources Alaska Corp. 3. Address: P.O. Box 871845 WaslJla, AK 99687 7. KB Elevation (ft): 9, Welf Name and Number. Uttle Su #1 / 810.1' 8, Property Designation: 10. FieldlPool(s): . Private Wild Cat 11. Total Depth MD (ft): 117' CaSing Structural PRESENT WELL CONDITION SUMMARY !..TQtal Depth. TVD Cft): ¡Effective Dept..· h MD (it): I. Effective DeP.· th TVD{ft): I 117' .... 0' O' . . Length Size MD TVD Plugs (measured): None Burst Conductor Surface Intermediate 3320 117' 117' 117' 4.5" Production liner Perforation Depth MD (ft): I. Perforation Depth TVD (ft): I None None Packers and SSSV MD (ft): Tubing Size: Tubing Grade: None None Packers and S$SV Type: None 13. Well Class after proposed work: Exploratory IZI Development 0 None 12. Attachments: Description Summary off>roposa! C21 Detailed Operations Program 0 BOP Sketch. 0 14, Estimated Date for Commencing Operations: 22 Mar 2004 16, Verbal Approval: Commission Representative: 17, I hereby certify that the foregoing is true and correct to the best of my knowJedgè, Date: 15, Well Status after proposed work: Oil 0 Gas 0 ptugged 0 WAG 0 GINJ 0 WtNJ 0 Contact Shane GaQliardi Printed Name Shane ~:q~ Signature d :::J) X../:- Title PetrOleum EnQìneer Phone 907-~55-8569 Cbmmission Use Only Date 03/22104 Sundry Number: Conditions of approval: Notify Commission so that a representative may witness BOP Test ~ Location Clearance 0 Plug Integrity 0 Mechanicatlntegrity Test 0 P.37 I \¡J6A) 2-¥. 2-004 t)æf d ( ¿.<j/rf .. Junk (measured): None Collapse 2650 Tubing MD (ft): None Service 0 Abandoned [81 WDSPL 0 .3 é) 7'- 09( Other: ~ 1\ í' 2·4 'JO(. ;/,þÜ< .. L : BY ORDER OF COMMISSIONER THE COMMISSION OR\G\~JAL ßll)MS aFt -- ----- {',_;~~~lj Date: ~;3¡tu;eff MAR? ?"ql! .~4r~ ~." . · MEMORANDUM e State of Alaska Alaska Oil and Gas Conservation Commission d \4.\rk TO: Jim Regg ~t 11\ DATE: March 22,2004 P.I. Supervisor From: John Spaulidng Petroleum Inspector SUBJECT: Mechanical Integrity Tests Evergreen Resources Alaska Wildcat Little Su 1 PTD 203-205 NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min, 30 Min, weill Little Su 11 Type Inj, I NA I TV,D. 512 I TUb~ng I I I I Interval P,T.D. 203405 Type test P Test psi 128 Casing + 1500 1500 1400 P/F f Notes: weill I Type Inj. I TV,D'I I Tub~ng I I I I Ilnterval P.TD, Type test Test psi Casing P/F Notes: weill I Type Inj'l I TV,D, I Tub~ng I I I I Ilnterval P.TD, Type test Test psi Casing P/F Notes: well I Type Inj'l I TV,D_I I Tub~ng I I I I Ilnterval P,T,D, Type test Test psi Casing P/F Notes: weill I Type Inj, \ I TV,D, I Tub~ng I I I I Ilnterval P,TD, Type test Test psi Casing P/F Notes: Type INJ, Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALTWATER INJ. R= Intemal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details 4.5" casing set at 115' md' md. Tested casing to 1500 psi for 30 minutes prior to drilling out. M.I.T.'s performed: 1 Attachments: ~ Number of Failures: º Total Time during tests: 2 hrs. cc: none MIT report form 5/12/00 L.G. Little Su 1 surface casing test 3-22-04jhs.xls 4/14/2004 . bl03-~C6 . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, P.I. Supervisor ! .I'o\tft ~e~(1 t. ' DATE: January 28,2004 FROM: John Spaulding, Petroleum Inspector SUBJECT: Location Inspections Evergreen Resources Coal Bed Methane January 2004: I traveled to Evergreen Resources locations in the Mat-Su Borough. Susttna 1, Kashwitna 1 and Sheep Creek 1 are noted in this report. At present all wells are being drilled for core sampling purposes of the formations. I was notified of the Susitna 1 well after the rig had encountered some problems cementing surface casing. The well was suspended and the rig had moved off location when I arrived. There was probably a foot of new snow when I visited the location and and the casing and the location was pretty well covered over. I intend to revisit at a later date when the rig has returned or the well is P&Aed. Kashwitna 1 located North and West of Willow, AK: I observed a BOPE test and inspected the rig and location. Pictures were taken of the BOPE, rig and surrounding location. I observed the technique for water sampling, and to my estimations found it adequate. Sheep Cr. 1 located farther North and West from the Kashwitna location near the Parks Highway: I was only able to look at the location, as the rig had not moved in yet. I am questioning the requirements for a manual annular device and a manual valve for a blind ram. These are located under the rig floor as with all drilling rigs, but are not hydraulically operated from a remote location. If in the event of an influx of gas a person would have to lay on their stomach and have their face next to the top of the casing in order to close either portion of BOPE. Should we be requiring hydraulically operated BOPE? Should we relax the requirements for the manual BOPE? Hopefully the accompanying photos will help explain. SUMMARY; I inspected the above-mentioned locations and found all to be quite clean and orderly. A BOP test was witnessed, with no failures. Attachments: Photo's CONFIDENTIAL 2004-0128_Locations_ CBM_ Suisitna1_Kashwitna1_ SheepCk1..,js.doc . . Evergreen Resources - Pioneer CBM Project Inspections from January 11 and January 22, 2004 Photos from AOGCC Inspector John Spaulding Blowing casing dry Cuttings catcher 1 . . Cuttings and water return lines Welding casing 2 . . Location - Kashwitna # 1 Rig and choke manifold 3 . . BOP Manual BOP valve 4 . . Gas buster 5 Jan 07 04 12f07p DH ( · .. - =\'=I~GI~==I~~ ReSOURCES(ALASKA)COR~ A Sullsidiary 01 EVfJ¡g~ Resources, Inc. 807.357.8340 p.2 . December 30, 2003 Winton Aubert Petroleum Engineer Alaska Oil and Gas Conservation Commission (AOGCC) 333 West 7th Ave. #100 Anchorage, AK 99501-3539 RE: Request for Operational Shutdown for the Little Su #1 Dear Mr. Aubert: Attached is a 10-403 application for sundry approval requesting that an . operational shut down be granted for the Little Su #1. The anticipated date for ,/ resuming operations is 15 Feb 2004. Rig avaìlability is the reason for requesting the operational shutdown. A water well contractor was used for setting surface casing and the core drilling rig is ,/' currently committed on another well. The well has 4.5 inch casing set to 117' and has a full column of cement and /' hammer shoe that needs to be drilled prior to core drilling. If you have any questions, please feel free to contact me at 907-355-8569 or shaneg (ã) everÇ1 reen 9 as. com. :2l¥ Shane Gagliardi Petroleum Engineer RECEIVED JAN 0 7 2004 Alaska Oil & Gas Cons. Commission Anchorage LJ ;'\ i lJ' f~AL J075 Check Street, Suite 202 . Wasilla AK 99654 PO, Box 871845 . Wasil/a, AK 99687 . TEL 907,357,8130 . FAX 907.357,8340 Jan 07 04 12:07p DH 907.357.8340 t. " . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 Abandon 0 Alter Caf>Îng 0 Change Approved Program 0 2, Operator Name: Evergreen Resources Alaska Corp. 3, Address: P.O. Box 871845 Wasil1a, AK 99687 7, KB Elevation (ft): Operation Shutdown I8J Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Exploratory 0 Stratigraphic I8J Service 0 Perforate 0 Variance 0 Annular Disposal 0 Stimulate 0 Time Extension 0 Other 0 Re-enter Suspended Well 0 5. Pel111il to Drill Number:/ 203-205 6. API Number: /'" 50- 009-20027 1. Type of Request: Suspend 0 Repair Well 0 Pull Tubing 0 9, Well Name and Number: 810.1' Little Su #1 8. Property Designation: 10, Field/Pool(s): Private Wild Cat 11. Total Depth MD (ft): 117' Casing Structural PRESENT WELL CONDITION SUMMARY ITotal Depth TVD (ft):! Effective Depth MD (ft): I Effective Depth TVD(ft):1 117' 0' O' Length Size MD TVD Plugs (measured): None Burst Conductor Surface Intermediate 117' 117' 3320 4.5" 117' Production Liner Perforation Depth MD (ft): \ Perforation Depth TVD (ft): I None None Tubing Size: Tubing Grade: None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 13, Well Class after proposed work: Exploratory [8 Development 0 12, Attachments: Description Summary of Proposal [8 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 15 ~4 16. Verbal Approval: ~ Commission Representative: 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Date: 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 WAG 0 GINJ 0 WINJ 0 Contact Shane Gaqlìardi Printed Name ?tne Gagliar . Signature ~ Title Petroleum Enqineer Phone 907·355-8569 Commission Use Only Date 12/30/03 Sundry Number; Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Location Clearance 0 BOP Test 0 Mechanical Integrity Test 0 p3 iN6A- i 111 '2-00'1 ~7S 1/7 /1-- ~r 71ü~ /' Junk (measured); None Collapse 2650 Tubing MD (ft): None Service 0 Abandoned I8J WDSPL 0 ..3o"f.....ò.3 Other: RECEIVED JAN 0 7 2004 Alaska Oil & Gas Cons. Commission An~h age BY ORDER OF /1 '/}} / THE COMMISSION Date: V <-¡ . ,b I, ,"pI,,,t. Subsequent Form Required: to ... 40 3 ~ veçtav t ð-J> ~Co.-p.'t'vt-ç . Approved by: Form 10-403 Revised 2/2003 ~ina' SiSJI'*f êy "'Ša.N6 COMMISSIONER G\NAL RØDMS BFt JAN 09 2004 . . FRANK H. MURKOWSKI, GOVERNOR AI#ASIiA ORAND 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: Little Su #1 Evergreen Resources (Alaska) Corp. Pennit No: 203-205 Surface Location: 1191' FNL and 604' FWL, Sec. 35, T19N, RIE, SM Bottomhole Location: 1191' FNL and 604' FWL, Sec. 35, T19N, RIE, SM Dear Mr. Gagliardi: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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). 0Ø Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED thisjj day of December, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. irJ41\- /2-1 C}/ ZOO 3 . STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of Work: Drill [8J Re-entry D Redrill D 2, Operator Name: Evergreen Resources (Alaska) Corp. 3, Address: P.O. Box 871845, Wasilla, AK 99687 4a. Location of Well (Governmental Section): Sec 35, TWN 19N, Rng 1E Surface: 1191' FNL and 604' FWL Top of Productive Horizon: Same as above 1 b, Current Well Class: ExploratoryD Development Oil 0 Multiple Zone D Stratigraphic Test i:8I Service 0 Development GasO Single ZoneD 5. Bond; [8JBlanke! DSingle Well 11, Well Name and Number: Little Su #1 ,/ Bond No, RLB0003430 6, Proposed Depth: MD: 3000 ft TVD: 3000 ft 7. Property Designation: Private 12, Field/Pool(s): Wildcat 8, Land Use Permit: N/A 13, Approximate Spud Date: 10 Dec 03 9, Acres in Property: 110 acres 14, Distance to Nearest Property: 450 feet, Total Depth: Same as above 4b, ~~ ~ ~W5~t4rfe Plan:b.s.9~~~~~~/~~ 7 Surface: x- ~3146,~4 'ý'-~8f31~1.r; Zone- 4 16, Deviated Wells: N/A 10, KB Elevation (Height above GL): 810.1' 15, Distance to Nearest feet Well within Pool: 10,000 feet Kickoff Depth: N/A ft, Maximum Hole Angle: N/A 18, Casing Program: Specifications Size Hole Casing Weight Grade Coupling Length 6 4.5 10.8 LP LP 150 17, Anticipated Pressure (S:J~AAC 25,035) Be¡ Max, Downhole Pressur.....dí¡ . sig, Max,Surface pressUre~Sig. Setting DePt~ Quantity of Cèñíe"nt Top Bottom e,f, or sacks, MD TVD MD TVD (Including Stage Data) o 0 154 154 12.9 cu. Ft. IIJ6A- 19. Total Depth MD (ft): PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD(ft): Plugs (measured): Junk (measured): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): None Length Size Cement Volume MD TVD kl-(~f-IVI-LJ UI:.C - 5 2003 Alaska Oil & Gas Cons. Commission And Drage Perforation Depth TVD (ft): None 20, Attachments: Filing Fee i:8I BOP Sketch i:8I Property Platl3J Diverter SketchO 21, Verbal Approval: Commission Representative: 22, I hereby certify that the foregoing is true and correct to the best of my knowledge, Printed Namedhane;~ Signature ß-. ~ Drilling Program i:8I . Seabed ReportO Time v, Depth Plot 0 Shallow Hazard Analysis 0 Drilling Fluid programl8l 20 AAC 25,050 Requirements 0 Date: Contact Shane Gaqliardi Title Petroleum Enqineer Date 12!.5ß:¡ Permit to Drill Number: 2.0 3 - Conditions of approval: Phone 907-355-8569 Commission Use Only I API Number: .2.0 S 50- oc> 1- :z. Ó ð ;2.. 7 Samples requireC .81 Yes . DNo I See cover letter for other requirements, £8!Yes DNo I Permit Approval Date: Mud log required, Directional survey requireC DYes )gNO [). r I _ );iydro.gen iulfide me~. ¡;u)'es DYes I5(INo. I Other: ,q~..,.. 'tv ~.t....e d ~cl.¿j::Ù/1-V;. ¡gf AffYr"Ji/A.. . Original Signed BY BY ORDER OF Approved by: sarah P~ßMISSIONER THE COMMISSION Form 10-401 Revised 3/2003 Core Program 2003 APD If) I ~fO¿d"PI;oa" Date: (' r" 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 S~IÞ.>,<-<-·, S,^I'VLV\ 0" 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 12/16/20038:48 AM It e Proposed Drilling Procedure 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 diameter and the surface casing will be X-42 4 inch nominal schedule 40 line pi Je. 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 TD, 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. being pulled out of the hole. Log Single Induction Sonic Porosity Gamma Ray Caliper Compensated Density Neutron Porosity Formation Tops Formation Quarternary Gravel Tertiary Tyonek The hole will be logged as the drill pipe is Interval TD to ± 20 ft in Surface Casing TD to ± 20 ft in Surface Casing TD to ± 20 ft in Surface Casing TD to ± 20 ft in Surface Casing TD to ± 20 ft in Surface Casing TD to ± 20 ft in Surface Casing Estimated Tops (ft KB) Surface 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. I D 2. MIRU Discovery Drilling, ~ \1 " 3. Drill 6" hole through base of gravel (50'-200' anticipated) and set 4" casing to bottom. .-/ a. Evergreen perSOnnm'll call TD on surface hole. 4. Cement casing in place wI ~ bl cmt wi cmt wt @ 15.6 ppg a. Water requirement .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. woe 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 and LD drill pipe, rods, core barrel and core bit and logging tools. 19. TIH wI "B" rods to TO. (Cmt calculations are based on TO=2500' and surface csg @ 200') a. Surface casing - (0.01574bbls/ft)(200') = 3.14 bbls b. HQ Hole - (0.01440 bblslft)(2300') = 33.12 bbls c. ¡Total fluid required to¡..~ole - 36.26 bbls 20. Pump 3 bbls cmt and POOH 1 . ft. 21. Pump 18 bbls (1250ft) of mu and cuttings and POOH to 1000 ft. 22. Pump 15.1 bbls cmt / 23. POOH wI "B" rods. 24. Clean-up well site, 25. ROMO Layne Christianson to next hole. 26. woe 24 hours. If I, J 27. MIRU OJ Excavation. / ' É? Mß~.litA-l \:"~ a. Cut 4" casing 3' below ~ginal ground level. b. Weld W' thick plate wlYdiameter 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 \¡J61\ / · 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 Proposed Drilling Procedure e 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 9' A R' 23' Core Solids Drill Control Van 40' 'I' Core 60' 20' Handling Rods D Parts Trailer Water Truck De-ç¡asser Vehicle Parking 'I' ... 45' . Core Program 2003 APD Company Evergreen Resources Inc. Evergreen Resources Inc. Evergreen Resources Alaska Evergreen Resources Alaska Evergreen Resources Inc. Hampton & Waechter Layne Christiansen MI Swaco Reeves Wireline Core Program 2003 APD e e Proposed Telephone Contact List Core Program 2003 Matanuska-Susitna Borough, Alaska Address Name Telephone Suite 1200 1401 Seventeenth Street Denver, Colorado 80202 Suite 1200 1401 Seventeenth Street Denver, Colorado 80202 P.O. Box 871845 Wasilla, AK 99687 P.O, Box 871845 Wasilla, AK 99687 Suite 1200 1401 Seventeenth Street Denver, Colorado 80202 Suite 300 1645 Court PI. Denver, Colorado 80202 2370 Steese Hwy. Fairbanks, AK 99712 721 West 1st Ave. Anchorage, AK 99501 121 South Country Estates Road, Liberal, KS 67901 Dennis Carlton Senior Vice President of Operations Scott Zimmerman Vice President of Operations and Engineering Shane Gagliardi AK Project Engineer Mike Bellowich AK Project Geologist Jerry Jacobs Environmental Manager Noel Waechter Shane Crum Dennis Jackson Bob Gales Office: 303-298-8100 Fax: 303-298-7800 Office: 303-298-8100 Cell: 303-981-3314 Fax: 303-298-7800 Office: 907-357-8130 Cell: 907-355-8569 Fax: 907-357-8340 Office: 907-357-8130 Cell: 907-232-9538 Fax: 907-357-8340 Office: 303-298-8100 Fax: 303-298-7800 Office: 303-825-7140 Office:918-322-3095 Mobil 918-625-1668 Fax: 918-322-3829 Office: 907-274-5501 Office: 785-331-2933 Manufacturer: Size: Rating: Usage: e e ,/ ~. ,.._-. _ ,... 1- ..~ '. .._ OKJOOD¡ ..., _ ~T"" . .....~...... _.~- í. -.. --. 1.-- . I i 1 j~-,-~ ..........~-, . ¡ Ir--- i i i i i I i 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 tested 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 timeto close the master gate should a well blowout occur. 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. .. ~- . 'l~- 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 tins 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 r 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 tne well. Core Program 2003 APD e Well Control Diagrams Core Program 2003 Matanuska-Susitna Borough, Alaska e BOPE Diagram 1. Oil saver fitted with stripping rubbers to fit 3/16" slick line. Can be operated 2 manually and/or 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 10 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 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. 18-5/8 Inches 8. 4" Full port 3000 psi valve. 13 Inches 9. Standard spool threaded to fit 4" line pipe connections w/ two 2" ports that will be fitted w/ 3000 psi full port ball valves. 10. 4" API line pipe suñace 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-Ibs) (bbl/ft) (fVbbl) (bbllft) (ftlbbl) 3.5 HMQ 4.5 3.188 3,188 3910 4600 88.46 0.00911 109,7 0.02307 43.35 Suñace Casing Size Pipe Weight 10 Drift Collapse Burst Tensile Capacity Capacity 6" Hole 6" Hole Annulus Annulus (in) Grade (ppf) (in) (in) (psi) (psi) (k-Ibs) (bblslft) (fVbbl) (bbllft) (fVbbl) 4.5" LP X42 10.8 4.026 4,026 2650 3320 0.01574 63,51 0.0153 65.36 Sch 40 Core Program 2003 APD e e Core Program 2003 Matanuska-Susitna. Borough, Alaska / List of Exceptions For Drilling 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 atter 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 well bore 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). 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 tank 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. (j) 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. (8) 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 (h) Upon test of the operator, the commission will, in its !retion, 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 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 locatíons 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, / I 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 blind/shear 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. ,/ I 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 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. /' e e / 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 surface 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 ANDDIVERTER 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 surface 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. 7 J 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) ofthis section if the variance provides at least an equally effective means of well control; and . Core Program 2003 APD 10m the diverter system requirements in (c) of ~ection 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 lubricatQr system will be employed when the core is to be retrieved. / I 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 alternate 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; theref9re, 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 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. .7 e e Core Program 2003 APD . . Conditions of Approval Evergreen Resources (Alaska) Corp. Little Su #1 (PTD 203-205) 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 05:55p DH It 907.357.8340 e =\I=I~GI~==i\1 p.2 Landowner Letter of Non-Objection for Proposed Activities October 10, 2003 LANDOWNER LETTER Of-NON-OBJECTION FOR PROPOSED ACTIVITIES TO WHOM IT MAY CONCERN' i hereby grant permissIon to Evergreen Resources IP,i.;!ska) Cc¡poration to have access to my land as described below, ior purposes of drilling a strat!graphlc con:: hole test wel! on my property This will Include traveling on or through including possible improvements to be made on the 'v1atanuska Electric Association utility easement on my land as reflected on Appendix A. Figure 4 of the at~ached Pan of Opera1lons - 2003, Project Addendum LeClal Description The Northwest one-quarter (NW'/.) of Section 35, Township 19 North, Range 1 East. Seward Meridian, located in the Palmer Recording Dislríd, T;-¡ird Judicial District, State of Alaska, EXCEPTJNG THEREFROM the Northeast one-quarter of the Northwest one-quarter (NEX NW/.) of said Section 35 and FURTHER EXCEPTING THEREFROM that portion of said Section 35 lYing Westerly of the Palmer-FishhoOk Road right of way H IS understood thôt some additional work may be required to burJd the access road and clear a well s¡t~ 10Lation; that having reviewed the project with Mike Belowlcn, Geologist for Evergreen Resources (AlaSka) Corporation, hereby approve of same. 1¿\J ~/\.>- \):tb X Robert M. Rethenord ~ 3268 Sha8ping lady Lane Anchorage, AK 99515 (907) 522-4664 -Page 9- . Dee 05 03 05:56p DH e ~~OTES: 1. COGRDII\A TES SHOI~'~ ARE ~~AD83 ALAS<ð. STATE PLANE ZC~: 4 BASED O~ PROTRACTED VALU:S, 2. GEOGRA?hIC CCQRDI~IATES ARE NAD 83 3ASEG ON PROTRACTED VALuES, 3. êL'-D~STANCES ARE GROUND IN lJ,S, SLRiÆY FEET. 4, VERTICAL DATLJM IS BASt:D O~~ AJOT 6ENCrlMAR{ E'_ = 82.0.84' 28 3J Little Su #1 LOCA TEG ':,9" FROM THE NORTH Ut~E OF SECT,GN 35 MDGCS' FROM THE WEST LINE OF SECT-O,", 35 T 19 N, R 1 E. SEW.ARD MERIDIAN AT LAï. 6,·.j.:'52,52S'N LONG. 149'14'0740S'W ASP zm,l~ 4 N=281312717 E=1ï73146.94 (NAD83) GROUND ELEVATIO,'~ = 81G.1' 1 Pj - j! ~& J ~ / ~I j 8 I 8\ / z·L. 605,11'/.~_LitJ~'e Su 'J~ 'I if 1 _01 ~ SEC" O~~ 35 \ R1~, SJv1., ALASKA ~' ~I i'~;%/ J I 0.$£/ U I ~ --~J ¿J I, - :~~ ~! ~ ~3:5 ~, 89'59'58" If! 1319,29' CW 1/16 N 34 I r " A " :; ~IL ::~ N J \ "1:'1 . I\LÞ :Þ~~' , \ \ SCALE l' ï'19N. Lihl e ~u 27 26 S 'C) ~If n :1 89'58'2:" ~ 13'9,93' 600' 90.357.8340 , \ HATCHER _\ \\ ?~SS RO \; " ),\6 // /J ; "J~::RTQJ PARK RD / 34 1 n 'r; 'n w r- -") p co o V1 ~ S 89'59'43" t NW 1/16 1319.75' 89"59'56" W ¡ ¡ II ':319,35' '" " , / 11_ / I'" I , r-\", Ir, r'I' /l""l''''~ ...... I I \ ILl I' t , ~. \' ...... I I ~ < 1 I f II ,...... J} II \ J ....... ... -' I...· .., -, L. .. _ "" _ I ........ ..... c....... L...... r .......... '.... I ~ p.3 25 56 T19j 118'. 1 M I LC: "CN 1/16 V N o r--: n ~ o o o If) o ::::1/4 ·U·~ , J - , .1/1 TT (fjL. '" L01:NSBURY & ASSOCIATES, INC. 1\ \ ::NG'^~EERS-FLM'~ERS-SURVEYORS .(~) 723 W, 6th ,4VE. ANCHORAGE. ALAS~A 99501 CY (907) 272-5451 FAX (907) 272-9065 DRAW:.. PER ;\111 T C R ,ß, WI ~~ G KWA I CHECKED r<.WA I SCALE l' 600' ~Joverr.~er 13, 2003 OWG ~',l.ME 03-031-3.DWG =\I=I~GI~==I'. RESOURCES (ALASKA) COR~ A Subsidiary of Evergreen Resources, Inc. . December 10, 2003 Mr. Bob Crandall Alaska Oil and Gas Conservation Commission 333 W. 7th Ave #100 Anchorage, Alaska, 99501-3539 RE: Additional Information for Evergreen Resources Alaska's Core Program 2003 Dear Mr. Crandall: The surface casing set depths were chosen based on anticipated contact depths between the Quaternary gravel and the Tyonek Formation. Evergreen Resources (Alaska) personnel will be on site to ensure that the surface hole for each well is drilled at least twenty feet into the Tyonek Formation. Once the entire core has been extracted from each well, they will be shipped to an independent lab to be slabbed, photographed and analyzed. Evergreen Resources (Alaska) personnel will ensure that two ounces of chips representative of each foot of recovered core is submitted within thirty days of analysis to the Alaska Oil and Gas Conservation Commission. If you have any questions, please feel free to contact me at 907-355-8569 or shaneg@everqreenqas.com. Sincerely, d14fl2 Shane Gagliardi Petroleum Engineer 1075 Check Street, Suite 202 . Wasitla AK 99654 P.O. Box 871845 . Wasitla, AK 99687 . TEL 907,357,8130 . FAX 907.357.8340 =\'=I~GI~==I~" RESOURCES (ALASKA) COR"" A Subsidiary of Evergreen Resources, Inc. e 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: 300~~~~ Proposed Spud DaV . ecember-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 ? 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 TD. A logging suite consisting of gamma ray, array induction, compensated neutron density, caliper and sonic porosity tpols will be run. After all cores have been retrieved and logs run, the hole will be permanently abandoned, /' Attached is information required by 20 MC 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, ß~k~,co~o~tion Shane Gagliardi Alaska Projects Engineer OR\G\î\~ RECE\VED DE.C - 6 '2.003 C mroiSS\Of\ a Oi\ & Gas Cons. 0 MaI~ Anchorage enclosures Core Program 2003. APD 1075 Check Street, Suite 202 . Wasil/a AK 99654 P'Q, Box 871845 . Wasil/a, AK 99687 . TEL 907,357,8130 . FAX 907,357,8340 '\. Controlled .'...... ou n"" Hibern. No Check Dàte 0.0.770.00.728 12/0.8/200.3 '************$10.0..0.0. to THE ORDER OF.' . AI~ska Oil a Conservation .' 333 West 7th Avenue #10.0. Anchor e AK ".' .::' ; ::_'_ _ ',' '::,ii .-~::,:,',:: ,;',>''',':: ':' :":' ::: ':' _.:-,::",-"', -------_._-~~--,-~~--------~--~---~--_._--- ·PLEASE DETACH AT PERFORATION ABOVE· ·PLEASE DETACH AT PERFORATION ABOVE" :V:I~GI~::~I EVERGREEN RESOURCES, INC, Evergreen Resources (Alaska) Corp 1401 17th Street Suite hoo Denver CO 80202 303-298-8100 0,00 Invoice # Inv, Date II:I-i:'!II.H¡'JI 12 month permit fee Little Su 1 100,00 ~~~~~I~~~íI 100,00 112403SG4 11/24/2003 RECEI\ 'ED DEC - 9 z,m Alaska Oil & Gas Cons. Commission Anchorag 3 I 0.0.9195 I ~ Vendor Check Date: 12/0.8/20.0.3 Check Amount g I 10.0.,00. I · e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK WHAT APPLIES Rev: 07/]0/02 C\jody\templates WELL NAME PTD# ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly 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). Pll,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing . exception that may occur. All dry ditcb sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Administration Well Name: Little Su No, 1 Program STR PTD#: 2032050 Company EVERGREEN RESOURCES (ALASKA) CORPORATION Initial ClasslType STR /INFO GeoArea Unit On/Off Shore On 1 p~(lT]itfee éi!ttaçhed . . . . . . . . . . . . . . . . . . . . . . . No . . . . .. ....... ....................... 2 .Leéi!s~number .apRropriate. . . . . . . . . . . . . . . . . .. ........ . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 .U.nlque welln_a!11~.and lJumb.er . . . . . _ . . . . . . . . . . . . . . _ . . . . . . . _ . . . . . . . _ . .Y~s . . . . . . . . . _ _ . . . . . . _ . . . . . . _ . . . . . . . . . . . . . _ . . . . . . _ . . . . . . . . _ . . . . . . . _ . . . . . . . . . . . . 4 WeJlJocat~d ina. d.efineø JJool . . . No . . . . . . . . . . . . . . . . . . . 5 WeJlJocat~d pr.oper .distance. from driJling unitb.oundary. . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . .. ....... ................. . . . . . . . 6 WellJocat~d pr.operdistance from otlJe.r W!'1lJs . . . . . . . . . . . . . . . . . . .. ........ Yes . . . . . . . . . . . . . . . . . . . . . . . . . . . 7S.utfiçientacr!'1éi!ge.aYéi!ilable in.d.rilJilJg unjt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Jfd~viéi!ted, js weJlbore plaUncJu.ded . . . . . . . . . . . . . . . . . . . . . NA . . . . .. .............. . . . . . . . . . . .. .............. 9 .0JJ!'1(ator onlY' éi!ffeçt!'1d party. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 .0JJ!'1(ator bas. appropriate. Qond inJorce . . . . . _ _ . . . . . . _ . . . . . . _ _ _ _ . . . . _ . . . . .Y~s _ . . . . . . . . . . . . _ _ _ . . . . . _ _ . . . . . _ _ . . . . . . _ . . . . . . . . _ . . . . . _ _ . . . . . . . _ _ . . . . . . _ . . . . . _ 11 P~rmit can be issued witlJout co.nservation order. . . . . . . . . . . . . .. ...... .Y~s . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............... Appr Date 12 P~rmit can be issued witlJout éi!dministrati\le.aJJprovaJ .......... . . . . . . . . . . . . . .Y~s . . . . . . . . . . . . .. ...... ....... .............. ....... . . . . . . . . . . . . RPC 12/8/2003 13 Can permit be approved before 15-daywait Yes 14 We.IIJocat~d within éi!reéi! éi!nd.strataauthorized by.lojectiolJ Ord~r # (putlOil in.cpm!11eots).(ForNA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 AJI W!'1lJs.wit!1i.n Jl4.mile.are.a_of reyi!'1W id~otlfied (For servjce.w.ell Only). . . . _ . . . . . . . _ . . .NA _ . . . . . _ . . . . . . . _ _ . . . . . _ _ . . . . . . _ . . . . . . _ _ _ . . . . . . . . . . . . . _ _ . . . . . . . _ _ . . . . . . . . . . . _ 16 p.re.-produ~ed ioj!'1ctor; øuration.of pre-JJroøuctiolJ I~ss. théi!n 3 months. (For.service well QnJy) . .NA . . . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17 .AÇMP.findingofCQn.sistencyh.as bee.nissued.for.this pr.oieçt . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 18 .C.onductor stringp.rQvid!'1d . . . . . . . . . . . . . . . .NA . . . . . . . . . . . . . . . . . . . . . . . . . . .. .......... 19Sulface.casingp.rQtects éi!lIknown. USDWs . . . . . . . . . . . . . . . . . . . .Y~s. $et@ 150ft,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 20 .ÇMTv.olad!'1Quate.to çirculate.o.n.conductor.& sUrfC$g . . . . . . . . . . . . . . . . . . . .Y~s. . . . . . . . . . . . . . .. .............. ............................... 21CMTv.olad!'1Quate.totie-inJQng.stringtosurfÇsg......... ........ .NA . NQcasing Þelowsurtaçe, ............................................. 22 .CMT wilJ coyer.aU kno.w.npro.ductiye 1J0ri;zons. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . No. . . $tra.tigraphic test.. . . . . .. ...... . . . . .. ....... .............. 23 .C.asiog de.signs éi!dequate. fpr C.T, B.&.perruafr.ost. .. ...... ....... . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . 24 Aøequatetankage.o.r re.serve pit. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Yes . . . Core rig tanks, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ 25 Jfare-drill. héi!sa 10A03 fQr abandonment be~o apPJQv!'1d . . . . . . . . . . . . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 26 .ÄØequatewellQore.sepéi!ratjon.proJJoseø.. _ _ . . . . . . _ _ . . . . _ _ . . . . . . _ . . . . . . _ _ .Y~s. . _ . . . . . . . _ _ .. . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . _ _ . . . . . . _ . . . . . . . . . . . . . . . _ . . . . . _ _ . . 27 Jf.div!'1rter Jeq.ui.red, does it.meet reguJations . . . . . .. ...... . NA . . . . . Requireme.nt Wéi!ive.d, . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Appr Date 28 .D.rillilJg fluid program schematic&. equip Jist.adequate . . . . . . . . Yes.. . . Water,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . WGA 12/8/2003 29 BOP1=s,.d.othey meet r!'1guJation .............................. .NA . . ,ð.nn.ular QnJy., . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ................ 30 .B.OP1=pre.ssratiog éi!PJJropriate;testto.(put psig in.comments). .. ....... ...... . .Y~s . . . . . . TE~stto.1500ps¡, .II/IS~ 1080 psi,. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31 .Chokemanifold compJies. w/API R~-53 (May 64). . . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 32 WQrk wiU occ.ur withoyt.operation .shutdown. . . . . . . . . . . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ........ 33 Js. Rres.ence. of H2S 9éi!S. RroQable. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . No . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 34 MeçhanicaLCOlJditionPfwe.lIswithin,ð.ORyerified<For.s.ervic!'1welJonJyJ.... ....... NA ...... ...................................... Field & Pool Well bore seg Annular Disposal D D ~ - - - - - - - -- Engineering - - - - - - - Date 12/8/2003 35 P~rmit can be issued w!o hyd(ogen. s.ulfide meéi!s.ures . . . . . . . . . . . . . .. .Y~s.. 36 .D.ata.p.re.s!'1lJted on Rote.ntiéi!1 ove.rpressure .zones. . . . . . . . . No. 37 .S~ismic.analysjs. of shaJlow géi!s.zooes. . . . . . . . .. ....... ...... No. . 38S~abed .conditiolJ survey (if off-shoœ) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . NA 39 . CQntactnamelpnoneJor.weekly progres.s.reRorts [eXRloratoryonly] . . . . . . . . . . . . . NA . . . . . . - - - - - - - - - - - - - - - - - - - Geology Appr RPC . . . Drjinghistory.of adjéi!centweJls have no e\lidence Qf .ove.rpressur.e. . . . . The operator will be equippedto.w.eightupin case ofa kick.. . ......... - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -- - - - - - - - - - - - - -- - - - - - - - - Geologic Commissioner: OD Date: /2.J (D!3 Engineering Commissioner: Date Public \ .. C¡.';~V\~ \61') D,t, 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 file under APPENDIX. No special effort has been made to chronologically organize this category of information.