The URL can be used to link to this page

Home My WebLink AboutO 030 Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. () ()3CJ Order File Identifier Organizing (done) D Two-sided III 1111111111111111 0 Rescan Needed 1111111111111111111 RESCAN DIGITAL DATA OVERSIZED (Scannable) D Maps: 0 Color Items: 0 Greyscale Items: D Diskettes, No. D Other, No/Type: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: Scanning Preparation x 30 = + 0 Other:: , Date:! ~ q 0 if /s/ JIM. P ,1111111111111111111 Date:r;)-- Iq be¡.. /s/ n1 P = TOTAL PAGES -:=57 (Count does!not ¡,c. lude cover shee lAA ¡./) Date:/ r:J-, q Ô 4- 151 r r~. r ¡ 1111111111111111111 BY: Helen ~ Project Proofing BY: Helen Maria BY: Helen~ (" '.':;..-"'.,1 \ Production Scanning Stage 1 Page Count from Scanned File: 3 ~ (Count does inC~Ude """ sheet) Page Count Matches Number in Scanning Preparation: V YES I I' HelenCMaria:) Date: Id- C¡, tlLf If NO in stage 1, page(s) discrepancies were found: YES NO NO /s/ mp BY: Stage 1 BY: Helen Maria Date: 151 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: 151 Comments about this file: Quality Checked III 111111111 1111111 12/1/2004 Orders File Cover Page.doc 1. October 8, 2004 2. November 16,2004 3. November 16,2004 4. November 16, 2004 5. ----------------------- ) INDEX OTHER NO. 30 Regulatory Cost Charge 2005 Notice of Hearing, affidavit, bulk mailing list and e-mail mailing Sign In sheet for Hearing Invoice and Notice of Regulatory Cost Charge Transcript Financial Information Other Order #30 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501-3539 Re: Regulatory Cost Charges for Fiscal Year 2005. ) ) Other No. 030 November 16,2004 ORDER ESTABLISHING FISCAL YEAR 2005 REGULATORY COST CHARGES IT APPEARING THAT: 1. On October 6, 2004, pursuant to 20 AAC 25.615 the Commission gave written notice of proposed fiscal year 2005 regulatory cost charges under AS 31.05.093 to operators subject to those charges. 2. Notice of public hearing on the proposed fiscal year 2005 regulatory cost charges was published in the Anchorage Daily News on October 8,2004. 3. A public hearing was held at the Commission's offices on November 16,2004. FINDINGS: 1. The appropriation, other than of federal receipts, made for the operating costs of the Commission for this fiscal year is $4,270,300.00 2. The lapsed amount of the fiscal year 2004 appropriation that is included in this fiscal year's appropriation under AS 31.05.093(d) is $877,206.29. 3. A reasonable estimate of the total fees to be collected under AS 31.05.090 during this fiscal year is $20,000.00. 4. The amounts constituting V OP under 20 AAC 25.605(a) for the operators subject to a fiscal year 2005 regulatory cost charge are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. Evergreen Resources, Inc. Forest Oil Corporation 212,703 2,026,047,299 453,138,498 80,590 3,953,095 Bbl Bbl Bbl Bbl Bbl RCC FY 2005 Page 2 of3 ) Marathon Oil Company North Slope Borough Phillips Petroleum Co. Pioneer Natural Resources Company UNOCAL XTO Energy Inc. 8,321,168 236,135 5,131,700 3,828 55,446,246 4,033,953 CONCLUSIONS: ') November 16,2004 Bbl Bbl Bbl Bbl Bbl Bbl 1. The Commission chooses not to include in its calculation of fiscal year 2005 regulatory cost charges an allowance to cover charges that the Commission may be unable to collect. 2. Using the formula set out in 20 AAC 25.605, the fiscal year 2005 regulatory cost charges for the operators subject to those charges are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. EvergreenResources Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Co. Pioneer Natural Resources Company UNOCAL XTO Energy Inc. $280.64 $2,673,094.53 $597,854.76 $106.32 $5,215.57 $10,978.66 $311.55 $6,770.58 $5.05 $73,153.80 $5,322.25 3. Appropriate payments dates under 20 AAC 25.620 are December 15, 2004, for the second quarter of the fiscal year; January 15, 2005, for the third quarter, and March 15, 2005, for the fourth quarter. RCC FY 2005 Page 3 of3 ) ) November16,2004 NOW THEREFORE IT IS ORDERED that the operators listed in Conclusion 2 of this order shall pay their respective regulatory cost charges set out therein, less their respective estimated fiscal year 2005 regulatory cost charges that have previously been paid, by paying one third of the amount owed by each payment date set out in Conclusion 3 of this order or sooner. Daniel T. Seamou , Jr., Commissioner Alaska Oil and as Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., lOth day after the application for rehearing was filed). Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 ) David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise,ID 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 /lJ/l/ /¿d "j / Ø9)( Order 30 ) ) Subject: Order 30 From: Jody Colombie <jody - colombie@admin.state.ak.us> Date: Tue, 16 Nov 2004 11: 19:54 -0900 To: undisclosed-recipients:; 10f2 11/16/2004 11:20 AM Order 30 20f2 ) ) . Content-Type: applicationlmsword ¡Other30.doc , : Content-Encoding: base64 11/16/2004 11 :20 AM #5 ) " ) Final RCC November ) ) w~ s~-S .f) ~ 'J I L- ~~ C(JL~~s ~ '! if UNITED STATES POSTAL SERVIC~ ,. - .. 't), C' ." ~ .- --.,~. - - - ,-" --!~~._~?~ ~-- .~. -~\;'.-'-~-~~ ~ · Sender: Please prin~tiC.~{É1ddress Mct'Zfb~'s<box-~~- - -. - _,.-~.~, ".~~~~kCJassJ\A<iÛ!---,- GH '~~.~~!~~;~:paid ~, - .... f Í...~i, ./~ {1 r~ui 4- NÛ'v- \ - -~ .;n AK Oil & Gas ConselVation CShWrtišs1bn 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 " L.~ ¡! ¡ 1 ¡ ¡! ¡!:! ¡ 1 ¡! ¡ II! ¡! ¡;¡ ¡ ¡ ¡ ¡ L ¡!: L ¡ ¡ ìI ¡ L L Hi ¡ L ¡¡ If: Ii ¡ j f"l~'¥1: r~~:~"':~"]~~;::;:_,:~·. ...~,"":$;'''; ..J] r-Q...,. ç; . _1,., 1\IJ" .'.,-,,' ,___.~f ~ r=~=~~;~~~Î1 Lf1 m Postage $ ,¿;,n ~.~v ,.16 òc.,(\. ~ c.fi./. ~ H~,' G) o ~ frJ ~ ~- 0'0 Tolal Po<laoe & Fees!!; 4. "s- ~ lS ...;q ~ ru a Sent To XTO Energy Inc. a ._'h___n Attn: William A. Miller, District Adm Mgr I'- Street, A or PO B¡ 52260 Shell Road "ëirÿ,"Šrå Kenai, AK 99611-9704 ~. Lf1 o a Return Reciept Fee o (Endorsement Required) o Restricted Delivery Fee Lf1 (Endorsement Required) r=I rr1 Certified Fee JIDti1ff~L · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. 1. Article Addressed to: ~; A. S· nature c_ I. C\/7i I lCA (j I ~ 0 Aoent , '. u.. XÇLNV~ 0 Addressee B.' . e\ived b~ (.. prjn!e~ Na,:,e. ~ C. f>at~ of Del~ery . \".J\(\ \\\\ -( \ \- \')- at{ D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No XTO Energy Inc. Attn: William A. Miller, District Adm Mgr 52260 Shell Road Kenai, AK 99611-9704 3. Se¡vice Type r:sl Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transfer from service label) PS Form 3811, August 2001 7002 3150 00053521 1386 -~---...r:__~~~~_","", Domestic Return Receipt 1 02S9S-02-M-083S UNITED STATES POSTAL SERVlsP\.-::'~,,~ ./~":-:'¡~' -<'7'·· .~ ""'='.... ::h.¡¡ L:} ~. ..:~ "1' .- j First-Class Mail Postage & Fßßs Paid USPS < Permit No. G-10 (. ,,-( ~_ ' ~ _--. _ _",~-'- -'- -;,e " -_ ~~.¡- .{ . - ~ ,'. '""' ,""c.;...... \_¡~_..... td :",¡Ùl.i / _.' _ ; :;_.~__'~ '_'.<:" / . S~µd~r:<PIî~~~~l~1i~lt.r.n.liat1)e', address, aö"{T7iP+4 in thfs bÖ~; }--{, ¡ :. '. ,,) ~~--;~ ~ AK Oil & Gas ConselVation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 ~.~ IT'" I'- m ....., ~~Q[~fiWf~~~Y&':rilliL~~~ r=I ru Lf1 m "'~'''''~J_ - --. : -.."- . '." ·~'~~;~t~~L~~:~~::~;···;1tT~~~·t:-~ ~.~~~·:":,".~~.~~r~-:-~...·· ~~ -. Lf1 a o CJ o Lf1 ....., rr1 Postage $ -ÞQ ~ Certified Fee a..~v ¿; P'>lma," ø ~ Return Reciept Fee I. 1,':; ~ _9\ ~ (Endorsement Required) Restricted Delivery Fee \ 0' (Endorsement Required) ~ I'l) Total Postage & Fees $ Lf. ft:JÇ 0.[ § 1'<1}. scJf ru o Sent To o I'- -~ UNOCAL ·S¡reeCÃþiì\ Attn: Dale Haines, Mgr Oil & Gas orPOBoxN( P.O. Box 196247 ·Ci[Y~-Štãtë:i Anchorage, AK 99519-6247 í~~~Rt[ít · Complete items 1 J 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: UNOCAL Attn: Dale Haines, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 2. Article Number (Transfer from service label) PS Form 3811, August 2001 A.æig~?e 7ffi- "- ~~- '¡':J~nt X . ~ çV'~~dd" "e B. Re.ceived by (Printed Na~.e.~ '.' -~.....,. .~~e Of[)'&;'...;.., .' v(þfl.o (f"Z-þJÁ-;' f ,,\\~U LJ~ ~ð;. D. :; ~;~~e:t:~~::e~ff:~e~r~:'~~~æ..r)? ~~ i......:.._....,..t.:..,.?. ...~.~..~.. .. .'{iI' '.. .~...::.¡' ~t~~" '~ÊS66 )\-.! "'-'- >..r 3. Se¡vice Type ril Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 7002 3150 0005 3521 1379 102595-02-M-OB35 Domestic Return Receipt UNITED STATES POSTAL SERVICE '" 4- ! I I First-Class Maii Postage & Fees Paid USPS Permit No, G-10 · Sender: Please print your name, address, and ZIP+4 in this box oj AK Oil & Gas ConselVation Commissioh-';' 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 L-, ~'\ NOV ff ? 20û4 ¡ L L ¡ 1 J ;¡ U: ¡¡ ¡ i ¡ ¡¡ : ¡¡ ¡¡ ¡ L d ¡ I ¡¡ ¡ í L ¡ ! i ¡¡ i : i L ¡ :;1: i L ¡ ¡ ¡ ~/(fff(~,t,~¡~~~~r~i~~Æf~I~~~tÆW#-k~%~~~jttll~I~~";~tt~~£P~i ~ t£~~\Æ~~~lg~hl~t'1k;j rl ~ r~~~~~f,\í rr1 Ø~01 ~ ~~mark \?\ t> ~ » ± ct .,Þ tilL ,- ~Oy:;1 Total Post""A R. FAA" ~ ~ ~ ~6:) ~:/' ~ Sent To Pioneer Natural Resources Company CJ Attn: Scott D. Sheffield, CEO I'- ';;r~~:t; 5205 N. O'Connor Blvd, Suite 1400 'Cirÿ,'Štåte Irving, TX 75039-3746 - . Postage $ -bO d, ,aD ( .1~ Lf1 o o o Return Reciept Fee (Endorsement Required) Certified Fee o Restricted Delivery Fee Lf1 (Endorsement Required) r=I m ~~L_~_~~~_ rœœ;:a~~'Ò"' - A.~ SJ~1£/1'Î /1')/wrr1Cfil 0 Agent Ytfyt(¡ (J/) 0 Addressee 81 ~eived, by (rr,' . te,d Na,me) C C. Dt}e of p'f:1ivery n,¿íít7 V(fIYl¿{~ ì I r/7 #6ý' D. Is delivery address different from item 1? 0 Yes 1. Article Addressed to:,/~~er delivery address below: 0 No /,'\ , Pioneer Natural Resources company.'/~·¿ >/ -- "'\ ~\ Attn: Scott D. Sheffield, CE~ ~;~1, 'f \ .~ } 5205 N. O'Connor Blvd, SUite 1400 )( \ ':: I Irving, TX 75039-3746u,x. '-,-,~._~içe:ty~?,/, :;fWff~:; ',- / ,-D~~:~I;~~e~a'l ~ ~:~~;~sR~ca~liPt for Merchandise c;:t IIl.$Ured Mail 0 C.O.D. 4. Restricted Deiivery? (Extra Fee) · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. 2. Article Number (Transfer from service label) PS Form 3811 , August 2001 DYes '~~~~",~~.~~~?~~~_~ -§"15IT~~~~~:~\i;j~i~_1 _13 ~ 2 102595-02-M.QB35 Domestic Return Receipt UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and ZIP+4 in this box .. AK Oil & Gas ConselVation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 L.~ 011 OJ Iii I ¡: j! H I I 1'1 :¡ i p II H ¡ ¡i ., '1"'I"I"!'''''''¡''II''II¡''11 ¡ ,'f"·¡I,,'li'¡'·¡: , I . It J ¡ . ...:.. &- ... t.... . I 4.. .... .. it. ¡,~~~~~~~r~~1r~f;;~:=:'~'J Lf1 Lf1 m r=I ~~~l;¡;;~M&~~~~'ID;I~~~j M ru Lf1 m o Lf1 ,-:¡ ITl ru a Sent To o r- "sti-ëêCAjj or PO Bo) "ë¡¡ÿ, 'siã¡'; Postage $ ."0 Certified Fee a.3V Retum Reciept Fee 1.15 (Endorsement Required) Restricted Delivery Fee (Endorsement Required) Total Postage & Fees $ 4-9 ~s- Lf1 a a a Phillips Petroleum Company Attn: Steven Arbelovsky, ClOp Mgr P.O. Box 66 Kenai, AK 99611 ~~i ~ 1. Article Addressed to: AX' ~n~~ure ¡/, In n 0 Agent ~ ~ 0 Addressee Mæ~d:; J¡;,7;:;~ Co Date of Delivery D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired, · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. Phillips Petroleum Company Attn: Steven Arbelovsky, ClOp Mgr P.O. Box 66 Kenai, AK 99611 Se¡;ice Type ~ Certified Mail 0 Express Mail o Registered 0 Return Receipt for Merchandise o Insured Mail 0 C.OD. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (fransfer from service label) PS Form 3811 August 2001 7002 3150 0005 3521 1355 -- ......... ~~~-:>~-~... -- -~-=--=-.._-- Domestic Return Receipt 102595-02-M-OB35 ¡ ~ UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No, G-10 · Sender: Pt~~9;>~o print your name, address, and ZIP+4 in this box · v 'ì (\\J t:~ t~-~! \.-~V t~' \ -', AK Oil & Gas ConselVation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 L, ßa.K~ ~~~ ¡¡ ~~i't ., i~ ~1 iii" 11 ~~!!_.¡ II ¡ ¡ ¡ d ¡ ! ¡ i ¡ ¡ ¡ ¡ /I! ¡ ¡ ! ; ¡ II ¡¡II !i I d ¡¡ ¡ 11 ¡¡¡I ¡ ¡ ¡ ! Ii ¡ ¡¡ i Ii I ¡ J: ¡ I f';~' . ..... ~ - , . -. '..- _r'-'~_..'..., .... _.__ ___ ~ ~ :t~~;~:#f~;~';'~~,~~~;~;~ißi!;,ÚL"i M r-1 ru IJ1 rn Postage $ Lf1 o o CJ Return Reciept Fee (Endorsement Required) CJ Restricted Delivery Fee L.11 (Endorsement Required) ;:;: Total Postaç¡e & Fees:£ 4 · ~S"" ~ Sent ï North Slope Borough CJ Attn: Dorothy Savok, Manager I'- -sirè'ël Barrow Gas Fields or PO --Citý,-~ P.O. Box 69 Barrow, AK 99723 Certified Fee tit¡r~d: · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: North Slope Borough Attn: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 A. Signature X:~/~!, ~.~, 0 Agent 7' 17 <...--,-~-~ ,'-~ ':;'-, 0 Addressee ~A'-;, ", Rec~ived by (P, rin", ted, !N~,m, eJ, ~-, ~~Y,<,DatJ, Of,9élivery _ W¿œK (l-z cJ..f!- ~si)/ . \'i Ilfl/ó Ý D. Is delivery addr~,~ifferent ttb¡fi ~~ 1 j 0 Yes If YES. enter deIJV~~~:ress bel~: 0 No ,~"~, /l.-,F.- ¡......! -, -'- 3. S~ice Type Ii1 Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transfer from service label) PS Form 3811. August 2001 7002 3150 0005 3521 1348 :"--~~-.:;-~ ~=--'--O---<""-~-~~'----~__.,o...o",:"-=---..=o~-<c__~~ ___~...__"'-..."..~~-'-'-=._ --'----~..,.-<,-"".--:--~- Domestic Return Receipt 1 02S9S-02-M-0835 UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and ZIP+4 in this box .. AK Oil & Gas Conservation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 L..~ /"1.'[ .,' " ..i I··ii......!··. ¡¡.J 'r...Ji.U. ..!!...P'p. .1 , !, ! ¡,,¡¡ :11::::::1 sdl::/! :::II:lI!:!:d¡¡:,¡I:lÎd:l ?r~·t~.~ ',~-, ,:'¡~, p':;-:c~H~~~:'r~ -.;t'~"':"·;;··· : : " ~ ~~~~GL~~ª~~~~~hiciL~¡ r=I :,~2t:~'!)~~Øii!U.!r~ð'[~f1í:¿!'5¿~~1(:'~~:lt"77:;".!!:t?~~:::.~.~,..~~., . ~I (T1 U1 o CJ o CJ Lí) n ITl Postage $ ..~O Certified Fee ~.~-V Reîurn Reciept Fee ". (Endorsement Required) 1·1~ Restricted Delivery Fee (Endorsement Required) Total Postaae & Fees $ "'. tÇJ S' ru o Sent To o I'- ·SireëCAþi or PO Box - ëi&:-Ståiè Marathon Oil Company Attn: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 I -'---'1 ------1 ! ~ ttiittß';tii, ~ sYnc£) ~gent o Addressee · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1, Article Addressed to: 6\;\ived~f) c{)Zfe~),{' Dati \o~~ D. Is der~ address different from item 11 0 Yes If YES. enter delivery address below: 0 No Marathon Oil Company Attn: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 3. Se¡vìce Type ßt Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transfer from service label) PS Form 3811 August 2001 7002 3150 0005 3521 1324 --"-".._~--,----~,"""",,,--~~-~ - Domestic Return Receipt 1 02.595-02 -M·0835 UNITED STATES POSTAL SERVICE . ~ ~ t. First-Class Mail Postage & Fees Paid USPS Permit No. G-10 i I I- .."'~ }...~, ....-.- .-. ~ '", 'l'~ - ~ ~::'~'ç ¡Š'é~d~è~:'ÞI~a;:print your name, address, and ZIP+4 in this box tI .- ¡\iO V 1 ",7 2Q04 , ,- p..~~~:;F::~ l~~: ~,. ._" ~d Î.;) '"'. Cj;l~¡TÜSS¡Ór~ !_L ~;:.;: ';~ÄK Oil & Gas ConselVation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 ¡\! 10 \J ",i ~" 'J-' n 01 f¡ ,'1, if..l ~U"'t ."-- --- ...._"-- .---- 1:~,,~ d' U;i~;<;J}ljj; L , e.-,<~ -' , i Ì; I ¡ ¡ I ¡ ¡ ¡¡ ¡ ¡, U L ¡ ¡¡ ¡ ¡ II ¡; f L ¡ L f ¡¡ ¡ ¡ L L L ! ¡ ¡ ¡ L ¡ ¡ i I: I L ¡ ¡ I ["'- r=I rr1 r=\ Postage $ .{PO Ul Certified Fee d. . ~O 0 0 Retum Reciept Fee \.'5 0 (Endorsement Required) 0 Resrricted Delivery Fee Lf1 (Endorsement Required) r=I 4. (p S- T) Total postaae & Fees $ ru o Sent To o ["'- - StreéCApt or PO Box . -arÿ, - Stå¡ë: Forest Oil Corporation Attn: Accts Payable 310 K Street, #700 Anchorage, AK 99501 ____t¡Êì~~" ~~ · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpjece, or on the front if space permits. A. Signature B. Received by ( Printed Name) o Agent o Addressee C. Date of Delivery x 1. Article Addressed to: D, Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No Forest Oil Corporation Attn: Accts Payable 310 K Street, #700 Anchorage, AK 99501 3. Sejlice Type !!t Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D, 4. Restricted Delivery? (Extra Fee) DYes 2, Article Number (Transfer from service label) 7002 3150 0005 3521 1317 PS Form 3811, August 2001 ~-L.-4""'---~~Õ---""~--""'~~---=---=.o=-"=>~=~~~~f-=-._~~~=-~~-,.O_~"-,-;c..-_~..-...,__"-=o:-~=""-,,,,,......~-"'-=-'"=-~~-=-'~-_."'-=~~T'r.~ - - -- Domestic Return Receipt 102595-02-M·0835 UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and ZIP+4 in this box · -' ) AK Oil & Gas ConselVatioIH~pm!Jlis$i0n .~~_>:- ~ ~~_. ,;:-.- ~ 'f! 333 W 7TH Ave, Ste 100 j "ik~ '--j L=. ~ Anchorage, AK 99501-3539 f~¡n\f ~} ~~ nU tf £¡ 0' 2004 l-. ß~ - , Jf i .! I ~t.~.II~...._.'I..i!.,~.~.~_ii.:_l._..it...¡!_f:...f II: I ¡ "',:,·1'1,1 '" ·1' .{ "I . .¡.J..,. ¡ '" .... ¡ I," ,'!' " I" ., ., . .O'.. 0" . t.. I .." ... . 0.' . ..... ". . ;>J'~,~S, :7:,;:.é::-5H~:;:~~:\~:;~~ :," ~ c~>f_,~è -.- ~ ¡.~~~;~;~é~rj~~~L~::tL,j CJ ~:L1:tir~lr[~3!f'~~~~j!ii~~I"\t¿~~~ i I I r=I ru L.I1 m Postage $ .(oCÞ 'ß~ d . 3-0 ;;0 Po"',. ~~ L-1C:;:~ \~e ~) 'f~ ' / 4-f"~ ~ #Y Lf1 CJ o Return Reciept Fee o (Endorsement Requiredì Certified Fee o Restricted Delivery Fee U1 (Endorsement Required) r=I rT1 Total Postage & Fees $ ru o Sent To o I'- 'SìreèCXp"f{ï. or PO Box N( . ciiý~ 'sìåìë:-Ž Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1ih Street, Suite 1200 Denver, CO 80202 ~ifuW:~ B · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. , ~ "nrt mu 8. ïVt~~ve~ I£ri;z}1&J? c;tAgent o Addressee 1. Article Addressed to: C. Datt of Delivery 1/ / Ie¡ þLI D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: t:fl.. No Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1ih Street, Suite 1200 Denver, CO 80202 3. Se!yice Type f!i!" Certified Mail o Registered o Insured Mail o Expt~ss Mail o Return Rèceip,t for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transfer from service label) PS Form 3811 , August 2001 7002 3150 0005 3521 0983 --------- --- - -_._--~--- --.---_._~ _.__O~__~__~~~_~-=-·~~~ - - Domestic Return Receipt 102595·02-M·0835 UNITED STATES POSTAL SERVICE First-Class Mail Postage & Fees Paid USPS Permit No. G-10 ~ Sender: Please print your name, address, and ZIP+4 in this 'box j ~\.ii'-U-í\1 \ ': " -~ < '. L\jÇjlt 1- C; \ )<., '.. ~ ; , , ',AK,QiI & Gas Conservation Commission '·'33~:rW 7TH Ave, Ste 100 Anchorage, AK 99501-3539 . .~ ~ ~ ~. :>.",." L., \1CU"~ t~ ~ : t : \ j~ ;1 1; t í fi.~.i.. ~:i...¡~¡:i;;;¡ II d ¡ ¡ I ¡ L I ¡ ¡ ¡ /¡ I i ¡ ¡ ¡¡ i ¡II ¡ ¡[ J ¡ ¡ f ¡ ¡ ¡ ¡¡ ! ¡ : :I :: j : I ¡ : I :II .1 ... I o Restricted Delivery Fee U1 (Endorsement Required) r--1 fTl Total Postage & Fees 5) H . "S ~ Sent To ConocoPhillips Alaska, Inc. a Production Revenue Accounting I'- 'sirë'ãCX¡JCiv; Attn: Noel Dike ATO-1668 or PO Box No "êjiÿ,'Štåte;zÏi P.O. Box 100360 Anchorage, AK 99510-0360 ~jJlli·tITl~" '~~~~~It~~~~~·~~ ..J] I'- a- D ,..:;¡ ru Lrl rr1 Postage $ ./Do ~.30 1.'1'5 Lf1 o o Return Reciept Fee o (Endorsement Required) Certified Fee · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front jf space permits. A. Signature ¿: /J/ 0 Agent ~ 0 Addressee :. ceivad ~rinled Name) C. Date 01 DeHveoj /'ftc!l /F55 //-/l---e?f D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No 1. Article Addressed to: ConocoPhillips Alaska, Inc. Production Revenue Accounting Attn: Noel Dike ATO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 3. Sey'lce Type rJ! Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number , 7002 3150 0005 3521 0976 (Transfer from service JabeJ)___,____,______~~__~~_,~~.~~~ - - - PS Form 3811. August 2001 Domestic Return Receipt 102595·02-M,0835 UNITED STATES POSTAL SERVICE ,~ r, First-Class Mail Postage & Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and ZIP+4 in this box · AK Oil & Gas Conservation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 )... · &zx-S i j : I: : ~ f : ! : :; ! ; i: j 1: : ~ i ;. ¡ j! . J i ~ . : 11 1 ~; ; f ~ i} : i:: f: ij 11. i i 1 i i ~: : i ! ¡. .., ./... . ¡. ......,. ¡ .. '1.,.. I".. ,. i.J.. ..1 ,.. ..1.',.. ,I :...~ J,-,: ,-.;c: ~. "::~ _-:. :- _ -; - _ - ~ -....-.:. .-_:::":-i ;..-_-: -~; - - _ ,'-, ;,: -'-- '--':i- -' '- ~ ii~~~~~;¡~~~;~:i~$~:¡·t", o ~~~~~~'!¡~~~~tID1~4:~~~f~ r-=I ru 111 T} Postage $ Certified Fee .q~ Return Reciept Fee (Endorsement Required) Restricted Delivery Fee (Endorsement Required) Total Postage & Fees $ U1 o o o o Lf1 r-=I m ru o Sent To o BP Exploration (Alaska), Inc. I'- 'Sireët,ÄÏ- Attn: Steve Marshall, President orPOBo, P.O. Box 196612 "(;iiy;'štàt, Anchorage, AK 99519-6612 ~1?i1f£mi iH · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. A. Mi ture t(¡9 tl , ' ¡j //) ,gent _ X _~¡) ,~ ~~rossee B.~ceíved ,,:Jr, ( Printed Name) , C. Date7Del~ry (!~~ 5/f19A..v II I.g D. Is delivery a ress different from item 1? 0 Yes If YES, ent r delivery address below: 0 No 1. Article Addressed to: BP Exploration (Alaska), Inc. Attn: Steve Marshall, President P.O. Box 196612 Anchorage, AK 99519-6612 3. Se!)'ice Type ~ Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transfer from service label) 7002 3150 ODDS 3521 0969 ~'~"---------.......---~- PS Form 3811, August 2001 Domestic Return Receipt 102595·02-M-0835 . , UNITED STATES POSTAL SERVICE Firsi-Class Mail po.stc¡ge.. &.Fee~ E.aid USPS Per(l1itNo;, G:-1 0 ¡ ""to c · Sender: Please prihtyò9,~nam~/addressl ~..r:~~~+4~~t_~_i$ box,:- "'-..._>_:-"'..J</ ~:! ~ ,.......J .:.-....-... AK Oil & Gas Conservation Commission 333 W 7TH Ave. Ste 100 Anchorage, AK 99501-3539 ,.~ -7 '-, '7' ': ~ . --..... :'-.-.:.-.~ I.-.ßax~ I it it j L /; i ! L L ¡¡! ! i j i If ¡ 111 ¡ ¡ Lid ¡ j! L ¡ L ¡ n L 1 ¡ j¡ 1 Î U ! if ~o flf¡,t~r'~f-rt(V~Iif¥h?ffrf~~" -., _ .. ~"ß5 ;, y,"/> ..' ~ i.;~;~1~ši¡;j;;;~2;'~~~i:';}"..J o CJ Restricted Delivery Fee LIl (Endorsement Required) ,.:¡ rr1 ~J1:t~':ll\'lf!:~':'L~~lÎ!r./~ '-',~ii,_~:I:c:~~?r1l'~""~:' '< ,-~?2?~::':~~S:~'" --' --1 : I cert;::';:: $ c1~~~'T~ i o UJ ¡ ~ ark' ...;>. o , -, 5 c> "' Here ' · I ~~ q ~0J ~(~y $ rl., J_r ~~Y> Total Postage & Fees .., ~:::» .:;: Return Reciept Fee (Endorsement Required) ru o Sent To CJ r- - SÎrë-eC; or PO B . cfcÿ; -Sii Aurora Gas LLC Attn: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 ..~~ - ---.------ -~ ~,..,~ .. Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. . Print your name and address on the reverse so that we can return the card to you. . Attach this card to the back of the mailpiece, or on th~':froht if space permits. 1. Article Addressed to: A Signature , X ø~~ g~~~:ssee ,v;;;J;;;P ¿7:;j;L ¡;a:;o¿¡~ D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No Aurora qas LLC Attn: Ed,qones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 3. Service Type Þ4 Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number 7002 3150 0005 3521 0952 (Transfer from service labe_~,~__,____~~~_~_~~~~__~~___~__~~ PS Form 3811 August 2001 Domestic Return Receipt t02595-02·M-0835 I" i( @~ff1\T,-e ¡!F I~ lÆ\~-f!fl\ rj)) - UlJ w L 0 ~ u~ ~J u \ill ):::'Lru AlASKA. OIL AND GJt S CONSERVATION COJ.".Il"IISSION / / / I FRANK H. MURKOWSK', GOVERNOR 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: BP Exploration (Alaska), Inc. Attention: Steve Marshall, President P.O. Box 196612 Anchorage,AJ< 99519-6612 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $2,673,094.53. You previously paid an estimated regulatory cost charge of $677,626.09, leaving a balance of $1,995,468.44. One third of this balance, $665,156.15, is due no later than December 15, 2004. A second payment of $665,156.15 is due no later than January 15,2005. A third payment of$665,156.14 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on sis described in the October 6, 2004, Notice of Proposed Regulatory c/le8''Of'séal ar 2~05. Date: November 16, 2004 (! l/ ~ / ~~ ~an, Ch~:IL ~~!Æ~E ~ f !Æ~!Æ~~~ffiu / / / / I / FRANK H. MURKOWSK', GOVERNOR ~ A T1ASKA. OIL AND G~ S CONSERVATION C01".I1"IISSION 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Aurora Gas LLC Attention: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $280.64. You previously paid an estimated regulatory cost charge of $284.56, leaving a credit balance of$3.92. Your refund will be issued to you before December 31, 2004. is described in the October 6, 2005. Date: November 16,2004 ~ ~1!A\V1 rïìJ I [ I I,ll r'¿ ~J L! /I\ 11 /1:\ ((Ù r~\7 m\ j !J \ !: ¡ Ll \ ",,\ : I U LnJ L~ JrJ @J ~ ~ Lrû FRANK H. MURKOWSK', GOVERNOR ~T/)J.SKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ']"H AVENUE, SUITE 1 00 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 **REVISED** INVOICE AND NOTICE OF REGULATORY COST CHARGE To: ConocoPhillips Alaska, Inc. Attention: Noel Dike, Prod Rev Acctg Accounts Payable, A TO-1668 P.O. Box 100360 Anchorage, AJ( 99510-0360 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $597,854.76. You previously paid an estimated regulatory cost charge of$151,555.43, leaving a balance of $446,299.33. One third of this balance, $148,766.44, is due no later than December 15,2004. A second payment of $148,766.44 is due no later than January 15,2005. A third payment of $148,766.45 is due no later than March 15, 2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calcul::ltp.cl on the b' scribed in the October 6, 2004, Notice of Proposed Regulatory co~s for f),cal year 10~5. Date: November 17, 2004 ( . ~ / A J unn . hairm~ \... i( ~7~7Œ [,} !Æl!Æ~~i~ AT,A.SKA. OIL AND GAS CONSERVATION COMMISSION I / / / / / í ! FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 1 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1 ih Street, Suite 1200 Denver, CO 80202 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory , cost charges and payment dates is enclosed. Your regulatory cost charge is $1 06.32. You previously paid an estimated regulatory cost charge of $26.96, leaving a balance of $79.36. One third of this balance, $26.45, is due no later than December 15, 2004. A second payment of $26.45 is due no later than January 15, 2005. A third payment of $26.46 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16,2004 Your regulatory cost charge has been calculated { ¡t @? ff1\ ~-e ~ 1: ®; ® ~ rf! ~ æ) ~i tru ~ 1 ~J ~ ~ lru \~ ~~ U Ü AlASKA. OIL AND GAS CONSERVATION COMMISSION / I / / / I FRANK H. MURKOWSK', GOVERNOR 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Forest Oil Corporation Attn: Accounts Payable 310 K Street, #700 Anchorage, AK 99501 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5,215.57. You previously paid an estimated regulatory cost charge of$1,322.14, leaving a balance of$3,893.43. One third of this balance, $1,297.81, is due no later than December 15,2004. A second payment of$I,297.81 is due no later than January 15,2005. A third payment of$1,297.81 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16,2004 . described in the October 6, 005. If ")1 ~, @~®I[ J. l-e I~ _1' ®@r1!F0 rj)) w UlJ L r ~ J UlJ [#j @ LJ~u-j AlASKA. OIL AND GAS CONSERVATION COMMISSION / / / i FRANK H. MURKOWSK'J GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $10,978.66. Your estimated regulatory cost charge of $2,783.08 has not yet been paid and is due immediately. Upon payment of the estimated regulatory cost charge the remaining balance will be $8,195.58. One third of this balance, $2,731.86, is due no later than December 15,2004. A second payment of $2,731.86 is due no later than January 15,2005. A third payment of $2,731.86 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16,2004 ( ~ ~rlA\1JŒ 'f ~~ \..:!j J fE\ ¡In /ß\ ~ íV1 fE\ ¿~ l1 Lr-'~ 02) L\~ u-u 1/ ! í I / I :' / ¡ FRANK H. MURKOWSK', GOVERNOR AlASKA. OIL AND GAS CONSERVATION C01"JJIISSION 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: North Slope Borough Attention: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $311.55. You previously paid an estimated regulatory cost charge of$315.91, leaving acredit balance of$4.36. Your refund wilI be issued to you before December 31, 2004. Your regulatory cost charge has been calculated on t 2004, Notice of Proposed Regulatory cos~/~ tis Date: November 16, 2004 ( . I A J~.' (' I( @~®~~ ~~ ~ r !fl ~w ® rj)) Co IK1 -" ~ ~ u !rJ ~ iÆ æ)f0. ~ AlASKA. OIL AND GAS CONSERVATION COMMISSION / / / ¡ i ! FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steven Arbelovsky, Cook Inlet Ops Mgr P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $6, 770.58. You previously paid an estimated regulatory cost charge of$1,716.33, leaving a balance of$5,054.25. One third of this balance, $1,684.75, is due no later than December 15,2004. A second payment of$1,684.75 is due no later than January 15,2005. A third payment of$1,684.75 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated ~n ~s described in the October 6, 2004, Notice of Proposed Regulatory C~ges fDr ~.z2005. Date: November 16, 2004 (/AJ ___ ~~an, Chainnan ~' ~ ~ IL\\ ~ rc 'D[ fr cQ) u if\1 L lb ! If I~· n, r~\ ~~ nf7jT\ : î I ~ n' {U ¡ f i LJ L!'\ ~Lm ~ L1~L1~ ALJJ.SKA OIL AND GAS CONSERVATION cOl".I1".l.J.SSION / j :f / / FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Pioneer Natural Resources Company Attention: Scott D. Sheffield, CEO 5205 N O'Conner Blvd, Suite 1400 Irving, TX 75039 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5.05. You previously paid an estimated regulatory cost charge of$5.12, leaving a credit balance of $0.07. Your refund will be issued to you before December 31, 2004. Date: November 16,2004 / i( ~' @~ff1\~, .t jlt ~r¡ 1~~~(1 ~\ rj)) - fj{j - - ~ J LJ'U I ~ UU C~~/ ..J ~ L~~ AlASKA. OIL AND GAS CONSERVATION COMMISSION / / / / / f / / I FRANK H. MURKOWSK', GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: UNOCAL Attention: Martin Morell, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $73,153.80. You previously paid an estimated regulatory cost charge of$18,544.40, leaving a balance of $54,609.40. One third of this balance, $18,203.13, is due no later than December 15,2004. A second payment of$18,203.13 is due no later than January 15,2005. A third payment of$18,203.14 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/ AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated 2004, Notice of Proposed Regulatory Cost g DISC I I ~ K.~an,.C~an November 16, 2004 basis described in the October 6, ar 2005. Date: { ~ ~7~~Œ 0'·.-,· [ ¡I r wi J IÆf 'l % ~ rvl7 I~~ [j ·lfJ 1\\ iU\ Lu i Lr-u æ/ LJ ~ U'\J. / J ! / I .I ;' f / FRANK H. MURKOWSK', GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: XTO Energy Inc Attn: William A. Miller, District Admin Mgr 52260 Shell Road Kenai, AK 99611-9704 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5,322.25. You previously paid an estimated regulatory cost charge of$I,349.19Ieaving a balance of$3,973.06. One third of this balance, $1,324.35, is due no later than December 15,2004. A second payment of$I,324.35 is due no later than January 15,2005. A third payment of$I,324.36 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/ AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated 0 e asis described in the October 6, , 2004, Notice of Proposed Regulatory cos(7C e -or c ~ar 2005. ~ Date: November 16, 2004 .( Â . 0 K<~an.. -Ch~an ~' { Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this' fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: PtI')t. Ûp~^n, :ç:n. t .,~ Fax #: lIl"'s -d \C\4- From: L¡....c:La- ~ (J j'r ~ Date: '7.-1 \-¡. \ 0 L\- Phone #: 1q3 - \~ M~v...s.+ Q..C~ Pages (including \ ."... Subject: cover sheet): Message: £"'~ \.ø JL.,'C" a f'\ ~ I ~~ I t\ L\ -t"\ ce' (>.r T ~..:r P~~, p\.ct.A.~~. \""'-~ ~ \ . Lc..v: ~ If you do not receive all the pages or have any problems with this fax, please call for assistance at (907) 793-1223. ) ) ALASKA OIL & GAS CONSERVATION COMMISSI.oN FAX 907-276-7542 PHONE 907-279-1433 FROM: \,.,-~E:k- R{1~ DATE, I . ---, l TOTAL NOl:;. A~~ JCJ.~DJ:. COVEll, ~ FACSIMILE TRANSMITTAL SHEET, TO: T €.K' e--,,~'\2ø ~l \ \ COMPANY: FAX NUMBER: PHONE NUMBER: SENDER'S REFERENCE NUMBER: RE: YOUR REFERENCE NUMBER: o URGENT 0 FOR REVIEW o PLEASE'COMMENT 0 PLEASE REPLY NOTES/COMMENTS: AOG CC 333 WEST 7TH AVENUE, SUITE 100 ANCHORAGE, AK 99501-3935 o PLEASE RECYCLE ' TIME 10/11/2004 15:52 NAME AOGCC FAX# 9072767542 TEL# SER.# : BR02J2502370 10/11 15:51 AOGA 00:01:08 03 OK STANDARD JOB STATUS REPORT ) ) DATE, TIME FAX NO./NAME DURATION PAGE(S) RESULT MODE ) ) Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: ~'" \.....d.., tl...:> ~à5 c..c~or ~ ~~c.\\:rS From: L\~,Q ð ~ 'R n~ Phone#: L'\~ - \ ~3~ Subject: ~c.c..... \"'ve>lt..A.r \2a.v \.~ Fax #: ;;)k, ~- .., S é}.. \ Date: II } 18 '0 'i i Pages (including cover sheet): ~ Message: If you do not receive all the pages or have any problems with this fax, please call for assistance at (907) 793-1223. @!F"lmi~r· Œ", I ) II IlJ\ ., -- cQ.1 d ~nJ. U . ) rrrr¡' F fi1\ II ®, (!,l~ 11,~ ~ ~ ,02 Lf~ _b JJ J (20 J~ Lr lJ ) ATtASKA. OIL AND GAS CONSERVATION C01"IJ."uSSION / / ) l l FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 **REVISED** INVOICE AND NOTICE OF REGULATORY COST CHARGE To: ConocoPhillips Alaska, Inc. Attention: Noel Dike, Prod Rev Acctg Accounts Payable, A TO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $597,854.76. You previously paid an estimated regulatory cost charge of$151,555.43, leaving a balance of $446,299.33. One third of this balance, $148,766.44, is due no later than December 15,2004. A second payment of$148,766.44 is due no later than January 15,2005. A third payment of $148,766.45 is due no later than March 15, 2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/ AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculFltecl on the b' scribed in the October 6, 2004, Notice of Proposed Regulatory co~es for fl.,cal year ,0./5' Date: November 17, 2004 ( I."{ ~ A J unn . hairm\trr \... DATE, TIME FAX NO./NAME DURATION PAGE(S) RESULT MODE ) JOB STATUS REPORT 11/18 10:57 2651521 00:00:21 02 OK STANDARD ECM ) TIME NAME FAX# TEL# SER.# 11/18/2004 10:58 AOGCC 9072767542 BR02J2502370 ) h~OIL~ð~ (~"'\ \ I í/ ~ .........~, Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 Phone: (907) 279-1433 Fax: (907) 276-7542 Fax Transmission The information contained in this fax is confidential and/or privileged. This fax is intended to be reviewed initially by only the individual named below. If the reader of this transmittal page is not the intended recipient or a representative of the intended recipient, you are hereby notified that any review, dissemination or copying of this fax or the information contained herein is prohibited. If you have received this fax in error, please immediately notify the sender by telephone and return this fax to the sender at the above address. Thank you. To: S~V"d "i S:1~~~......~~ Fax #: ðtQ5 - '~d--' G",lOc.o~.¡ IIp-'' From: L\~~ ~ Date: \\/ll,loc.f Phone #: ,'1.6 -\~~9 ~.c.o$+ ~... Pages (including I Subject: cover sheet): Message: If you do not receive all the pages or have any problems with this fax, please call for assistance at (907) 793-1223. ) ') INVOICE AND NOTICE OF REGULATORY COST CHARGE To: ConocoPhillips Alaska, Inc. Attention: Noel Dike, Prod Rev Acctg Accounts Payable, A TO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25,615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. ,A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $597,854.76. You previously paid an estimated regulatory cost charge of$151,555.43, leaving a balance of $446,299.33. One third of this balance, $148,766.44, is due no later than December 15, 2004. A second payment of$148,766.44 is due no later than January 15, 2005. A third payment of$148,766.45 is due no later than March 15, 2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of AlaskaJAOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AJ( 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on the basis described in the October 6, 2004, Notice of Proposed Regulatory Cost Charges for fiscal year 2005. Date: November 16,2004 John K. Norman, Chairman 11/15/2004 17:20 AOGCC 9072757542 BR02J2502370 TIME NAME FAX# TEL# SER.# 11/15 17:19 2551521 00:01:15 09 OK STANDARD ECM JOB STATUS REPORT ) DATE, TIME FAX NO./NAME DURATION PAGE(S) RESULT MODE -) FY05 AOGCC Regulatory Cost Charges Final November 9, 2005 Total Due First Payment Remainder Due 2nd Payment 3rd Payment 4th Payment Aurora Gas LLC $ 280.64 $ 284.56 $ (3.92) $ $ $ BP Exploration (Alaska), Inc $ 2,673'i~4.53 $ 677,626.09 $ 1,995,468.44 $ 665,156.15 $ 665,156.15 $ 665,156.14 ConocoPhillips Alaska Inc $ 597, t1.76 $ 151,555.43 $ 446,029.33 $ 148,676.44 $ 148,676.44 $ 148,676.45 Evergreen Resources (Alaska) $ 106.32 $ 26.96 $ 79.36 $ 26.45 $ 26.45 $ 26.46 ) Forest Oil Corporation $ 5,215.57 $ 1,322.14 $ 3,893.43 $ 1,297.81 $ 1,297.81 $ 1,297.81 Marathon Oil Company $ 10,978.66 $ 2,783.08 $ 8,195.58 $ 2,731.86 $ 2,731.86 $ 2,731.86 North Slope Borough $ 311.55 $ 315.91 $ (4.36) $ $ $ Phillips Petroleum Company $ 6,770.58 $ 1,716.33 $ 5,054.25 $ 1,684.75 $ 1,684.75 $ 1,684.75 Pioneer Natural Resources $ 5.05 $ 5.12 $ (0.07) $ $ $ Union Oil Company of California $ 73,153.80 $ 18,544.40 $ 54,609.40 $ 18,203.13 $ 18,203.13 $ 18,203.14 XTO Energy $ 5,322.25 $ 1,349.19 $ 3,973.06 $ 1,324.35 $ 1,324.35 $ 1,324.36 Totals $ 3,372,823.71 $ 855,529.21 $ 2,517,294.50 $ 839,100.94 $ 839,100.94 $ 839,100.97 l ) ,I ) Budget Explanation Other Budget Info AOGCC Authorized Budget Explanation of Changes in Budget ) AOGCC Receipts Only FY 2000 FY 2001 FY 2002 Capital Budget Ch 2/SLA 99 Sec 61 $ 321,900 Operating Budget Ch 84/SLA99 $ 2,601,300 Ch 133/SLAOO $ 2,768,300 Ch 89/SLAOO $ 200 Ch 105/SLAOO $ 2,200 Ch /SLAOO $ 35,900 Did not charge operators $ 38,300 FY01 Final Authorized $ 2,806,600 FY02 Increments Tech Staff Increases ($61 .9); Reclass 2 stat techs ($6.9); reclass acctg clerk ($4.6); addtl travel for meetings/training ($25.0); addt'l training costs ($8.0) Additional Lease Costs Dbase Dev, Implementation & Data Mgt (Adm Ck I) Add itional Contract Labor Costs FY02 Budget Request Budget Am - Tech Staff Salary Increases Budget Am - North Slope Lease Space Costs $ 106,400 $ 50,000 $ 137,700 $ 10,600 $ 3,111 ,300 $ 180,000 $ 26,000 $ 3,31 7,300 Ch 60/SLA01 FY03 Increments Increased Drilling Activity Costs Salary Adjustments & Position Reclassification Costs Year 3 Labor Costs FY03 Operating Budget Request Estimated FY03 Capital Costs: Ch 1 /SLA02 -- AR 07588 AK Gas Development Study Ch 1/SLA02 -- AR 07594 Electronic Permitting Initiative FY03 Total FY04 Increments Continuation COLA Funding (Commissioners & Technical Staff) Annualize FY2003 COLA Increase for Gen Govt & Supvr Bargaining Units Health Insurance Increase for Non-covered Staff Health Insurance Increase for Bargaining Unit Staff FY04 Operating Budget Request Estimated FY04 Capital Costs: Ch 1 /SLA02 -- AR 07588 AK Gas Development Study Ch 1 /SLA02 -- AR 07594 Electronic Permitting Initiative FY04 Total ) FY 2003 $ 562,500 $ 11 8,100 $ 48,300 $ 4,046,200 $ 1 50,000 $ 140,000 4,336,200 FY 2004 FY 2005 $ 40,000 $ 3,300 $ 17,100 $ 6,300 $ 4,112,900 $ $ 50,000 $ 4,1 62,900 AOGCC Authorized Budget Explanation of Changes in Budget ) ) AOGCC Receipts Only FY 2000 FY 2001 FY 2002 FY 2003 FY 2004 FY 2005 FY05 Increments Underground Injection Control Grant Adjustment Deadhorse Office/Bunkhouse Lease Costs Changes to Retirement & Other Personal Services Rates Staff-Reduction and Related Expenses FY05 Non-Covered Health Insurance FY05 Bargaining Unit Contract Terms: Supervisory Unit Chapter 49 SLA 04 (HB 531) Shallow Natural Gas FY05 Operating Budget Request Estimated FY05 Capital Costs: Ch 1 /SLA02 -- AR 07588 AK Gas Development Study Ch 1/SLA02 -- AR 07594 Electronic Permitting Initiative FY05 Total $ $ $ 113,700 $ (245,100) $ 8,300 $ 500 $ 20,000 $ 4,010,300 $ 1 00,000 $ 160,000 $ 4,270,300 A $ 2,923,200 $ 2,768,300 $ 3,317,300 $ 4,336,200 $ 4,162,900 $ 4,270,300 INumbers & Language I Change Detail - FY 2005 Operating Budget - Conf Comm Structure Agency: Department of Administration Appropriation: Alaska Oil and Gas Conservation Commission Allocation: Alaska Oil and Gas Conservation Commission Transaction Title FY04 Conference Committee 1002 Fed Rcpts 1162 AOGCC Rct 119.9 4,112.9 Underground Injection Control Grant Adjustment Deadhorse Office/Bunkhouse Lease Costs Changes to Retirement and Other Personal Services Rates 1002 Fed Rcpts 1162 AOGCC Rct Staff Reduction and Related Expenses 1162 AOGCC Rct 5.7 113.7 -245.1 FY05 Non-Covereds Health Insurance 1002 Fed Rcpts 1162 AOGCC Rct FY 05 Bargaining Unit Contract Terms: Supervisory Unit 1162 AOGCC Rct Page: 35 Trans Total Personal Lands! Type Expenditure Services Travel Contractual Commodities Equipment Bldgs Grants Mise PFT PPT Tmp * * * * * FY04 - Management Plan * * * * * ConfCom 4,232.8 2,763.5 214.0 1,148.6 35.6 71.1 0.0 0.0 0.0 27 0 * * * * * Changes from FY04 - Management Plan to FY05 - Governor Amended * * * * * LIT 0.0 14.3 0.0 -14.3 0.0 0.0 0.0 0.0 0.0 0 0 0 LIT 0.0 0.0 -26.8 26.8 0.0 0.0 0.0 0.0 0.0 0 0 0 SalAdj 119.4 119.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 Dec -245.1 -219.8 0.0 -9.0 -4.8 -11.5 0.0 0.0 0.0 -3 0 0 * * * * * Changes from FY05 - Governor Amended to Canf Com + Operating in SB283 * * * * * ~ SalAdj 8.7 8.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 SalAdj 0.5 0.5 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0 0 0 ~ 0.4 8.3 0.5 L~~ 7Ú«UeU ÐWi4i<m 5/27/2004 5:22:48 PM INumbers & Language I Allocation Detail - FY 2005 Operating Budget - Conf Comm Structure Agency: Department of Administration Appropriation: Allocation: Alaska Oil and Gas Conservation Commission Alaska Oil and Gas Conservation Commission 04MgtPln Gov Amd CC+SB283 Total Objects of Expenditure: Personal SelîlÏces Travel Contractual Commodities Equipment Lands/Buildings Grants, Claims Miscellaneous Fundinq Sources: F 1002 Fed Rcpts o 1162 AOGCC Rct Page: 61 04MQtPln to CC+SB283 Gov Amd to CC+SB283 4,232.8 4,107.1 0.2 % 4,116.3 -2.8 % -116.5 9.2 -" 2,763.5 2,677.4 2,686.6 -76.9 -2.8 % 9.2 0.3 % 214.0 187.2 187.2 -26.8 -12.5 % 0.0 1,148.6 1,152.1 1,152.1 3.5 0.3 % 0.0 35.6 30.8 30.8 -4.8 -13.5 % 0.0 71.1 59.6 59.6 -11.5 -16.2 % 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 119.9 4,112.9 125.6 3,981. 5 126.0 3,990.3 0.2 % 6.1 -122.6 5.1 % 0.4 8.8 0.3 % -3.0 % '~ '¿~?Ú1aHee Z>~ 5/27/20045:34:10 PM Allocation Detail - FY 2005 Operating Budget - Conf Comm Structure INumbers & Language I Agency: Department of Administration Appropriation: Allocation: Alaska Oil and Gas Conservation Commission Alaska Oil and Gas Conservation Commission 04MgtPln Gov Amd CC+S8283 04MgtPln to CC+S8283 Gov Amd to CC+SB283 Positions: Perm Full lime 27 24 24 -3 -11.1 % 0 Perm Part lime 1 1 1 0 0 Temporary 0 0 0 0 0 Fundinq Summary: General Funds 0.0 0.0 0.0 0.0 0.0 Federal Receipts 119.9 125.6 126.0 6.1 5.1 % 0.4 0.3 % Other Funds 4,112.9 3,981.5 3,990.3 -122.6 -3.0 % 8.8 0.2 % -.~ Page: 62 L~?iHaHa z>~ 5/27/20045:34:10 PM ,~ ) ') FISCAL NOTE STATE OF ALASKA 2004 LEGISLATIVE SESSION Fiscal Note Number: Bill Version: (S) Publish Date: Ch~ 4~ ~L~ 04- 3 SCS CSHB 531 (RES) 5/5/04 Revision Date/Time (Note if correction): Title Shallow Natural Gas Dept. Affected: Administration RDU Oil & Gas Conservation Commission Component Oil & Gas Conservation Commission Sponsor Requester House Resources Committee Sen. Resources Component No. 2010 Expenditures/Revenues (Thousands of Dollars) Note: Amounts do not include inflation unless otherwise noted below. OPERATING EXPENDITURES FY 2005 FY 2006 FY 2007 FY 2008 FY 2009 FY 2010 Personal Services Travel Contractual 20.0 5.0 5.0 5.0 5.0 5.0 Supplies Equipment Land & Structures Grants & Claims Miscellaneous TOTAL OPERATING 20.0 5.0 5.0 5.0 5.0 5.0 ICAPITAL EXPENDITURES ICHANGE IN REVENUES ( FUND SOURCE 1002 Federal Receipts 1003 GF Match 1004 GF 1005 GF/Program Receipts 1037 GF/Mental Health 1162 AOGCC Receipts TOTAL (Thousands of Dollars) 20.0 20.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 5.0 Estimate of any current year (FY2004) cost: 0.0 Mark this box (X) if funding for this bill is included in the Governor's FY 2005 budget proposal: POSITIONS Full-time Part-time Temporary o o o o o o ANALYSIS: (Attach a separate page if necessary) $20.0 for hydrology training and contractual costs. Prepared by: Division John Norman, Chair Alaska Oil & Gas Conservation Commission Ray Matiashowski, Commissioner Department of Administration Phone DatelTime 5/5/04 7:44 AM Date 5/5/2004 Approved by: Agency (Revised 912003 OMS) Page 1 of _1_ JÌ3ill Te·xt for HB 531 - 23rd Legislature ) Page 1 of25 Bill Text ) [üJ ""..,,,,,,,,^ç.~,,~!~~,,,,,~"~,,,,,..,,,~b8,,,\,º~\\, '" " 01:>,';'';/. A,,~ (, . ,.:, .\ , " , ,'" "-:1,\\·,\11,;,;",\,,, .",,', ... ", .. -,;, ' , ...;:.{, ,~H ¡',-II~¡.\II.:..."A,n.~,~,:;·:, . . ;. ,,.,, ,,., , ",,,. :::,'II.WA.¡'..¡;Þ', A.. r:MI,..\,. {.I.,~,l.. .V,)..¡I,~,t.!, ,I,I,I.\I¡,I.I,I,If!;\I, -",f,¡'-.\.(,\_"{II.. ,':.-. . -; :.-. ". ;,<\-, , , ,\ ,(, :, " , ,~,\", , " , .. , " '" , ,;,;/:11,\ lI,).I,I!;)!,-:, -:,,. , ,,1,1... ,..:,..-, .\,,)~ . , " " .-,.. M ,.".;" ,;,;,;"A\ BILL ID: OR 531 00 Enrolled HB 531 01 Relating to natural gas exploration and development and to non conventional gas, and 02 amending the section under which shallow natural gas leases may be issued; and providing for 03 an effective date. 04 05 * Section 1. AS 14.40.365(a) is amended to read: 06 (a) The University of Alaska may select and is entitled to receive the 07 conveyance of not less than 250,000 and not more than 260,000 acres of land 08 conveyed to the state under sec. 6(b) of the Alaska Statehood Act (P.L. 85-508, 72 09 Stat. 339). The Board of Regents of the University of Alaska shall periodically submit 10 a list of selections to the commissioner of natural resources and, if the list of selec 11 contains land within the boundaries of a municipality, the Board of Regents of the 12 University of Alaska shall submit the list to the municipality. The Board of Regents 13 and the commissioner of natural resources shall periodically and jointly submit to the 14 legislature, within 30 days of the beginning of a regular legislative session, a list 0 01 selections of land proposed to be conveyed by the state to the University of Alaska 02 under this section. If the list submitted to the legislature contains land within the 03 boundaries of a municipality, the Board of Regents and the commissioner of natural 04 resources shall provide a copy of the list to the municipality. Each list must contain 05 not more than 25 percent of the total acres of land to which the university is entitled 06 after subtracting previous conveyances under this section, but not less than 25,000 07 acres or the remaining entitlement under this section, whichever is less. A list of 08 selections submitted shall be considered approved for conveyance to the University of 09 Alaska unless the legislature acts to disapprove the list during the legislative sessio 10 during which the list was submitted. If the amount of land to be conveyed exceeds the 11 balance due the university under this section, the university shall set out the land to 12 conveyed in priority order. Land may not be selected if, on the date of its selection 13 the university, it 14 (1) is identified in AS 16.20, AS 41.15.300 - 41.15.330, or AS 41.21 or 15 has been reserved by law from the public domain; 16 (2) is located within a municipality unless the land is vacant, 17 unappropriated, unreserved land; if land included on the list of selections is selected 18 by the municipality with remaining selection rights under AS 29.65 within 120 days of 19 receiving the Board of Regents' list of selections under this subsection, the universit 20 may not select the land unless a binding agreement between the university and the 21 municipality is negotiated to allow the selection; if the municipal selection is 22 disapproved, in whole or in part, the university may select the land, or any available 23 portion of the land, and that selection will relate back to the date of the Board of 24 Regents' list of selections under this subsection and shall have priority over all othe 25 selections or claims made subsequent to that notice; in this paragraph, "vacant, 26 unappropriated, unreserved land" has the meaning given in AS 29.65.130; 27 (3) is land 28 (A) included in a five-year proposed [OIL AND GAS] leasing 29 program under AS 38.05.180(b); or 30 (B) leased under, or for which a lease application is pending 31 under, AS 38.05.180(d) or 38.05.150; 01 (4) is subject to 02 (A) an oil, gas, or coal lease, or coal prospecting permit; 03 (B) a mining claim, offshore prospecting permit, a prospecting 04 site, an upland mining lease, or a mining leasehold location; 05 (5) is necessary to carry out the purpose of an interagency land 06 management agreement; or 07 (6) is subject to conveyance under a land exchange or land settlement 08 agreement. 09 * Sec. 2. AS 14.40.365(e) is amended to read: 10 (e) The list of selections of land submitted to the legislature may not include a http://www.legis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 2 of 2) 11 land selection made b~ le University of Alaska under 3 section if the commissioner 12 of natural resources determines in writing that the proposed selection 13 (1) includes land that the commissioner, in ,consultation with the 14 commissioner of fish and game, determines has demonstrated value to the public as a 15 habitat area that is especially critical to the perpetuation of fish or wildlife; 16 (2) includes land for which, at the time of its selection under this 17 section, a municipality has made a selection under AS 29.65 unless the land selection 18 is, at a later date, rejected by the commissioner of natural resources or relinquished 19 the municipality; 20 (3) includes land that the commissioner reasonably believes may be 21 selected by a newly formed municipality under AS 29.65.030, but the commissioner 22 may not withhold selection under this paragraph for more than three years after the 23 municipality's incorporation; 24 (4) includes land within the boundaries of a municipality, the 25 municipality has a remaining entitlement under AS 29.65, and the municipality selects 26 the land under AS 29.65 within 120 days after receipt by the municipality of the Board 27 of Regents' list of selections under (a) of this section; 28 (5) includes land that, at the time of its selection under this section, 29 (A) is subject to an [OIL AND GAS] exploration license 30 issued under AS 38.05.131 - 38.05.134; or 31 (B) the commissioner reasonably believes will be made part of 01 an [OIL AND GAS] exploration license issued under AS 38.05.131 - 02 38.05.134; the commissioner may not refuse to convey title to land to the 03 University of Alaska under this subparagraph for more than two years after its 04 first selection by the University of Alaska; or 05 (6) includes land the commissioner of natural resources reasonably 06 believes would not be in the best interests of the state to convey outside of state 07 ownership. 08 * Sec. 3. AS 19.40.200(b) is amended to read: 09 (b) The prohibition on disposal of state land under (a) of this section does not 10 apply to a disposal 11 (1) to a licensed public utility or a licensed common carrier under 12 AS 38.05.810(e); 13 (2) for the reauthorization of leases that were in effect on January 1, 14 1994, for nonresidential purposes within the following development nodes: 15 (A) Coldfoot: 16 Township 28 North, Range 12 West, Fairbanks Meridian 17 Sections 3 - 4 18 Sections 9 - 10 19 Sections 15 - 16 20 Sections 20 - 22 21 (B) Yukon River Crossing: 22 Township 12 North, Range 10 West, Fairbanks Meridian 23 Sections 6 - 7 24 Township 12 North, Range 11 West, Fairbanks Meridian 25 Sections 1 - 2 26 Section 12 27 Township 13 North, Range 10 West, Fairbanks Meridian 28 Sections 29 - 32 29 Township 13 North, Range 11 West, Fairbanks Meridian 30 Section 22 31 Sections 25 - 27 01 Sections 34 - 36 02 (3) for nonresidential development within the following development 03 nodes: 04 (A) Deadhorse: 05 Township 10 North, Range 14 East, Umiat Meridian 06 Township 10 North, Range 15 East, Umiat Meridian 07 Section 8 08 Sections 17 - 20 09 Section 30 10 (B) Coldfoot: 11 Township 28 North, Range 12 West, Fairbanks Meridian http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 -Bill Tèxt for HB 531 - 23rd Legislature 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 ) i}ions 3 - 4 St::ctions 9 - 10 Sections 15 - 16 Sections 20 - 22 Township 29 North, Range 12 West, Fairbanks Meridian Sections 23 - 27 Sections 34 - 35 (C) Franklin Bluffs: Township 4 North, Range 14 East, umiat Meridian Sections 3 - 4 Sections 9 - 10 Sections 15 - 16 (D) Happy Valley: Township 3 South, Range 14 East, umiat Meridian Sections 19 - 20 Sections 29 - 30 (E) Yukon River Crossing: Township 12 North, Range 10 West, Fairbanks Meridian Sections 6 - 7 Township 12 North, Range 11 West, Fairbanks Meridian Sections 1 - 2 Section 12 Township 13 North, Range 10 West, Fairbanks Meridian Sections 29 - 32 Township 13 North, Range 11 West, Fairbanks Meridian Section 22 Sections 25 - 27 Sections 34 - 36; or (4) necessary for (A) an oil and gas lease or gas only lease under AS 38.05.180; (B) exploration, development, production, or transportation of oil and gas north of 68 degrees north latitude; or (C) a state lease or materials sale for (i) exploration, development, production, or transportation of oil ~r [AND] gas; (ii) reconstruction or maintenance of state highways; or (iii) construction or maintenance of airports. * Sec. 4. AS 31.05.030(j) is amended to read: (j) For exploration and development operations involvinq nonconventional qas, the commission (l) may not (A) issue a pe~it to drill under this chapter if the well would be used to produce qas from an aquifer that serves as a source of water for human consumption or aqricultural purposes unless the commission dete~ines that the well will not adversely affect the aquifer as a source of water for human consumption or agricultural purposes; or (B) allow injection of produced water except at depths below known sources of water for human consumption or aqricultura~ purposes; (2) shall (A) requlate hydraulic fracturing in nonconventional qas wells to assure protection of drinkinq water quality; (B) requlate the disposal of wastes produced from the operations unless the disposal is otherwise subject to requlation by the Department of Environmental Conservation or the United States Environmental Protection AqencYL (C) for the purposes of AS 46.04.030 (b), [THE COMMISSION SHALL] determine whether a well drilled for nonconventional [SHALLOW NATURAL] gas may penetrate a formation capable of flowing oil and, if so, whether the volume of oil encountered of such quantities that an oil discharge prevention and contingency plan required; and ~_as a condition of approval of a pe~it to drill a well for http://www.legis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 Page 3 of 25 will be will be 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 4 of 25 13 produ~tion orpr~ :tion testing of coal b~d rneth , require the 14 operator to ciesigIl éUld impl~ment a wat~rwell test1ng program to provide 15 baf3~~_:i:!!~_Clél1:a on water quality and quantity; the cOmmission shall make 16 theref:,mltsofthe water",~l~ t(3stiI1g progréll11 aYélilélþle to the public . 17 * Sec. 5. AS 31.05.060(c) is amended to read: 18 (c) Notwithstanding the requirements of (a) and (b) of this section that relate 19 to fixing a date for a hearing and causing notice of the hearing to be given, for an 20 action under this chapter that involves the exploration for or development of 21 nOIlc::onventional [SHALLOW NATURAL] gas and that has application to a single 22 well or a single field, upon the request of a lessee or operator, the commission may, 23 where operations might be unduly delayed, approve a variance from the commission's 24 regulations that apply to the well or field without providing notice and opportunity to 25 be heard. In the exercise of its authority to issue the variance, 26 (1) the commission may approve the variance if 27 (A) the approval provides at least an equally effective means of 28 accomplishing the requirement set out in the commission's regulation; or 29 (B) the commission determines that the request is more 30 appropriate to the proposed operation than compliance with the requirement of 31 the regulation; and 01 (2) the terms of the approval of the variance may include exempting 02 the lessee or operator from a requirement of a regulation if the commission determines 03 that the requirement is not necessary or not suited to the well or field taking into 04 consideration 05 (A) the nature of the operation involved; 06 (B) the characteristics of the well or field for which the 07 variance is sought; and 08 (C) the reasonably anticipated risks of the exemption from the 09 requirement to human safety and the environment. 10 * Sec. 6. AS 31.05.170 is amended by adding a new paragraph to read: 11 (16) "nonconventional gas" has the meaning given in AS 38.05.965. 12 * Sec. 7. AS 36.30.850(b) (25) is amended to read: 13 (25) acquisition of confidential seismic survey data necessary for pre- 14 sale oil and gas lease orgél~()J:l~Y_:Leél::;~ analyses under AS 38.05.180; 15 * Sec. 8. AS 36.30.850(b) (33) is amended to read: 16 (33) contracts between the Department of Natural Resources and 17 contractors qualified to evaluate hydrocarbon development, production, transportation, 18 and economics, to assist the commissioner of natural resources in evaluating 19 applications for [OIL AND GAS] royalty increases or decreases or other [OIL AND 20 GAS] royalty adjustments, and evaluating the related financial and technical data, 21 entered into under AS 38.05.180(j); 22 * Sec. 9. AS 38.04.065(i) is amended to read: 23 (i) An oil and gas lease sale ()J;.9§lf;()Il::LY lease sale is not subject to this 24 section. oil and gas lease sales élI.J:c:igas oIllylease sales are subject to the planning 25 process established under AS 38.05.180. 26 * Sec. 10. AS 38.05.035(e) is amended to read: 27 (e) Upon a written finding that the interests of the state will be best served, t 28 director may, with the consent of the commissioner, approve contracts for the sale, 29 lease, or other disposal of available land, resources, property, or interests in them. 30 approving a contract under this subsection, the director need only prepare a single 31 written finding. In addition to the conditions and limitations imposed by law, the 01 director may impose additional conditions or limitations in the contracts as the direct 02 determines, with the consent of the commissioner, will best serve the interests of the 03 state. The preparation and issuance of the written finding by the director are subject 04 the following: 05 (1) with the consent of the commissioner and subject to the director's 06 discretion, for a specific proposed disposal of available land, resources, or property, 07 of an interest in them, the director, in the written finding, 08 (A) shall establish the scope of the administrative review on 09 which the director's determination is based, and the scope of the written 10 finding supporting that determination; the scope of the administrative review 11 and finding may address only reasonably foreseeable, significant effects of the 12 uses proposed to be authorized by the disposal; 13 (B) may limit the scope of an administrative review and finding http://wwwJegis.state.ak.uslbasis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 Bill Te'xt for HB 531 - 23rd Legislature 14 for a proposed ,,}osal to ), 15 (~) applicable statutes and regulatlons; 16 (ii) the facts pertaining to the land, resources, or 17 property, or interest in them, that the director finds are material to the 18 determination and that are known to the director or knowledge of which 19 is made available to the director during the administrative review; and 20 (iii) issues that, based on the statutes and regulations 21 referred to in (i) of this subparagraph, on the facts as described in (ii) 22 this subparagraph, and on the nature of the uses sought to be authorized 23 by the disposal, the director finds are material to the determination of 24 whether the proposed disposal will best serve the interests of the state; 25 and 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 Page 5 of 25 of (C) may, if the project for which the proposed disposal is sought is a multiphased development, limit the scope of an administrative review and finding for the proposed disposal to the applicable statutes and regulations, facts, and issues identified in (B) (i) - (iii) of this paragraph pertain solely to the disposal phase of the project when (i) the only uses to be authorized by the proposed disposal are part of that phase; (ii) the disposal is ª [AN OIL AND GAS] disposal of oil and qas, or of qas only, and, before the next phase of the project may proceed, public notice and the opportunity to comment are provided under regulations adopted by the department unless the project is subject to a consistency review under AS 46.40 and public notice and the opportunity to comment are provided under AS 46.40.096(c); (iii) the department's approval is required before the next phase of the project may proceed; and (iv) the department describes its reasons for a decision that to phase; (2) the director shall discuss in the written finding prepared and issued under this subsection the reasons that each of the following was not material to the director's determination that the interests of the state will be best served: (A) facts pertaining to the land, resources, or property, or an interest in them other than those that the director finds material under (1) (B) (ii of this subsection; and (B) issues based on the statutes and regulations referred to in (1) (B) (i) of this subsection and on the facts described in (1) (B) (ii) of this subsection; (3) a written finding for an oil and gas lease sale or qas only lease sale under AS 38.05.180 is subject to (g) of this section; (4) a contract for the sale, lease, or other disposal of available land or an interest in land is not legally binding on the state until the commissioner approves the contract, but if the appraised value is not greater than $50,000 in the case of the ,.sale of land or an interest in land, or $5,000 in the case of the annual rental of land interest in land, the director may execute the contract without the approval of the commissioner; (5) public notice requirements relating to the sale, lease, or other disposal of available land or an interest in land for oil and gas, or for qas only, proposed to be scheduled in the five-year oil and gas leasing program under AS 38.05.180(b), except for a sale under (6) (F) of this subsection, are as follows: (A) before a public hearing, if held, or in any case not less than 180 days before the sale, lease, or other disposal of available land or an interes in land, the director shall make available to the public a preliminary written finding that states the scope of the review established under (1) (A) of this subsection and includes the applicable statutes and regulations, the material facts and issues in accordance with (1) (B) of this subsection, and information required by (g) of this section, upon which the determination that the sale, lease, or other disposal will serve the best interests of the state will be based; the director shall provide opportunity for public comment on the preliminary written finding for a period of not less than 60 days; (B) after the public comment period for the preliminary written finding and not less than 90 days before the sale, lease, or other disposal of http://www.legis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 6 of 2S 15 available land 0: 1 interest in land for oil and 5 or for gas only, the directo 16 shall make available to the public a final written rinding that states the scope 0 17 the review established under (1) (A) of this subsection and includes the 18 applicable statutes and regulations, the material facts and issues in accordance 19 with (1) of this subsection, and information required by (g) of this section, 20 upon which the determination that the sale, lease, or other disposal will serve 21 the best interests of the state is based; 22 (6) before a public hearing, if held, or in any case not less than 21 days 23 before the sale, lease, or other disposal of available land, property, resources, or 24 interests in them other than a sale, lease, or other disposal of available land or an 25 interest in land for oil and gas or for gas only under (5) of this subsection, the dire 26 shall make available to the public a written finding that, in accordance with (1) of th 27 subsection, sets out the material facts and applicable statutes and regulations and any 28 other information required by statute or regulation to be considered upon which the 29 determination that the sale, lease, or other disposal will best serve the interests of 30 state was based; however, a written finding is not required before the approval of 31 (A) a contract for a negotiated sale authorized under 01 AS 38.05.115; 02 (B) a lease of land for a shore fishery site under AS 38.05.082; 03 (C) a permit or other authorization revocable by the 04 commissioner; 05 (D) a mineral claim located under AS 38.05.195; 06 (E) a mineral lease issued under AS 38.05.205; 07 (F) an exempt oil and gas lease sale ()r gas only lease sale 08 under AS 38.05.180(d) of acreage subject to a best interest finding issued 09 within the previous 10 years or a reoffer oil and gas lease sale ()rgªª()nly 10 lease sale under AS 38.05.180(w) of acreage subject to a best interest finding 11 issued within the previous 10 years, unless the commissioner determines that 12 substantial new information has become available that justifies a supplement to 13 the most recent best interest finding for the exempt oil and gas lease sale or 14 gas on~yleas~sale acreage and for the reoffer oil and gas lease sale or gas 15 ()n:LY~~ª_ª__~__ªª:I:,~ acreage; however, for each oil and gas lease sale orgasol1ly 16 leélseªªle described in this subparagraph, the director shall call for comments 17 from the public; the director's call for public comments must provide 18 opportunity for public comment for a period of not less than 30 days; if the 19 director determines that a supplement to the most recent best interest finding 20 for the acreage is required under this subparagraph, 21 (i) the director shall issue the supplement to the best 22 interest finding not later than 90 days before the sale; 23 (ii) not later than 45 days before the sale, the director 24 shall issue a notice describing the interests to be offered, the location 25 and time of the sale, and the terms and conditions of the sale; and 26 (iii) the supplement has the status of a final written best 27 interest finding for purposes of (i) and (1) of this section; 28 (G) [A SHALLOW GAS LEASE AUTHORIZED UNDER 29 AS 38.05.177 IN AN AREA FOR WHICH LEASING IS AUTHORIZED 30 UNDER AS 38.05.177; 31 (H)] a surface use lease under AS 38.05.255; 01 (H) [(I)] a permit, right-of-way, or easement under 02 AS 38.05.850; 03 (7) the director shall include in 04 (A) a preliminary written finding, if required, a summary of 05 agency and public comments, if any, obtained as a result of contacts with other 06 agencies concerning a proposed disposal or as a result of informal efforts 07 undertaken by the department to solicit public response to a proposed disposal, 08 and the department's preliminary responses to those comments; and 09 (B) the final written finding a summary of agency and public 10 comments received and the department's responses to those comments. 11 * Sec. 11. AS 38.05.035(g) is amended to read: 12 (g) Notwithstanding (e) (1) (A) and (B) of this section, when the director 13 prepares a written finding required under (e) of this section for an oil and gas lease 14 sale ora gas only lease sale scheduled under AS 38.05.180, the director shall consider 15 and discuss http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 ~Bin Text for HB 531 - 23rd Legislature Page 7 0[25 16 (1) in a 1 ~iminary or final written find ') facts that are known to the 17 director at the time of preparation of the finding and that are 18 (A) material to issues that were raised during the period 19 allowed for receipt of public comment, whether or not material to a matter set 20 out in (B) of this paragraph, and within the scope of the administrative review 21 established by the director under (e) (1) of this section; or 22 (B) material to the following matters: 23 (i) property descriptions and locations; 24 (ii) the petroleum potential of the sale area, in general 25 terms; 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 (iii) fish and wildlife species and their habitats in the area; (iv) the current and projected uses in the area, including uses and value of fish and wildlife; (v) the governmental powers to regulate .~e [OIL AND GAS] exploration, development, production, and transportation of oil and qas or of qas only; (vi) the reasonably foreseeable cumulative effects of [OIL AND GAS] exploration, development, production, and transportation for oil and qas or for qas only on the sale area, including effects on subsistence uses, fish and wildlife habitat and populations and their uses, and historic and cultural resources; (vii) lease stipulations and mitigation measures, including any measures to prevent and mitigate releases of oil and hazardous substances, to be included in the leases, and a discussion of the protections offered by these measures; (viii) the method or methods most likely to be used to transport oil or gas from the lease sale area, and the advantages, disadvantages, and relative risks of each; (ix) the reasonably foreseeable fiscal effects of the lease sale and the subsequent activity on the state and affected municipalities and communities, including the explicit and implicit subsidies associated with the lease sale, if any; (x) the reasonably foreseeable effects of [OIL AND GAS] exploration, development, production, and transportation involvinq oil and qas or qas only on municipalities and communities within or adjacent to the lease sale area; and (xi) the bidding method or methods adopted by the commissioner under AS 38.05.180; and (2) the basis for the director's preliminary or final finding, as applicable, that, on balance, leasing the area would be in the state's best interest. * Sec. 12. AS 38.05.036(a) is amended to read: (a) The department may conduct audits regarding royalty and net profits under oil and gas contracts, agreements, or leases under this chapter and regarding costs related to [OIL AND GAS] exploration licenses entered into under AS 38.05.131 - g8.05.134 and exploration incentive credits under this chapter or under AS 41.09. For purposes of audit under this section, (1) the department may examine the books, papers, records, or memoranda of a person regarding matters related to the audit; and (2) the records and premises where a business is conducted shall be open at all reasonable times for inspection by the department. * Sec. 13. AS 38.05.127(e) is amended to read: (e) The establishment of easements or rights-of-way for oil and gas, qas only, and mineral leases under (a) of this section need not be made until the leases are read to be developed. * Sec. 14. AS 38.05.131(a) is amended to read: (a) Unless specifically provided otherwise in AS 38.05.132 - 38.05.134, the provisions of AS 38.05.005 - 38.05.037, 38.05.140(f), 38.05.180, 38.05.182 - 38.05.184, and 38.05.920 - 38.05.990 apply to the issuance of [OIL AND GAS] exploration licenses and leases for oil and qas, or for qas only, as appropriate, under AS 38.05.132 - 38.05.134. * Sec. 15. AS 38.05.132(a) is amended to (a) To encourage exploration for read: oil and gas on state land, the commissioner http://www.legis.state.ak.uslbasis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for lIB 531 - 23rd Legislature Page 8 of 25 17 may issue [OIL AND GA, ~xploration licenses. The com sioner may limit the 18 exploration lic~nses under AS 38.05.132 - 38.05.134 to exploratioIl for and 19 recovery of gaso!l!Yu. The commissioner may not issue an exploration license on 20 land that is helclunder an exist:i.!lgcoal lease entered into under AS 38.05.150 that 21 h.as a.n active permit for exploratioJ:l__Q}::'_1.1liI1ing unless the licensee under this 22 subsection is also the lessee under AS 38.05.150 of that land. 23 * Sec. 16. AS 38.05.132(b) is amended to read: 24 (b) An [OIL AND GAS] exploration license issued under this section gives 25 the licensee 26 (1) the exclusive right to explore, for a term not to exceed 10 years, 27 [FOR DEPOSITS OF OIL AND GAS] on unleased state land described in the 28 exploration licensefo:rclepositso:f oila.ndgas, or for deposits of gas only, as 29 appropriate, unless the exploration license is terminated under (d) (1) of this section 30 or the land is earlier relinquished, removed, or deleted under (d) (2) of this section; 31 (2) unless the exploration license is terminated under (d) (1) of this 01 section, the option to convert the exploration license for all or part of the state Ian 02 except the land that is deleted or removed from the land described in the exploration 03 license under (d) (2) of this section, into an oil and gas lease, or a gas lease only, a 04 appropriélte, upon fulfillment of the work commitments contained in the exploration 05 license. 06 * Sec. 17. AS 38.05.132(c) is amended to read: 07 (c) An exploration license awarded under this section 08 (1) is not subject to the acreage limitations imposed by 09 AS 38.05.140(c) or 38.05.180(m); 10 (2) may cover, subject to the maximum acreage limitation on 11 exploration licenses by one licensee under AS 38.05.131(e), an area of not less than 12 10,000 acres and not more than 500,000 acres, that must be reasonably compact and 13 contiguous; 14 (3) must be conditioned upon an obligation to perform a specified 15 work commitment, in total for the term of the license, expressed in dollars of direct 16 exploration expenditures; the specified work commitment 17 (A) may include a provision that adjusts the total amount of 18 work commitment, expressed in dollars of direct exploration expenditures, to 19 account for inflation; 20 (B) must include a requirement that the licensee complete at 21 least 25 percent of the licensee's total specified work commitment by the fourth 22 anniversary of the effective date of the issuance of the [OIL AND GAS] 23 exploration license; 24 (4) must be conditioned upon the posting of a bond or other security 25 acceptable to the commissioner, in favor of the state and subject to the following 26 requirements: 27 (A) the bond or other security must be renewed annually; 28 (B) the annual bond or other security shall be calculated as the 29 entire work commitment expressed in dollars, less the cumulative direct 30 exploration expenditures of the licensee as of the last day of the most recent 31 project year, divided by the number of years remaining in the term of the 01 exploration license; 02 (5) is subject to an annual review and revocation if the commissioner 03 determines that the licensee has failed to provide or maintain in effect the bond or 04 other security required by (4) of this subsection; 05 (6) must be conditioned upon the licensee's payment to the state of a 06 nonrefundable [OIL AND GAS] exploration license fee of $1 for each acre of land or 07 fraction of each acre that is subject to the exploration license; and 08 (7) must be conditioned upon an agreement that exploration 09 expenditures are subject to audit by the commissioner. 10 * Sec. 18. AS 38.05.132(f) is amended to read: 11 (f) In this section, 12 (1) "direct exploration expenditure" means cash expenses undertaken 13 in performance of a specified work commitment under the provisions of AS 38.05.131 14 - 38.05.134 and necessarily incurred by the licensee in the permitting, mobilization, 15 conducting, demobilization, and evaluation of geophysical and geological surveys, or 16 the drilling, logging, coring, testing, and evaluation of oil and gas c>_:t::_gªªoI1ly wells 17 the term http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 Bill Téxt for HB 531 - 23rd Legislature Page 90f25 18 (A)}udes direct labor costs, incl )ng the cost of benefits, 19 for employees diLectly associated with the work cummitment programs, the 20 cost of renting or leasing equipment from parties not affiliated with the 21 licensee, the reasonable costs of maintaining and operating equipment, 22 payments to consultants and independent contractors not affiliated with the 23 licensee, and costs of materials and supplies; 24 (B) does not include noncash expenses such as depreciation 25 and reserves, interest or other costs of borrowed funds, return on investment, 26 overhead, insurance or bond premiums, or any other expense that is 27 unreasonable or that the licensee has not incurred to satisfy the licensee's work 28 commitment; 29 (2) "work commitment" includes the drilling of one or more 30 exploration wells or the gathering of data from activities described in (1) of this 31 subsection, or both. 01 * Sec. 19. AS 38.05.133(a) is amended to read: 02 (a) The procedures in this section apply to the issuance of an [OIL AND GAS] 03 exploration license under AS 38.05.132. 04 * Sec. 20. AS 38.05.133(f) is amended to read: 05 (f) After considering proposals not rejected under (d) of this section and public 06 comment on those proposals, the commissioner shall issue a written finding 07 addressing all matters set out in AS 38.05.035(e) and (g), except for 08 AS 38.05.035(g) (1) (B) (xi). If the finding concludes that the state's best interests 09 would be served by issuing an [OIL AND GAS] exploration license, the finding must 10 (1) describe the limitations, stipulations, conditions, or changes from the initiating 11 proposal or competing proposals that are required to make the issuance of the 12 exploration license conform to the best interests of the state, and (2) if only one 13 proposal was submitted, identify the prospective licensee whom the commissioner 14 finds should be issued the exploration license. The commissioner shall attach to the 15 finding a copy of the exploration license to be issued and the form of lease that will 16 used for any portion of the exploration license area subsequently converted to ª [AN 17 OIL AND GAS] lease under AS 38.05.134. 18 * Sec. 21. AS 38.05.133(h) is amended to read: 19 (h) If competing proposals are submitted, and the commissioner's finding 20 under (f) of this section concludes that an [OIL AND GAS] exploration license should 21 be issued, the commissioner shall issue a request for competitive sealed bids, under 22 procedures adopted by the commissioner by regulation, to determine which 23 prospective licensee should be issued the exploration license. The finding provided to 24 the prospective licensees and the public under (f) of this section must contain notice 25 that (1) the commissioner intends to request competitive sealed bids, (2) a prospective 26 licensee who intends to participate in the bidding must notify the commissioner in 27 writing by the date specified in the notice, and (3) a prospective licensee's notice of 28 intent to participate in the bidding constitutes acceptance of issuance of the 29 exploration license, as limited or conditioned by the terms contained in the finding an 30 by the exploration license to be issued and the form of lease to be used that have been 31 attached to that finding, if the prospective li~ensee is the successful bidder. The 01 successful bidder is the prospective licensee who submits the highest bid in terms of 02 the minimum work commitment dollar amount. 03 * Sec. 22. AS 38.05.134 is amended to read: 04 Sec. 38.05.134. Conversion to lease. If the licensee requests and the 05 commissioner determines that the work commitment obligation set out in an [OIL 06 AND GAS] exploration license issued under AS 38.05.132 has been met, the 07 commissioner shall convert to one or more [OIL AND GAS] leases all or part, as the 08 licensee may indicate, of the area described in the exploration license that remains 09 after the relinquishments, removals, or deletions required by AS 38.05.132(d) (2). A 10 lease issued under this section 11 (1) is subject to the acreage limitations imposed by AS 38.05.140(c); 12 (2) is subject to AS 38.05.180 (j) - (m), (0) - (u), and (x) - (z); 13 (3) must be conditioned upon a royalty in amount or value of not less 14 than 12.5 percent of production, except that the lessee who, proceeding under 15 AS 38.05.131 - 38.05.134, under a lease issued in the Cook Inlet sedimentary basin 16 who is the first to file with the commissioner a nonconfidential sworn statement 17 claiming to be the first to have drilled a well discovering oil or gas in a previously 18 undiscovered oil or gas pool and who is certified by the commissioner within one year http://www.1egis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for lIB 531 - 23rd Legislature Page 10 of25 19 of completion of that 3covery well to have drilled a 11 in that pool that is capabl 20 of producing in paying quantities shall pay a royalty OI five percent on all production 21 of oil or gas from that pool attributable to that lease for a period of 10 years follow 22 the date of discovery of that pool, and thereafter the royalty payable on all productio 23 of oil or gas from the pool attributable to that lease shall be determined and payable 24 specified in the lease; the payment of the five percent royalty under this paragraph is 25 authorized only to a holder of a lease who meets the requirements of 2 6 AS 3 8 . 0 5 . 18 0 (f) (4) ; 27 (4) must include an annual rent of $3 per acre or fraction of an acre 28 initially paid to the state at inception of the lease and payable annually after that u 29 the income to the state from royalty under that lease exceeds the rental income to the 30 state under that lease for that year; and 31 (5) is subject to other conditions and obligations that are specified in 01 the lease. 02 * Sec. 23. AS 38.05.140(a) is amended to read: 03 (a) A person may not take or hold coal leases or permits during the life of coal 04 leases on state land exceeding an aggregate of 92,160 acres, except that a person may 05 apply for coal leases or permits for acreage in addition to 92,160 acres, not exceeding 06 a total of 5,120 additional acres of state land. The additional area applied for shall 07 in multiples of 40 acres, and the application shall contain a statement that the granti 08 of a lease for additional land is necessary for the person to carryon business 09 economically and is in the public interest. On the filing of the application, except a 10 provided by ~ª38 .05.180 (f:fJJ3) oJ:" :3?OS.18.()(gg) [AS 38.05.177 (a) (2) (C) ], the coal 11 deposits in the land covered by the application shall be temporarily set aside and 12 withdrawn from all other forms of disposal provided under AS 38.05.135 - 38.05.181. 13 * Sec. 24. AS 38.05.140(f) is amended to read: 14 (f) The submerged and shoreland lying north of 57 degrees, 30 minutes, North 15 [NORTH] latitude and east of 159 degrees, 49 minutes,w~~:t: [WEST] longitude 16 within the Bristol Bay drainage are designated as the Bristol Bay Fisheries Reserve. 17 Within the Bristol Bay Fisheries Reserve, ~ [NO] surface entry permit to develop an 18 oil or gas lease or an [OIL AND GAS] exploration license under AS 38.05.131 - 19 .:3ª-~.ºS~134 maY:J:}o.t be issued on state owned or controlled land until the legislature by 20 appropriate resolution specifically finds that the entry will not constitute danger to 21 fishery. 22 * Sec. 25. AS 38.05.150(f) is amended to read: 23 (f) Notwithstanding AS 38. OS .132(aL,:3.ª~()5.:J..8()J:f:fJ,. ():r::}ª~()!5 .1?O(gg). 24 [AS 38.05.177] / a lease entered into under this section gives the lessee the right to v 25 or remove methane and other gas held in association with the coal in the land covered 26 by the lease to ensure safe coal mining operations. 27 * Sec. 26. AS 38.05.177(a) is amended to read: 28 (a) The provisions of this section 29 [ (1) ] apply t0l1.0l1.C::9l1.yel1.ti0:I1§l1 gas [, WHETHER METHANE 30 ASSOCIATED WITH AND DERIVED FROM COAL DEPOSITS OR 31 OTHERWISE, FROM A FIELD IF A PART OF THE FIELD IS WITHIN 3/000 01 FEET OF THE SURFACE; AND 02 (2) DO NOT APPLY TO AUTHORIZE LEASE OF 03 (A) LAND 04 (i) THAT IS SUBJECT TO AN OIL AND GAS 05 EXPLORATION LICENSE OR LEASE ISSUED UNDER 06 AS 38.05.131 - 38.05.134; OR 07 (ii) THAT IS LEASED UNDER AS 38.05.180; 08 (B) THE LAND (i) THAT IS PROPOSED TO BE SUBJECT 09 TO AN OIL AND GAS EXPLORATION LICENSE OR LEASE ISSUED 10 UNDER AS 38.05.131 - 38.0'5.134¡ OR (ii) THAT IS DESCRIBED IN AND 11 PART OF A PROPOSED OIL AND GAS LEASING PROGRAM 12 PREPARED UNDER AS 38.05.180(b); HOWEVER, THE COMMISSIONER 13 MAY WAIVE THE LIMITATIONS OF THIS SUBPARAGRAPH; 14 (C) THE LAND THAT IS HELD UNDER A COAL LEASE 15 ENTERED INTO UNDER AS 38.05.150/ UNLESS THE APPLICANT FOR 16 A SHALLOW NATURAL GAS LEASE IS ALSO THE LESSEE UNDER 17 AS 38.05.150 OF THAT LAND; OR 18 (D) THE VALID EXISTING SELECTIONS OF THE 19 ALASKA MENTAL HEALTH TRUST AUTHORITY MADE FOR THE http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB053lZ&session=23 8/9/2004 'Bill Text for HB 531 - 23rd Legislature 20 PURPOSE OF RECO: ·'TUTING THE MENTAL HEALTH TRUS ') 21 ESTABLISHED UNDEKTHE ALASKA MENTAL HEALTH ENABLING 22 ACT, P.L. 84-830, 70 STAT. 709 (1956), THAT BECOME SUBJECT TO 23 MANAGEMENT UNDER AS 38.05.801, OR OF LAND THAT HAS BEEN 24 DESIGNATED BY LAW FOR OR IS SUBJECT TO DESIGNATION FOR 25 CONVEYANCE TO THE ALASKA MENTAL HEALTH TRUST 26 AUTHORITY; HOWEVER, AFTER CONSULTATION WITH THE 27 ALASKA MENTAL HEALTH TRUST AUTHORITY, THE 28 COMMISSIONER MAY WAIVE THE LIMITATIONS OF THIS 29 SUBPARAGRAPH] . 30 * Sec. 27. AS 38.05.177(d) is amended to read: 31 (d) A lease 01 _~L shall be automatically extended if and for so long thereafter as gas 02 is produced in paying quantities from the lease and the lessee continues to meet all 03 requirements of the leaseL_~ [. A] lease issued under this section covering land on 04 which there is a well capable of producing gas in paying quantities does not expire 05 because the lessee fails to produce gas unless the lessee is allowed reasonable time to 06 place the well on a producing status~f [. IF] drilling has commenced on the 07 expiration date of the primary term of the lease and is continued with reasonable 08 diligence, including such operations as redrilling, sidetracking, or other means 09 necessary to reach the originally proposed bottom hole location, the lease is extended 10 for one year and for so long thereafter as gas is produced in paying quantitiesL_ª [. 11 gas lease issued under this section that is subject to termination by reason of cessati 12 of production does not terminate if, within 90 days after production ceases or a longer 13 period determined at the discretion of the director, reworking or drilling operations a 14 commenced on the land under lease and are thereafter conducted with reasonable 15 diligence during the period of nonproduction; on application by the lessee, the 16 director may extend the lease issued under this section for a period of not mor~ 17 than 10 years if the qas produced from the lease is to be used by the lessee solely 18 for its mininq operations; 19 J..2) issued under former (c) of this section before January 1, 200_1.J_ 20 may be extended at the discretion of the director; a lease may be extended under 21 this paraqraph [. IN ADDITION,] upon application by the lesseeL [,] the director 22 may once extend ~þe [A] lease [ISSUED UNDER (c) OF THIS SECTION] for a 23 period of not more than three years; in exercisinq discretion to extend a lease under 24 this paraqraph, the director may not extend the lease unless the director 25 considers 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 Page 11 of25 (A) the extent of the shallow natural qas exploration activity already conducted on the lease and on adjacent areas; (B) the probability that further shallow natural qas exploration activity will occur on the lease and will lead to shallow natural ~s development and production; and (C) whether extension of the lease's primary term will accelerate the eventual production of shallow natural qas from the lease. * Sec. 28. AS 38.05.177(1) is amended to read: (1) A lessee holdinq [OBTAINING] a lease modified under AS 38.0S.180(n) (2) (A) [THIS SECTION] may exercise the rights authorized by this section and the lease. The rights granted by the lease must be exercised in a manner that does not unreasonably interfere with eventual development of other mineral deposits on the land leased. However, in a lease entered into under AS 38.05.150 for land that is already subject to a lease covered [LEASED] under this section, coal may not be mined or extracted by the coal lessee from the coal lease without prior agreement with the lessee holding the lease covered [ISSUED] under this section. * Sec. 29. AS 38.05.180(a) is amended to read: (a) The legislature finds that (1) the people of Alaska have an interest in the development of the state's oil and gas resources to (A) maximize the economic and physical recovery of the resources; (B) maximize competition among parties seeking to explore and develop the resources; (C) maximize use of Alaska's human resources in the development of the resources; http://www.1egis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature 21 (2) it is: :he best interests of the stat( 22 (A) to encourage an assessment of its Ol~ and gas resources 23 to allow the maximum flexibility in the methods of issuing leases to 24 (i) recognize the many varied geographical regions of 25 the state and the different costs of exploring for oil and gas in 26 regions; 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 Page 12 of25 and these (ii) minimize the adverse impact of exploration, development, production, and transportation activity; and (B) to offer acreage for oil and gas leases or for gas only leases, specifically including (i) state acreage that has been the subject of a best interest finding at annual areawide lease sales; and (ii) land in areas that, under (d) of this section, may be leased without having been included in the leasing program prepared and submitted under (b) of this section. * Sec. 30. AS 38.05.180(b) is amended to read: (b) The commissioner shall biennially prepare and, between the first and the 15th day of the first regular session of each legislature, notify the legislature of th availability of, a five-year proposed oil and gas leasing program consisting of a schedule of proposed lease sales and specifying as precisely as practicable the locatio of tracts proposed to be offered for oil and gas leasing orf():r:l~asing()f gas only during the calendar year in which the proposed program is made available to the legislature and the following four calendar years. * Sec. 31. AS 38.05.180(c) is amended to read: (c) Except as provided in (d) and (w) of this section, an oil and gas lease sale or gas only ~eªsesale may not be held unless it was included in the proposed leasing programs submitted to the legislature during the two calendar years preceding the year in which the sale is held. A lease sale,yih~th~r for" oil aIlc1gasor for gas only I may not be held before the date it is scheduled in the proposed oil and gas leasing program * Sec. 32. AS 38.05.180(d) is amended to read: (d) The commissioner (1) may annually offer leases for oil and gas 0:r ~eªl3esforgal3 only [LEASES] of the acreage described in AS 38.05.035(e) (6) (F); (2) may issue [OIL AND GAS] leases in an area that has not been included in a leasing program prepared, in accordance with (b) of this section, if the land to be leased (A) was previously subject to a valid state ().i).é:lJ:lCl9é:lª- l~a:;;~la valid st.a't:.~ gasleé:l::;e, or a va:Lici federal oil and gas lease; (B) is contiguous to land already under state, federal, or private lease and the commissioner makes a written finding, after hearing, that leasing of the land would result in a substantial probability of early evaluation and development of the land to be leased; (C) is adjacent to land owned or controlled by another party on which a discovery of commercial quantities of oil or gas has been made, and the commissioner finds, after hearing, that there is a reasonable probability that the land to be leased contains oil or gas in communication with the oil or gas discovered on the land of the other party; (D) is adjacent to land included in the federal five-year Outer Continental Shelf leasing program under 43 U.S.C. 1344, and the commissioner makes a written finding, after hearing, that coordinated or simultaneous leasing with the federal government is in the public interest; or (E) is the subject of an [OIL AND GAS] exploration license issued under AS 38.05.131 - 38.05. 134tþ-ºy,7'~y~r I ittÞ~;L:i.._ç~p:ª~uá:~ª,~~_el_~_ªª- for exp:L()I::élt::i..ºIl fora!l.c:i x.:-ecoyery 0 fHgª:;;ºIlly_,t:hentJ;l~1~ªI3~H:i..131311e<:i under thil3subs~ç't:.iC?IlI3J:lallbe lim:i..tedt()e:xp:Lc>ration for a.lld:r;ec.overyofgas only. * Sec. 33. AS 38.05.180(f) is amended to read: (f) Except as provided by AS 38.05.131 - 38.05.134 [AND 38.05.177], the commissioner may issue oil and gas leases o:rl~ª::;esforgas 0Il:LY on state land to the highest responsible qualified bidder as follows: (1) the commissioner shall issue an oil and gas lease (),:J;:é:lga::; only l~ase, asappr()pr:iélt~1 to the successful bidder determined by competitive bidding under regulations adopted by the commissioner; bidding may be by sealed bid or according to any other bidding procedure the commissioner determines is in the best http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 -Bill Téxt for HB 531 - 23rd Legislature Page 13 of25 22 interests of the sta ) ) 23 (2) whenever, under any of the leasing methods listed in this 24 subsection, a royalty share is reserved to the state, it shall be delivered in pipeline 25 quality and free of all lease or unit expenses, including but not limited to separation 26 cleaning, dehydration, gathering, salt water disposal, and preparation for transportati 27 off the lease or unit area; 28 (3) following a pre-sale analysis, the commissioner may choose at least 29 one of the following leasing methods: 30 (A) a cash bonus bid with a fixed royalty share reserved to the 31 state of not less than 12.5 percent in amount or value of the production 01 removed or sold from the lease; 02 (B) a cash bonus bid with a fixed royalty share reserved to the 03 state of not less than 12.5 percent in amount or value of the production 04 removed or sold from the lease and a fixed share of the net profit derived from 05 the lease of not less than 30 percent reserved to the state; 06 (C) a fixed cash bonus with a royalty share reserved to the state 07 as the bid variable but no less than 12.5 percent in amount or value of the 08 production removed or sold from the lease; 09 (D) a fixed cash bonus with the share of the net profit derived 10 from the lease reserved to the state as the bid variable; 11 (E) a fixed cash bonus with a fixed royalty share reserved to the 12 state of not less than 12.5 percent in amount or value of the production 13 removed or sold from the lease with the share of the net profit derived from the 14 lease reserved to the state as the bid variable; 15 (F) a cash bonus bid with a fixed royalty share reserved to the 16 state based on a sliding scale according to the volume of production or other 17 factor but in no event less than 12.5 percent in amount or value of the 18 production removed or sold from the lease; 19 (G) a fixed cash bonus with a royalty share reserved to the state 20 based on a sliding scale according to the volume of production or other factor 21 as the bid variable but not less than 12.5 percent in amount or value of the 22 production removed or sold from the lease; 23 (4) notwithstanding a requirement in the leasing method chosen of a 24 minimum fixed royalty share, on and after March 3, 1997, the lessee under a lease 25 issued in the Cook Inlet sedimentary basin who is the first to file with the 26 commissioner a nonconfidential sworn statement claiming to be the first to have 27 drilled a well discovering oil or gas in a previously undiscovered oil or gas pool and 28 who is certified by the commissioner within one year of completion of that discovery 29 well to have drilled a well in that pool that is capable of producing in paying quantit 30 shall pay a royalty of five percent on all production of oil or gas from that pool 31 attributable to that lease for a period of 10 years following the date of discovery of 01 pool, and thereafter the royalty payable on all production of oil or gas from the pool 02 attributable to that lease shall be determined and payable as specified in the lease; f 03 purposes of this paragraph, the reduced royalty authorized by this paragraph is subject 04 ~o the following: 05 (A) only one reduction of royalty authorized by this paragraph 06 may be allowed on each lease that qualifies for reduction of royalty under this 07 paragraph; 08 (B) if, under this paragraph, application is made for a royalty 09 reduction for a lease that was entered into before March 3, 1997, the 10 commissioner may approve the application only if, on that date, the lease was a 11 nonproducing lease that was not committed to a unit approved by the 12 commissioner under (m) of this section, that is not part of a unit under (p) or 13 (q) of this section, and that has not been made part of a unit under AS 31.05; 14 (C) if application for a royalty reduction is made under this 15 paragraph for a lease on which a discovery royalty was claimed or may be 16 claimed under the discovery royalty provisions of former AS 38.05.180(a) in 17 effect before May 6, 1969, the commissioner shall disallow the application 18 under this paragraph unless the applicant waives the right to claim the right to 19 a reduced royalty under the discovery royalty provisions of former 20 AS 38.05.180(a) in effect before May 6, 1969; and 21 (D) the commissioner shall adopt regulations setting out the 22 standards, criteria, and definitions of terms that apply to implement the filing http://www.1egis.state.ak.us/basis/ get_ bill_ text.asp?hsid= HB05 31 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 Page 14 of25 of applications j and the review and certifica' 1 of, discovery [OIL AND GAS ROYALTY] certltications under this paragraph; (5) notwithstanding and in lieu of a requirement in the leasing method chosen of a minimum fixed royalty share, or the royalty provision of a lease, for lease unitized as described in (p) of this section, leases subject to an agreement described (s) or (t) of this section, or interests unitized under AS 31.05, the lessee of all or an oil or gas field identified in this section that has been granted approval of a writ plan submitted to the Alaska Oil and Gas Conservation Commission under AS 31.05.030(i) shall, subject to (dd) of this section, pay a royalty of five percent 0 the first 25,000,000 barrels of oil and the first 35,000,000,000 cubic feet of gas produced for sale from that field that occurs in the 10 years following the date on which the production for sale commences; the fields eligible for royalty reduction under this paragraph, all of which are located within the Cook Inlet sedimentary basin, were discovered before January I, 1988, and have been undeveloped or shut in from at least January I, 1988, through December 31, 1997, are (A) Falls Creek; (B) Nicolai Creek; (C) North Fork; (D) Point Starichkof; (E) Redoubt Shoal; and (F) West Foreland; (6) notwithstanding and in lieu of a requirement in the leasing method chosen of a minimum fixed royalty share, or the royalty provision of a lease, for lease unitized as described in (p) of this section, leases subject to an agreement described (s) or (t) of this section, or interests unitized under AS 31.05, the lessee of all or an oil field located offshore in Cook Inlet on which an oil production platform specified in (A), (C), or (E) of this paragraph operates, or the lessee of all or part field located offshore in Cook Inlet and described in (G) of this paragraph, (A) shall pay a royalty of five percent on oil produced from the platform if oil production that equaled or exceeded a volume of 1,200 barrels a day declines to less than that amount for a period of at least one calendar quarter, as certified by the Alaska Oil and Gas Conservation Commission, for as long as the volume of oil produced from the platform remains less than 1,200 barrels a day; the provisions of this subparagraph apply to (i) Dolly; (ii) Grayling; (iii) King Salmon; (iv) Steelhead; and (v) Monopod ; (B) shall pay a royalty calculated under this subparagraph if the volume of oil produced from the platform that was certified by the Alaska oil and Gas Conservation Commission under (A) of this paragraph later increases to 1,200 or more barrels a day and remains at 1,200 or more barrels a day for a period of at least one calendar quarter; until the royalty rate determined under this subparagraph applies, the royalty continues to be calculated under (A) of this paragraph; on and after the first day of the month following the month the increased production exceeds the period specified in this subparagraph, the royalty payable under this subparagraph is (i) for production of at least 1,200 barrels a day but not more than 1,300 barrels a day - seven percent; (ii) for production of more than 1,300 barrels a day but not more than 1,400 barrels a day - 8.5 percent; (iii) for production of more than 1,400 barrels a day but not more than 1,500 barrels a day - 10 percent; and (iv) for production of more than 1,500 barrels a day - 12.5 percent; (C) shall pay a royalty of five percent on oil produced from the platform if oil production that equaled or exceeded a volume of 975 barrels a day declines to less than that amount for a period of at least one calendar quarter, as certified by the Alaska Oil and Gas Conservation Commission, for as long as the volume of oil produced from the platform remains less than 975 barrels a day; the provisions of this subparagraph apply to (i) Baker; http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Têxt for HB 531 - 23rd Legislature 24 ) Dillon; 25 (i{i) XTO.A; and 26 (iv) XTO.C; 27 (D) shall pay a royalty calculated under this subparagraph if the 28 volume of oil produced from the platform that was certified by the Alaska oil 29 and Gas Conservation Commission under (C) of this paragraph later increases 30 to 975 or more barrels a day and remains at 975 or more barrels a day for a 31 period of at least one calendar quarter; until the royalty rate determined under 01 this subparagraph applies, the royalty continues to be calculated under (C) of 02 this paragraph; on and after the first day of the month following the month the 03 increased production exceeds the period specified in this subparagraph, the 04 royalty payable under this subparagraph is 05 (i) for production of at least 975 barrels a day but not 06 more than 1,100 barrels a day - seven percent; 07 (ii) for production of more than 1,100 barrels a day but 08 not more than 1,200 barrels a day - 8.5 percent; 09 (iii) for production of more than 1,200 barrels a day but 10 not more than 1,350 barrels a day - 10 percent; and 11 (iv) for production of more than 1,350 barrels a day - 12 12.5 percent; 13 (E) shall pay a royalty of five percent on oil produced from the 14 platform if oil production that equaled or exceeded a volume of 750 barrels a 15 day declines to less than that amount for a period of at least one calendar 16 quarter, as certified by the Alaska oil and Gas Conservation Commission, for 17 as long as the volume of oil produced from the platform remains less than 750 18 barrels a day; the provisions of this subparagraph apply to 19 (i) Granite Point; 20 (ii) Anna; and 21 (iii) Bruce; 22 (F) shall pay a royalty calculated under this subparagraph if the 23 volume of oil produced from the platform that was certified by the Alaska Oil 24 and Gas Conservation Commission under (E) of this paragraph later increases 25 to 750 or more barrels a day and remains at 750 or more barrels a day for a 26 period of at least one calendar quarter; until the royalty rate determined under 27 this subparagraph applies, the royalty continues to be calculated under (E) of 28 this paragraph; on and after the first day of the month following the month the 29 increased production exceeds the period specified in this subparagraph, the 30 royalty payable under this subparagraph is 31 (i) for production of at least 750 barrels a day but not 01 more than 850 barrels a day - seven percent; 02 (ii) for production of more than 850 barrels a day but 03 not more than 1,000 barrels a day - 8.5 percent; 04 (iii) for production of more than 1,000 barrels a day but 05 not more than 1,200 barrels a day - 10 percent; and 06 (iv) for production of more than 1,200 barrels a day - 07 12.5 percent; 08 (G) shall pay a royalty of five percent on oil produced from the 09 field if oil production that equaled or exceeded a volume of 750 barrels a day 10 declines to less than that amount for a period of at least one calendar quarter, 11 as certified by the Alaska Oil and Gas Conservation Commission, for as long 12 as the volume of oil produced from the field remains less than 750 barrels a 13 day; the provisions of this subparagraph apply to the West McArthur River 14 field; 15 16 17 18 19 20 21 22 23 24 Page 15 of25 ) (H) shall pay a royalty calculated under this subparagraph if the volume of oil produced from the field that was certified by the Alaska Oil and Gas Conservation commission under (G) of this paragraph later increases to 750 or more barrels a day and remains at 750 or more barrels a day for a period of at least one calendar quarter; until the royalty rate determined under this subparagraph applies, the royalty continues to be calculated under (G) of this paragraph; on and after the first day of the month following the month the increased production exceeds the period specified in this subparagraph, the royalty payable under this subparagraph is (i) for production of at least 750 barrels a day but not http://www.legis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 16 of25 25 more than 8~ )arrels a day - seven percent; 26 (il) for production of more than 8~ù barrels a day but 27 not more than 1,000 barrels a day - 8.5 percent; 28 (iii) for production of more than 1,000 barrels a day but 29 not more than 1,200 barrels a day - 10 percent; and 30 (iv) for production of more than 1,200 barrels a day - 31 12.5 percent; and 01 (I) may obtain the benefits of the royalty adjustments set out in 02 (A) - (H) of this paragraph only if the commissioner determines that the 03 reduction in production from the platform or the field is 04 (i) based on the average daily production during the 05 calendar quarter based on reservoir conditions; and 06 (ii) not the result of short-term production declines due 07 to mechanical or other choke-back factors, temporary shutdowns or 08 decreased production due to environmental or facility constraints, or 09 market conditions. 10 * Sec. 34. AS 38.05.180(h) is amended to read: 11 (h) The commissioner may include terms in any [OIL AND GAS] lease 12 imposing a minimum work commitment on the lessee. These terms shall be made 13 public before the sale, and may include appropriate penalty provisions to take effect i 14 the event the lessee does not fulfill the minimum work commitment. If it is 15 demonstrated that a lease has been proven unproductive by actions of adjacent lease 16 holders, the commissioner may set aside a work commitment. The commissioner may 17 waive for a period not to exceed one two-year period any term of a minimum work 18 commitment if the commissioner makes a written finding either that conditions 19 preventing drilling or exploration were beyond the lessee's reasonable ability to 20 foresee or control or that the lessee has demonstrated through good faith efforts an 21 intent and ability to drill or develop the lease during the term of the waiver. 22 * Sec. 35. AS 38.05.180(i) is amended to read: 23 (i) The commissioner may provide for the establishment of an exploration 24 incentive credit system under which a lessee of state land drilling an exploratory well 25 on that land may earn credits based upon the footage drilled and the region in which 26 the well is situated. The commissioner may also provide for credits to be earned by 27 persons performing geophysical work on state land, if that work is performed during 28 the two seasons immediately preceding an announced lease sale and on land included 29 within the sale area and the geophysical information is made public following the sale. 30 Credits may not exceed 50 percent of the cost of the drilling or geophysical work. 31 Credits may be used during a limited period established by the commissioner and may 01 be assigned during that period. Credits may be applied against (1) [OIL AND GAS] 02 royalty and rental payments _~o~()~lél:J::ld. ga::; or f()rgè3J30J:lJ.Y payable to the state or (2) 03 taxes payable under AS 43.55. A credit may not exceed 50 percent of the payment 04 toward which it is being applied. Amounts due the Alaska permanent fund 05 (AS 37.13.010) shall be calculated before the application of credits under this 06 subsection. 07 * Sec. 36. AS 38.05.180(j) is amended to read: 08 (j) The commissioner 09 (1) may provide for modification of royalty on individual leases, leases 10 unitized as described in (p) of this section, leases subject to an agreement described 11 (s) or (t) of this section, or interests unitized under AS 31.05 12 (A) to allow for production from an oil or gas field or pool if 13 (i) the oil or gas field or pool has been sufficiently 14 delineated to the satisfaction of the commissioner; 15 (ii) the field or pool has not previously produced oil or 16 gas for sale; and 17 (iii) oil or gas production from the field or pool would 18 not otherwise be economically feasible; 19 (B) to prolong the economic life of an oil or gas field or pool as 20 per barrel or barrel equivalent costs increase or as the price of oil or gas 21 decreases, and the increase or decrease is sufficient to make future production 22 no longer economically feasible; or 23 (C) to reestablish production of shut-in oil or gas that would 24 not otherwise be economically feasible; 25 (2) may not grant a royalty modification unless the lessee or lessees http://www.legis.state.ak.uslbasis/ get bill text. asp ?hsid= HB05 31 Z&session=23 8/9/2004 · Bill Téxt for HB 531 - 23rd Legislature 26 requesting the chang '~ke a clear and 27 royalty meets the requlrements of this 28 state; 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 Page 17 of25 convincing she )g that a modification of subsection and lS in the best interests of the or decrease or other modification of royalty or other mechanism that shall be and may also be based on other relevant projected ultimate recovery, development (3) shall provide for an increase the state's royalty share by a sliding scale based on a change in the price of oil or gas factors such as a change in production rate, costs, and operating costsL (4) may not grant a royalty reduction for a field or pool (A) under (1) (A) of this subsection if the royalty modification for the field or pool would establish a royalty rate of less than five percent amount or value of the production removed or sold from a lease or leases covering the field or pool; (B) under (1) (B) or (1) (C) of this subsection if the royalty modification for the field or pool would establish a royalty rate of less than three percent in amount or value of the production removed or sold from a lease or leases covering the field or pool; (5) may not grant a royalty reduction under this subsection without including an explicit condition that the royalty reduction is not assignable without prior written approval, which may not be unreasonably withheld, by the commissioner; the commissioner shall, in the preliminary and final findings and determinations, set out the conditions under which the royalty reduction may be assigned; in th (6) shall require the lessee or lessees to submit, with the application for the royalty reduction, financial and technical data that demonstrate that the requirements of this subsection are met; the commissioner (A) may require disclosure of only the financial and technical data related to development, production, and transportation of oil and gas ~~ gas only from the field or pool that are reasonably available to the applicant; and (B) shall keep the data confidential under AS 38.05.035(a) (9) at the request of the lessee or lessees making application for the royalty reduction; the confidential data may be disclosed by the commissioner to legislators and to the legislative auditor and as directed by the chair or vice- chair of the Legislative Budget and Audit Committee to the director of the division of legislative finance, the permanent employees of their respective divisions who are responsible for evaluating a royalty reduction, and to agents or contractors of the legislative auditor or the legislative finance director who are engaged under contract to evaluate the royalty reduction, if they sign an appropriate confidentiality agreement; ( 7 ) ma y (A) require the lessee or lessees making application for the royalty reduction under (1) (A) of this subsection to pay for the services of an independent contractor, selected by the lessee or lessees from a list of qualified consultants compiled by the commissioner, to evaluate hydrocarbon development, production, transportation, and economics and to assist the commissioner in evaluating the application and financial and technical data; if, under this subparagraph, the commissioner requires payment for the services of an independent contractor, the total cost of the services to be paid for by the lessee or lessees may not exceed $150,000 for each application, and the commissioner shall determine the relevant scope of the work to be performed by the contractor; selection of an independent contractor under this subparagraph is not subject to AS 36.30; (B) with the mutual consent of the lessee or lessees making application for the royalty reduction under (1) (B) or (1) (C) of this subsection, request payment for the services of an independent contractor, selected from a list of qualified consultants to evaluate hydrocarbon development, production, transportation, and economics by the commissioner to assist the commissioner in evaluating the application and financial and technical data; if, under this subparagraph, the commissioner requires payment for the services of an independent contractor, the total cost of the services that may be paid for by the lessee or lessees may not exceed $150,000 for each application, and the commissioner shall determine the relevant scope of the work to be performed http://www.legis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for lIB 531 - 23rd Legislature Page 18 of25 27 by the contracto: ;election of an independent co: lctor under this 28 subparagraph is not subject to AS 36.30; 29 (8) shall make and publish a preliminary findings and determination on 30 the royalty reduction application, give reasonable public notice of the preliminary 31 findings and determination, and invite public comment on the preliminary findings 01 and determination during a 30-day period for receipt of public comment; 02 (9) shall offer to appear before the Legislative Budget and Audit 03 Committee, on a day that is not earlier than 10 days and not later than 20 days after 04 giving public notice under (8) of this subsection, to provide the committee a review of 05 the commissioner's preliminary findings and determination on the royalty reduction 06 application and administrative process; if the Legislative Budget and Audit Committee 07 accepts the commissioner's offer, the committee shall give notice of the committee's 08 meeting to all members of the legislature; 09 (10) shall make copies of the preliminary findings and determination 10 available to 11 (A) the presiding officer of each house of the legislature; 12 (B) the chairs of the legislature's standing committees on 13 resources; and 14 (C) the chairs of the legislature's special committees on oil and 15 gas, if any; 16 (11) shall, within 30 days after the close of the public comment period 17 under (8) of this subsection, 18 (A) prepare a summary of the public response to the 19 commissioner's preliminary findings and determination; 20 (B) make a final findings and determination; the 21 commissioner's final findings and determination prepared under this 22 subparagraph regarding a royalty reduction is final and not appealable to the 23 court; 24 (C) transmit a copy of the final findings and determination to 25 the lessee; 26 (D) with the applicant's consent, amend the applicant's lease or 27 unitization agreement consistent with the commissioner's final decision; and 28 (E) make copies of the final findings and determination 29 available to each person who submitted comment under (8) of this subsection 30 and who has filed a request for the copies; 31 (12) is not limited by the provisions of AS 38.05.134(3) or (f) of this 01 section in the commissioner's determination under this subsection. 02 * Sec. 37. AS 38.05.180(1) is amended to read: 03 (1) Subject to the provisions of AS 31.05, the commissioner has discretion to 04 enter into an agreement whereby, with the consent of the lessee, the state's royalty 05 share of [OIL AND GAS] production of oi~ él:I1<.1 9éls or gas oIlly may be stored or 06 retained in storage by the lessee, or the commissioner may enter into an agreement 07 with one or more of the affected field lease holders to trade current royalty productio 08 from a field for a like amount, kind, and quality of future production, on the conditio 09 that the state receives back its stored or traded royalty share during the first half 0 10 estimated field life or no later than 15 years after start of production, whichever is 11 sooner. 12 * Sec. 38. AS 38.05.180(m) is amended to read: 13 (m) An oil and gas lease or a 9éls oIlly leéis~ must cover a reasonably compact 14 area not exceeding 5,760 acres, and may be for a maximum period of 10 years, except 15 that the commissioner may issue a lease for a period not less than five years upon a 16 finding that it is in the best interests of the state. An oil and gas lease shall be 17 automatically extended if and for so long thereafter as oil or gas is produced in payin 18 quantities from the lease or if the lease is committed to a unit approved by the 19 commissioner,élI1.<.1a9ëi.soIlly lease Slìéll~.Þ~éi'll~C::>Inat::~c:ally e:x:te:I1cl~cl Af and for so 2 0 :to:I1gthereélft::~rél~ ,gªsi:=,;p:r()<.1'llc:~cl inpªY~Ilg~ª:I1t:i t~~s;:f:r():LT:lt::l1~:t~_ª_~~_():r .:if tlìe 21 :Leas~is c0JIlJJ.\it::t::~clt()él un~tªpprovecl:bY t::l1~C:::C?IJ:1IIlissioner. A lease issued under 22 this section covering land on which there is a well capable of producing oil or gas in 23 paying quantities does not expire because the lessee fails to produce oil or gas unless 24 the lessee is allowed reasonable time to place the well on a producing status. Upon 25 extension, the commissioner may increase lease rentals so long as the increased rental 26 rate does not exceed 150 percent of the rate for the preceding year. If drilling has 27 commenced on the expiration date of the primary term of the lease and is continued http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 'Bill Text for HB 531 - 23rd Legislature Page 19 of25 28 with reasonable dili ~e, including such operations. ')redrilling, sidetracking, or 29 other means necessary co reach the originally proposea bottom hole location, the lease 30 continues in effect until 90 days after drilling has ceased and for so long thereafter 31 oil or gas is produced in paying quantities. An oil and gas lease or a qas only l~as~ 01 issued under this section which is subject to termination by reason of cessation of 02 production does not terminate if, within 60 days after production ceases, reworking or 03 drilling operations are commenced on the land under lease and are thereafter 04 conducted with reasonable diligence during the period of nonproduction. 05 * Sec. 39. AS 38.05.180(n) is amended to read: 06 (n) The commissioner may establish by regulation that after a well has been 07 plugged and abandoned, the rental rate which was in effect during the year of 08 abandonment is maintained for the remainder of the term. Rental is payable in 09 advance and continues until income to the state from royalty or net profit share 10 exceeds rental income to the state for that year. Under this subsection, 11 ~_ [OIL AND GAS] leases for oil and qas or for qas only shall 12 provide for payment to the state of rental on the following basis: 13 (A) [(1)] for the first year, $1.00 per acre; 14 (B) [(2)] for the second year, $1.50 per acre; 15 (C) [(3)] for the third year, $2.00 per acre; 16 (D) [(4)] for the fourth year, $2.50 per acre; 17 (E) [(5)] for the fifth and following years, $3.00 per acreL 18 (2) if the lessee under a qas only lease demonstrates to the 19 commissioner that the potential resources underlyinq the lease are reasonably 20 estimated to be only nonconventional qas, 21 (A) the rental payment is $1.00 per acre until the lease 22 expires or payinq quantities of conventional oil or qas are discovered 23 underlyinq the lease; and 24 (B) if the nonconventional qas produced will not be in 25 direct competition with qas on which a royalty at a rate of at least 12.5 26 percent is payable, then the royalty share payable to the state on all 27 production of qas from the pool attributable to that lease shall be 6.25 28 percent based upon production delivered in pipeline quality and free of all 29 lease expenses, includinq separation, cleaninq, dehydration, qatherinq, salt 30 water disposal, and preparation for transportation off the lease. 31 * Sec. 40. AS 38.05.180(p) is amended to read: 01 (p) To conserve the natural resources of all or a part of an oil or gas pool, 02 field, or like area, the lessees and their representatives may unite with each other, 0 03 jointly or separately with others, in collectively adopting or operating under a 04 cooperative or a unit plan of development or operation of the pool, field, or like area 05 or a part of it, when determined and certified by the commissioner to be necessary or 06 advisable in the public interest. The commissioner may, with the consent of the 07 holders of leases involved, establish, change, or revoke drilling, producing, and 08 royalty requirements of the leases and adopt regulations with reference to the leases, 09 with like consent on the part of the lessees, in connection with the institution and 10 operation of a cooperative or unit plan as the commissioner determines necessary or 11 .proper to secure the proper protection of the public interest. The commissioner may 12 not reduce royalty on leases in connection with a cooperative or unit plan except as 13 provided in (j) of this section. The commissioner may require a lease [OIL AND 14 GAS LEASES] issued under this section to contain a provision requiring the lessee to 15 operate under a reasonable cooperative or unit plan, and may prescribe a plan under 16 which the lessee must operate. The plan must adequately protect all parties in interes 17 including the state. 18 * Sec. 41. AS 38.05.180 is amended by adding new subsections to read: 19 (ff) The provisions of this section that authorize oil and gas leases also apply 20 to authorize the commissioner to issue leases for the production of gas only, subject t 21 the following: 22 (1) in authorizing and managing leases under this subsection, the terms 23 "oil and gas" or "oil or gas" as they are used in this chapter may be read and applied 24 appropriate as referring to gas only; 25 (2) when a lease is authorized as a gas only lease, the lease does not 26 give the lessee the right to produce oil; if a well drilling for gas under a gas only I 27 authorized by this subsection penetrates a formation capable of producing oil, the 28 owner or operator http://www.1egis.state.ak.us/basis/ get_ bill_ text. asp ?hsid=HB05 31 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature 29 (A) sl _ notify the department and th 30 Conservation Commlssion; and 31 (B) may not conduct further operations in the drilled well until 01 the facility complies with all applicable laws and regulations relating to oil 02 gas exploration and production; however, this subparagraph does not prevent 03 the owner or operator from conducting activities that may be required by the 04 Alaska oil and Gas Conservation Commission to plug, plug-back, or abandon 05 a well; 06 (3) the provisions of this subsection do not apply to authorize a lease 07 for the recovery of nonconventional gas on land that is held under an existing coal 08 lease entered into under AS 38.05.150 that has an active permit for exploration or 09 mining unless the lessee under this subsection is also the lessee under AS 38.05.150 10 that land. 11 ( gg ) 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 Page 20 of 25 ~aska oil and Gas and of For an activity or operation related to the extraction of coal bed methane, (1) for which the department by regulation requires submission and approval of a plan of operations before activities or operations may be undértaken, the director shall, as a condition for determining a bond requested under AS 38.05.130, after notice and an opportunity to be heard, review the plan of operations to determine if use of the owner's land is reasonably necessary to extract the coal bed methane; a bond determined under AS 38.05.130 and this paragraph may, at the discretion of the director, be imposed against a statewide bond that has been posted by the person initiating the request for determination of the bond if the statewide bond remains in effect, and an additional bond is not required; (2) before approving operations for the development of coal bed methane under AS 38.05.134, 38.05.177, or this section, the director shall ensure that the approval is conditioned upon reasonable and appropriate (A) setbacks governing the placement by the operator of compressor stations; setbacks approved under this subparagraph must be determined with reference to the population density and general character of the parcels surrounding the proposed compressor station site; and (B) measures to mitigate the noise of compressors, engines, and other noise generating equipment operated by the operator on the lease or license; measures approved under this subparagraph must be determined with reference to the population density and general character of the parcels surrounding the proposed compressor, engine, or other noise-generating equipment. * Sec. 42. AS 38.05.860(a) is amended to read: (a) The commissioner may require an applicant seeking the sale, lease, or other disposal of land or an interest in land, other than under an oil and gas 1~as~, 9 C>Il}·y_lea.se, or mineral lease, to deposit an amount covering the estimated cost of an appraisal, survey, and other costs necessary to offer the land or interest in land, including advertising. All deposited funds not expended shall be refunded to the applicant. If the land or interest in land is awarded to a person other than the appli making the deposit, the person awarded the land shall pay the total actual cost incurre by the department in making the disposal, and the deposit shall be returned to the original applicant. In lieu of requiring the deposit under this subsection, the commissioner may enter into an agreement with an applicant seeking land or an interest in land requiring the applicant to reimburse the department for costs incurred in the disposal if the applicant is awarded the land or interest in land. * Sec. 43. AS 38.05.860(c) is amended to read: (c) The commissioner shall require each bidder for the competitive leasing of [OIL AND GAS] land:f():r oil andga;;, orforg¿;¡,s OIlly, to submit with each bid a deposit of money equal to 20 percent of the bonus. * Sec. 44. AS 38.05.945(a) is amended to read: (a) This section establishes the requirements for notice given by the department for the following actions: (1) classification or reclassification of state land under AS 38.05.300 and the closing of land to mineral leasing or entry under AS 38.05.185; (2) zoning of land under applicable law; (3) issuance of a (A) preliminary written finding under AS 38.05.035(e) (5) (A) regarding the sale, lease, or disposal of an interest in state land or resources f oil and gas, or for gas only, subject to AS 38.05.180(b); http://www.legis.state.ak.us/basis/get bill text.asp?hsid=HB0531Z&session=23 8/9/2004 "Bill Text for HB 531 - 23rd Legislature 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 Page 21 of25 (B) - )PEALED ) (C)] written finding for the sale, lease, or disposal of an interest in state land or resources under AS 38.05.035(e) (6), except ~ [AN OIL OR GAS] lease sale described in AS 38.05.035(e) (6) (F) for which the director must provide opportunity for public comment under the provisions of that subparagraph; (4) a competitive disposal of an interest in state land or resources after final decision under AS 38.05.035(e); (5) a preliminary finding under AS 38.05.035(e) concerning sites for aquatic farms and related hatcheries; (6) a decision under AS 38.05.132 - 38.05.134 regarding the sale, lease, or disposal of an interest in state land or resources. * Sec. 45. AS 38.05.965 is amended by adding a new paragraph to read: (25) "nonconventional gas" means coal bed methane, gas contained in shales, or gas hydrates. * Sec. 46. AS 38.06.080(2) is amended to read: (2) "state lease" means an oil and gas lease or qas only lease on state land. * Sec. 47. AS 38.35.020(a) is amended to read: (a) Rights-of-way on state land including rights-of-way over, under, along, across, or upon the right-of-way of a public road or highway or the right-of-way of a railroad or other public utility, or across, upon, over, or under a river or other body water or land belonging to or administered by the state may be granted by noncompetitive lease by the commissioner for pipeline purposes for the transportation of oil, products, or natural gas under those conditions prescribed by law or by administrative regulation. Except to the extent authorized by an oil and gas lease~ qas only lease, or an oil and qas or qas only unit agreement approved by the state, no person may engage in any construction or operation of any part of an oil, products, or natural gas pipeline, which in whole or in part is or is proposed to be on state land unless that person has obtained from the commissioner a right-of-way lease of the land under this chapter. * Sec. 48. AS 43.20.072(c) is amended to read: (c) A taxpayer's business income shall be apportioned to this state by multiplying the taxpayer's income determined under (b) of this section by the apportionment factor applicable to the taxpayer among the following factors: (1) the apportionment factor of a taxpayer subject to this section but not engaged in the production of oil and gas, or of gas only, as appropriate, from a lease or property in this state during the tax period is a fraction, the numerator of which is the sum of the property factor under AS 43.19 (Multistate Tax Compact) and the sales factor under (d) of this section for the taxpayer for that tax period, and th denominator of which is two; (2) the apportionment factor of a taxpayer subject to this section but not engaged in the pipeline transportation of oil or gas in this state during the tax period is a fraction, the numerator of which is the sum of the property factor under (e of this section and the extraction factor under (f) of this section for the taxpayer fo tax period, and the denominator of which is two; (3) the apportionment factor of a taxpayer engaged both in the production of oil or gas from a lease or property in this state and in the pipeline transportation of oil or gas in this state during the tax period is a fraction, the numerator of which is the sum of the sales factor under (d) of this section, the proper factor under (e) of this section, and the extraction factor under (f) of this section f the taxpayer for the tax period, and the denominator of which is three. * Sec. 49. AS 43.55.025(a) is amended to read: (a) Subject to the terms and conditions of this section, on oil and gas produced from an oil and qas lease, or on qas produced from a qas only lease, on or after July 1, 2004, a credit against the tax due under this chapter is allowed in an amount equal to (1) 20 percent of the total exploration expenditures that qualify under (b) and (c) of this section, 20 percent of the total exploration expenditures that qual under (b) and (d) of this section, or both, for a total credit that does not exceed 40 percent of the total exploration expenditures; or (2) 40 percent of the total exploration expenditures that qualify under (b) and (e) of this section, for a total production tax credit that does not exceed 40 http://www.1egis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 22 of 25 31 percent of the total ~ ,ified exploration expenditure: 01 * Sec. 50. AS 43.55.900(~) is amended to read: 02 (9) "lease or property" means any right, title, or interest in or the right 03 to produce or recover oil or gas including: 04 (A) a mineral interest; [,] 05 (B) a leasehold interest; [,] 06 (C) a working interest, royalty interest, overriding royalty 07 interest, production payment, net profit interest, or any other interest in a leas 08 concession, joint venture, or other agreement for [OIL AND GAS] exploration, 09 development, or production of oil and gas or of gas only; [,] 10 (D) a working interest, royalty interest, overriding royalty 11 interest, production payment, net profit interest or any other interest in an 12 agreement for unitization or pooling under the provisions of 26 U.S.C. 13 614(b) (3) (Internal Revenue Code) as defined on January 1, 1974; 14 * Sec. 51. AS 46.03.100(f) is amended to read: 15 (f) This section does not apply to discharges of solid or liquid waste material 16 or water discharges from the following activities if the discharge is incidental to the 17 activity and the activity does not produce a discharge from a point source, as that ter 18 is defined in regulations adopted under this chapter, directly into any surface water 0 19 the state: 20 (1) mineral drilling, trenching, ditching, and similar activities; 21 (2) landscaping; 22 (3) water well drillingéiIld [,] geophysical drilling [, OR COAL BED 23 METHANE DRILLING OR OTHER NATURAL GAS DRILLING TO RECOVER 24 GAS FROM A FIELD IF A PART OF THE FIELD IS WITHIN 3,000 FEET OF THE 25 SURFACE]; or 26 (4) drilling, ditching, trenching, and similar activities associated with 27 facility construction and maintenance or with road or other transportation facility 28 construction and maintenance; however, the exemption provided by this paragraph 29 does not relieve a person from obtaining a permit under this section if 30 (A) the drilling, ditching, trenching, or similar activity will 31 involve the removal of the groundwater, stormwater, or wastewater runoff that 01 has accumulated and is present at an excavation site for facility, road, or other 02 transportation construction or maintenance; and 03 (B) a permit is otherwise required by this section. 04 * Sec. 52. AS 46.04.030(b) is amended to read: 05 (b) A person may not cause or permit the operation of a pipeline or an 06 exploration or production facility in the state unless an oil discharge prevention and 07 contingency plan for the pipeline or facility has been approved by the department and 08 the person is in compliance with the plan. This subsection does not apply to an 09 exploration or production facility used solely to explore for or to develop or produce 10 Il<:?IlC:()IlY~Il1;.~<?Ilª:L [SHALLOW NATURAL] gas resources, except that this exemption 11 does not apply if the Alaska oil and Gas Conservation commission determines under 12 AS 31.05.030(j) that 13 (1) a well drilled for Il()_Ilçonventional [SHALLOW NATURAL] gas 14 may penetrate a formation capable of flowing oil; and 15 (2) the volume of oil encountered will be of such quantities that a 16 contingency plan will be required. 17 * Sec. 53. AS 46.04.040(b) is amended to read: 18 (b) A person may not cause or permit the operation of a pipeline or an 19 exploration or production facility in the state unless the person has furnished to the 20 department, and the department has approved, proof of financial ability to respond in 21 damages. Proof of financial responsibility required for 22 (1) a pipeline or an offshore exploration or production facility is 23 $50,000,000 per incident; 24 (2) an onshore production facility is 25 (A) $20,000,000 per incident if the facility produces over 26 10,000 barrels per day of oil; 27 (B) $10,000,000 per incident if the facility produces over 5,000 28 barrels per day but not more than 10,000 barrels per day of oil; 29 (C) $5,000,000 per incident if the facility produces over 2,500 30 barrels per day but not more than 5,000 barrels per day of oil; 31 (D) $1,000,000 per incident if the facility produces 2,500 http://www.legis.state.ak.us/basis/ get bill text. asp ?hsid= HB05 31 Z&session=23 8/9/2004 "Bill Têxt for HB 531 - 23rd Legislature Page 23 of 25 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 01 '\ barrels per day ) less of oil; (3) an ons.uðre exploration facility is (A) $25,000 per incident for a facility used solely to explore for nonconventional [SHALLOW NATURAL] gas by means of drilling a well to explore for ~h~ gas [, WHETHER METHANE ASSOCIATED WITH AND DERIVED FROM COAL DEPOSITS OR OTHERWISE, FROM A FIELD IF A PART OF THE FIELD IS WITHIN 3,000 FEET OF THE SURFACE]; and (B) except as provided by (A) of this paragraph, $1,000,000 per incident. * Sec. 54. AS 46.04.900 is amended by adding a new paragraph to read: (31) "nonconventional gas" has the meaning given in AS 38.05.965. * Sec. 55. AS 46.40.205 is amended to read: Sec. 46.40.205. Consistency deter.minations for certain activities involving nonconventional [SHALLOW NATURAL] gas. (a) When conducted under oversight and regulation of the Alaska oil and Gas Conservation commission and the state's resource agencies, projects for the exploration and development of nonconventional [SHALLOW NATURAL] gas are consistent with the program described in this chapter. Persons responsible for activities subject to this section obtain all required permits and approvals from municipal, state, and federal agencies as otherwise required by law. (b) In this section, "nonconventional [SHALLOW NATURAL] gas" has the meaning given in AS 38.05.965 [AS 46.04.900]. * Sec. 56. AS 46.40.210(12) is amended to read: (12) "uses of state concern" means those land and water uses that would significantly affect the long-term public interest; "uses of state concern" inclu (A) uses of national interest, including the use of resources for the siting of ports and major facilities that contribute to meeting national energy needs, construction and maintenance of navigational facilities and systems, resource development of federal land, and national defense and related security facilities that are dependent upon coastal locations; (B) uses of more than local concern, including those land and water uses that confer significant environmental, social, cultural, or economic benefits or burdens beyond a single coastal resource district; (C) the siting of major energy facilities, activities pursuant to a state oil and qas lease, a state qas only ~ease, or ª federal oil and gas lease, 0 large-scale industrial or commercial development activities that are dependent on a coastal location and that, because of their magnitude or the magnitude of their effect on the economy of the state or the surrounding area, are reasonably likely to present issues of more than local significance; (D) facilities serving statewide or interregional transportation and communication needs; and (E) uses in areas established as state parks or recreational areas under AS 41.21 or as state game refuges, game sanctuaries, or critical habitat areas under AS 16.20. * Sec. 57. The uncodified law of the State of Alaska added by sec. I, ch. 45, SLA 2003, i amended to read: LEGISLATIVE FINDINGS. The legislature finds that (1) [THE DEVELOPMENT OF SHALLOW NATURAL GAS RESOURCES IS IN THE BEST INTERESTS OF THE STATE OF ALASKA; (2)] shallow natural gas is abundant and widespread in Alaska and bears the promise of providing Alaskans, particularly Alaskans living in rural areas, with an inexpensive and clean source of energy if those resources can be economically developed; _t?~_ [(3)] the development of shallow natural gas poses significantly fewer risks and creates substantially less impact to the environment than traditional deep oil and gas projects, which have served as the model for oil and gas industry and environmental regulations to date in Alaska; ill [(4)] the regulatory requirements developed and applied to traditional deep oil and gas projects in Alaska are ill-suited and unduly onerous when applied to shallow natural gas projects, threatening the economic viability of otherwis desirable exploration and development projects; (4) [(5)] there is an immediate state and national need for the development of clean and economical unconventional energy sources, such as shallow ') .! http://www.legis.state.ak.us/basis/get_ bill_text.asp?hsid=HB0531Z&session=23 8/9/2004 Bill Text for HB 531 - 23rd Legislature Page 24 of 25 02 natural gas resources, 03 (5) [(6)] rerorm of existing laws and regulations is needed to remove 04 unnecessary regulatory burdens on the private sector to foster and encourage the 05 development in Alaska of these necessary resources; 06 {§J_ [( 7) ] the legislature is acting in the interest of promoting the active 07 development of such resources, while ensuring that suitable measures are taken to 08 protect human health and safety and the natural environment, 09 (A) to remove impediments to the responsible development of 10 shallow natural gas; and 11 (B) to provide the proper state agencies with clear authority and 12 discretion to adopt regulatory practices appropriate to shallow natural gas 13 exploration and development projects, in recognition of the lower risks posed 14 by such projects to human health and safety and the natural environment [; 15 AND 16 (C) TO RESERVE ALL RIGHTS AND POWERS NOT 17 PREEMPTED BY FEDERAL LAW AND REGULATION IN ORDER TO 18 ASSERT STATE PRIMACY OVER THE REGULATION OF SHALLOW 19 NATURAL GAS] . 20 * Sec. 58. AS 31.05.125, 31.05.170(14); AS 38.0S.177(b), 38.0S.177(c), 38.0S.177(e), 21 38.0S.177(f), 38.0S.177(g), 38.0S.177(h), 38.0S.177(j), 38.0S.177(k), 38.0S.177(m), 22 38.0S.177(n), 38.05.177(0); and AS 46.04.900(25) are repealed. 23 * Sec. 59. The uncodified law of the State of Alaska is amended by adding a new section t 24 read: 25 CERTAIN SHALLOW NATURAL GAS LEASES AND LEASE APPLICATIONS 26 TO BE ADMINISTERED UNDER FORMER LAW. The provisions of AS 38.0S.177(a), 27 (d) (1), and (1), amended by secs. 26 - 28 of this Act, as those provisions read on the day 28 before the effective date of amendment of those subsections, and the provisions of 29 AS 38.05.177 (b), (c), (e) - (h), (j), (k), (m), (n), and (0), repealed by sec. 58 of this Act 30 those provisions read on the day before the effective date of the repeal of those subsections 31 apply to shallow natural gas leases issued under AS 38.05.177 and in effect on December 31, 01 2003. 02 * Sec. 60. The uncodified law of the State of Alaska is amended by adding a new section t 03 read: 04 CONVERSION OF EXISTING SHALLOW NATURAL GAS LEASE 05 APPLICATIONS. (a) The applicant for a shallow natural gas lease under AS 38.05.177 06 whose application was received by the Department of Natural Resources before the effective 07 date of this section may, not later than August 31, 2004, or 60 days after the effective date 08 this Act, whichever is later, convert the application to an exploration license and lease 09 application under AS 38.0S.131(a), as amended by sec. 14 of this Act. An applicant 10 converting an application under this subsection 11 (1) may apply for as few as 3,000 acres, notwithstanding the minimum 12 limitation of acreage set out in AS 38.05.132 (c) (2); 13 (2) shall pay the fee required by AS 38.0S.132(c) (6); 14 (3) is subject to a three-year work commitment in lieu of a work commitment 15 of any other duration required by AS 38.05.132 and, notwithstanding AS 38.0S.132(c) (3), is 16 under an obligation to perform a specified work commitment of $1 per acre per year; and 17 (4) may, subject to (b) of this section, convert an exploration license to a leas 18 under AS 38.05.134, as amended by sec. 22 of this Act. 19 (b) The provisions of AS 38.0S.03S(e) apply to an application made under (a) of this 20 section. 21 (c) For an application made under (a) of this section, the director of the division of 22 lands shall remit to the applicant the application fee paid by the applicant under 2 3 AS 3 8 . 05 . 1 7 7 (b) (2) . 24 * Sec. 61. This Act takes effect immediately under AS 01.10.070(c). Bill Root: , ~isplgy ~m Root' ,~,'I "1"0 Report PrQþlerns with B<:lsislllquiry l"iyeKI'QQ Strçal11s Return tp BasisM(1in Menu (23 rdLegislature) http://www.1egis.state.ak.us/basis/get bill text.asp?hsid=HB0531 Z&session=23 8/9/2004 "Bill Téxt for HB 531 - 23rd Legislature ) Rçtu,r,n,JQ",I/Ggisl,ªtYxG...,I"JmJ.1.ç,...p.ªgç ) Page 25 of 25 http://www.1egis.state.ak.us/basis/get_ bill_ text.asp?hsid=HB0531 Z&session=23 8/9/2004 ) LAWS OF ALASKA 2004 Source CCS HB 375 Chapter No. 158 AN ACT Making appropriations for the operating and loan program expenses of state government, for certain programs, and to capitalize funds; and providing for an effective date. BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF ALASKA: THE ACT FOLLOWS ON PAGE 1 ) ) AN ACT Making appropriations for the operating and loan program expenses of state government, for 2 certain programs, and to capitalize funds; and providing for an effective date. 3 4 (SECTION 1 OF THIS ACT BEGINS ON PAGE 2) -1- CCS HB 375 * Section 1. The following appropriation items are for operating expenditures from the 2 general fund or other funds as set out in section 2 of this Act to the agencies named for the 3 purposes expressed for the fiscal year beginning July 1, 2004 and ending June 30, 2005, 4 unless otherwise indicated. A department-wide, agency-wide, or branch-wide unallocated 5 reduction set out in this section may be allocated among the appropriations made in this 6 section to that department, agency, or branch. 7 It is the intent of the legislature that the administration work with the legislature to: 1) ensure 8 that missions and measures continually align with the organizational structure of departments; 9 2) promote the ultimate goal of supporting effective activities and change; 3) eliminate 10 ineffective programs and activities; and 4) develop mutually agreeable End Results. It is the 11 intent of the legislature that, in addition to the requirements prescribed by AS 37.07.050, each 12 executive branch agency report the following to the legislature, no later than February 1, 13 2005, in a forum to be determined by the legislature: 14 1. Any desired legislative action, including proposed changes to missions and measures. 15 2. A comparison of expected and actual results, including analysis of trends, reasons for 16 improvement and actions that resulted in no change or a decline in performance. 17 In instances of no change or deteriorated performance, it is the intent of the legislature that 18 each agency describe actions the agency will take to advance progress toward performance 19 targets. For measures lacking data, it is the intent of the legislature that the reporting agency 20 describe any significant impediments to measuring progress toward the performance target, 21 describe how and when impediments will be overcome, and estimate when the agency 22 anticipates data will be reported to the legislature. When desired results involve more than one 23 agency, each agency will note the joint effort and report on its contribution to achieving 24 desired results. 25 It is the intent of the legislature that the Department of Administration, Office of the 26 Governor, and other state agencies actively pursue implementation of the state procurement 27 pilot program authorized by ch. 51, SLA 2003 (HB 313, Twenty-Third Alaska State 28 Legislature). It is essential that state policy makers show strong leadership in reducing the 29 cost of government at a time when the State of Alaska is facing a fiscal gap. The procurement 30 pilot program provides an opportunity to address the fiscal condition of the state in a way that CCS DB 375, Sec. I -2- ) ) 1 does not reduce program delivery. The procurement pilot program will reduce the costs 2 associated with procurement and supply chain management, which are significant areas of the 3 state's administrative costs and represent an area of potentially substantial cost savings in the 4 future. As a basic administrative function, procurement and supply management represent 5 appropriate opportunities for achieving costs savings through the use of process management 6 specialists from the private sector and, when combined with electronic commerce tools, offer 7 opportunities to reduce the amount of back-office overhead resources required to requisition, 8 procure, and otherwise administer the acquisition of goods and services, as well as to reduce 9 the actual costs of goods and services. Given the early indications of large potential cost 1 0 savings to the state from the procurement pilot program, the legislature encourages the 11 executive branch to actively pursue full implementation authorized by ch.51, SLA 2003. (SECTION 1 OF THIS ACT CONTINUES ON PAGE 4) CCS HB 375, Sec. 1 -3- Appropriation General Other 2 Allocations Items Funds Funds 3 ***** ****** 4 * * * * * * Department of Administration * * * * * * 5 ****** ****** 6 Centralized Administrative 5~ ~~1 '188 ~,~~~tg88 44,949,400 , , 7 Services 8 Office of the Commissioner 603,900 9 Administrative Services ] ,279,900 ]0 DOA Information Technology 1,047,200 1 ] Support 12 Finance 6,129,600 ]3 Personnel 12,029,600 14 Labor Relations 1,172,600 15 Purchasing 995,100 16 Property Management 907,500 17 Central Mail 2,247,300 18 Tax Appeals 227,600 19 Centralized Human Resources 103,500 20 Retirement and Benefits 11,378,000 2] Group Health Insurance ]4,349,400 22 Labor Agreements 50,000 23 Miscellaneous Items 24 Leases 36,249,000 19,989,100 16,259,900 25 Leases 35,398,000 26 The money appropriated by this appropriation may be distributed to state departments and 27 agencies to pay the cost of leasing space occupied by the department or agency. 28 It is the intent of the legislature that the department transfer funding for all leases to 29 occupying agencies during FY05. 30 Lease Administration 851,000 31 State Owned Facilities 7,621,700 927,800 6,693,900 32 Facilities 6,049,900 33 Facilities Administration 587,300 CCS HB 375, Sec. ] -4- ) ,) 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Non-Public Building Fund 984,500 4 Facilities 5 Administration State 368,400 368,400 6 Facilities Rent 7 Administration State 368,400 8 Facilities Rent 9 Special Systems 1,568,900 1,568,900 10 Unlicensed Vessel 75,000 11 Participant Annuity 12 Retirement Plan 13 Elected Public Officers 1,493,900 14 Retirement System Benefits 15 Enterprise Technology Services 34,517,000 34,517,000 16 Enterprise Technology 34,517,000 17 Services 18 Information Services Fund 55,000 55,000 19 Information Services Fund 55,000 20 This appropriation to the Information Services Fund capitalizes a fund and does not lapse. 21 Pu blic Comm unications Services 5,684,400 4,460,700 1,223,700 22 Public Broadcasting 54,200 23 Commission 24 Public Broadcasting - Radio 2,469,900 25 Public Broadcasting - T.V. 754,300 26 Satellite Infrastructure 2,406,000 27 AIRRES Grant 76,000 76,000 28 AIRRES Grant 76,000 29 Risk Management 24,865,600 24,865,600 30 Risk Management 24,865,600 31 Alaska Oil and Gas 4,116,300 4,116,300 32 Conservation Commission 33 Alaska Oil and Gas 4,116,300 CCS DB 375, Sec. 1 -5- Appropriation General Other 2 Allocations Items Funds Funds 3 Conservation Commission 4 The amount appropriated by this appropriation includes the unexpended and unobligated 5 balance on June 30, 2004, of the receipts of the Department of Administration, Alaska Oil and 6 Gas Conservation Commission receipts account for regulatory cost charges under AS 7 31.05.093 and permit fees under AS 31.05.090. 8 Legal and Advocacy Services 23,858,800 23,331,600 527,200 9 Office of Public Advocacy 11 ,601 ,400 10 Public Defender Agency 12,257,400 11 Violent Crimes Compensation 1,511,400 226,700 1,284,700 12 Board 13 Violent Crimes Compensation 1,511,400 14 Board 15 Alaska Public Offices 665,500 665,500 16 Commission 17 Alaska Public Offices 665,500 18 Commission 19 Motor Vehicles 9,678,900 9,678,900 20 Motor Vehicles 9,678,900 21 General Services Facilities 39,700 39,700 22 Maintenance 23 General Services Facilities 39,700 24 Maintenance 25 ITG Facilities Maintenance 23,000 23,000 26 ITG Facilities Maintenance 23,000 27 ***** ****** 28 * * * * * * Department of Comm unity and Economic Development * * * * * * 29 ****** ****** 30 Executive Administration and 4,469,200 1,088,100 3,381,100 31 Development 32 Commissioner's Office 815,300 33 Administrative Services 2,460,200 CCS HB 375, Sec. 1 -6- Office of Economic Development Community Assistance & Economic Development Community Advocacy State Revenue Sharing National Program Receipts Fisheries Business Tax Qualified Trade Association Contract The amount appropriated by this appropriation includes the unexpended and unobligated balance of business license receipts under AS 43.70.030 for fiscal year 2004, not to exceed $2,000,000. ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Qualified Trade Association Contract Investments Investments ì ) Appropriation Allocations Items General Funds Other Funds 1,193,700 71815,700 ,959,000 3j,~i~~~88 4,077,400 7 815 700 7;959,'000 17,600,000 17,600,000 16,000,000 1,600,000 4,005,100 2,005,100 2,000,000 4,005,100 3,773,300 3,773,300 3,773,300 Alaska Aerospace Development 22,190,600 22,190,600 Corporation The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30, 2004, of corporate receipts of the Department of Community and Economic Development, Alaska Aerospace Development Corporation. Alaska Aerospace 2,039,700 Development Corporation Alaska Aerospace 20,150,900 Development Corporation Facilities Maintenance Alaska Industrial Development and Export Authority Alaska Industrial Development and Export 6,793,700 6,793,700 6,601,700 CCS HB 375, Sec. 1 -7- 1 2 3 4 5 6 7 8 9 ]0 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Authority Alaska Industrial Development Corporation Facilities Maintenance Alaska Energy Authority Alaska Energy Authority Owned Facilities Appropriation Allocations Items 192,000 19,794,900 1,067,100 2,827,100 200,700 15,700,000 11,097,900 11,097,900 General Funds Other Funds 289,300 19,505,600 Alaska Energy Authority Rural Energy Operations Alaska Energy Authority Circuit Rider Alaska Energy Authority Power Cost Equalization Alaska Seafood Marketing 11,097,900 Institute Alaska Seafood Marketing Institute The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30,2004, of the receipts trom the salmon marketing tax (AS 43.76.110), trom the seafood marketing assessment (AS 16.51.120), and from program receipts of the Alaska Seafood Marketing Institute. Banking, Securities and 2,736,200 2,736,200 Corporations Banking, Securities and 2,736,200 Corporations Insurance Operations 5,323,100 5,323,100 Insurance Operations 5,323,100 The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30, 2004, of the Department of Community and Economic Development, division of insurance, program receipts trom license fees and service fees. Occupational Licensing 8,269,700 8,269,700 CCS DB 375, Sec. 1 -8- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 '? J Appropriation Allocations Items General Funds Other Funds Occupational Licensing 8,269,700 The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30, 2004, of the Department of Community and Economic Development, division of occupational licensing, receipts ITom occupational license fees under AS 08.01.065(a), (c), and (t). Regulatory Commission of 5,501,300 5,501,300 Alaska Regulatory Commission of 5,501,300 Alaska The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30, 2004, of the Department of Community and Economic Development, Regulatory Commission of Alaska receipts account for regulatory cost charges under AS 42.05.254 and AS 42.06.286. RCA Audits & Investigations 1,012,800 1,012,800 RCA Audits & Investigations 1,012,800 DCED State Facilities Rent 794,400 384,600 409,800 DCED State Facilities Rent 794,400 Alaska State Community 2,969,700 65,600 2,904,100 Services Commission Alaska State Community 2,969,700 Services Commission ***** ****** ****** * * * * * * Department of Corrections * * * * * * ****** Administration and Support Office of the Commissioner Correctional Academy Administrative Services Information Technology MIS Research and Records Facility-Capital 38 919 300 2Z 168 200 39,005',300 21,851;200 11,151,100 1 , 141 ,400 858,200 2,069,800 1,402,800 208,600 341,000 CCS DB 375, Sec. 1 -9- Appropriation General Other 2 Allocations Items Funds Funds 3 Improvement Unit 4 Offender Habilitative 2,032,200 5 Programs 6 Community Jails 4,325,200 7 Classification and Furlough 2,812,700 8 Inmate Transportation 1,272,500 9 Point of Arrest 507,200 10 Facility Maintenance 7,780,500 11 DOC State Facilities Rent 98,100 12 Out-of-State Contractual 14,155,100 13 Inmate Health Care 15,862,300 15,025,700 836,600 14 Inmate Health Care 15,862,300 15 Institutional Facilities 99~~~~~~88 8¡5~~Í',~88 9,191,700 16 Institution Director's 2,059,200 17 Office 18 Correctional Industries 3,114,300 19 Product Cost 20 Anchorage Correctional 18,964,500 2] Complex 22 Anvil Mountain Correctional 4,285,200 23 Center 24 Combined Hiland Mountain 7,788,700 25 Correctional Center 26 Fairbanks Correctional 7,386,200 27 Center 28 Ketchikan Correctional 2,977,500 29 Center 30 Lemon Creek Correctional 6,286,200 31 Center 32 Matanuska-Susitna 2,939,100 33 Correctional Center CCS DB 375, Sec. 1 -10- y ) 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Palmer Correctional Center 8,782,400 4 Spring Creek Correctional 14,680,300 5 Center 6 Wildwood Correctional Center 8,649,200 7 Yukon-Kuskokwim 4,600,800 8 Correctional Center 9 Point MacKenzie 2,485,000 10 Correctional Farm 11 Existing Community 15,598,400 11,233,900 4,364,500 12 Residential Centers 13 Existing Community 15,598,400 14 Residential Centers 10 699 400 9 738 600 15 Probation and Parole 10~718t100 9,75'1,600 960,800 16 Probation and Parole 1,301,100 17 Director's Office 18 Probation Region 1 6,130,500 19 Probation Region 2 3,286,800 20 Parole Board 459,200 459,200 21 Parole Board 459,200 22 ***** ****** 23 * * * * * * Department of Education and Early Development * * * * * * 24 ****** ****** 25 It is the intent of the legislature that the Department of Education & Early Development make 26 every effort to reduce interagency charge back between divisions and that the department 27 advance a general fund appropriation for executive administration, including the state board 28 of education and early development and the commissioner's office in the Governor's FY2006 29 budget request. 30 Education Support Services 3,787,700 1,605,000 2,182,700 31 Executive Administration 551, 1 00 32 Administrative Services 1,135,100 33 Infonnation Services 555,400 CCS HB 375, Sec. 1 -11- Appropriation Allocations Items School Finance & Facilities 1,546,100 Teaching and Learning Support Special and Supplemental 79,671,000 Services 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 General Funds Other Funds 162 603 800 161,613;800 11 625 500 11',635;500 150,978,300 Quality Schools 42,567,000 It is the intent of the legislature that the department expend funds appropriated for a new Education Specialist II position to create an office uniquely focused on maximization of all Alaska alternative public school initiatives, including charter schools. Duties of the office shall include the following: (1) monitor and evaluate the expenditures of state funds in accordance with state statutes and regulations; (2) monitor and evaluate curriculum as it pertains to state education and graduation requirements; and (3) monitor and evaluate benchmark and other standardized test results to insure that a quality education is being provided by Alaska's alternative educational system. "Maximization" means: finding ways to use alternative schools to accomplish the requirements of the federal No Child Left Behind Act (NCLB); increasing public choices for quality education; monitoring and overseeing alternative schools in the context of these goals; and providing information to the legislature regarding alternative school legislation, challenges, evaluation and opportunities. Existing alternative schools include: charter schools, boarding schools, correspondence schools and district-operated alternative schools. Teacher Certification 622,200 The amount allocated for Teacher Certification includes the unexpended and unobligated balance on June 30, 2004, of the Department of Education and Early Development receipts from teacher certification fees under AS 14.20.020( c). Child Nutrition 33,433,400 Head Start Grants 6,320,200 Commissions and Boards Professional Teaching Practices Commission Alaska State Council on the Arts Mt. Edgecum be Boarding School CCS HB 375, Sec. 1 1,332,900 466,600 866,300 226,600 1,106,300 4,705,700 2,498,300 2,207,400 -12- ~ ~ l 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Mt. Edgecumbe Boarding 4,705,700 4 School 5 State Facilities Maintenance 1,183,800 253,900 929,900 6 State Facilities Maintenance 903,900 7 EED State Facilities Rent 279,900 8 Alaska Library and Museums 71°81,888 55~,~88 2,003,800 ,251, 9 Library Operations 4,880,600 1,980,600 10 Archives 739,100 808,500 11 Museum Operations 1,461,900 12 Alaska Postsecondary 11,125,200 1,507,300 9,617,900 13 Education Commission 14 Program Administration & 9,617,900 15 Operations 16 WW AMI Medical Education 1,507,300 17 ***** ****** 18 * * * * * * Department of Environmental Conservation * * * * * * 19 ****** ****** 4 49~ 700 ~~,~æ 20 Administration 1',-119 ;300 3,606,400 21 Office of the Commissioner 605,700 22 Information and 3,488,700 23 Administrative Services 24 State Support Services 397,900 17 44~ 700 66~1~,~Bß 25 Environmental Health 1'7 ;1 1,900 11,269,200 26 Environmental Health 267,100 27 Director 28 Food Safety & Sanitation 2,936,700 29 Laboratory Services 2,448,100 30 Drinking Water 3,737,300 31 Solid Waste Management 1,145,900 32 Air Director 217,000 33 Air Quality 6,705,800 CCS HB 375, Sec. 1 -13- 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Appropriation General Other Allocations Items Funds Funds Spill Prevention and Response 16,459,700 12,000 16,447,700 Spill Prevention and 2 I 6,300 Response Director Contaminated Sites Program 7,580,200 Industry Preparedness and 3,379,000 Pipeline Operations Prevention and Emergency 3,448,900 Response Response Fund Administration 1,835,300 14 729 600 41~57~~ Water 1 ~,731,600 10,279,700 Water Quality 8,860,700 Facility Construction 5,876,900 ***** ****** * * * * * * Department of Fish and Game * * * * * * ****** ****** Commercial Fisheries 4~9~U~13i 22~3~~,~88 26,698,700 Southeast Region Fisheries 5,504,600 Management The amount allocated for Southeast Region Fisheries Management includes the unexpended and unobligated balance on June 30, 2004, of the Department ofFish and Game receipts from commercial fisheries test fishing operations receipts under AS 16.05.050(a)(l5). Central Region Fisheries 6,153,800 Management A YK Region Fisheries 4,203,400 Management Westward Region Fisheries 6,753,700 Management Headquarters Fisheries 2,864,700 Management The amount allocated for Headquarters Fisheries Management includes the unexpended and unobligated balance on June 30, 2004, of the Department of Fish and Game, Commercial CCS HB 375, Sec. 1 -14- ) \ 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Fisheries Entry Commission, program receipts from licenses, permits and other fees. 4 Fisheries Development 2,377,400 5 Commercial Fisheries 18,752,900 6 Special Projects 7 Commercial Fish Capital 2,396,700 8 Improvement Position Costs 9 Sport Fisheries 38,833,800 266,000 38,567,800 10 Sport Fisheries 25,751,900 11 Sport Fisheries Special 6,854,800 12 Projects 13 Sport Fisherie~ Habitat 5,986,200 14 Assert/Protect State's 240,900 15 Rights 16 Wildlife Conservation 30,928,300 30,928,300 17 Wildlife Conservation 19,073,200 18 Wildlife Conservation 5,672,700 19 Restoration Program 20 Wildlife Conservation 6,182,400 21 Special Projects 22 Administration and Support 18,648,600 3,619,500 15,029,100 23 Commissioner's Office 1,060,600 24 Administrative Services 6,029,800 25 Boards of Fisheries and Game 978,100 26 Advisory Committees 407,700 27 State Subsistence 4,440,700 28 EVOS Trustee Council 4,447,700 29 State Facilities Maintenance 1,008,800 30 Fish and Game State 275,200 31 Facilities Rent 32 The amount allocated for Fish and Game State Facilities Rent includes the unexpended and 33 unobligated balance on June 30, 2004, of the Department of Fish and Game, Commercial CCS DB 375, Sec. 1 -15- Appropriation General Other 2 Allocations Items Funds Funds 3 Fisheries Entry Commission, program receipts from licenses, permits and other fees. 4 Commercial Fisheries Entry 2,894,300 2,894,300 5 Commission 6 The amount appropriated for Commercial Fisheries Entry Commission includes the 7 unexpended and unobligated balance on June 30, 2004, of the Department of Fish and Game, 8 Commercial Fisheries Entry Commission, program receipts from licenses, permits and other 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 fees. Commercial Fisheries Entry 2,894,300 Commission ***** ****** * * * * * * Office of the Governor * * * * * * ****** ****** Commissions/Special Offices 1,386,400 1,231,100 155,300 Human Rights Commission 1,386,400 Executive Operations 9g 343, igg \542,888 801,800 ,118, ,617, 0 Executive Office 8,357,700 Governor's House 351,100 Contingency Fund 710,000 Office of the Governor State 387,600 387,600 Facilities Rent Governor's Office State 387,600 Facilities Rent 1 950 300 1 950 300 Office of Management and 2,000,300 2',000;300 Budget Office of Management and ~'~B8'r88 , , Budget Lieutenant Governor B~~ '188 ~1,~ 91,200 , Lieutenant Governor ~g~ :188 Elections 2,228,800 2,045,700 183,100 Elections 2,228,800 CCS DB 375, Sec. 1 -16- ) ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Appropriation Allocations Items General Funds Other Funds ***** ****** * * * * * * Department of Health and Social Services * * * * * * ****** ****** No money appropriated in this appropriation may be expended for an abortion that is not a mandatory service required under AS 47.07.030(a). The money appropriated for Health and Social Services may be expended only for mandatory services required under Title XIX of the Social Security Act and for optional services offered by the state under the state plan for medical assistance that has been approved by the United States Department of Health and Human Services. This statement is a statement of the purpose of the appropriation and is neither merely descriptive language nor a statement of legislative intent. Alaskan Pioneer Homes ~6~,~OO Il1~'i-,~88 13,937,300 Alaskan Pioneer Homes Management Pioneer Homes 801,600 25,522,600 Behavioral Health AK Fetal Alcohol Syndrome Program Alcohol Safety Action Program (ASAP) It is the intent of the legislature that the Department of Health and Social Services collaborate with the Alaska Court System and ASAP providers to devise a system of centralized revenue collection ITom those persons assigned to ASAP screening and evaluation as a condition of their sentence in DWI and alcohol and drug related misdemeanors. The Department is directed to prepare a comprehensive plan to address the deficiencies in the current ASAP system, including a cost-benefit analysis of transitioning the Anchorage ASAP to a local nonprofit provider, an evaluation of which agency should logically manage the program, and a review of other states' ASAP programs. This report is to be provided to the legislature by January 10,2005. Behavioral Health Medicaid Il38g,~~~,~88 21 381 400 21,389',000 116,887,400 6,924,400 1,140,800 90,359,200 Services Behavioral Health Grants 13,671,900 CCS DB 375, Sec. 1 -17- Appropriation General Other 2 Allocations Items Funds Funds 3 Behavioral Health 6,159,700 4 Administration 5 Community Action Prevention 2,050,100 6 & Intervention Grants 7 Rural Services and Suicide 785,900 8 Prevention 9 Psychiatric Emergency 670,800 10 Services 11 Services to the Seriously 1,894,400 12 Mentally III 13 Services for Severely 906,200 14 Emotionally Disturbed Youth 15 Alaska Psychiatric Institute 13,713,000 123 ~39 ~ 41 ~1~ 500 16 Children's Services 123', 53: 0 11', 3 ; 00 81,721,200 17 Children's Medicaid Services 8,851,700 18 Children's Services 6,353,900 19 Management 20 Children's Services Training 1,209,000 21 Front Line Social Workers 28,616,400 22 Family Preservation 9,035,600 23 F oster Care Base Rate 10,106,900 24 F oster Care Augmented Rate 1,626,100 25 Foster Care Special Need 3,914,100 26 Subsidized Adoptions & 19,732,900 27 Guardianship 28 Residential Child Care 3,446,600 29 Infant Learning Program 3,358,200 30 Grants 31 Women, Infants and Children 25,548,900 32 Children's Trust Programs 1,025,900 33 Child Protection Legal 227,500 CCS HB 375, Sec. 1 -18- J 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Services , ) Appropriation Allocations Items General Funds Other Funds 675 900,200 109 276 300 Health Care Services 675,902,500 10~,278,600 566,623,900 No money appropriated in this appropriation may be expended for an abortion that is not a mandatory service required under AS 47.07.030(a). The money appropriated for Health Care Services may be expended only for mandatory services required under Title XIX of the Social Security Act and for optional services offered by the state under the state plan for medical assistance that has been approved by the United States Department of Health and Human Services. This statement is a statement of the purpose of the appropriation for Health Care Services and is neither merely descriptive language nor a statement of legislative intent. Medicaid Services 649,258,200 Catastrophic and Chronic 1,471,000 Illness Assistance (AS 47.08) Medical Assistance Administration Health Purchasing Group Hearings and Appeals Women's and Adolescents' Services Juvenile Justice McLaughlin Youth Center Mat-Su Youth Facility Kenai Peninsula Youth Facility Fairbanks Youth Facility Bethel Youth Facility Nome Youth Facility Johnson Youth Center Ketchikan Regional Youth Facility Probation Services 6,477,100 15,610,000 492,600 2,593,600 36 514,000 32 541 900 36,540,100 3::!,568',000 3,972,100 11,822,800 1,520,300 1,411,300 3,260,900 2,770,800 1,175,200 2,434,500 1,144,300 8,412,400 CCS HB 375, Sec. 1 -19- 2 3 4 5 6 7 8 9 ]0 ] 1 ]2 ]3 14 15 ]6 ]7 18 19 20 21 22 23 24 25 26 27 28 29 30 3] 32 33 Appropriation Allocations Items Delinquency Prevention 2,279,300 Youth Courts 308,300 231 907 jßß Public Assistance 231,913',3 Alaska Temporary Assistance 44,796,900 Program Adult Public Assistance 57,161,400 Child Care Benefits 46,015,100 General Relief Assistance 1,499,000 Tribal Assistance Programs 8,381,400 Permanent Fund Dividend 15,949,900 lIold lIarmless Energy Assistance Program 9,640,900 Public Assistance 2,735,200 Administration Public Assistance Field 27,014,600 Services General Funds Other Funds \\~~~3~;r8C 121,609,100 It is the intent of the legislature that there shall be no fee agents engaged in activities within 50 road miles of any public assistance office. Fraud Investigation 1,449, I 00 Quality Control ],] 00,500 Work Services 16,169,300 Pu blic Health 61 111 300 20 485 000 61;150,100 2å,523;800 40,626,300 Nursing Public lIealth 18,851,100 2,368,800 Administrative Services Certification and Licensing Epidemiology Bureau of Vital Statistics Community lIealthÆmergency Medical Services 1,607,300 17,282,800 1,824,700 5,994,200 Community lIealth Grants 2,214,900 CCS HB 375, Sec. 1 -20- \ ) ) I 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Appropriation Allocations Items General Funds Other Funds Emergency Medical Services Grants State Medical Examiner Public Health Laboratories Tobacco Prevention and Control Senior and Disabilities 1,760,100 1,272,400 4,658,500 3,315,300 207 943,900 80 856 800 201,918,300 80',861;200 127,087,100 Services It is the intent of the legislature that the Department of Health and Social Services continue cost containment by encouraging lower cost residential based care for the elderly and severely disabled. Further, it is the intent of the legislature that the Department address escalating growth in the Personal Care Attendant program through regulation to avoid the loss of home care provider services and the consequential growth in institutional facilities in this state. Senior and Disabilities 191,291,200 Medicaid Services Senior and Disabilities 4,335,800 Services Administration Protection, Community Services, and Administration Nutrition, Transportation and Support Services Home and Community Based Care Senior Residential Services Community Developmental Disabilities Grants 2,587,700 6,582,100 1,499,000 815,000 837,500 9,682,300 9,689,100 34,346,400 ~~8Jg;l98 Departmental Support Services Commissioner's Office Office of Program Review Rate Review Assessment and Planning 811,600 1 , 111,000 814,500 250,000 CCS DB 375, Sec. 1 -21- Appropriation General Other Allocations Items Funds Funds It is the intent of the legislature that the Assessment and Planning funding is specifical1y provided to identify and implement actions and regulatory changes necessary to achieve Medicaid and related program growth cost containment requested in this budget with the least possible effect on the most vulnerable beneficiaries. The Department is to dedicate necessary resources to analyze and project future entitlement growth of Medicaid and related program spending and to identify alternatives to mitigate or stop increases. A progress report is to be provided to the legislature prior to the beginning of the 2005 session and wil1 include a rationalization for any supplemental budget request expected to be made as a result of failure to achieve Medicaid growth cost containment requested in this budget. Administrative Support 10,156,000 Services 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 ]6 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Audit Medicaid School Based Administrative Claims Health Planning & Facilities Management Health Planning and Infrastructure Information Technology Services Facilities Maintenance Pioneers' Homes Facilities Maintenance HSS State Facilities Rent Boards and Commissions Alaska Mental Health Board Commission on Aging Governor's Council on Disabilities and Special Education Pioneers Homes Advisory CCS HB 375, Sec. I 225,000 6,239,300 882,800 3,527,100 14,309,900 2,584,900 2,125,000 998,400 2,494,700 62,600 2,432,100 121,900 317,800 2,041,300 13,700 -22- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Appropriation Allocations Items General Funds Other Funds Board Human Services Community 1,159,300 1,159,300 Matching Grant Human Services Community 1,159,300 Matching Grant It is the intent of the legislature that the Human Services Community Matching Grant funding is subject to future phase-out or elimination. This anticipated reduction is to provide opportunity for development of Faith Based and other community focused initiatives to supplant dependency upon direct State funding. Faith Based and other community focused initiatives are most appropriate to direct specific resources to particular community needs, complimenting the concentration of State resources on core public health and social services needs. ***** ****** * * * * * * Department of Labor and Workforce Development * * * * * * ****** ****** 11~,~~~~~ 1 1r~ 900 Commissioner and 1, S,OOO 13,039,500 Administrative Services Commissioner's Office 538,200 Alaska Labor Relations 370,900 Agency Management Services 2,636,900 Human Resources 659,000 Data Processing 5,877,900 Labor Market Information 4,124,600 15422 700 1 4i~ 200 Workers' Compensation and 15',125;600 1, S,100 13,967,500 Safety Workers' Compensation 3,089,000 Second Injury Fund 4,019,700 Fishermens Fund 1,328,500 Wage and Hour Administration 1,430,500 Mechanical Inspection 1,872,000 CCS DB 375, Sec. 1 -23- Occupational Safety and Health Alaska Safety Advisory Council The amount allocated for the Alaska Safety Advisory Council includes the unexpended and unobligated balance on June 30, 2004, of the Department of Labor and Workforce Development, Alaska Safety Advisory Council receipts under AS 18.60.840. Workforce Development 11~lr,1í~;r88 41~~5~~ 96,915,100 Employment and Training 27,588,000 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 Services Unemployment Insurance Adult Basic Education Workforce Investment Boards Business Services Alaska Vocational Technical Center A VTEC Facilities Maintenance Kotzebue Technical Center Operations Grant Vocational Rehabilitation V ocational Rehabilitation Administration Client Services Independent Living Rehabilitation Disability Determination Special Projects Assistive Technology Americans With Disabilities Act (ADA) CCS HB 375, Sec. 1 Appropriation Allocations Items General Other Funds Funds 3,574,600 111,300 19,218,700 2,805,800 1,146,100 41,786,300 7,242,200 879,100 800,900 21,979,200 3,631,300 18,347,900 1,332,600 12,605,300 1,296,700 4,444,700 1,661,300 438,600 200,000 -24- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 ) Appropriation Allocations Items General Funds Other Funds ***** ****** * * * * * * Department of Law * * * * * * Criminal Division First Judicial District Second Judicial District Third Judicial District: Anchorage Third Judicial District: Outside Anchorage Fourth Judicial District Criminal Justice Litigation Criminal Appeals/Special Litigation Component Civil Division Deputy Attorney General's Office Collections and Support 1,977,600 Commercial and Fair Business 3,851,000 The amount allocated for Commercial and Fair Business section includes the unexpended and unobligated balance on June 30, 2004, of designated program receipts and general fund program receipts of the Department of Law, Commercial and Fair Business section. Environmental Law 1,443,100 Human Services Section 4,353,000 Labor and State Affairs 3,681,100 Natural Resources 1,139,700 Oil, Gas and Mining 4,419,400 Opinions, Appeals and Ethics 1,132,700 Regulatory Affairs Public 1,013,300 Advocacy Statehood Defense ****** ****** llir,t1!;388 11~,~~IJ88 2,804,200 1,532,500 971,100 4,954,400 2,711,700 3,898,600 1,265,700 3,311,300 29,617,900 12,052,200 17,565,700 228,000 961,100 CCS DB 375, Sec. 1 -25- Appropriation General Other 2 Allocations Items Funds Funds 3 Timekeeping and Support 820,100 4 Torts & Workers' 2,585,200 5 Compensation 6 Transportation Section 2,012,600 7 Administration and Support 2,716,200 1,746,800 969,400 8 Office of the Attorney 392,400 9 General 10 Administrative Services 1,528,800 11 Legislation/Regulations 795,000 12 Agency-wide Un allocated -100,000 -100,000 13 Reduction 14 Agency-wide Unallocated -100,000 ]5 Reduction 16 ***** ****** 17 * * * * * * Department of Military and Veterans Affairs * * * * * * 18 ****** ****** 553~(ti83 1 519 600 19 Office of Homeland Security 1,532:100 3,739,700 20 and Emergency Services 21 Homeland Security and 4,971,800 22 Emergency Services 23 Local Emergency Planning 300,000 24 Committee 25 Alaska National Guard 2í~3i,988 ~~~~,~88 22,323,000 2 , 1 ,1 26 Office of the Commissioner 2,486,100 27 National Guard Military 243,700 28 Headquarters 29 Army Guard Facilities 11,396,500 30 Maintenance 31 Air Guard Facilities 5,632,200 32 Maintenance 33 State Active Duty 320,000 CCS DB 375, Sec. 1 -26- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Alaska Military Youth Academy ST ARBASE Alaska National Guard Benefits Educational Benefits Retirement Benefits Veterans' Affairs Veterans' Services ***** ) Appropriation General Other Allocations Items Funds Funds 6,460,500 309,400 2,275,300 2,275,300 278,500 1,996,800 675,000 675,000 675,000 ****** ****** * ** * * * Department of Natural Resources * * * * * * ****** Resource Development Commissioner's Office Administrative Services Information Resource Management Oil & Gas Development Pipeline Coordinator Alaska Coastal Management Program Large Project Permitting Office of Habitat Management and Permitting Claims, Permits & Leases Land Sales & Municipal Entitlements Title Acquisition & Defense Water Development RS 2477/Navigability Assertions and Litigation Support 68 229 200 ,6 698 800 68,236,600 2 i), 706~200 41,530,400 741,700 1,876,600 2,595,600 8,015,100 3,844,100 5,306,100 2,373,700 3,636,100 8,113,200 3,622,000 1,183,700 1,511,900 266,400 CCS HB 375, Sec. 1 -27- Director's Office/Mining, Land, & Water Forest Management and Development The amount allocated for Forest Management and Development includes the unexpended and unobligated balance on June 30,2004, of the timber receipts account (AS 38.05.110). Emergency Firefighters 250,000 Non-Emergency Projects Geological Development Recorder's OfficefUniform Commercial Code Agricultural Development North Latitude Plant Material Center Agriculture Revolving Loan Program Administration Conservation and 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Development Board Public Services Office Trustee Council Projects Interdepartmental Information Technology Chargeback Human Resources Chargeback DNR Facilities Rent and Chargeback Facilities Maintenance Development - Special Projects Fire Suppression Fire Suppression CCS HB 375, Sec. 1 Appropriation Allocations Items General Funds Other Funds 403,800 4,887,500 4,761,200 3,371,300 1,706,600 2,084,200 2,563,100 92,100 385,100 656,600 1,087,800 704,300 1,746,800 300,000 150,000 2i1?æf(J~ lPg~i~',š88 5,979,900 12,366,500 -28- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Preparedness Fire Suppression Activity Parks and Recreation Management State Historic Preservation Program Parks Management Parks & Recreation Access ***** ) Appropriation Allocations Items General Funds Other Funds 11,673,900 9g,~~~d88 33~~~',~88 5,615,900 1,403,300 5,808,900 2,185,800 ****** ****** * * * * * * Department of Public Safety * * * * * * ****** 4,104,0~7tt,800 11'28~2oo 2~ 766,600 Fire Prevention 'I 6(, .000 ~,281 ,200 ¿,,772,800 The amount appropriated by this appropriation includes up to $125,000 of the unexpended and unobligated balance on June 30, 2004, of the receipts collected under AS 18.70.080(b). Fire Prevention Operations 2,382,400 Fire Service Training 1,677,600 Alaska Fire Standards Council 229,300 229,300 The amount appropriated by this appropriation includes the unexpended and unobligated balance on June 30, 2004, of the receipts collected under AS 18.70.350(4) and AS 18.70.360. Alaska Fire Standards 229,300 Council Alaska State Troopers Special Projects Director's Office Judicial Services-Anchorage Prisoner Transportation Search and Rescue Rural Trooper Housing Narcotics Task Force Alaska State Trooper Detachments 76 975 700 66 443 900 10,531,800 71,815',900 6'1,231',400 10,584 ,500 4,714,600 289,600 2,222,000 1,701,700 368,100 730,200 3,429,000 39,388,000 CCS HB 375, Sec. 1 -29- 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 The amount appropriated by this appropriation includes up to $125,000 of the unexpended 18 and unobligated balance on June 30, 2004, of the receipts collected under AS 12.25.195(c), 19 AS 12.55.039, AS 28.05.151, and AS 29.25.074 and receipts collected under AS 20 18.65.220(7). 21 Alaska Police Standards 990,000 22 Council 23 Council on Domestic Violence 9,599,400 854,000 8,745,400 24 and Sexual Assault 25 Notwithstanding AS 43.23.028(b)(2), up to 10% of the amount appropriated by this 26 appropriation under AS 43.23.028(b)(2) to the Council on Domestic Violence and Sexual 27 Assault may be used to fund operations and grant administration. 28 It is the intent of the legislature that the Council on Domestic Violence and Sexual Assault 29 use all of the federal grant funds awarded to the Council in federal fiscal year 2005 for the 30 grants and services required of the federal grant awards in state fiscal year 2005 to the 31 maximum extent allowable by the federal grants. 32 Council on Domestic 9,399,400 33 Violence and Sexual Assault Appropriation General Other Allocations I terns Funds Funds Alaska Bureau of 4,888,000 Investigation AK Bureau of Alcohol & Drug 2,242,600 Enforcement AK Bureau of Wildlife 11,619,300 Enforcement Aircraft Section 2,832,600 Marine Enforcement 3,390,200 55~c¡&,Ï88 11; 188 Village Public Safety Officer 5,685,400 11 ;7 0 Program VPSO Contracts 5,436,400 Support 366,700 Alaska Police Standards 990,000 990,000 Council CCS HB 375, Sec. 1 -30- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Appropriation Allocations Items Batterers Intervention 200,000 Program Statewide Support If6~ïB(),~ß'3 Commissioner's Office 736,400 Training Academy 1,552,200 Administrative Services 3,026,200 Alaska Wing Civil Air Patrol 503,100 Alcohol Beverage Control 940,900 Board Alaska Public Safety 2,520,400 Information Network Alaska Criminal Records and 4,407,600 Identification The amount allocated for Alaska Criminal Records and ID includes up to $125,000 of the unexpended and unobligated balance on June 30, 2004, of the receipts collected by the Department of Public Safety from the Alaska automated fingerprint system under AS 44.41.025(b ). Laboratory Services 2,779,500 Statewide Facility Maintenance Facility Maintenance 608,800 DPS State Facilities Rent DPS State Facilities Rent 111,800 ***** 608,800 111,800 ****** ) General Other Funds Funds \-,~~~;~88 66,"~~888 608,800 111,800 ****** * * * * * * Department of Revenue * * * * * * Taxation and Treasury Tax Division Treasury Division Alaska State Pension Investment Board State Pension Custody and 7,145,600 3,889,500 3,599,500 26,413,600 -31- ****** 46L631,300 1u,&12,500 7011 000 7,022~200 39,620,300 CCS HB 375, Sec. 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Management Fees 4 Permanent Fund Dividend 5,594,300 5 Division 6 Child Support Enforcement 19,491,200 19,491,200 7 Child Support Enforcement 19,491,200 8 Division 9 Administration and Support 3,342,300 565,300 2,777,000 10 Commissioner's Office 1,860,100 11 Administrative Services 1,259,200 12 State Facilities Rent 223,000 13 Alaska Natural Gas 256,600 256,600 14 Development Authority 15 Gas Authority Operations 256,600 16 Alaska Mental Health Trust 405,600 405,600 17 Authority 18 Long Term Care Ombudsman 405,600 19 Office 20 Alaska Municipal Bond Bank 677,700 677,700 21 Authority 22 AMBBA Operations 677,700 23 Alaska Housing Finance 41,444,300 41,444,300 24 Corporation 25 AHFC Operations 40,644,300 26 Anchorage State Office 800,000 27 Building 28 Alaska Permanent Fund 48,439,600 48,439,600 29 Corporation 30 It is the intent of the legislature to give notice as permitted by AS 15.13.145, and regulations 31 of the Alaska Public Offices Commission, that the Alaska Permanent Fund Corporation may 32 use amounts appropriated for operations of the corporation within the corporation's fiscal 33 Year 2004 and 2005 budgets to educate voters concerning the Percent of Market Value CCS HB 375, Sec. 1 -32- ) 'ì ) Appropriation General Other Allocations Items Funds Funds Amendment to the Alaska Constitution and the reasons why the Trustees recommended this change in law. It is further the intent of the legislature that the Alaska Permanent Fund Corporation not advocate a position on the ballot question, must permit persons with all viewpoints to participate in a public forum, and shall present all known effects that the Percent of Market Value proposal could have on the Alaska Permanent Fund. APFC Operations 7,009,600 APFC Custody and Management 41,430,000 Fees 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 ***** ****** ****** * * * * * * Department of Transportation & Public Facilities * * * * * * ****** Administration and Support Commissioner's Office Contracting, Procurement and Appeals Equal Employment and Civil Rights Internal Review Transportation Management and Security Statewide Administrative Services Statewide Information Systems State Equipment Fleet Administration Human Resources Central Region Support Services Northern Region Support Services 31 592 500 31,610',000 6 079 400 6,09b,900 25,513,100 1,108,300 478,800 768,700 795,900 658,200 3,714,300 1,899,900 2,738,100 2,058,800 810,400 1,132,900 CCS HB 375, Sec. 1 -33- Appropriation General Other 2 Allocations I terns Funds Funds 3 Southeast Region Support 2,344,800 4 Services 5 Statewide Aviation 1,854,900 6 Program Development 3,190,800 7 Central Region Planning 1,437,000 8 Northern Region Planning 1,401,600 9 Southeast Region Planning 484,100 10 Measurement Standards & 4,721,100 11 Commercial Vehicle 12 Enforcement 13 DOT State Facilities Rent 11,400 14 Design, Engineering & 76,860,900 1,618,200 75,242,700 15 Construction 16 Statewide Design and 7,636,200 17 Engineering Services 18 Central Design and 15,593,200 19 Engineering Services 20 Northern Design and 11,580,300 21 Engineering Services 22 Southeast Design and 7,234,700 23 Engineering Services 24 Central Region Construction 16,573,400 25 and CIP Support 26 Northern Region 12,887,100 27 Construction and CIP Support 28 Southeast Region 5,034,500 29 Construction 30 Knik Arm Bridge and Toll 321,500 31 Authority ll32~~~1~i88 8~ 487 600 32 Highways, Aviation & 0,306,100 43,197,000 33 Facilities CCS DB 375, Sec. 1 -34- Northern Region Highways and Aviation Southeast Region Highways and Aviation The amount allocated for highways and aviation shall lapse into the general fund on August 31,2005. Whittier Access & Tunnel 3,818,800 The amount allocated for Whittier Access & Tunnel includes the unexpended and unobligated balance on June 30, 2004, of the Whittier Tunnel toll receipts collected by the Department of Transportation and Public Facilities under AS 19.05.040(11). 56 649 600 International Airports 5b,821,900 International Airport 596,800 Systems Office Anchorage Airport Administration Anchorage Airport Facilities Anchorage Airport Field and Equipment Maintenance Anchorage Airport Operations ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 Central Region Facilities Northern Region Facilities Southeast Region Facilities Traffic Signal Management Central Region State Equipment Fleet Northern Region State Equipment Fleet Southeast Region State Equipment Fleet Central Region Highways and Aviation ) Appropriation Allocations Items General Funds Other Funds 4,597,400 8,491,600 1,041,500 1,083,200 8,193,200 11,125,700 1,885,400 35,306,900 47,169,700 10,789,700 56 649 600 56,821,900 7,119,100 16,128,700 9,696,800 2,428,000 CCS HB 375, Sec. 1 -35- 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Anchorage Airport Safety 9,187,700 4 Fairbanks Airport 1,597,]00 5 Administration 6 Fairbanks Airport Facilities 2,580,900 7 Fairbanks Airport Field and 3,053,900 8 Equipment Maintenance 9 Fairbanks Airport Operations 1,567,700 10 Fairbanks Airport Safety 2,871,200 11 Alaska Marine Highway System 85,355,000 85,355,000 12 Marine Vessel Operations 72,760,300 13 Marine Engineering 2,265,600 14 Overhaul 1,698,400 15 Reservations and Marketing 2,266,800 16 Southeast Shore Operations 3,368,100 17 Southwest Shore Operations ],174,900 18 Vessel Operations Management 1,820,900 ]9 ***** ****** 20 * * * * * * Alaska Court System * * * * * * 21 ****** ****** 22 Alaska Court System 58,590,900 57,543,900 1,047,000 23 Appellate Courts 4,419,600 24 Trial Courts 47,225,500 25 Administration and Support 6,945,800 26 Commission on Judicial Conduct 251,200 251,200 27 Commission on Judicial 251,200 28 Conduct 29 Judicial Council 753,200 753,200 30 Judicial Council 753,200 31 ***** ****** 32 * * * * * * Legislature * * * * * * 33 ****** ****** CCS HB 375, Sec. 1 -36- ') ) 1 Appropriation General Other 2 Allocations Items Funds Funds 3 Budget and Audit Committee 8,593,700 8,343,700 250,000 4 Legislative Audit 3,142,300 5 Ombudsman 567,100 6 Legislative Finance 3,837,300 7 Committee Expenses 922,400 8 Legislature State 124,600 9 Facilities Rent 10 Legislative Council 23,726,700 23,258,100 468,600 11 Salaries and Allowances 4,710,600 12 Administrative Services 7,987,100 13 Session Expenses 6,702,700 14 Council and Subcommittees 1,289,400 15 Legal and Research Services 2,427,300 16 Select Committee on Ethics 128,000 17 Office of Victims Rights 481,600 18 Legislative Operating Budget 6,868,100 6,868,100 19 Legislative Operating Budget 6,868,100 20 (SECTION 2 OF THIS ACT BEGINS ON PAGE 38) CCS HB 375, Sec. 1 -37- * Sec. 2 The following appropriation items are for operating expenditures from the general 2 fund or other funds as set out in the fiscal year 2005 budget summary by funding source to the 3 state agencies named and for the purposes set out in the new legislation for the fiscal year 4 beginning July 1, 2004 and ending June 30, 2005. The appropriation items contain funding 5 for legislation assumed to have passed during the second session of the twenty-third 6 legislature and are to be considered part of the agency operating budget. Should a measure 7 listed in this section either fail to pass, its substance fail to be incorporated in some other 8 measure, or be vetoed by the governor, the appropriation for that measure shall lapse. A 9 department-wide, agency-wide, or branch-wide unallocated reduction or increase set out in 10 the New Legislation section may be allocated among the appropriations made in this section 11 to that department, agency, or branch. 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Appropriation General Other Items Funds Funds HB 93 Boating Safety, Registration, -24,800 -24,800 Numbering appropriated to Department of Administration HB 213 Provisional Driver's License 13,600 13,600 appropriated to Department of Administration HB 233 Increase Education Funding 520,100 520,100 appropriated to Department of Education and Early Development HB 233 Increase Education Funding 520,100 520,100 appropriated to Department of Military and Veterans Affairs HB 319 Rec. Cabin Sites/Lottery Sale/Rts. 390,500 390,500 Reserv appropriated to Department of Natural Resources HB 337 Anatomical Gifts Registry 7,000 7,000 appropriated to Department of Administration HB 367 Licensing Adult-Oriented Businesses 26,200 26,200 appropriated to Department of Community and CCS HB 375, Sec. 2 -38- ) ) 1 Appropriation General Other 2 Items Funds Funds 3 Economic Development 4 HB 374 SeniorCare appropriated to Department 14,902,500 14,902,500 5 of Health and Social Services 6 HB 378 Food, Drugs, Cosmetics, Certain 210,700 210,700 7 Devices appropriated to Department of 8 Environmental Conservation 9 HB 379 Office of Citizenship Assistance 77,000 77,000 10 appropriated to Department of Labor and 11 Workforce Development 12 HB 422 Budget Reserve Fund Investment -125,000 -125,000 13 appropriated to Department of Revenue 14 HB 452 Guided Sport Fishing/ ADFG & CFEC 345,600 345,600 15 Records appropriated to Department of Fish and 16 Game 17 HB 459 Electronic/Optical Scan Voting 442,800 442,800 18 Machines appropriated to Office of the Governor 19 HB 184 r'^....octions: Focs/Surchargo 16,500 16.500 20 3pproprie.Ì\.Ià ~v Jöpartmont of Law 21 HB 486 Mining Reclamation Assurances/Fund 21,000 21,000 22 appropriated to Department of Revenue 23 HB 512 Hydrogen Energy Research Program 75,000 75,000 24 appropriated to Department of Community and 25 Economic Development 26 HB 531 Conventional and Nonconventional Gas 20,000 20,000 27 Leases appropriated to Department of 28 Administration 29 HB 531 Conventional and Nonconventional Gas 252,600 252,600 30 Leases appropriated to Department of Natural 31 Resources 32 HB 533 IfUnreas. Agency Delay, Court 84,300 84,300 33 Decides appropriated to Department of Law CCS HB 375, Sec. 2 -39- Appropriation General Other 2 Items Funds Funds 3 HB 546 Pollution Discharge & Waste TRMT/ 412,600 177,600 235,000 4 Disposal appropriated to Department of 5 Environmental Conservation 6 HCR 32 AK Info Infrastructure Policy Task 58,000 58,000 7 Force appropriated to Legislature 8 HJR 5 Const. Am: InitiativeIReferendum 1,500 1,500 9 Petitions appropriated to Office of the Governor 10 HJR 9 Const Am: Appropriation Limit 1,500 1,500 11 appropriated to Office of the Governor 12 SB 30 Abortion: Informed Consent; 50,000 50,000 13 Information appropriated to Department of 14 Health and Social Services 15 SB 65 (' "'........"i-; ')nal Facility /Pcrsonnel 260,000 260,000 16 apprÐp~ :"t;.,~ w ucpartmcnt of Corrections 17 SB 170 Criminal Law /Sentencing/Probation/ 90,800 90,800 18 Parole appropriated to Department of 19 Administration 20 SB 173 Science & Tech Foundation/BIDCO/ 75,500 75,500 21 International Trade appropriated to Department 22 of Community and Economic Development 23 SB 203 Administrative Hearings/Office 386,900 88,500 298,400 24 appropriated to Department of Administration 25 SB 203 Administrative Hearings/Office 38,300 38,300 26 appropriated to Department of Community and 27 Economic Development 28 SB 203 Administrative Hearings/Office -5,000 -5,000 29 appropriated to Department of Public Safety 30 SB 203 Administrative Hearings/Office -256,000 -22,900 -233,100 31 appropriated to Department of Revenue 32 SB 203 Administrative Hearings/Office -11,000 -11,000 33 appropriated to Office of the Governor CCS HB 375, Sec. 2 -40- ) ) 1 Appropriation General Other 2 Items Funds Funds 3 SB 22.1 T rww"'~ T)WI for Minors to .02 131,700 131.700 4 approprib...",u LV .LJ"'pu" u...."'...... V.I. J. ~u................,uuuv.... 5 SB 231 Decrease Time to Claim Unclaimed ~caæ ~, 888 , , 6 Property appropriated to Department of Revenue 7 SB 272 Deferred Deposit Advances (Payday 95,500 95,500 8 Loans) appropriated to Department of Community 9 and Economic Development 10 SB 277 Student Loan Programs/Post Sec. Educ. 120,000 120,000 11 Comm. appropriated to Department of Education 12 and Early Development 13 SB 278 Labor and Workforce Development Fees 142,000 142,000 14 appropriated to Department of Labor and 15 Workforce Development 16 SB 282 Prepared Food: Wild/Farmed Fish 77,200 77,200 17 Disclosure appropriated to Department of 18 Environmental Conservation 19 SB 303 Big Game Services and Comm Svcs Bd 30,000 30,000 20 appropriated to Department of Community and 21 Economic Development 22 SB 305 Asserting State Title to Submerged 186,500 186,500 23 Land appropriated to Department of Natural 24 Resources 25 SB 308 Domestic Violence Protective Orders 54,300 54,300 26 appropriated to Department of Administration 27 SB 311 Insurance & Worker's Compensation 198,800 198,800 28 System appropriated to Alaska Court System 29 SB 311 Insurance & Worker's Compensation 627,000 627,000 30 System appropriated to Department of Labor and 31 Workforce Development 32 SB 347 Comm. Fishing Moratoria, IncI. AK 40,800 40,800 33 Gulf appropriated to Department of Fish and Game CCS HB 375, Sec. 2 -41- 1 Appropriation General Other 2 Items Funds Funds 3 SB 349 Midwifery Birth Center Licensing 19,400 19,400 4 appropriated to Department of Health and Social 5 Services 6 SB 365 Speech-Language Pathologist 800 800 7 Assistants appropriated to Department of 8 Community and Economic Development 9 SB 368 Tobacco Tax; Licensing; Penalties 206,400 206,400 10 appropriated to Department of Public Safety 11 SB 368 Tobacco Tax; Licensing; Penalties 621,700 621,700 12 appropriated to Department of Revenue 13 SB 376 Subpoena Power: Pub Asstnce & Perm -19,600 -19,600 14 Fund appropriated to Department of Health and 15 Social Services 16 SB 392 Regulatory Commission of Alasska 300,000 300,000 17 appropriated to Department of Law 18 SB 393 Take Perm Fund Dividend for Univ Fees 15,000 15,000 19 appropriated to Department of Revenue 20 SB 393 Take Perm Fund Dividend for Univ Fees 100,000 100,000 21 appropriated to University of Alaska 22 (SECTION 3 OF THIS ACT BEGINS ON PAGE 43) CCS DB 375, Sec. 2 -42- 1) ) 1 * Sec. 3. The following sets out the funding by agency for the appropriations made in sec. 1 2 and sec. 2 of this Act. 3 Department of Administration 4 Federal Receipts 587,600 5 General Fund Receipts 58,473,700 6 General Fund/Program Receipts 712,800 7 Inter-Agency Receipts 60,468,500 8 Group Health and Life Benefits Fund 17,434,600 9 FICA Administration Fund Account 151,700 10 Public Employees Retirement Trust Fund 5,717,700 11 Federal Surplus Property Revolving Fund 490,300 12 Teachers Retirement System Fund 2,288,400 13 Judicial Retirement System 29,100 14 National Guard Retirement System 104,400 15 Capital Improvement Project Receipts 573,200 16 Information Services Fund 34,517,000 17 Statutory Designated Program Receipts 1,391,200 18 Public Building Fund 5,974,100 19 Receipt Supported Services 9,641,000 20 Alaska Oil & Gas Conservation Commission Receipts 3,990,300 21 PFD Appropriations in lieu of Dividends to Criminals 875,200 22 *** Total Agency Funding *** $203,420,800 23 Department of Community and Economic Development 24 Federal Receipts 25,942,000 25 General Fund Match 356,700 26 General Fund Receipts 7,338,900 27 General Fund/Program Receipts 18,700 28 Inter-Agency Receipts 9,322,700 29 Commercial Fishing Loan Fund 3,176,800 30 Real Estate Surety Fund 257,300 31 Capital Improvement Project Receipts 2,876,100 CCS DB 375, Sec. 3 -43- Power Project Loan Fund 965,200 2 Fisheries Enhancement Revolving Loan Fund 501,100 3 Bulk Fuel Revolving Loan Fund 51,000 4 Power Cost Equalization Fund 15,700,000 5 Alaska Aerospace Development Corporation Revolving Fund 20,884,900 6 Alaska Industrial Development & Export Authority Receipts 4,288,400 7 Alaska Energy Authority Corporate Receipts 1,067,100 8 Statutory Designated Program Receipts 350,800 9 Fishermen's Fund Income 115,000 10 Regulatory Commission of Alaska Receipts 6,514,100 11 Receipt Supported Services 20,625,200 12 Rural Development Initiative Fund 44,700 13 Small Business Economic Development Revolving Loan Fund 43,400 14 Business Lic,ense Receipts 3,850,800 15 *** Total Agency Funding *** $124,290,900 16 Department of Corrections 17 Federal Receipts 4,397,400 18 General Fund Match 128,400 19 General Fund Receipts 149,981,200 20 General Fund/Program Receipts 27,900 2 I Inter-Agency Receipts 8,411,000 22 Correctional Industries Fund 3,114,300 23 Capital Improvement Project Receipts 237,000 24 Statutory Designated Program Receipts 2,465,800 25 Receipt Supported Services 2,786,800 26 PFD Appropriations in lieu of Dividends to Criminals 5,092,400 27 *** Total Agency Funding *** $ I 76,642,200 28 Department of Education and Early Development 29 Federal Receipts 150,546, I 00 30 General Fund Match 699,600 31 General Fund Receipts 22,445,900 CCS HB 375, Sec. 3 -44- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 General Fund/Program Receipts Inter-Agency Receipts Donated Commodity/Handling Fee Account Alaska Commission on Postsecondary Education Receipts Statutory Designated Program Receipts Art in Public Places Fund Technical Vocational Education Program Receipts Receipt Supported Services * * * Total Agency Funding * * * Department of Environmental Conservation Federal Receipts General Fund Match General Fund Receipts General Fund/Program Receipts Inter-Agency Receipts Oil/Hazardous Release Prevention & Response Fund Capital Improvement Project Receipts Alaska Clean Water Fund Underground Storage Tank Revolving Loan Fund Clean Air Protection Fund Alaska Drinking Water Fund Statutory Designated Program Receipts Receipt Supported Services Vessel Environmental Compliance Fund *** Total Agency Funding *** Department of Fish and Game Federal Receipts General Fund Match General Fund Receipts General Fund/Program Receipts Inter-Agency Receipts -45- ) 68,300 6,611,100 319,700 9,185,100 672,800 30,000 182,200 1,239,300 $192,000,100 16,428,600 2,683,000 7,422,700 1,438,800 1,157,000 13,481,300 2,601,600 489,700 964,500 3,893,500 557,800 77,400 1,237,600 714,000 $53,147,500 56,971,200 381,400 25,800,700 11,900 10,152,300 CCS DB 375, Sec. 3 Exxon Valdez Oil Spill Trust 4,425,000 2 Fish and Game Fund 26,373,400 3 Commercial Fishing Loan Fund 1,976,300 4 Inter-Agency/Oil & Hazardous Waste 64,000 5 Capital Improvement Project Receipts 4,745,000 6 Statutory Designated Program Receipts 3,513,200 7 Test Fisheries Receipts 2,500,900 8 Receipt Supported Services 3,396,900 9 *** Total Agency Funding *** $140,312,200 10 Office of the Governor 11 Federal Receipts 155,300 12 General Fund Receipts 15,151,300 13 General Fund/Program Receipts 4,900 14 Inter-Agency Receipts 91,200 15 Capital Improvement Project Receipts 183,100 16 Statutory Designated Program Receipts 95,000 17 Business License Receipts 706,800 18 *** Total Agency Funding *** $16,387,600 19 Department of Health and Social Services 20 Federal Receipts 935,245,800 21 General Fund Match 265,433,200 22 General Fund Receipts 174,122,000 23 Inter-Agency Receipts 67,713,900 24 Alcoholism and Drug Abuse Revolving Loan Fund 2,000 25 Permanent Fund Dividend Fund 15,949,900 26 Capital Improvement Project Receipts 1,873,700 27 Children's Trust Fund Earnings 395,900 28 Statutory Designated Program Receipts 65,228,300 29 Receipt Supported Services 18,163,900 30 Tobacco Use Education and Cessation Fund 4,669,500 31 *** Total Agency Funding *** $1,548,798,100 CCS DB 375, Sec. 3 -46- ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 Department of Labor and Workforce Development Federal Receipts General Fund Match General Fund Receipts General Fund/Program Receipts Inter-Agency Receipts Second Injury Fund Reserve Account Fishermen's Fund Training and Building Fund State Employment & Training Program Statutory Designated Program Receipts V ocational Rehabilitation Small Business Enterprise Fund Technical Vocational Education Program Receipts Receipt Supported Services Workers Safety and Compensation Administration Account Building Safety Account *** Total Agency Funding *** Department of Law Federal Receipts General Fund Match General Fund Receipts General Fund/Program Receipts Inter-Agency Receipts Inter-Agency/Oil & Hazardous Waste Permanent Fund Corporation Receipts Statutory Designated Program Receipts Fish and Game Criminal Fines and Penalties Regulatory Commission of Alaska Receipts *** Total Agency Funding *** Department of Military and Veterans Affairs Federal Receipts -47- ) 98,667,900 4,706,800 6,038,900 63,700 21,296,600 4,014,400 1,328,500 733,300 5,648,000 659,200 325,000 1,627,500 1,974,800 4,438,600 1,556,200 $153,079,400 761,000 165,800 28,962,300 412,000 17,612,500 508,100 1,477,000 844,500 135,700 500 $50,879,400 18,825,700 CCS HB 375, Sec. 3 General Fund Match 2,050,400 2 General Fund Receipts 6,929,000 3 General Fund/Program Receipts 28,400 4 Inter-Agency Receipts 5,550,200 5 OillHazardous Release Prevention & Response Fund 300,000 6 Inter-Agency/Oil & Hazardous Waste 250,300 7 Capital Improvement Project Receipts 551,500 8 Statutory Designated Program Receipts 585,000 9 *** Total Agency Funding *** $35,070,500 10 Department of Natural Resources 11 Federal Receipts 14,206,300 12 General Fund Match 1,582,300 13 General Fund Receipts 43,968,400 14 General Fund/Program Receipts 2,998,100 15 Inter-Agency Receipts 7,426,800 16 Exxon Valdez Oil Spill Trust 616,000 17 Agricultural Revolving Loan Fund 3,375,600 18 Inter-Agency/Oil & Hazardous Waste 67,000 19 Capital Improvement Project Receipts 4,374,800 20 Permanent Fund Corporation Receipts 3,987,400 21 Statutory Designated Program Receipts 7,398,700 22 State Land Disposal Income Fund 4,759,300 23 Shore Fisheries Development Lease Program 341,700 24 Timber Sale Receipts 712,500 25 Receipt Supported Services 5,860,100 26 * * * Total Agency Funding * * * $101,675,000 27 Department of Public Safety 28 Federal Receipts 11,914,800 29 General Fund Match 539,800 30 General Fund Receipts 83,600,600 31 General Fund/Program Receipts 802,700 CCS HB 375, Sec. 3 -48- ') ) 1 Inter-Agency Receipts 7,566,300 2 Inter-Agency/Oil & Hazardous Waste 25,000 3 Capital Improvement Project Receipts 1,460,700 4 Statutory Designated Program Receipts 1,458,900 5 Fish and Game Criminal Fines and Penalties 1,034,100 6 Alaska Fire Standards Council Receipts 229,300 7 Receipt Supported Services 3,945,400 8 PFD Appropriations in lieu of Dividends to Criminals 3,107,000 9 *** Total Agency Funding *** $115,684,600 10 Department of Revenue 11 Federal Receipts 34,810,900 12 General Fund Receipts 7,230,500 13 General Fund/Program Receipts 613,600 14 Inter-Agency Receipts 4,264,000 15 CSED Federal Incentive Payments 1,625,200 16 Group Health and Life Benefits Fund 99,000 17 International Airports Revenue Fund 67,800 18 Public Employees Retirement Trust Fund 19,444,800 19 Teachers Retirement System Fund 10,017,200 20 Judicial Retirement System 278,400 21 National Guard Retirement System 173,700 22 Education Loan Fund 48,800 23 Permanent Fund Dividend Fund 5,559,300 24 Capital Improvement Project Receipts 1,731,800 25 Public School Trust Fund 187,700 26 Children's Trust Fund Earnings 34,700 27 Alaska Housing Finance Corporation Receipts 17,106,700 28 Alaska Municipal Bond Bank Receipts 677,700 29 Permanent Fund Corporation Receipts 48,506,900 30 Statutory Designated Program Receipts 750,000 31 CSED Administrative Cost Reimbursement 1,197,100 CCS DB 375, Sec. 3 -49- Retiree Health Insurance Fund/Major Medical 64,000 2 Retiree Health Insurance Fund/Long- Term Care 70,600 3 Receipt Supported Services 4,874,300 4 Power Cost Equalization Endowment Fund 165,100 5 Business License Receipts 1,100,000 6 *** Total Agency Funding *** $160,699,800 7 Department of Transportation & Public Facilities 8 Federal Receipts 3,502,100 9 General Fund Receipts 98,000,200 10 General FundlProgram Receipts 21,000 11 Inter-Agency Receipts 5,668,600 12 Highways Equipment Working Capital Fund 24,621,600 13 International Airports Revenue Fund 55,871,200 14 OillHazardous Release Prevention & Response Fund 825,000 15 Capital Improvement Project Receipts 100,640,900 16 Alaska Marine Highway System Fund 86,601,600 17 Statutory Designated Program Receipts 1,146,700 18 Receipt Supported Services 7,258,000 19 *** Total Agency Funding *** $384,156,900 20 Alaska Court System 21 Federal Receipts 716,000 22 General Fund Receipts 58,548,300 23 Inter-Agency Receipts 321,000 24 Statutory Designated Program Receipts 10,000 25 *** Total Agency Funding *** $59,595,300 26 Legislature 27 General Fund Receipts 38,371,000 28 General FundlProgram Receipts 98,900 29 Inter-Agency Receipts 390,000 30 PFD Appropriations in lieu of Dividends to Criminals 328,600 31 *** Total Agency Funding *** $39,188,500 CCS DB 375, Sec. 3 -50- ) ) 1 New Legislation 2 Constitutional Budget Reserve Fund -125,000 3 Federal Receipts 364,900 4 General Fund Receipts 3,164,700 5 General Fund/Program Receipts 55,000 6 Inter-Agency Receipts -343,100 7 Fish and Game Fund 345,600 8 University of Alaska Restricted Receipts 100,000 9 Permanent Fund Dividend Fund 15,000 10 Statutory Designated Program Receipts 47,000 11 Regulatory Commission of Alaska Receipts 1,312,800 12 State Land Disposal Income Fund 390,500 13 Receipt Supported Services 436,600 14 Workers Safety and Compensation Administration Account 627,000 15 Alaska Oil & Gas Conservation Commission Receipts 20,000 16 Building Safety Account 142,000 17 Election Fund 442,800 18 Senior Care Fund 14,902,500 19 Mine Reclamation Trust Fund 21,000 20 *** Total New Legislation *** $21,919,300 21 * * * * * Total Budget * * * * * $3,576,948,100 22 (SECTION 4 OF THIS ACT BEGINS ON PAGE 52) CCS DB 375, Sec. 3 -51- * Sec. 4. The following sets out the statewide funding for the appropriations made in sec. 1 2 and sec. 2 of this Act. 3 New 4 Funding Source Operating Legislation Total 5 General Funds 6 1003 General Fund Match 278,727,400 278,727,400 7 1004 General Fund Receipts 832,385,600 3,164,700 835,550,300 8 1005 General Fund/Program Receipts 7,321,700 55,000 7,376,700 9 * * * Total General Funds*** $1,118,434,700 $3,219,700 $1,121,654,400 10 Federal Funds 11 1002 Federal Receipts 1,373,678,700 364,900 1,374,043,600 12 1013 Alcoholism and Drug Abuse 2,000 2,000 13 Revolving Loan Fund 14 1014 Donated Commodity/Handling Fee 319,700 319,700 15 Account 16 1016 CSED Federal Incentive Payments 1,625,200 1,625,200 17 1033 Federal Surplus Property 490,300 490,300 18 Revolving Fund 19 1133 CSED Administrative Cost 1,197,100 1,197,100 20 Reimbursement 21 ***Total Federal Funds*** $1,377,313,000 $364,900 $1,377,677,900 22 Other Non-Duplicated Funds 23 1001 Constitutional Budget Reserve Fund -125,000 -125,000 24 1017 Group Health and Life Benefits 17,533,600 17,533,600 25 Fund 26 1018 Exxon Valdez Oil Spill Trust 5,041,000 5,041,000 27 1021 Agricultural Revolving Loan Fund 3,375,600 3,375,600 28 1023 FICA Administration Fund Account 151,700 151,700 29 1024 Fish and Game Fund 26,373,400 345,600 26,719,000 30 1027 International Airports Revenue 55,939,000 55,939,000 31 Fund CCS DB 375, Sec. 4 -52- ) ') New 2 Funding Source Operating Legislation Total 3 1029 Public Employees Retirement Trust 25,162,500 25,162,500 4 Fund 5 1031 Second Injury Fund Reserve Account 4,014,400 4,014,400 6 1032 Fishermen's Fund 1,328,500 1,328,500 7 1034 Teachers Retirement System Fund 12,305,600 12,305,600 8 1036 Commercial Fishing Loan Fund 5,153,100 5,153,100 9 1040 Real Estate Surety Fund 257,300 257,300 10 1042 Judicial Retirement System 307,500 307,500 11 1045 National Guard Retirement System 278,100 278,100 12 1046 Education Loan Fund 48,800 48,800 13 1048 University of Alaska Restricted 100,000 100,000 14 Receipts 15 1049 Training and Building Fund 733,300 733,300 16 1054 State Employment & Training 5,648,000 5,648,000 17 Program 18 1059 Correctional Industries Fund 3,114,300 3,114,300 19 1062 Power Project Loan Fund 965,200 965,200 20 1066 Public School Trust Fund 187,700 187,700 21 1070 Fisheries Enhancement Revolving 501,100 501,100 22 Loan Fund 23 1074 Bulk Fuel Revolving Loan Fund 51,000 51 ,000 24 1076 Alaska Marine Highway System Fund 86,601,600 86,601,600 25 1093 Clean Air Protection Fund 3,893,500 3,893,500 26 1098 Children's Trust Fund Earnings 430,600 430,600 27 1101 Alaska Aerospace Development 20,884,900 20,884,900 28 Corporation Revolving Fund 29 1102 Alaska Industrial Development & 4,288,400 4,288,400 30 Export Authority Receipts 31 1103 Alaska Housing Finance 17,106,700 17,106,700 32 Corporation Receipts 33 1104 Alaska Municipal Bond Bank 677,700 677,700 CCS HB 375, Sec. 4 -53- New 2 Funding Source Operating Legislation Total 3 Receipts 4 1105 Permanent Fund Corporation 53,971,300 53,971,300 5 Receipts 6 1106 Alaska Commission on 9,185,100 9,185,100 7 Postsecondary Education Receipts 8 1107 Alaska Energy Authority Corporate 1,067,100 1,067,100 9 Receipts 10 1108 Statutory Designated Program 86,647,500 47,000 86,694,500 11 Receipts 12 1109 Test Fisheries Receipts 2,500,900 2,500,900 13 1111 Fishermen's Fund Income 115,000 115,000 14 1117 V ocational Rehabilitation Small 325,000 325,000 15 Business Enterprise Fund 16 1141 Regulatory Commission of Alaska 6,514,600 1,312,800 7,827,400 17 Receipts 18 1142 Retiree Health Insurance Fundi 64,000 64,000 19 Major Medical 20 1143 Retiree Health Insurance Fundi 70,600 70,600 21 Long-Term Care 22 1151 Technical Vocational Education 1,809,700 1,809,700 23 Program Receipts 24 1152 Alaska Fire Standards Council 229,300 229,300 25 Receipts 26 1153 State Land Disposal Incom,e Fund 4,759,300 390,500 5,149,800 27 1154 Shore Fisheries Development Lease 341,700 341,700 28 Program 29 1155 Timber Sale Receipts 712,500 712,500 30 1156 Receipt Supported Services 81,003,300 436,600 81,439,900 31 1157 Workers Safety and Compensation 4,438,600 627,000 5,065,600 32 Administration Account 33 1162 Alaska Oil & Gas Conservation 3,990,300 20,000 4,010,300 CCS HB 375, Sec. 4 -54- ) ) 1 New 2 Funding Source Operating Legislation Total 3 Commission Receipts 4 1164 Rural Development Initiative Fund 44,700 44,700 5 1166 Vessel Environmental Compliance 714,000 714,000 6 Fund 7 1168 Tobacco Use Education and 4,669,500 4,669,500 8 Cessation Fund 9 1169 Power Cost Equalization Endowment 165,100 165,100 10 Fund 11 1170 Small Business Economic 43,400 43,400 12 Development Revolving Loan Fund 13 1172 Building Safety Account 1,556,200 142,000 1,698,200 14 1175 Business License Receipts 5,657,600 5,657,600 15 1192 Mine Reclamation Trust Fund 21,000 21,000 16 ***Total Other Non-Duplicated Funds*** $572,950,400 $3,317,500 $576,267,900 17 Duplicated Funds 18 1007 Inter-Agency Receipts 234,023,700 -343,100 233,680,600 19 1026 Highways Equipment Working 24,621,600 24,621,600 20 Capital Fund 21 1050 Permanent Fund Dividend Fund 21,509,200 15,000 21,524,200 22 1052 Oil/Hazardous Release Prevention 14,606,300 14,606,300 23 & Response Fund 24 1055 Inter-Agency/Oil & Hazardous Waste 914,400 914,400 25 1061 Capital Improvement Project 121,849,400 121,849,400 26 Receipts 27 1075 Alaska Clean Water Fund 489,700 489,700 28 1079 Underground Storage Tank 964,500 964,500 29 Revolving Loan Fund 30 1081 Information Services Fund 34,517,000 34,517,000 31 1089 Power Cost Equalization Fund 15,700,000 15,700,000 32 1100 Alaska Drinking Water Fund 557,800 557,800 33 1134 Fish and Game Criminal Fines and 1,169,800 1,169,800 CCS HB 375, Sec. 4 -55- 2 3 4 5 6 7 8 9 10 11 New Operating Legislation Funding Source Penalties I 145 Art in Public Places Fund 1147 Public Building Fund 1171 PFD Appropriations in lieu of Dividends to Criminals 1185 Election Fund 442,800 1189 Senior Care Fund 14,902,500 ***Total Duplicated Funds*** $486,330,700 $15,017,200 (SECTION 5 OF THIS ACT BEGINS ON PAGE 57) 30,000 5,974,100 9,403,200 CCS HB 375, Sec. 4 -56- Total 30,000 5,974,100 9,403,200 442,800 14,902,500 $501,347,900 ) ) 1 * Sec. 5. LEGISLATIVE INTENT. It is the intent of the legislature that the amounts 2 appropriated by this Act are the full amounts that will be appropriated for those purposes for 3 the fiscal year ending June 30, 2005. 4 * Sec. 6. COSTS OF JOB RECLASSIFICATIONS. The money appropriated in this Act 5 includes the amount necessary to pay the costs of personal services due to reclassification of 6 job classes during the fiscal year ending June 30, 2005. 7 * Sec. 7. ALASKA AEROSPACE DEVELOPMENT CORPORATION. Corporate 8 receipts of the Alaska Aerospace Development Corporation received during the fiscal year 9 ending June 30, 2005, that are in excess of the amount appropriated in sec. 1 of this Act are 10 appropriated to the Alaska Aerospace Development Corporation for operations during the 11 fiscal year ending June 30, 2005. 12 * Sec. 8. ALASKA CHILDREN'S TRUST. The portions of the fees listed in this section 13 that are collected during the fiscal year ending June 30, 2005, are appropriated to the Alaska 14 children's trust (AS 37.14.200): 15 (1) fees collected under AS 18.50.225, less the cost of supplies, for the 16 issuance of birth certificates; 17 (2) fees collected under AS 18.50.272, less the cost of supplies, for the 18 issuance of heirloom marriage certificates; and 19 (3) fees collected under AS 28.I0.421(d) for the issuance of special request 20 Alaska children's trust license plates, less the cost of issuing the license plates. 21 * Sec. 9. ALASKA CLEAN WATER FUND. The sum of $9,720,000 is appropriated to 22 the Alaska clean water fund (AS 46.03.032) for the Alaska clean water loan program from the 23 following sources: 24 Alaska clean water fund revenue bond receipts $1,620,000 25 Federal receipts 8,100,000 26 * Sec. 10. ALASKA DRINKING WATER FUND. The sum of $9,720,000 is appropriated 27 to the Alaska drinking water fund (AS 46.03.036) for the Alaska drinking water loan program 28 from the following sources: 29 Alaska drinking water fund revenue bond receipts $1,020,000 30 Federal receipts 8,100,000 31 General fund match 600,000 -57- CCS HB 375 * Sec. 11. ALASKA HOUSING FINANCE CORPORATION. (a) The board of directors 2 of the Alaska Housing Finance Corporation anticipates that the net income trom the second 3 preceding fiscal year will be available in each of the fiscal years 2005 through 2006. During 4 fiscal year 2005, the board of directors anticipates that $103,000,000 will be available for 5 payment of debt service, appropriation in this Act, appropriation for capital projects, and 6 transfer to the Alaska debt retirement fund (AS 37.15.011). 7 (b) A portion of the amount set out in (a) of this section for the fiscal year ending 8 June 30, 2005, will be retained by the Alaska Housing Finance Corporation for the following 9 purposes in the following estimated amounts: 10 (1) $1,000,000 for debt service on University of Alaska, Anchorage, 11 dormitory construction, authorized under ch. 26, SLA 1996; 12 (2) $37,978,856 for debt service on the bonds authorized under sec. 2(c), ch. 13 129, SLA 1998; 14 (3) $12,019,790 for debt service on the bonds authorized under sec. 10, ch. 15 130, SLA 2000; 16 (4) $2,893,808 for debt service on the bonds authorized under ch. 2, SSSLA J 7 2002; 18 (5) $29,894,063 for debt service; J 9 (6) $2,050,000 to capitalize the senior care fund (sec. 2, ch. 3, SLA 2004); and 20 (7) $17,163,400 for capital projects. 21 (c) After deductions for the items set out in (b) of this section and for appropriations 22 for operating and capital purposes are made, any remaining balance of the amount set out in 23 (a) of this section for the fiscal year ending June 30, 2005, is appropriated to the Alaska debt 24 retirement fund (AS 37.15.011). 25 (d) All unrestricted mortgage loan interest payments, mortgage loan commitment 26 fees, and other unrestricted receipts received by or accrued to the Alaska Housing Finance 27 Corporation during fiscal year 2005 and all income earned on assets of the corporation during 28 that period are appropriated to the Alaska Housing Finance Corporation to hold as corporate 29 receipts for the purposes described in AS 18.55 and AS 18.56. The corporation shall allocate 30 its corporate receipts among the Alaska housing finance revolving fund (AS 18.56.082), 31 housing assistance loan fund (AS 18.56.420), and senior housing revolving fund CCS HB 375 -58- ) ) 1 (AS 18.56.710) in accordance with procedures adopted by the board of directors. 2 (e) The sum of $800,000,000 is appropriated from the corporate receipts appropriated 3 to the Alaska Housing Finance Corporation and allocated among the Alaska housing finance 4 revolving fund (AS 18.56.082), housing assistance loan fund (AS 18.56.420), and senior 5 housing revolving fund (AS 18.56.710) under (d) of this section to the Alaska Housing 6 Finance Corporation for the fiscal year ending June 30, 2005, for housing loan programs not 7 subsidized by the corporation. 8 (f) The sum of $30,000,000 is appropriated from the portion of the corporate receipts 9 appropriated to the Alaska Housing Finance Corporation and allocated among the Alaska 10 housing finance revolving fund (AS 18.56.082), housing assistance loan fund (AS 18.56.420), 11 and senior housing revolving fund (AS 18.56.710) under (d) of this section that is derived 12 from arbitrage earnings to the Alaska Housing Finance Corporation for the fiscal year ending 13 June 30, 2005, for housing loan programs and projects subsidized by the corporation. 14 (g) The sum of $30,000,000 is appropriated from federal receipts to the Alaska 15 Housing Finance Corporation for housing assistance payments under the Section 8 program 16 for the fiscal year ending June 30, 2005. 17 * Sec. 12. ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY. (a) 18 The sum of $22,000,000 has been declared available by the Alaska Industrial Development 19 and Export Authority board of directors for appropriation as the fiscal year 2005 dividend 20 from the unrestricted balance in the Alaska Industrial Development and Export Authority 21 revolving fund (AS 44.88.060). 22 (b) After deductions for appropriations made for operating and capital purposes are 23 made, any remaining balance of the amount setout in (a) of this section for the fiscal year 24 ending June 30, 2005, is appropriated to the Alaska debt retirement fund (AS 37.15.011). 25 * Sec. 13. ALASKA PERMANENT FUND CORPORATION. (a) The amount authorized 26 under AS 37.13.145(b) for transfer by the Alaska Permanent Fund Corporation on June 30, 27 2005, is appropriated from the earnings reserve account (AS 37.13.145) to the dividend fund 28 (AS 43.23.045(a» for the payment of permanent fund dividends and administrative and 29 associated costs for the fiscal year ending June 30, 2005. 30 (b) After money is transferred to the dividend fund under (a) of this section, the 31 amount calculated under AS 37.13.145 to offset the effect of inflation on the principal of the -59- CCS HB 375 1 Alaska permanent fund during fiscal year 2005 is appropriated from the earnings reserve 2 account (AS 37.13.145) to the principal of the Alaska permanent fund. 3 (c) The amount required to be deposited under AS 37.13.010(a)(l) and (2) during 4 fiscal year 2005 is appropriated to the principal of the Alaska permanent fund in satisfaction 5 of that requirement. 6 (d) The income earned during fiscal year 2005 on revenue from the sources set out in 7 AS 37.13.145(d) is appropriated to the principal of the Alaska permanent fund. 8 * Sec. 14. ALASKA STUDENT LOAN CORPORATION DIVIDEND. (a) The sum of 9 $5,600,000 has been declared available by the Alaska Student Loan Corporation board of 10 directors for appropriation as the fiscal year 2005 dividend. 11 (b) After deductions for appropriations made for operating and capital purposes are 12 made, any remaining balance of the amount set out in (a) of this section for the fiscal year 13 ending June 30, 2005, is appropriated to the Alaska debt retirement fund (AS 37.15.011). 14 * Sec. 15. CHILD SUPPORT ENFORCEMENT. (a) The minimum amount of program 15 receipts received during the fiscal year ending June 30, 2005, by the child support 16 enforcement division that is required to secure the federal funding appropriated for the child 17 support enforcement program in sec. 1 of this Act is appropriated to the Department of 18 Revenue, child support enforcement division, for the fiscal year ending June 30, 2005. 19 (b) Program receipts collected as cost recovery for paternity testing administered by 20 the child support enforcement division, as required under AS 25.27.040 and 25.27.165, and as 21 collected under AS 25.20.050(f), are appropriated to the Department of Revenue, child 22 support enforcement division, for the fiscal year ending June 30, 2005. 23 * Sec. 16. DISASTER RELIEF AND FIRE SUPPRESSION. (a) Federal receipts received 24 for disaster relief during the fiscal year ending June 30, 2005, are appropriated to the disaster 25 relief fund (AS 26.23.300). 26 (b) Federal receipts received for fire suppreSSIOn during the fiscal year ending 27 June 30, 2005, are appropriated to the Department of Natural Resources for fire suppression 28 activities for the fiscal year ending June 30, 2005. 29 * Sec. 17. EDUCA TION LOAN PROGRAM. The amount of loan origination fees 30 collected by the Alaska Commission on Postsecondary Education for the fiscal year ending 31 June 30, 2005, is appropriated to the origination fee account (AS 14.43.120(u)) within the CCS HB 375 -60- ) ) 1 education loan fund of the Alaska Student Loan Corporation for the purposes specified in 2 AS 14.43.120(u). 3 * Sec. 18. FEDERAL AND OTHER PROGRAM RECEIPTS. (a) Federal receipts, 4 designated program receipts as defined in AS 37.05.146(b)(3), information services fund 5 program receipts as defined in AS 44.21.045(b), Exxon Valdez oil spill trust receipts as 6 defined in AS 37.05.146(b)(4), and receipts of the Alaska Fire Standards Council under 7 AS 37.05.146(b)(5) that are received during the fiscal year ending June 30, 2005, and that 8 exceed the amounts appropriated by this Act, are appropriated conditioned on compliance 9 with the program review provisions of AS 37.07.080(h). 10 (b) If federal or other program receipts as defined in AS 37.05.146 and in 11 AS 44.21.045{b) that are received during the fiscal year ending June 30, 2005, exceed the 12 estimates appropriated by this Act, the appropriations from state funds for the affected 13 program may be reduced by the excess if the reductions are consistent with applicable federal 14 statutes. 15 (c) If federal or other program receipts as defined in AS 37.05.146 and in 16 AS 44.21.045{b) that are received during the fiscal year ending June 30, 2005, fall short of the 1 7 estimates appropriated by this Act, the affected appropriation is reduced by the amount of the 18 shortfall in receipts. 19 * Sec. 19. FISH AND GAME ENFORCEMENT. (a) To increase enforcement of the fish 20 and game laws of the state, the amount deposited in the general fund during the fiscal year 21 ending June 30, 2004, fTom criminal fines, penalties, and forfeitures imposed for violation of 22 AS 16 and its implementing regulations and from the sale of forfeited property or alternative 23 damages collected under AS 16.05.195 is appropriated to the fish and game fund 24 (AS 16.05.100). 25 (b) Appropriations totaling the estimated amount of the deposits described in (a) of 26 this section and the remaining unexpended and unobligated balances fTom prior year transfers 27 for these purposes are made in sec. 1 of this Act to the Department of Public Safety and the 28 Department of Law for increased enforcement, investigation, and prosecution of state fish and 29 game laws. If the amounts of the deposits and unexpended and unobligated balances fall 30 short of the estimates appropriated in sec. 1 of this Act, the amounts appropriated to the 31 Department of Public Safety and the Department of Law fTom the fish and game fund as set -61- CCS HB 375 out in sec. 1 of this Act are reduced proportionately. 2 * Sec. 20. FISH AND GAME FUND. The following revenue collected during the fiscal 3 year ending June 30, 2005, is appropriated to the fish and game fund (AS 16.05.100): 4 (1) receipts from the sale of crewmember fishing licenses (AS 16.05.480(a)) 5 that are not deposited into the fishermen's fund under AS 23.35.060; 6 (2) range fees collected at shooting ranges operated by the Department of Fish 7 and Game (AS 16.05.050(a)(16)); 8 (3) fees collected at boating and angling access sites described in 9 AS 16.05.050(a)(7) and managed by the Department of Natural Resources, division of parks 10 and outdoor recreation, under a cooperative agreement; 11 (4) receipts from the sale of waterfowl conservation stamp limited edition 12 prints (AS 16.05.826(a)); and 13 (5) fees collected for sanctuary access permits (AS 16.05.050(a)(16)). 14 * Sec. 21. FUND TRANSFERS. (a) The amount of the net income earned during the 15 fiscal year ending June 30, 2005, on the appropriation made by sec. 2(a), ch. 19, SLA 1993, to 16 the Department of Administration for a grant to the Chugach Electric Association and held by 17 the Alaska Industrial Development and Export Authority is appropriated to the general fund. 18 (b) The sum of ?l1~',888 is appropriated from the general fund to the Alaska 19 marine highway system fund (AS 19.65.060). 20 (c) The sum of $2,473,124 is appropriated from the investment earnings on the bond 21 proceeds deposited in the capital project funds for the series 2003A general obligation bonds 22 to the Alaska debt retirement fund (AS 37.15.011). 23 (d) The sum of $8,606,387 is appropriated from federal receipts for state guaranteed 24 transportation revenue anticipation bonds, series 2003B, to the Alaska debt retirement fund 25 (AS 37.15.011). 26 (e) The sum of $438,614 is appropriated from Alaska accelerated transportation 27 projects fund bond proceeds for state guaranteed transportation revenue anticipation bonds, 28 series 2003B, to the Alaska debt retirement fund (AS 37.15.011). 29 (f) The sum of $24,815,000 is appropriated from Alaska Student Loan Corporation 30 bond proceeds to the Alaska debt retirement fund (AS 37.15.011). 31 (g) The sum of $27,568,000 is appropriated trom Alaska Housing Finance CCS HB 375 -62- ) ) 1 Corporation fiscal year 2005 dividend to the Alaska debt retirement fund (AS 37.15.011). 2 (h) The sum of $11,000,000 is appropriated from Alaska Industrial Development and 3 Export Authority fiscal year 2005 dividend to the Alaska debt retirement fund 4 (AS 37.15.011). 5 (i) The sum of $775,000 is appropriated from miscellaneous earnings from earnings 6 on unreserved investment earnings of the Alaska Municipal Bond Bank to the Alaska debt 7 retirement fund (AS 37.15.011). 8 G) The sum of $109,800 is appropriated from residual balances in lease payment 9 accounts to the Alaska debt retirement fund (AS 37.15.011). 10 (k) The sum of $104,029 is appropriated trom the investment loss trust fund 11 (AS 37.14.300) to the Alaska debt retirement fund (AS 37.15.011). 12 (l) The balance of the electrical service extension fund (AS 42.45.200) is appropriated 13 to the general fund. 14 (m) The sum of $14,902,500 is appropriated to the senior care fund (sec. 2, ch. 3, 15 SLA 2004) from the following sources in the amounts stated: 16 General fund $1,942,000 17 Alaska Housing Finance Corporation dividend 2,050,000 18 Alaska Industrial Development and Export Authority dividend 8,162,600 19 Alaska Student Loan Corporation dividend 2,747,900 20 (n) The sum of $2,837,400 is appropriated from the Alaska Industrial Development 21 and Export Authority dividend to the Alaska debt retirement fund (AS 37.15.011). 22 * Sec. 22. INSURANCE AND BOND CLAIMS. (a) The amount necessary to fund the 23 uses of the state insurance catastrophe reserve account described in AS 37.05.289(a) is 24 appropriated from that account to the Department of Administration for those uses during the 25 fiscal year ending June 30, 2005. 26 (b) The amounts received in settlement of claims against bonds guaranteeing the 27 reclamation of state, federal, or private land, including the plugging or repair of wells, are 28 appropriated to the agency secured by the bond for the fiscal year ending June 30, 2005, for 29 the purpose of reclaiming the state, federal, or private land affected by a use covered by the 30 bond. 31 * Sec. 23. LEGISLATIVE COUNCIL. The unexpended and unobligated balance, -63- CCS HB 375 estimated to be $60,000, of that portion of the appropriation made by sec. 1, ch. 83, SLA 2 2003, page 37, line 26 (Legislative Council - $22,824,800) that is appropriated from PFD 3 Appropriations in lieu of Dividends to Criminals is reappropriated to the Legislative Council 4 for office of victims' rights expenses for the fiscal year ending June 30, 2005. 5 * Sec. 24. NATIONAL FOREST RECEIPTS. The unexpended and unobligated balance of 6 federal money apportioned to the state as national forest income that the Department of 7 Community and Economic Development determines would lapse into the unrestricted portion 8 of the general fund June 30, 2005, under AS 41.15.1800) is appropriated as follows: 9 (1) up to $170,000 is appropriated to the Department of Transportation and 10 Public Facilities, commissioner's office, for road maintenance in the unorganized borough; 11 and ] 2 (2) the balance remaining is appropriated to home rule cities, first class cities, 13 second class cities, a municipality organized under federal law, or regional educational 14 attendance areas entitled to payment from the national forest income for the fiscal year ending 15 June 30, 2005, to be allocated among the recipients of national forest income according to 16 their pro rata share of the total amount distributed under AS 41.15.l80(c) and (d) for the fiscal 17 year ending June 30, 2005. 18 * Sec. 25. OFFICE OF THE GOVERNOR. (a) The sum of $7,446,803 is appropriated 19 from federal receipts to the election fund required by the federal Help America Vote Act. 20 (b) Interest earned on amounts in the election fund are appropriated to the election 2] fund as required by the federal Help America Vote Act. 22 * Sec. 26. OIL AND HAZARDOUS SUBSTANCE RELEASE PREVENTION 23 ACCOUNT. The following amounts are appropriated to the oil and hazardous substance 24 release prevention account (AS 46.08.010(a)(l» in the oil and hazardous substance release 25 prevention and response fund (AS 46.08.010) from the sources indicated: 26 (1) the balance of the oil and hazardous substance release prevention 27 mitigation account (AS 46.08.020(b» in the general fund on July 1, 2004, not otherwise 28 appropriated by this Act; 29 (2) the amount collected for the fiscal year ending June 30, 2004, estimated to 30 be $9,500,000, from the surcharge levied under AS 43.55.300. 31 * Sec. 27. OIL AND HAZARDOUS SUBSTANCE RELEASE RESPONSE ACCOUNT. CCS HB 375 -64- ) ') 1 The following amounts are appropriated to the oil and hazardous substance release response 2 account (AS 46.08.010(a)(2)) in the oil and hazardous substance release prevention and 3 response fund (AS 46.08.010) from the following sources: 4 (1) the balance of the oil and hazardous substance release response mitigation 5 account (AS 46.08.025(b)) in the general fund on July 1, 2004, not otherwise appropriated by 6 this Act; 7 (2) the amount collected for the fiscal year ending June 30, 2004, from the 8 surcharge levied under AS 43.55.201. 9 * Sec. 28. POWER COST EQUALIZATION. (a) The sum of $4,400,000 is appropriated 10 to the power cost equalization and rural electric capitalization fund (AS 42.45.100) from the 11 following sources in the amounts set out: 12 Power cost equalization endowment fund (AS 42.45.070) $2,200,000 13 General fund 2,200,000 14 (b) The amount necessary to provide the sum appropriated from the power cost 15 equalization and rural electric capitalization fund (AS 42.45.100) by sec. 1 of this Act, after 16 the appropriation made in (a) of this section, is appropriated from the power cost equalization 17 endowment fund (AS 42.45.070) to the power cost equalization and rural electric 18 capitalization fund, However, in accordance with AS 42.45.085(a), the amount appropriated 19 by this subsection may not exceed seven percent of the market value of the power cost 20 equalization endowment fund, determined by the commissioner of revenue to be 21 $11,369,441.16, minus amounts appropriated during the fiscal year ending June 30, 2005, for 22 reimbursement of the costs set out in AS 42.45.085(a)(2) and (3). 23 * Sec. 29. RETAINED FEES AND BANKCARD SERVICE FEES. (a) The amount 24 retained to compensate the collector or trustee of fees, licenses, taxes, or other money 25 belonging to the state during the fiscal year ending June 30, 2005, is appropriated for that 26 purpose to the agency authorized by law to generate the revenue. 27 (b) The amount retained to compensate the provider of bankcard or credit card 28 services to the state during the fiscal year ending June 30, 2005, is appropriated for that 29 purpose to each agency of the executive, legislative, and judicial branches that accepts 30 payment by bankcard or credit card for licenses, permits, goods, and services provided by that 31 agency on behalf of the state, from the funds and accounts in which the payments received by -65- CCS HB 375 the state are deposited. 2 * Sec. 30. SALARY AND BENEFIT ADJUSTMENTS. (a) The operating budget 3 appropriations made in sec. 1 of this Act, and in sec. 1 of the Act making appropriations for 4 the state's integrated comprehensive mental health program, in elude $5)1~1,~~ for benefit 5 adjustments for public officials, officers, and employees of the executive branch, Alaska 6 Court System employees, employees of the legislature, and legislators and to implement the 7 monetary terms for the fiscal year ending June 30, 2005, of the following collective 8 bargaining agreements: 9 (1) Public Employees Local 71, for the Labor, Trades and Crafts Unit; 10 (2) Public Safety Employees Association, for the Correctional Officers Unit; 11 ~~ Public Safcty Employees Association, rcprcscnting statc troopers :mc1 otho¡: 12 commissioned 1.... n ,",u.a;. ccment personnel; 13 (4) Alaska Public Employees Association, for the Confidential Unit; 14 (5) Alaska Public Employees Association, for the Supervisory Unit; 15 (6) Teachers' Education Association ofMt. Edgecumbe. 16 The operating budget appropriations made to the University of Alaska for 17 ding June 30, 2005, inelude amounts for salary and benefit a . 18 university employee not members of a 19 implementing the monetary term 20 21 22 a Community Colleges' Federation ofTeac 23 (3) United Academics; 24 (1) United Acadcmics Adjuncts. 25 (c) If a collective bargaining agreement listed in (a) of this section is not ratified by 26 the membership of the respective collecting bargaining unit, the appropriations made by this 27 Act, and in the Act making appropriations for the state's integrated comprehensive mental 28 health program, that are applicable to that collective bargaining unit's agreement are reduced 29 proportionately by the amount for that collective bargaining agreement, and the corresponding 30 funding source amounts are reduced accordingly. 31 * Sec. 31. SALMON ENHANCEMENT TAX. The salmon enhancement tax collected CCS HB 375 -66- ) ) 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 under AS 43.76,010 - 43.76.028 in calendar year 2003 and deposited in the general fund under AS 43.76.025(c) is appropriated from the general fund to the Department of Community and Economic Development for payment in fiscal year 2005 to qualified regional associations operating within a region designated under AS 16.10.375. * Sec. 32. SHARED TAXES AND FEES. The amount necessary to refund to local governments their share of taxes and fees collected in the listed fiscal years under the following programs is appropriated to the Department of Revenue from the general fund for payment in fiscal year 2005: REVENUE SOURCE FISCAL YEAR COLLECTED fisheries taxes (AS 43.75) 2004 fishery resource landing tax (AS 43.77) 2004 aviation fuel tax (AS 43.40.010) 2005 electric and telephone cooperative tax (AS 10.25.570) 2005 liquor license fee (AS 04.11) 2005 * Sec. 33. STATE DEBT AND OTHER OBLIGATIONS. (a) The amount required to pay interest on any revenue anticipation notes issued by the commissioner of revenue under AS 43.08 during the fiscal year ending June 30, 2005, is appropriated from the general fund to the Department of Revenue for payment of the interest on those notes. (b) The sum of$81,870,084 is appropriated to the Department of Education and Early Development for state aid for costs of school construction under AS 14.11.100 from the following sources: Alaska debt retirement fund (AS 37.15.011) $51,670,084 School fund (AS 43.50.140) 30,200,000 (c) The sum of $13,811,346 is appropriated from the Alaska debt retirement fund (AS 37.15.011) to the state bond committee for the fiscal year ending June 30, 2005, for trustee fees and lease payments relating to certificates of participation issued for real property. (d) The sum of $3,549,363 is appropriated to the Department of Administration for the fiscal year ending June 30, 2005, for payment of obligations to the Alaska Housing Finance Corporation for the Robert B. Atwood Building in Anchorage from the following sources: Alaska Housing Finance Corporation dividend $2,326,063 -67- CCS HB 375 Miscellaneous earnings 1,223,300 2 (e) The amount required to be paid by the state for principal and interest on all issued 3 and outstanding state-guaranteed bonds is appropriated from the general fund to the Alaska 4 Housing Finance Corporation for the fiscal year ending June 30, 2005, for payment of 5 principal and interest on those bonds. 6 (f) The sum of $2,735,919 is appropriated from the general fund to the following 7 departments for the fiscal year ending June 30, 2005, for payment of debt service on 8 outstanding debt authorized by AS 14.40.257, AS 29.60.700, and AS 42.45.065, respectively, 9 for the following projects: 10 DEPARTMENT AND PROJECT APPROPRIATION AMOUNT 11 (1) University of Alaska $1,413,993 12 Anchorage Community and Technical College Center 13 Juneau Readiness Center/UAS Joint Facility 14 (2) Department of Transportation and Public Facilities 129,962 15 Nome port facility addition and renovation 16 (3) Department of Community and Economic Development 1,191,964 17 Metlakatla Power and Light (utility plant and 18 capital additions) 19 (g) The sum of $19,706,207 is appropriated to the state bond committee from the 20 Alaska debt retirement fund (AS 37.15.011) for payment of debt service, accrued interest, and 21 trustee fees on outstanding State of Alaska general obligation bonds, series 2003A. 22 (h) The sum of$12,609,306 is appropriated to the state bond committee from State of 23 Alaska general obligation bonds, series 2003A bond issue premium, interest earnings, and 24 accrued interest held in the Alaska debt service fund for the fiscal year ending June 30, 2005, 25 for payment of debt service, accrued interest, and trustee fees on outstanding State of Alaska 26 general obligation bonds, series 2003A. 27 (i) The sum of $9,045,000 is appropriated to the state bond committee from the 28 Alaska debt retirement fund (AS 37.15.011) for payment of debt service, accrued interest, and 29 trustee fees on outstanding state guaranteed transportation revenue anticipation bonds, series 30 2003B. 31 U) The sum of $5,045,613 is appropriated to the state bond committee from state CCS HB 375 -68- ) ) 1 guaranteed transportation revenue anticipation bonds, series 2003B bond issue premium, 2 interest earnings, and accrued interest held in the Alaska debt service fund for the fiscal year 3 ending June 30, 2005, for payment of debt service and trustee fees on outstanding state 4 guaranteed transportation revenue anticipation bonds, series 2003B. 5 (k) The sum of $5,274,800 is appropriated from the general fund to the Department of 6 Administration, for the fiscal year ending June 30, 2005, for payment of obligations and fees 7 for the Anchorage Jail. 8 (I) The sum of $1,630,000 is appropriated from interest earnings of the Alaska clean 9 water fund (AS 46.03.032) to the Alaska clean water fund revenue bond redemption fund 10 (AS 37.15.565) for payment of principal and interest, redemption premium, and trustee fees, 11 if any, on bonds issued by the state bond committee under AS 37.15.560 during the fiscal year 12 ending June 30, 2005. 13 (m) The sum of $1,030,000 is appropriated from interest earnings of the Alaska 14 drinking water fund (AS 46.03.036) to the Alaska drinking water fund revenue bond 15 redemption fund (AS 37.15.565) for payment of principal and interest, redemption premium, 16 and trustee fees, if any, on bonds issued by the state bond committee under AS 37.15.560 17 during the fiscal year ending June 30, 2005. 18 (n) The sum of $31,423,824 is appropriated to the state bond committee for the fiscal 19 year ending June 30, 2005, for payment of debt service and trustee fees on outstanding 20 international airports revenue bonds from the following sources in the amounts stated: 21 SOURCE AMOUNT 22 International Airports Revenue Fund (AS 37.15.430) $29,423,824 23 Passenger facility charge 2,000,000 24 ( 0 ) The amount necessary to pay the arbitrage rebate liability arising from the 25 issuance of the Alaska International Airports System's 1999 Series C construction bonds, 26 estimated to be $134,000, is appropriated from the Alaska International Airports System's 27 1999 Series C construction fund (A Y18) to the state bond committee for payment of this 28 arbitrage rebate liability. 29 * Sec. 34. STATEWIDE ELECTION COSTS. The sum of $2,382,600 is appropriated 30 from the general fund to the Office of the Governor, division of elections, for costs associated 31 with conducting the statewide primary and general elections in the fiscal year ending June 30, -69- CCS HB 375 2005. 2 * Sec. 35. UNDERGROUND STORAGE TANK REVOLVING LOAN FUND. The sum 3 of $875,000 is appropriated from the oil and hazardous substance release prevention account 4 (AS 46.08.010(a)(1)) to the underground storage tank revolving loan fund (AS 46.03.410). 5 * Sec. 36. UNIVERSITY OF ALASKA. The fees collected under AS 28.10.421(d) during 6 the fiscal year ending June 30, 2004, for the issuance of special request university plates, less 7 the cost of issuing the license plates, are appropriated from the general fund to the University 8 of Alaska for support of alumni programs at the campuses of the university for the fiscal year 9 ending June 30, 2005. 10 * Sec. 37. VETERANS' MEMORIAL ENDOWMENT. Five percent of the market value 1 ] of the average ending balance in the Alaska veterans' memorial endowment fund 12 (AS 37. ]4.700) from July 31, 2002, to June 30, 2004, is appropriated to the Department of 13 Military and Veterans' Affairs for the purposes specified in AS 37.14. 730(b) for the fiscal 14 year ending June 30, 2005. 15 * Sec. 38. GRANTS FOR CHARTER SCHOOLS. The sum of $106,000 is appropriated 16 from the general fund to the Department of Education and Early Development for the fiscal 17 year ending June 30, 2005, for payment as grants to each school district that operates a charter 18 school with an average daily membership of 150 or less for support of those charter schools in 19 those districts. The amount appropriated for grants by this section is to be allocated among 20 eligible school districts in the proportion that the average daily membership of eligible charter 21 schools in a district bears to the total average daily membership of all eligible charter schools 22 in all school districts that operate an eligible charter school. 23 * Sec. 39. NONLAPSE OF APPROPRIATIONS. The appropriations made by secs. 8, 9, 24 10, ]1(c), 12(b), 13(b), 13(c), 13(d), 14(b), 16(a), 17, 19(a), 20, 21(b) - (k), 21(m), 21(n), 25, 25 26,27,28, 33(1), 33(m), and 35 of this Act are for the capitalization of funds and do not lapse. 26 * Sec. 40. RETROACTIVITY. Those portions of the appropriations made in sec. 1 of this 27 Act that appropriate either the unexpended and unobligated balance of specific fiscal year 28 2004 program receipts or the unexpended and unobligated balance on June 30, 2004, of a 29 specified account are retroactive to June 30, 2004, solely for the purpose of carrying forward a 30 prior fiscal year balance. 31 * Sec. 41. Sections 23, 28(a), 36, and 39 of this Act take effect June 30, 2004. CCS HB 375 -70- ) ) 1 * Sec. 42. Except as provided in sec. 41 of this Act, this Act takes effect July 1,2004. -71- CCS HB 375 AUTHENTICATION The following officers of the Legislature certify that the attaêhed' enrolled bit1~' ,CCS HB 375, consisting of 71 pages, was passed in confonnity with the requirements of the constitution and laws of the State of Alaska and the Uniform Rules of the Legislature. Passed by the House May 1.1, 2004 A TIEST: S~OftheHouse Passed by the Senate May 11, 2004 /' ' ~/7 __ / { (;;~~--/ZC"~¡-·~ Gene Thbmlult, President of the Senate A TIEST: ~rJ Kirsten Waid, Secretary of the Senate ~~,~~~,,~ Approvechby the Governor '"$.J¡ Ii 20 ,OL{ . ¡/.ld. H. Murkowski, ~emor of Alaska ) ce of Estimated RCC July ) Noti ') i ,) ALL RECORDS PROCESSED OPEN ITEM CROSS REFERENCE SY:2005-2005 CC:02140100-02140100 09/07/2004 PAGE 1 OPEN ITEM LIN COA SY CC PGM LC ACCT FY BALANCE ---------- -------- ------- ---------- ------------- 1 RC-0258001 1 05 2140100 10106 04 71.14 2 RC-0258002 1 05 2140100 10106 04 677626.09 3 RC-0258003 1 05 2140100 10106 04 151555.43 4 RC-0258004 1 05 2140100 10106 04 26.96 5 RC-0258005 1 05 2140100 10106 04 1322.14 6 RC-0258006 1 05 2140100 10106 04 2783.08 7 RC-0258007 1 05 2140100 10106 04 78.98 8 RC-0258008 1 05 2140100 10106 04 1716.33 9 RC-0258009 1 05 2140100 10106 04 10 RC-0258010 1 05 2140100 10106 04 18544.40 11 RC-0258011 1 05 2140100 10106 04 ENTER SELECTION==> NEW OPEN ITEM TYPE==> Enter-PFI---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PFI0--PF11--PFI2--- CONT QUIT PGUP PGDN DTAIL ACTVY PFKYS HELP Remainder Due $ 213.42 $ 2,032,878.27 $ 454,666.29 $ 80.86 $ 3,966.42 $ 8,349.22 $ 236.93 $ 5,149.00 $ 3.84 $ 55,633.18 $ 4,047.55 $ 2,565,224.98 1/4 Payment $ 71.14 $ 677,626.09 $ 151,555.43 $ 26.96 $ 1,322.14 $ 2,783.08 $ 78.98 $ 1,716.33 $ 1.28 $ 18,544.40 $ 1,349.19 $ 855,075.02 Total Projected Due $ 284.56 $ 2,710,504.36 $ 606,221.72 $ 107.82 $ 5,288.56 $ 11,132.30 $ 315.91 $ 6,865.33 $ 5.12 $ 74,177.58 $ 5,396.74 $ 3,420,300.00 /~..., Aurora Gas LLC BP Exploration (Alaska), Inc ConocoPhillips Inc -., Evergreen Resources (Alaska) Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Company Pioneer Natural Resources Union Oil Company of California XTO Energy Inc Totals FY05 AOGCC Regulatory Cost Charges ..icf;+ 0 -H2- 1 V'\vo l~~ Ce~~ S\~p5 ~~s UNITED STATES POSTAL SERVICE First-Class Mail Postage-& Fees Paid USPS Permit No. 8-10 · Sender: Please print your name, address, and ZIP+4 in this' box · I AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3539 L~"v,..Ð....- 'e-AÁt! [i; l t t i ~L t~ {.¡ ! 1 Ii t~~ .!~ L{i~tl,.,; I ) I I I I I II ¡ ! ~ I i I ¡ ¡ I ; ¡ ¡ I ! 111 ¡ ¡¡I II ) 11 ! I ¡ I t í ! 11 ¡ ¡ ¡ I I I I , \ 1 111 . ¡ ,'I ...n .::ï t:() o Postage S .~o ~.~D \.\'$ rì nJ Ul n1 Ul o o CJ Return Reciept Fee (Endorsement Required) o Restricted Delivery Fee Lr) (Endorsement Required) ,...:¡ rrJ Cer1ified Fee Total Postage & Fees $ 4, 1.&1S- nJ CJ lsen! To BP Exploration (Alaska), Inc. Dr- ___h_______________. Attn· Steve Marshall President Sirt3el, Apt. No.;' , or PO Box No. P.O. Box 196612 -a¡Y;-šïåre:ziP+T- Anchorage, AK 99519-6612 . Complete items 1,2, and 3. Also complete item 4 if Restricted Delivery is desired. · . Print your name and address on the reverse . so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. A. R~;¡;~nrJarIY) Bf~ ~ ~very ~(:v¡;¡; D. Is delivery address different from item 1? If YES, enter delivery address below: o Agent o Addressee DYes o No 1. Article Addressed to: BP Exploration (Alaska), Inc. Attn: Steve Marshall, President P.O. Box 196612 Anchorage, AK 99519-6612 3. Service Type .ø{Certified Mail o Registered o Insured Mail o Express Mail ~ Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Copy from Ce:>rtlit"e:> ¡!Ohe:>/1 -, 7002 3150 0005 3521 0846 PS Form 3811, July 1999.----------D~mesti; Return Receipt ~--~-----=-----o~ _ ~ 102595-00-M-0952 UNITED STATES POSTAL SERVICÉ"">< -1_) '. i tJ AU 1.3 ! · Sender: Please print ~~~dress, an<d·'2r!:±:4~J~=I6I~_~~~~'.~~~_,~._,_ ~j First-Class.Mail POßtage' &Iees Paid USPS Permit No: - G-1 0 ~G~~TH AVE, STE 1of¡(ECE/VED ANCHORAGE, AK 99501-3~91 92004 Alaska Oil & Ga: Gon C __ . . - '. $. ,Ommi:iSlon Anchorage L," ~ ~ 'ße..r-¡t>~ Cí iL L: ¡: L ¡ ¡ LL ¡/;ii¡:: IL¡ IL: Ì:lu ¡ Ii: L L¡¡; IL,; iLf!:;:! " . 0- f~;~;~;~~~1~~;0~=\;~~;~;:~.~~·········.'~N~¿'~ ~ L'f!I~?("Z-(':_ùY!:!!~1-:??:/~31! 2!te:~,;·:'::r"-;,'47i~&JJ:t-J::. .:-"'"_~ o ~dl:Nlq]~Œt~~1~~'fTL~~~1th~llÆf~tbll r1 ru U1 rrl Postage $ :~ì d. . 3-0 \.'5 U1 o o o Return Reciept Fee (Endorsement Required) o R&stricted Delivei]' Fee U1 (Endorsement Required) r1 rrl Certified Fee Total Postage & Fees $ 4 .Lt~ ru o Sent To o ['- -Sti-è-ëCÃpTf¡ö~,~"-- or PO Box No. - c1&; 'siâië: zip~;i u, Aurora Gas LLC Attn: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 _h._ Houston, TX 77042 ~-~~ · Complete itèms 1, 2, and 3. Also complete Hem 4 if Restricted Delivery is desired. · .Print your name and address on the reverse . so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. A. Received by (Please Print Clearly) ~7/~IiV_=- C. Signature X. ø;dW>~~C2- o Agent o Addressee D. Is delivery address differen.t from item 1? 0 Yes If YES, enter delivery address below: 0 No 1. Article Addressed to: Aurora Gas LLC Attn: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 3, Service Type ~ Certified Mail o Registered o Insured Mail o Express Mail - J(¡, Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes .., PS Form 3811, July 19~9-~ 2. Article Number (Copy from <:Arvif'A t::;¡hAII 7002 _~15_~~~D5 3521 0839__~ Domestic Return Receipt 102595-00-M-0952 UNITED STATES POSTAL SERVICE First-Class Mail Postage-& Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and ZIP+4 hi this box · AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3503~. ;;.-:.. "'-= Lu¡ &...- ~ '! i ¡ I 11 q 't 'î I' q r I '¡ '\' it ' Ii ¡ 1\ : II ¡ ! í í I \ I ¡ Ii!! Ii ¡ d . I jl1\ ill, ¡ ¡ ¡ í ! ! II i ì í í t ¡; i i ¡ d i ¡ ¡¡ i ~ r:~~~~~r~~~;~~~~~ô~,__ D ¥J~~¿~1llitt~!fIt:~f~~~~¡iiJl~ì~ M ru U1 rrl Postage $ · '::\1 ;\. 3-0 \.,~ U1 D D D Return Reciept Fee (Endorsement Required) D Restricted Delivery Fee U1 (Endorsement Required) M rrl Certified Fee Total Postage & Fees $ Lf. '-f :>-- ru D Sent To ConocoPhillips Alaska, Inc. D Production Revenue Accounting r- -~:r~~;t::~~~:-- Attn: Noel Dike ATO-1668 'c¡¡Y:-stãìê,-zTp¡;r P.O. Box 100360 ~¿~"";':N".J ~nchorage, AK 99510-0360 . . ~\i"C:;~;G, :!ili~~~~~~Æii.~~:~~~0;~1;::-::i~,º~?El~~q~I~---~~-?-~ttJ-~.E1{i!1!~~ .. Comp,lete- items 1; 2:anq3: Also' complete "':. item.4 if R~stricted Delivery is desired. , .. Print your name and address on the reverse' . so that we can return the card to you. . Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: 'P;. ;?~;~~Clearlj):;;~ø:;'Y C. Signature ~ /J/ 0 Agent X " c77----- 0 Addressee delivery address different from item 1? ,DYes If YES, enter delivery address below: 0 No :;onocoPhillips Alaska, Inc. Production Revenue Accounting I\ttn: Noel Dike ATO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 3. Service Type . ~ Certified Mail o Registered o Insured Mail o Express Mail $Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number /'"'-_.. &_-- --_.:_- I_~^I\ 7002 3150 0005 3521 0853 ~~ ~-~~~ PS Form 3811, Juiy 1999 Domestic Return Receipt 102595-00-M-0952 UNITED STATES POSTAL SERVICE First-Class Mail Postage.& Fees Paid USPS Permit No. G-10 It Sender: Please print your name, address, and ZIP+4 in this box · AOGCC RECEIVED 333 W 7TH AVE, STE 100 AUG 19 ZOOLl ANCHORAGE, AK 99501-:3539 ' Ala£ka Oif & Gas Cons. Con rr~$$iûn Anchofa~e WnåD- ~~ .-: '" -: ~.v II! I ¡; ì I ¡ I i! I ¡ L Hi ¡¡ ¡ It H j i f! ¡¡ J iÍ II ¡ It i ì! t 11 H If ¡¡¡It ¡ H !I ¡ 1 ~ 1.~~~I~~Y;~~;c~~;-'~:\:;,~ -...co. .""~~;'"'~., o ~ :~ìim¡;1WJ:ill'i@j;r;'tÌj!ffiß¡¡~~~;¡¡!Wr~, rrJ Postage $ .31 ~.30 , .& ~ LIl o D Return Reciept Fee D (Endorsement Required) Certiíied Fee o Restricted Deiivery Fee LIl (Endorsement Requiied) M rrJ TOIal Postage & Fees $ 4-.y.~ ru CJ Sent To o I'- Evergreen Resources Inc. -StTêeCApTÑõ~,~------' Attn: Mark S. Sexton, CEO _~:_r:..~_~~~_r-:~·__mu__ 1401 1 yth Street, Suite 1200 City, State, Z¡P.è4 Denver, CO 80202 1. Article Addressed to: Yl::1 ~ff:;Ÿr ·8(!Tr/ý""· c. Sigyzat ' Dent X ~/~see D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No · Complete ~tems 1; 2, ônd ~. Also complete. item 4 if Restricted Delivery is desired. · Print your name and address on the reverse . . so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1th Street, Suite 1200 Denver, CO 80202 3. Service Type E Certified Mail ,0 Registered o Insured Mail o Express Mail M Return Receipt for Merchandise b C.OD. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Numbr- 1'"'__.. s___ M~':~~ I~h~/I 70023150 0005 3521 0860 ðtoO -----~----~ PS Form 3811, July 1999 Dotnestic Return Receipt 102595-00-M-0952 UNITED STATES POSTAL SERVICE ~.~~.c:-~;:~, / ',\' "/, First-Class Mélìl ! <' 'posfagErKFe~s,eard ~-~ - PM ,. " , tic. .~ " .- ._,~~;:~ti·Ñi::G¡1cÒ~ ,,' . 'ì.;P· '\ ; ~~ AGG - ,,/ --~-¡ ~'. -.; ?:'~~¡ ; · Sender: Please print YQbi.tfla~ldress, and ZIP+4ih'tfíís'bir .l, i:__r~__ AOGCC 333 W 7TH AVE, STE 100 , ANCHORAGE, AK 99501-3539:' :. ~ 8~~_ II ¡ 1 I ! I .1 Ii 1/ I .¡. I I' .¡ H 1 I I ¡ I ¡ I ! ! I ! I I ¡ ¡¡I ì! ¡ : ¡ :.111 ¡ ¡ ! j ¡ ¡ ¡ ¡ i ¡ ¡ I II ¡ ì j I ¡ ¡ ! ¡ II : ¡ ¡ i í I ! ¡ ! ¡ ! r- r- t:Q o ,...:¡ ru Lr m Postage $ .31 ;1.. '30 \ ,If; Lr CJ CJ o Return Reciept Fee (Endorsement Required) CJ Restricted Delivery Fee Lr (Endorsement Required) ,-:¡ m Certiíied Fee Total Postage & Fees ,$ Lf.4')., ru g Sent To Forest Oil Corporation r- -s¡(ëefÄþn~ô:,7---- Attn: Accts Payable _~~~~_f!~~_^!~:______ 310 K Street, #700 City, State, ZIP+4 Anchorage, AK 99501 L~~!~~:·i-_·,.j~~';.·· ~::":~~~.~~1-~.'~. . ... ._____.~~~.~.:.~~.~~._~:.~. ~~~~~-~ "'" - , . ,- . . -', 'wt. 'w ': ~-,<." ~. - ~- ,., _....,.,¡.~'''-q- "''õ'1.;' ~ENPE~; cOMPL~rETHI$ SçCTIQN< ~<~~ 1. Article Addressed to: A..ßE;qeiv~d· by ~se Print Clearly) B~a~ 01 Delivery tlÁ-lo... -!-1/(YvtaA,- "6 /1- c.Sig12~at '~- - _' _; , ~ent X - CL., _' L-'~~ 0 Addressee D. Is delivery address different from item 1? 0 Yes If YE.S, enter delivery address below: 0 No . Cdmpléte items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. .' Print your name and address on the r~verse . so that we can return the card to you, . Attach this card to the back of the mail piece, or on the front if space permits. Forest Oil Corporation Attn: Accts Payable 310 K Street, #700 Anchorage, AK 99501 '1-},£-OLf 3. Service Type Jl Certified Mail o Registered Dlnsured Mail D Express Mail ~Return Recejpt for Merchandise DC.O.D. 4. Restricted Delivery? (Extra Fee) DYes, 2. Article Number (Cor" &_-- --_.:_- '_1-_11 . 7002 3150 0005;3521 0877 -----=--"--,<.-_._--"<~ -- _8" PS Form 3811, July 1999 Domestic Return Receipt 102595-00-M-0952 UNITED STATES POSTAL SERVICE First-Class Mail Postage'& Fees Paid USPS Permit No. G·10 · Sender: Please print your name, address, and ZIP+4 in this box · AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3539 G~d2~ 8-£Ã~ U ¡t I l t I q nit! ¡ Ii ì! !! H H. I I ì ¡ I ¡ ¡ i I ! i ! I d : ¡Ii ¡ : ¡ ! ! ¡ 11111111 ¡ \¡ ¡¡ I II ¡ it fi H 111 ¡ ¡¡II II :! ! I .. - -.... o.....;:;.,.........:...~.-....~'-..;...~- ~ U¡;i,"~~~~';~~~;i,~~~?,:,;,~~'i~:!';.>::h~~T...~ ~ r~~j~Æ~r!i'tì~.wN' ~ Postage $ '-0 ~G'E.POS):.. · \lóOi' t". ~ ~< '\ ~ Cel1ííied Fee ~ .30 2~ /{ ~;»narI( \ú:"o'\ o Return Reciept Fee Ü ~e~ ¡' ! o (Endorsement Required) \ .1 S \i' e I lev., j ¡,;~_~ 1 o Restricted Delive/)' Fee '\ \ ~'"'l.I<f ). .' 'J Wl (Endorsemeni Required) ...~C~ ;.ri Total Po,,",e & Fees $ ~. c.. S- ~_# ru o Sent To o r- Marathon Oil Company -si':èëCXpCNõ~,:-- Attn: Accounting Analyst -~:_~~.~-~~-~~:_._- P.O. Box 196168 ;CJt~,Sta£e' ~J~+'¡l:;ðQ.~~?J~~~~' AK 99519-6168 B~~Wli1ß~E1I:mtfi:N2ii":!~:tkr · Complete itBms 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse · so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: .A. Received by (Please Print Clearly) B. Date-.of Delivery 'DW'Y'f V~Y)c... ~J Q. r M t1\'t- ~ tL C. Signature '" " t.. X r'\" (' _ ,( \ ~gent ~~ 1\ ~-2 0 Addressee D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No Marathon Oil Company Attn: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 3. Service Type Ø-Certified Mail o Registered o Insured Mail o Express Mail ... Return Receipt for Merchandise_ o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes' 2. Article Number (Copy 'M~ M~';M J~¡"'nl\ 7002 3150 ODDS 3521 0884 PS Form 3811, July 1999 --.,..~~--- 8'3'1 102595-00-M-0952 Domestic Return Receipt - i First-Cla~s Mail Postage & Fees Paid USPS Permit No. G-10 ~"l UNITED STATES POSTAL SERVICE . Sender: Please print YOUí name, address, and ZIP+4 in this box .. AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3539 ~, C.·,,·, ç. "t'V·-r.:, .\\L'~ r{ '- 11.- AUG 1- ~ 'lûû4· L\"V\dA., ~~ . . -- C··..·'· c.ornl1i115fiìQO (c· ~I,,".îH"' Qi\Ci.u·a~ . 1,11\;). . \J t\\Ç.~Ml -. _. L .-.-e ., . ¡ \ ¡, ¡' ¡! ., ì ¡ P í j ·I! ft,i\cnO(è.\!J ILL¡ld\uLLI ¡¡¡¡¡¡i!¡dlli ;Ì¡¡¡ih,d¡¡;¡¡J¡¡¡i¡¡ ¡¡HI o Restricted Delivery Fee Lf1 (Endorsement Required) r=I m ru o Sent To D f'- -SF¡eëC.4jXNõ~;-" or PO Bax No. -Cí¡;;:Stãïë,' ziPi--r Postage $ ,~-, ~.30 \~15 r=I U- !:Q D .....::¡ ru l.l1 m l.l1 D o Return Reciept Fee o (Endorsement Required) Cerfliìed fee ~N~.>· Bliir~ ~" · Complete items 1, 2, and 3. Also complete . item 4 if Restricted Delivery is desired. · Print your name and' address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. A. Signature North Slope Borough Attn: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 o Agent ~ r D 0 Addressee ,{ i"e~ßd ;: ~..V.ed.. .b.Y. '. (. pr.inted Name) c~ . Dtte 0YDeliv~ry ~~)f::_-~ÇU'-e_LÒ K/16/éJ )t ~ "·c.'~~' D. !W1J~~':4~dr~different from item 1? 0 Yes I~YES, enter-ðe1~er~\addreSs below: 0 No ( ~OO(; ~ V ÒíW/¡(.'.._t..,..,~,',·.) ·"-'2\., " -- 1. Article Addressed to: 3. -S:~&i-C¡~0/ r:& èeftìiìéfM~il 0 Express Mail o Registered G(.Return Receipt for Merchandise o Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Transferfrom service label) 7 0 0 2 315 0 0 0 0 5 3 5 21 0 8 91 ;'j -------~-~.-----_._- '. ----.-...". ~'-- PS Form 3811, August 2001 Domestic Return Receipt ~ --- --- --~-- -- 1 (}1)C:;OkJ\O "A nðr)!:"" UNITED STATES POSTAL SERVICE ~ ~ ( First-Class Mail Postage -& Fees Paid , USPS Permit No. 8-10 I. ~: i i ~ QI Sender: Please print your name, address, and ZIP+4 in this box ... AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3539 ~~~ (R n...-4- ~ &i\ ._ c3 i L ! j: ¡ ¡ I ¡ ¡¡ I ¡ I d i ¡ Ii ¡ ! ¡ ì!:¡ ¡ L ¡ I ¡ I ¡¡ ¡ iI ¡ ì ¡ L ¡ ¡ ¡ it ¡ í ¡ ìI j I L ¡ ¡ i I'- o []""' : l;.1~ti1t1t;i1t1J;rW:r1rtJftt[G.~~~1i-1k~~~iÊZ1t$~1~Þî ru I 11l jT] Postage $ Ul D D Return Reciept Fee D (Endorsement Required) Certi1ìad Fee D Restricted Deiiverf Fee 11l (Endorsement Required) rl m .. - -. __31 ~. 3-0 \.."5 Total Postage & Fees $ <..\ . '-" ')... ru o -Sent To o I'- -si¡a-êi,Xpt:No~;---- or PO Box No. -"èiiÿ, sïåtë,'z/P+4U- Phillips Petroleum Company Attn: Steven Arbetovsky, ClOp Mgr------ P.O. Box 66 Kenai, AK 99611 (tjím¡'.~~~'· - . Co'mplete items 1, 2, and 3. Also complete . item 4 if Restricted Delivery is desired. lilt Print your name and address on the reverse so that we can return the card to you. .. Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Phillips Petroleum Company Attn: Steven Arbelovsky, ClOp Mgr P.O. Box 66 Kenai, AK 99611 2. Article Number (Transfer from service label) ~g~~ure^ IIOQ() 0 Agent . ~ '+r- tJ 0 0 Addressee B~I<:e;bYRRi!'~ v~~J;¡ 1,5 deH,e" address different from Item~es If YES, enter deliA~er1~ft'~1)4 0 No Alaska Oil & Gas Cons. Commission Anchorage 3. Service Type ~Certified Mail o Registered o Insured Mail o Express Mail ~ Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 7002 3150 0005 3521 0907 1 02595-02-M-OR~<; PS Form 3811, August 2001 Domestic Return Receipt UNITED STATES POSTAL SERVICE r ~ 1 Firsi-Class Mail postage· & Fees Paid USPS Pennìi No. G-10 . Sender: Please print your name, address, and ZIP+4 in this box ~ AOGCC 333 W 7TH AVE, STE 100 ANCHORAGE, AK 99501-3539 RECEIVED AUG 1 8 'Z.Ga~· L,~ ~5r- , ~., , .. \'" I \ ".. A'~~ka RH ~ ~as COilS. Commissic \ \ ! \ ¡ ¡ \ ¡ \ ¡ ¡ ¡ \ ¡ \ ! \ \ !! ¡! !! i \ ¡ i \ \ ii' ¡ ¡ ¡! i \ \ ! \ ¡ i ! ¡ ¡ i 1\ i! ! Ii! \ i ¡ Ãnchorage .::r- ~ . 'J ' u,-, -', ,,' _ " , ~ ~""2:"¢r.21:~..C'_h-¡:!2Tf:;::I:>r~~~:,!:¡~~tz::~~£ 7:rtT~:- -"~":¡ CJ :';::JZ~:?JWii"llli11il~Á~l~mffåCø.ntT1l~h~:~~({f$~~±ì~_¡:fÆt~~~~ ~ I ru I U1 £T1 Postage $ ::s 1 .;¡ :~o \ . is U1 CJ CJ Return Redeot Fee o (Endorsement Required) Certified Fee o Restricted Delivery Fee U1 (Endorsement Required) ~ fTl $ Lf-.~^ Total Posiage & Fees ru o Sent To -Pioneerf\Jaturar Resources Company - ~ .."..-"--------------, Attn' Scott 0 Sheffield CEO I - Street, Apt. No.; . . 1 or PO Box No. 5205 N. O'Connor Blvd, Suite 1400 -ë7¡y~-Štã¡é:ZfP+4--- Irving, TX 75039-3746 " -~,~~..", · Complete items 1, 2, and 3. Also complete . item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: Pioneer Natural Resources Company Attn: Scott D. Sheffield, CEO 5205 N. O'Connor Blvd, Suite 1400 Irving, TX 75039-3746 2. Article Number (Transfer from service label) PS Form 3811, August 2001 ~Si ature ... o Agent '. 0 Addressee B. Re~eived by ( P(in:!!d Narre?i' C. fðf, elf ~él~;ery -;J<Ø6J ~I rJm å IllfJ/ ó~ D. Is ~~vef}laddress different fr item 1? It]' Ye4 If YES, enter delivery address below: 0 No 3. Service Type ~ Certified Mail o Registered o Insured Mail o Express Mail R Return Receipt for Merchandise o C.O.D, 4. Restricted Delivery? (Extra Fee) 0 Yes 7002 3150 0005 3521 0914 102595-02-M-0835 ,-..-- -~~- Domestic Return Receipt UNITED STATES POSTAL SERVICE n Ii . ¡ ~ L ¡ First-Class Mail Postage & Fees Paid USPS Permii No. G-10 I, · Sender: Please print your name, address, and ZIP+4 in this box Iò AOGCC 333 W 7TH A VE, STE 100 ANCHORAGE, AK 99501-3539 r-l ~'~~;;~~;~1.4~; ...... ':... ~ l!1?'~' I-MT~:·t:.!i~'~J,:!,:C:_:__-! ;-}:: ~,t,._.. ::~~_:'~ ;~:=:t - -·'.:,·<~::~Z·I_'- _:_ -.; o rl ru L1l m UNOCAL -s¡re-êCÎ\pr:-/ŸÕ~;"--' Attn: Dale Haines, Mgr Oil & Gas ...,m.__ -~:cr:.~;,~.~~!~~:----.-. P O. Box 196247 u..u.___ City, ~[ate, ZfP+4 . An_9h~r~~~~c~~~_~~519-624 7 ~-ireEqi~~~fu:ßj~~i;"t~t~~ L.\~d.e- ~}.r~ Postage $ .CøQ ~.'30 \1,6 L1l o o Return Reciept Fee o (Endorsement Required) Certified Fee o Restricted Deliveri Fee L1l (Endorsement Required) rl fTl $ &.f .~S- Total Postage & Fees ru o Sent To o I'- á'i70Æii~~ ~ · Complete items 1,2, and 3. Also complete _ item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. 1. Article Addressed to: UNOCAL Attn: Dale Haines, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 2. Article Number (Transfer from service label) PS Form 3811 , August 2001 A. Si~ture ~{/ ~ _ J . rl,-- <------0 Agent X~~ I 0 Addressee B. Received by ( Printed Name) C. Date of Delivery ~W t¿4,-J/à If! z.---- D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No 3. Service Type lI!rC"ertified Mail o Registered o Insured Mail o Express Mail j;r-'Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 7002 3150 0005 3521 0921 102595-02·M-0835 - -. ----- -- -- --- -----~---- --- ---- -- Domestic Return Receipt UNITED STATES POSTAL SERVICE·(:r:;:~~ ~, '~ _ ',. _ ;": .~}~t~~~~~~~',~j~ · Sender: Please print Y~lri~ilii('á~dress, and~ZIP+4'irI1his~ t56;; -..LJ~__-L._..._ ~ 'B.u-y ~~3G~~THAVE, STE 100 RECEIVED ANCHORAGE, AK 99501-3539AUG 1 62Q04 Aìaska Oil & Gas Cons. Comnission Anchorage ¡ ! \ ì \ I ¡ ; I, 1 ; t ; \ ' ¡ \ ; : , ¡ : ¡ II : ; i ~ : ; ~ ¡ ¡ : ; : I \ 1 ! : ì ~ ' \ ~ ì ! I ; , ¡ : : ! ¡ ; : .' ¡ ~ ~~~,~r''>¡iøi:; ':'~"" ::;~':>;~~"":c-~~~¿r~~1 D ::'[;'!ê"''1~''i;o;':1i';~'^''"~~:;'~'' i:""l'jI'7':,.':";i";·i'('::c:;: :,,: ' ,', ,>, ' "1 ~ I I : $ ~ D típo,,~ \~ g (~_;. .ot,_ H~ . ~,_~ j \ -- ~ j.~ CJ \ & F~:":' U'1,\ <.,~ ~ /(^, ~ ".~~. ,~ Postage _ôl ~.30 \\\5 Certified Fee Return Reeiept Fee (Endorsement Required) Restricted Delivery Fee (Endorsernenr Requiredì Total Postage 8, Fees $ L.{. \.fJ- ru CJ Sent To CJ I'- 7;frêëCAþTÑõ:,~~--"" or PO Box No. . citÿ; St~iè,-z/p::"".r"" XTO Energy Inc. Attn: William A. Miller, District Adm Mgr 52260 Shell Road Kenai, AK 99611-9704 - __1 ~~;~~~~~:,t~~"~~=~~_:,-=_.::_""'~~;~:~_..=j;~=.:::~~~,~~ ~ · Complete items 1, 2, and 3. Also complete . item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. II Attach this card to the back of the mailpiece, or on the front if space permits. A S~ () I" N ~.Jl - , ,,,,¡.;¡ Agent X f,--Jv r7 I.. crh:6~ Add",s"'e B. Rece;ved by (Pdn'ed Name) , C.,¿'2';0f D,;I7Y /r~7 D. Is delivery address different from item 1? O'Yes If YES, enter delivery address below: D No 1. Article Addressed to: XT01~nlargy Inc. (I ~~n:Wif¡am A. Miller, District Adm Mgr . 52260 Shell Road " Kenái, AK ,99611-9704 3. Se9'ice Type ßl" Certified Mail D Registered D Insured Mail D ßxpress Mail Q'" Return Receipt for Merchandise DC.D.D. !:~: .~.';/,~ ~~ : ~ rs.l~· 2. Article Number (Transfer from service label) 4. Restricted Delivery? (Extra Fee) DYes PS Form 3811, August 2001 ----~---~-----_._--~~---~- 7002 3150 0005 3521 0938 Domesric Return Receipt 1 02'iq'i-n?..~A..f)".,,, , ) AlASKA. OIL AND GAS CONSERVATION COMMISSION / l ! / / FRANK H. MURKOWSK', GOVERNOR ~u~:)E [Jj~ !Æl~~~ißJ 333 W. ']"H AVENUE, SUITE 1 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Aurora Gas LLC Attention: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimatecj regulatory cost charge for the first quarter of fiscal year 2005 is $71.14 and the payment date for this charge is September 15,2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost es . editious manner. Date: August 11 2004 /' 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost AURORA GAS LLC LONE CREEK, 'UNDEFINED GAS 0 1,011,382 168,563.67 168,564 $225.51 Field/Pool Quantities and Allocated Costs Totals: 0 1,011,382 168,564 168,564 $225.51 A--fOQUAWKIE, UNDEFINED GAS 0 3,140 523.33 523 $0.70 FieldIPool Quantities and Allocated Costs Totals: 0 3,140 523 523 $0.70 NICOLAI CREEK, UNDEFINED GAS 0 261,696 43,616.00 43,616 $58.35 FieldIPool Quantities and Allocated Costs Totals: 0 261,696 43,616 43,616 $58.35 Summal}'jòr AURORA GAS LLC (3 records) Operator Quantities and Allocated Costs Totals: 0 1,276,218 212,703 212,703 $284.56 .~. Monday, August 09, 2004 10:38 A Page 1 of20 ~ 11 h, ~ ¡~l' r,. · Œ. ~', CYJ uJti r ) ITIJ ~ ,l^'~', r¡! (U 'i r ',~ ~__!~ !J ¡,' t.S ) {(1,) m',7 /70 ~ ',\ ¡L1\ ~fuLrD / / I / ¡ FRANK H. MURKOWSK', GOVERNOR AlASKA OIL AND GAS CONSERVATION COMMISSION 333 W. -¡Tfi AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: BP Exploration (Alaska), Inc Attention: Steve Marshall, President P.O. Box 196612 Anchorage, AK 99519-6612 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 MC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $677,626.09 and the payment date for this charge is September 15,2004. Under 20 MC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of AlaskalAOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 MC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 MC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Co ission so that the Commission will be better prepared to determine actual regulatory cost char es i n ditious manner. Date: August11,2004 ./ ." 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FÜddIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC BADAlv!!, BADAMI OIL 281,552 7,061,053 1,176,842.17 1,458,394 $1,951.08 Field/Pool Quantities and Allocated Costs Totals: '281,552 7,061,053 1,176,842 1,458,394 $1,951.08 BADAMI, UNDEFINED WDSP 52,942 0 0.00 52,942 $70.83 FieldIPool Quantities and Allocated Costs Totals: 52,942 0 0 52,942 $70.83 ENDIC01T, EIDER OIL 1,628,222 2,813,008 4p8,834.67 2,097,057 $2,805.50 FieldIPool Quantities and Allocated Costs Totals: 1,628,222 2,813,008 468,835 2,097,057 $2,805.50 ENDICOTT, ENDICOIT OIL ..............- 91,382,026 271,013,187 45,168,864.50 136,550,891 $182,681.71 FieldIPool Quantities and Allocated Costs Totals: 91,382,-026 271,013,187 45,168,865 136,550,891 $182,681.71 ENDICOIT, IVISHAK OIL 3,448,398 64,D26 10,£71.00 3,459,069 $4,627.64 FieldIPool Quantities and Allocated Costs Totals: 3,448,398 64,026 10,671 3,459,069 $4,627.64 ENDICOIT, UNDEFINED WDSP 325 0 0.00 325 $0.43 FieldIPool Quantities and Allocated Costs Totals: 325 ° 0 325 $0.43 MILNE POINT, KUP ARUK RIVER OIL 33,780,536 13,094,485 2,182,414.17 35,962,950 $48,112.27 Field/Pool Quantities and Allocated Costs Totals: 33,780,536 13,094,485 2,182,414 35,962,950 $48,112.27 MILNE POINT, SAG RIVER OIL 437,237 300,206 50,034.33 487,271 $651.89 FieldIPool Quantities and Allocated Costs Totals: 437,237 300,206 50,034 487,271 $651.89 !\.llLNE POINT, SCHRADER BLFF OIL 17,445,698 '6,005,224 1,015,870.67 18,461,569 $24,698.42 Field/Pool Quantities and Allocated Costs Totals: 17,445,698 6,095,224 1,015,871 18,461,569 $24,698.42 lvlILNE POINT, TERTI UNDEF WTRSP 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: 0 {} 0 0 $0.00 Monday, August 09, 2004 J 0:38 A Page 2 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Al/ócated Cost BP EXPLORATION (ALASKA) INC l\HLNE POINT, UGNU UNDEF WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 l'vDLlIfE POINT, UGNU UNDEFINE OIL 2,212 242 40.33 2,252 $3.01 FieldIPool Quantities and Allocated Costs Totals: 2,212 242 40 2,252 S3.01 NORTHSTAR, NORTHSTAR OIL 22,968,022 172,129,811 28,6138,301.83 51,656,324 569,107.32 FieldIPool Quantities and Allocated Costs Totals: ' 22,968,022 172,129,811 28,688,302 51,656,324 S69,107.32 NORTHSTAR UNDEFINED WDSP ,o-~~ 1,193,004 0 0.00 1,193,004 $1,596.04 FieldIPool Quantities and Allocated Costs Totals: 1,193,004 0 0 1,193,004 S1,596.04 PRUDHOE BAY, AURORA OIL 11,067,219 12,327,473 2,054,578.83 13,121,798 $17,554.72 Field/Pool Quantities and Allocated Costs Totals: 11,067,219 12,327,473 2,054,579 13,121,798 S17,554.72 PRUDHOE BAY, BOREALIS OIL 28,047,971 9,465,803 1,577,633.83 29,625,605 . 539,633.99 Field/Pool Quantities and Allocated Costs Totals: 28,047,971 9,465,803 1,577,634 29,625,605 $39,633.99 PRUDHOE BAY, LIS LWDEFINE WDSP 30,084,377 0 0.00 30,084,377 $40,247.74 FieldIPool Quantities and Allocated Costs Totals: 30,084,377 0 0 30,084,377 $40,247.74 PRUDHOE BAY, LISBURNE OIL 3,335,277 118,913,584 19,818,930.67 23,154,208 $30,976.37 FieldIPool Quantities and Allocated Costs Totals: 3,335,277 118,913,584 19,818,931 23,154,208 $30,976.37 PRUDHOE BAY, MIDNIGHT SUN OIL 7,428,728 3,499.585 583,264.17 8,011,992 $10,718.67 Field/Pool Quantities and Allocated Costs Totals: 7,428,728 3,499,585 583,264 8,011,992 $10,718.67 PRUDHOE BAY, N PRUDHOE BAY OIL 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: 0 0 0 0 SO. 00 Monday, August 09, 2004 10:38 A Page 3 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC PRUDHOE BAY, NIAKUK OIL 21,869,075 3,385,803 564,300.50 .22.433,376 $30,012.02 FieldIPool Quantities and Allocated Costs Totals: 21,869,075 3,385,803 564,301 22,433,376 $30,012.02 PRUDHOE BAY, ORION SCHR BL OIL 368,058 311,963 51,993.83 420,052 $561.96 FieldIPool Quantities and Allocated Costs Totals: 368,058 311,963 51,994 420,052 $561.96 PRUDHOE BAY, POLARIS OIL 1,580,518 999,965 1~6,660.83 1,747,179 $2,337.43 FieldIPool Quantities and Allocated Costs Totals: 1,580,518 999,965 166,661 1,747,179 $2,337.43 PRUDHOE BAY, PRUD UNDEFIN WDSP - 35,836,267 0 0.00 35,836,267 $47,942.79 Field/Pool Quantities and Allocated Costs Totals: 35,836,267 ° ° 35,836,267 $47,942.79 PRUDHOE BAY, PRUDHOE OIL 618,243,750 5,458,092,755 . 909,682,125.83 1.527,925,876 $2,044,103.19 FieldIPool Quantities and Allocated Costs Totals: 618,243,750 5,458,092,755 909,682,126 1,527,925,876 $2,044,103.19 PRUDHOE BA1: PT MCIlvTYRE OIL 61,351,973 116,139,973 19,356,662.17 80,708,635 . $107,974.33 FieldIPool Quantities and Allocated Costs Totals: 61,351,973 116,139,973 19,356,662 80,708,635 $107,974.33 PRUDHOE BAY, WBCHTR UNWTRSP 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: ° ° ° 0 $0.00 PRUDHOE BAY, W BEACH OIL 1,562,312 201,454 33,575.67 1 ,595,888 $2,135.02 FieldIPool Quantities and Allocated Costs Totals: 1,562,312 201,454 33,576 1,595,888 $2,135.02 Summary/or BP EXPLORATION (ALASKA) INC r18 recordsj Operator Quantities and Allocated Costs T<Jtals: 993,395,699 6,195;909,600 1,032,651,600 2,026,047,299 $2,710,504.36 Monday, August 09, 2004 10:38 A Page 4 of 20 , ~ 11 ®lr ~ ~ ~l¡ F ~ fll /l1ì\ ~ rJ~M æ) J IA\ 1_ l.I::JUJJ J LflJ __.:1 uu Q::> L Ù Lf ü ) AIfASKA. OIL AlVD GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: ConocoPhillips Inc. Production Revenue Accounting Attention: Noel Dike ATO-1668 P.O. Box 100360 Anchorage, AK 99510 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 MC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $151,555.43 and the payment date for this charge is September 15, 2004. Under 20 MC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 MC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 MC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory (;haryw,s in editious manner. Date: August 11, 2004 ~ 2004 Annual Production/Injection/Disposal Volumes For Allocation o/Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPIDLLIPS ALASKA INC BELUGA RIVER, UNDEFINED GAS 0 56,252,066 9,375,344.33 9,375,344 $12,542.61 Field/Pool Quantities and Allocated Costs Totals: 0 56,252,066 9,375,344 9,375,344 $12,542.61 BELUGA RIVER, UNDEFINED WDSP 14,165 0 0.00 14,165 $18.95 Field/Pool Quantities and Allocated Costs Totals: 14,165 0 0 14,165 $18.95 COLVILLE RIVER, ALPINE OIL 69,863,024 77,908,422 12,9{!4,737.00 82,847,761 $110,836.12 Field/Pool Quantities and Allocated Costs Totals: 69,863,024 77,908,422 12,984,737 82,847,761 $110,836.12 COLVILLE RIVER, NANUQ UNDF OIL ,-.-~ 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 COLVILLE RIVER, UNDEFINED WDSP 407,691 0 0.00 407,691 $545.42 Field/Pool Quantities and Allocated Costs Totals: 407,691 0 0 407,691 $545.42 KUPARUKRIVER, CRETACEO U'WDSP 552,674 0 0.00 552,674 $739.38 Field/Pool Quantities and Allocated Costs Totals: 552,674 0 0 552,674 $739.38 KUP ARUK RIVER, KUP ARUK RV OIL 267,392,115 193,782,278 32,297,046.33 299,689,161 $400,932.78 Field/Pool Quantities and Allocated Costs Totals: 267,392,115 193,782,278 32,297,046 299,689,161 $400,932.78 KUP ARUK RIVER, .ltÆELTWATER OIL 3,863,821 11,158,165 1,859,694.17 5,723,515 $7,657.08 Field/Pool Quantities and Allocated Costs Totals: 3,863,821 11,158,165 1,859,694 5,723,515 $7,657.08 KUP ARUK RIVER, TABASCO OIL 7,098,455 187,962 31,327.00 7,129,782 $9,538.43 Field/Pool Quantities and Allocated Costs Totals: 7,098,455 187,962 31,327 7,129,782 $9,538.43 KUP ARUK RIVER, TARN OIL 30,149,697 31,270,554 5,211,759.00 35,361,456 $47,307.57 Field/Pool Quantities and Allocated Costs Totals: 30,149,697 31,270,554 5,211,759 35,361,456 $47,307.57 Monday, August 09, 2004 10:38 A Page 5 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPIDLLIPS ALASKA INC KUPARUK RIVER, WEST SAK OIL 9,015,969 979,441 163,240,17 9,179,209 $12,280.21 FieldIPool Quantities and Allocated Costs Totals: 9;015,969 979,441 163,240 9,179,209, S12,280.21 NORTH COOK INLET, TERTIARY GAS 0 17,146,434 2,857,739.00 2,857,739 $3,823.17 FieldIPool Quantities and Allocated Costs Totals: 0 17;·146,434 2,857,739 2,857,739 S3,823.17 NORTH COOK INLET, UNDEF WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: " 0 0 0 0 SO. 00 Summary jòr CONOCOPHJLLIPS AL4SK4 JNC (13 records) --, Operator Quantities and Allocated Costs Totals: 388,357,611 388,685,322 64,780,887 453,138,498 S606,221.72 ~ c Monday, August 09, 2004 10:38 A Page 6 of 20 J (~ t:lT~~' ',,~r,~ r;::¡lt~' [ill. ñì ["~ flï\ , fl' 1 ,Æ\" (~l,J (l) )! ': [¡ u r Uì \ . L I r-\ rù\ ,-,'" ~! , '. L L:::! J 'L.l '-=U )! AlASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1ih Street, Suite 1200 Denver, CO 80202 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $26.96 and the payment date for this charge is September 15,2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of AlaskalAOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to determine actual regulatory cost charges in ditious manner. Date: August 11, 2004 .- 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperaJorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost EVERGREEN RESOURCES (ALAS PIONEER, TYONEK UNDEFINED GAS FieldIPool Quantities andAllocated Costs Totals: PIONEER, UNDEFINED WDSP 0 2,156 359.33 359 $0.48 0 2,156 359 359 $0.48 80,231 0 0.00 80,231 $107.34 80,231 0 0 80,231 $107.34 80,231 2,156 359 80,590 $107.82 Field/Pool Quantities and Allocated Costs Totals: SummmJ'jòr EVERGREEN RESOURCES (f1.L.J.SKAj CORPORATiON {2 recordsj Operator Quantities and Allocated Costs Totals: -- /~. Monday, August 09, 2004 10:38 A Page 70f20 J @ ~u' i ® t=":U-:: rÞ,: ~[ll: ~ ~ I~ (fP fV1¡.Í1\ æ) Lru 1t ~) J. £1-\..\ l1::¡ lF~, l~) L]\~ dl) AlASKA. OIL AND GAS CONSERVATION COMMISSION I / I I i ¡ I " .I j l FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Forest Oil Corporation Attention: Accounts Payable 310 K Street, #700 Anchorage, AK 99501 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $1,322.14 and the payment date for this charge is September 15, 2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the ommission's determination of your estimated regulatory cost charge, you are invited to inform the Co sion so that the Commission will be better prepared to determine actual regulatory ~s i n e p. ditious manner. Date: August 11, 2004 ~ /' . oh K.~, Ch~irm~~ 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost FOREST OIL CORP KUSTATAN, UNDEFINED WDSP 411,769 0 0.00 411,769 $550.88 Field/Pool Quantities and Allocated Costs Totals: 411,769 0 0 411,769' $550.88 REDOUBT SHOAL, UNDEFINED GAS 0 461,344 76,890.67 76,891 $102.87 Field/Pool Quantities and Allocated Costs Totals: 0 461,344 76,891 76,891 $102.87 REDOUBT SHOAL, UNDEFINED OIL 910,694 211,827 ~5,304.50 945,999 $1,265.58 Field/Pool Quantities and Allocated Costs Totals: 910,694 211,827 35,305 945,999 $1,265.58 REDOUBT SHOAL, UNDEFINED WDSP <~--"'" 331,185 0 0.00 331,185 $443.07 Field/Pool Quantities and Allocated Costs Totals: 331,185 0 0 331,185 $443.07 117 FORELAND, UNDEFINED GAS 0 940,110 156,685.00 156,685 $209.62 FieldIPool Quantities and Allocated Costs Totals: 0 940,110 156,685 156,685 $209.62 117 MCARTH RIV UNDEFINED WDSP 1,148,112 0 0.00 1,148,112 $1,535.98 FieldIPool Quantities and Allocated Costs Totals: 1,148,112 0 0 1,148,112 $1,535.98 117 MCARTH RIV, 117 l\1CARTH RIV OIL 849,195 199,559 33,259.83 882,455 $1,180.57 FieldIPool Quantities and Allocated Costs Totals: 849,195 199,559 33,260 882,455 $1,180.57 Summalyjòr FORESTOlL CORP (7 records) Operator Quantities and Allocated Costs Totals: 3,650,955 1,812,840 302,140 3,953,095 $5,288.56 .~ Monday, August 09, 2004 10:38 A Page 8 of 20 ~1T lK\lT~, \J_) .' lJ1u w i,~ ) fîì ~ Æ\ fllð\ ~ JJ lJ uD l:, ~ c]) ,-', 11\\ ILq tr"\j FRANK H. MURKOWSK', GOVERNOR AlASKA. OIL AND GAS C ONSERVAft ON COMMISSION 333W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservati~n Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $2,783.08 and the payment date for this charge is September 15,2004. Under20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2005 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Co ission so that the Commission will be better prepared to determine actual regUlato~es. an editious manner. Date: August 11, 2004 ,/ 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) AlIôcated Cost MARATHON OIL CO BEA VER CREEK, BEAVER CREEK OIL 76,134 23,040 3,840.00 79,974 $106.99 FieldIPool Quantities and Allocated Costs Totals: 76,134 23,040 3,840 79,974 $106.99 BEA VER CREEK, BELUGA GAS 0 7 :639,494 1,273,249.00 1,273,249 $1,703.39 FieldIPool Quantities andAllocated Costs Totals: 0 7;639,494 1,273,249 1.273,249 $1,703.39 BEA VER CREEK, STERLING GAS 0 104,140 ~17 ,356.67 17,357 $23.22 FieldIPool Quantities and Allocated Costs Totals: 0 104,140 17,357 17,357 $23.22 BEA VER CREEK, TYONEK UNDEF GAS 0 124,677 20,779.50 20,780 $27.80 FieldIPool Quantities and Allocated Costs Totals: 0 124,677 20,780 20,780 $27.80 BEAVER CREEK, UNDEFINED WDSP 39,405 0 0.00 39,405 $52.72 FieldIPool Quantities and Allocated Costs Totals: 39,405 0 0 39,405 $52.72 FALLS CREEK, TYONEK UNDEF GAS 0 1,088,595 181,432.50 181,433 $242.73 FieldIPool Quantities and Allocated Costs Totals: 0 1,088,595 181,433 181,433 $242.73 G OSKOLKOFF, TYONEK UNDEF GAS 0 1,760,238 293,373.00 293,373 $392.48 FieldIPool Quantities and Allocated Costs Totals: 0 1,760,238 293,373 293,373 $392.48 KENAI, CL. U. BELUGA GAS 0 1,116,673 186,112.17 186,112 $248.99 FieldIPool Quantities and Allocated Costs Totals: 0 1,116,673 186,112 186,112 $248.99 KENAI, CL. U. STERLING UND GAS 0 3,461,733 576,955.50 576,956 $771.87 FieldIPool Quantities and Allocated Costs Totals: 0 3,461,733 576,956 576,956 $771.87 ..-,' KENAI, CL.u. UPPER TYONEK GAS 0 1,564,964 260,827.33 260,827 $348.94 FieldIPool Quantities and Allocated Costs Totals: 0 1,564,964 260,827 260,827 $348.94 Monday, August 09, 2004 10:38 A Page 9 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldJPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARATHON OIL CO KENAL STERLING 3 GAS 0 1,668,534 278,089.00 278,089 $372.04 Field/Pool Quantities and Allocated Costs Totals: ° 1,668,534 278,089 278,089 $372.04 KENAL STERLING 4 GAS 0 2:911,391 485,231.83 485,232 $649.16 FieldIPool Quantities and Allocated Costs Totals: ° 2;911,391 485,232 485,232 $649.16 KENAL STERLING 5.1 GAS 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: . ° ° ° ° $0.00 KENAL STERLING 6 GAS ,- 0 11,539,229 1,923,204.83 1,923,205 $2,572.92 Field/Pool Quantities and Allocated Costs Totals: ° 11,539,229 1,923,205 1,923,205 $2,572.92 KENAL TYONEK GAS 0 1,340,364 223,394.00 223,394 $298.86 Fie/dlPool Quantities ami,Allocated Costs Totals: ° 1,340,364 223,394 223,394 $298.86 KENAL UNDEFINED WDSP 175,315 0 0.00 175,315 $234.54 Fie/dlPooI Quantities andAJlocated Costs Totals: 175,315 ° ° 175,315 $234.54 KENAL UNDEFINED WDSP G&I 282,309 0 0.00 282,309 $377.68 FieldIPool Quantities and Allocated Costs Totals: 282,309 ° ° 282,309 $377.68 KENAL UPPER TYONEK BELUGA GAS 0 11,126,101 1,854,350.17 1,854,350 $2,480.80 FieldIPool Quantities and Allocated Costs Totals: ° 11,126,101 1,854,350 1,854,350 $2,480.80 S DIOlvNE, TYONEK UNDEF GAS 0 195,575 32,595.83 32,596 $43.61 Field/Pool Quantities and Allocated Costs Totals: 0 195,575 32,596 32,596 $43.61 ,,-- STERLING, BELUGA UNDEFINED GAS 0 109,674 18,279.00 18,279 $24.45 Field/Pool Quantities and Allocated Costs Totals: 0 109,674 18,279 18,279 $24.45 Monday, August 09, 2004 10:38 A Pagel 0 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Fi.eld/Pool Name Gross Liquid (Stb) Gross Gas (Mscj) Gas BOE Total Volume (Liq+BOE) Allocate{l Cost MARATHON OIL CO STERLING, TYONEK UNDEFINED GAS 0 6,505 1,084.17 1,084 $1.45 FieldIPool Quantities and Allocated Costs Totals: ° 6,505 1,084 1,084 $1.45 STERLING, 'UNDEFINED GAS 0 241,846 40,307.67 40,308 $53.92 FieldIPool Quantities and Allocated Costs Totals: ° '241,846 40,308 40,308 $53.92 TRADING BA Y, G-NE/HEMLK-NE OIL 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: ° ° ° ° $0.00 TRADING BAY, HEMLOCK OIL ,----. 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: ° ° ° ° $0.00 TRADING BAY, MID KENAI DOlL 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: ° 0 ° 0 $0.00 TRADING BAY, MID KENAI E oIl 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: ° ° ° 0 $0.00 TRADING BAY, UNDEFINED GAS 0 100,598 16,766.33 16,766 $22.43 FieldIPool Quantities and Allocated Costs Totals: 0 100,598 16,766 16,766 $22.43 TRADING BAY, 'UNDEFINED WDSP 20,696 0 0.00 20,696 $27.69 FieldIPool Quantities and Allocated Costs Totals: 20,696 ° 0 20,696 $27.69 TRADING BAY, W FORELAND OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: ° 0 ° 0 $0.00 .- WOLF LAKE, BEL-TYON UNDEF GAS 0 240,480 40,080.00 40,080 $53.62 Field/Pool Quantities and Allocated Costs Totals: 0 240,480 40,080 40,080 $53.62 Monday, August 09, 2004 10:38 A Page 11 of20 2004 Annual Production/Injection/Disposal Volumes For Allocaiion of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName MARATHON OIL CO Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Summaryfor MARATHON OIL CO (30 records) Operator Quantities and AllocaJed Costs Tota/s: 593,859 46,363,851 7,727,309 8,321.168 S11,132.30 ,.~ ,-- Monday, August -09, 2004 10:38 A Page 12 of20 ~, --,' ¡:':-IS. ~; ';l,' ~--', r;-r rl t' ru¡· I! [ ......_~..- .. t... L,::::I } ffil~ _"') J, '} ;' ®n l~ C$? 1.nJ L~ fr~u (Q) FRANK H. MURKOWSK', GOVERNOR AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: North Slope Borough Attention: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $78.98 and the payment date for this charge is September 15,2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the C ission so that the Commission will be better prepared to determine actual regulatory cost c s . e editious manner. Date: August11,2004 2004 AnnuaIProduction/lnjection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost NORTH SLOPE BOROUGH BARROW, EAST BARROW GAS 0 92.659 15,443.17 15,443 $20.66 Field/Pool Quantities and Allocated Costs Totals: 0 92,659 15,443 15,443 $20.66 BARROW, SOUTH BARROW GAS 0 88.671 14,778.50 14,779 $19.77 FieldIPool Quantities and Allocated Costs Totals: 0 - 88,671 14,779 14,779 $19.77 WALAKPA, WALAKPA GAS 0 1,235,479 2p5.913.17 205,913 $275.48 Field/Pool Quantities and Allocated Costs Totals: 0 1,235,479 205,913 205,913 $275.48 Summary for NORTH SLOPE BOROUGH (3 records) - Operator Quantities and Allocated Costs Totals: 0 1,416,809 236,135 236,135 $315.91 ~ Monday, August 09, 2004 10:38 A Page 13 of 20 , @ìí fli\lf ~ rlJì ~ Æ\ fL1 /~ ~ ~r"JX fÆ ciD ~~ Ln1 U L~ JIJ if lfl1 L-:.. D 'U '_~I 'ù IJ L AlASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 1 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steve Arbelovsky, Cook Inlet Operations Manager P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $1,716.33 and the payment date for this charge is September 15, 2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you pr~fer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the ?~'iS' 0 that the Commission will be better prepared to determine actual regulatory cost charges i(~ diti us manner. rJ..l ~ oh K. Norman, Chairman Date: August11,2004 / 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName PIDLLIPS PETROLEUM CO Summaryjòr PHiLLIPS PETROLEUJl CO (2 recordsj -, Monday, August 09, 2004 10:38 A Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) NORTH COOK INLET, TERTIARY GAS Field/Pool Quantities and Allocated Costs Totals: NORTH COOK INLET, UNDEF WDSP Field/Pool Quantities and Allocated Costs Totals: Operator Quantities and Allocated Costs Totals: o o 30,773,377 30,773,377 2,804 2,804 2,804 30,773,377 Gas BOE Total Volume (Liq+BOE) Alldcated Cost 5,128,896.17 5,128,896 5,128,896 $6.861.58 5,128,896' $6,861.58 2,804 $3.75 2,804 $3.75 5,131,700 $6,865.33 o o 0.00 o 5~128,896 Page 14 of20 ) ~ '-If fA\ =1 J:J ŒE ffiì ~ ~\ ~ ¡ð\ ~ ¡~r¡ r{;l, cD ~ tru - -l JJ If i.J ù L::o úì.\ (\vh Ln.\ ,) AlASIiA OIL AND GAS CONSERVATION COMMISSION ,/ / / J' , FRANK H. MURKOWSK', GOVERNOR 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Pioneer Natural Resources Company Attn: Scott D. Sheffield, CEO 5205 N. O'Connor Blvd, Suite 1400 Irving, TX 75039-3746 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 MC 25.610 that your estimateØ regulatory cost charge for the first quarter of fiscal year 2005 is $1.28 and the payment date for this charge is September 15,2004. Under 20 MC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ¡th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 MC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 MC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commis . n so that the Commission will be better prepared to determine actual regulatory cost charges in an itious manner. Date: August11,2004 CZÆ " 2004 AnnualProductionllnjection/Disposal Volumes For Allocaiion of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PIONEER NATURAL RESOURCES OOOGURUK, UNDEFINED OIL Fie/dlPoo/ Quantities and Allocated Costs Totals: Swnmaryfor PIONEER NATUR4L RESOURCES USA, INC (J deiail record) Operator Quantities and Allocated Costs Totals: 3,828 0 0.00 3,828 $5.12 3,828 0 0 3,828 $5.12 3,828 0 0 3,828 $5.12 .~ - Monday, August 09, 2004 10:38 A Page 15 of20 ) ~ ii fli\ 'iT rE (ffi rç !fi\ n % (Cù rl' ~ r~\ ® J UlJ U [ LW lr Ik !1LfL\:Æ uVc,llÙ ) AlASKA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK', GOVERNOR 333 W. ']"H AVENUE, SUITE 1 00 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: Union Oil Company of California Attention: Dale Haines, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $18,544.40 and the payment date for this charge is September 15,2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Commission so that the Commission will be better prepared to detennine actual regulatory C(?:S in xpeditious manner, Date: August 11, 2004 . I t/ ~ ~ 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Li~uid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA GRANITE PT, HEMLOCK UNDEF OIL 41,217 54,336 9,~56.00 50,273 $67.26 Field/Pool Quantities and Allocated Costs Totals: 41,217 54,336 9,056 50,273 $67.26 GRANITE PT, MIDDLE KENAI OIL 2,494,887 1,232,872 205,478.67 2,700,366 $3,612.63 Field/Pool Quantities and Allocated Costs Totals: 2,494,887 1,232,872 205,479 2,700,366 $3,612.63 GRANITE PT, UNDEFINED GAS 0 91,232 ~5,205.33 15,205 $20.34 Field/Pool Quantities and Allocated Costs Tota/s: 0 91,232 15,205 15,205 $20.34 GRANITE PT, UNDEFINED WDSP G&I 58,262 0 D.OO 58,262 $77.9 Field/Pool Quantities and Allocated Costs Totals: 58,262 0 0 58,262 $77.94~· IVAN RIVER, UNDEFINED GAS 0 2,470,717 411,786.17 411,786 $550.90 Field/Pool Quantities and Allocated Costs Totals: {) 2,470,717 411,786 411,786 $550.90 IVAN RIVER, UNDEFINED WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 LEWIS RIVER, UNDEFINED GAS 0 575,122 95,853.67 95,854 $128.24 Field/Pool Quantities and Allocated Costs Totals: 0 575,122 95,854 95,854 $128.24 LEWIS RIVER, UNDEFINED WDSP 993 0 0.00 993 $1.33 Field/Pool Quantities and Allocated Costs Totals: 993 0 0 993 $1.33 MCARTHUR RIVER, HElvlLOCK OIL 28,488,869 1,415,741 235,956.83 28,724,826 $38,428.90 Field/Pool Quantities and Allocated Costs Totals: 28,488,869 1,415,741 235,957 28,724,826 $38,428.90 MCARTHUR RIVER, MIDKENAI GaIL 7,765,201 616,628 102,771.33 7,867,972 $1{),526.00 ',-" Field/Pool Quantities and A//ocatedCosts Totals: 7,765,201 616,628 102,771 7,867,972 $10,526.00 Monday, August 09, 2004 10:38 A Page 16 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA lvfCARTHUR RIVER, MIDKENAI GAS 0 37,133,934 6,188,989.00 6,188,989 $8,279.81 Field/Pool Quantities and Allocated Costs Totals: 0 37,133,934 6,188.989 6,188,989- $8,279.81 MCARTHUR RIVER, UNDEFINED OIL 0 0 0.{)0 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MCARTHUR RIVER, W FORELAND OIL 1,165,188 49,252 .8,208.67 1,173,397 $1,569.80 Field/Pool Quantities and Allocated Costs Totals: 1,165,188 49,252 8,209 1,173,397 $1,569.80 MIDDLE GROUND SHOAL, A OIL 24,178 27,915 4,652.50 28,831 $38.5, Field/Pool Quantities and Allocated Costs Totals: 24,178 27,915 4,653 28,831 $38.57-"" MIDDLE GROUND SHOAL, B.C,D OIL 4,373 18,731 3,12H13 7,495 $10.03 Field/Pool Quantities and Allocated Costs Totals: 4,373 18,731 3,122 7,495 $10.03 MIDDLE GROUND SHOAL, E,F,G OIL 83,898 26,315 4,385.83 88,284 $118.11 Field/Pool Quantities and Allocated Costs Totals: 83,898 26,315 4,386 88,284 $118.11 MIDDLE GROUND SHOAL, UNDEF GAS 0 145,444 24,240.67 24,241 $32.43 Field/Pool Quantities and Allocated Costs Totals: 0 145,444 24,241 24,241 $32.43 PRE17Y CREEK, UNDEFINED GAS 0 427,900 71,316.67 71,317 $95.41 Field/Pool Quantities and Allocated Costs Totals: 0 427,900 71,317 71,317 $95.41 STUMP LAKE, UNDEFINED GAS 0 277 46.17 46 $0.06 Field/Pool Quantities and Allocated Costs Totals: 0 277 46 46 $0.06 SWANSON RIVER, GAS STORAGE 0 1,466,572 244,428.67 244,429 $327.00 '~ Field/Pool Quantities and Allocated Costs Totals: 0 1,466,572 244,429 244,429 $327.00 Monday, Augu~'t 09, 2004 10:38 A Page 17 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA SWANSON RIVER, HElvfLOCK OIL 425,555 7,147,763 1,191,293.83 1,616,849 $2,163.07 Field/Pool Quantities and Allocated Costs Totals: 425,555 7,147,763 1,191,294 1,616,849- $2,163.07 SWANSON RIVER. UNDEFINED GAS 0 1,844,556 307,426.00 307,426 $411.28 Field/Pool Quantities and Allocated Costs Totals: ° 1,844,556 307,426 307,426 $411.28 SWANSON RIVER, UNDEFINED WDSP 2,720,342 0 0.00 2,720,342 $3,639.35 Field/Pool Quantities and Allocated Costs Totals: 2,720,342 ° ° 2,720,342 $3,639.35 TRADING BAY, HEMLOCK OIL 1,212,724 127,641 21,273.50 1,233,998 $1,650.88 FieldIPool Quantities and Allocated Costs Totals: 1,212,724 127,641 21,274 1,233,998 $1,650.88 ~ TRADING BAY, MID KENAI BOIL 57,484 19,031 3,171.83 60,656 $81.15 FieldIPool Quantities and Allocated Costs Totals: 57,484 19,031 3,172 60,656 $81.15 TRADING BAY, MID KENAI COIL 793,630 51,309 8,551.50 802,182 $1,073.18 FieldIPool Quantities and Allocated Costs Totals: 793,630 51,309 8,552 802,182 $1,073.18 TRADING BA Y, JlID KENAI D OIL 854,447 42,672 7,112.00 861,559 $1.152.62 Field/Pool Quantities and Allocated Costs Totals: 854,447 42,672 7,112 861,559 $1,152.62 TRADING BA Y, MID KENAI E OIL 72,407 18,022 3,003.67 75,411 $100.89 Field/Pool Quantities and Allocated Costs Totals: 72,407 18,022 3,004 75,411 $100.89 TRADING BAY, UNDEFINED OIL 14,613 3,887 647.83 15,261 $20.42 FieldIPool Quantities and Allocated Costs Totals: 14,613 3,887 648 15,261 $20.42 5'IImmaryfor UNION 011. CO OF CIUFORNlA (29 recordsj Operator Quantities and Allocated Costs Totals: 46,278,268 55,007,869 9,167,978 55,446,246 $74,177.58-' Monday, August 09, 2004 J 0:38 A Page 18 0120 ) ~~1. ~ ®lTŒ[ (u [1; L).UlJu Jr } 1M ~ rp Cf Iru ls ù·~ (I)) FRANK H. MURKOWSK', GOVERNOR AlASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ']"H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF ESTIMATED REGULATORY COST CHARGE To: XTO Energy Inc. Attention: William A. Miller, District Administration Mgr 52260 Shell Road Kenai, AK 99611-9704 YOU ARE NOTIFIED that the Alaska Oil and Gas Conservation Commission has determined pursuant to AS 31.05.093 and 20 AAC 25.610 that your estimated regulatory cost charge for the first quarter of fiscal year 2005 is $1,349.19 and the payment date for this charge is September 15, 2004. Under 20 AAC 25.610, you are required to pay this charge not later than the payment date. Please make your check payable to: Mail or deliver payment to: State of Alaska/AOGCC AOGCC 333 West ih Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. In accordance with 20 AAC 25.610, your estimated cost charge was computed as one-fourth of the Commission's reasonable estimate, based on available information, of what your actual annual regulatory cost charge will be for fiscal year 2005, using the formula set out in 20 AAC 25.605. For your information, the volume data and calculations used for this purpose are summarized in the attached spreadsheet. The appropriation for the Commission's operating and capital costs for fiscal year 2005, less federal receipts of $126,000 is $4,270,300. The Commission's estimate of the total fees to be collected under AS 31.05.090 (permit to drill fees) is $20,000. The Commission's estimate of the lapsed amount of fiscal year 2004 appropriations included in the fiscal 2005 appropriation is $830,000. Later in the fiscal year, after final information is available to the Commission for calculating actual regulatory cost charges, you will receive notice of your proposed actual annual regulatory cost charge for fiscal year 2005. At that time you will have an opportunity to submit comments on or request a revision to the proposed regulatory cost charge, and a hearing will be held before the Commission determines the final charges. Your estimated first quarter regulatory cost charge payment will be credited against your final charge. The Commission's regulations do not provide for objections or revisions to estimated regulatory cost charges. However, if you find what you believe may be errors in the Commission's determination of your estimated regulatory cost charge, you are invited to inform the Co I ion so that the Commission will be better prepared to determine actual regulatory cost charges in editious manner. 0~an,~...~~, Date: August 11, 2004 ------ 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE _Total Volume (Liq+BOE) Allocated Cost XTO ENERGY INC lvDDDLE GROUND SHOAL, B,C,D OIL 5,636 3,154 525.67 6,162 $8.24 FieldIPool Quantities and Allocated Costs Totals: 5,636 3,154 526 6,162' $8.24 lvflDDLE GROUND SHOAL, E,F,G OIL 3,939,469 ~31,019 71,836.50 4,011,306 $5,366.44 FieldIPool Quantities and Allocated Costs Totals: 3,939,469 431,019 71,837 4,011,306 $5,366.44 MIDDLE GROUND SHOAL, UNDF WDSP 16,486 0 0.00 16,486 $22.06 FieldIPool Quantities and Allocated Costs Totals: 16,486 ° ° 16,486 $22.06 Summary for )(1"0 ENERGY ¡NC (3 recordsj ~/~.,." Operator Quantities and Allocated Costs Totals: 3,961,591 434,173 72,362 4,033,953 $5,396.74 -- Monday, August 09, 2004 10:38 A Page 19 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation o/Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Report Quantities and Allocated Costs Totals: ],436.324,8461 6,721,682,21511 /,120,280,3691 I 2,556,605,215! ~,420,300.00 ! --- ----- Monday, August 09, 2004 10:38 A Page 20 of 20 ) ) FY 05 Regulatory Cost Charges Esti mate FY2005 Operating Appropriation $ 4,136,300 FY2005 Capital Appropriation $ 260,000 FY2005 Appropriation $ 4,396,300 Less Federal Receipts $ 126,000 Total Designated Program Rec $ 4,270,300 Less Estimated Permit Fees $ 20,000 Less Estimated 2004 Lapse $ 830,000 Total to use for Reg Cost Ch9S( 3,420,300) Final FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation Less Federal Receipts Total Designated Pro m Rec Less Estimated rmit Fees Less Actu 04 Lapse Total t se for Reg Cost Chgs 4,~~~~ ~OOO 4,396,300 126,000 4,270,300 20,000.00 $ 4,250,300 · . 2004 Annual Production/Injection/Disposal Volumes For Allocation o.fRegulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost AURORA GAS LLC LONE CREEK, UNDEFINED GAS 0 1,011,382 168,563.67 168,564 $225.51 Field/Pool Quantities and Allocated Costs Totals: 0 1,011,382 168,564 168,564 $225.51 MOQUAWKlE, UNDEFINED GAS 0 3,140 523.33 523 $0.70 FieldIPool Quantities and Allocated Costs Totals: (} 3,140 523 523 $0.70 NICOLAI CREEK, UNDEFINED GAS 0 261,696 43,616.00 43,616 $58.35 FieldIPool Quantities and Allocated Costs Totals: 0 261,696 43,616 43,616 $58.35 Summary/or AURORA GAS LLC (3 record,') Operator Quantities and Allocated Costs Totals: 0 1,276,218 212,703 212,703 $284.56 E__~_ .~~ Monday, August 09, 2004 10:38 A Page J of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC BADAMI, BADAMI OIL 281,552 7,061,053 1,176,842.17 1,458,394 $1,951.08 Field/Pool Quantities and Allocated Costs Totals: 281,552 7,061,053 1,176,842 1;458,394 $1,951.08 BADAlvf1, UNDEFINED WDSP 52,942 0 0.00 52,942 $70.83 Field/Pool Quantities and Allocated Costs Totals: 52,942 ° ° 52,942 $70.83 ENDICOIT, EIDER OIL 1,628.222 2,813,008 468,834.67 2,097,057 $2,805.50 Field/Pool Quantities and Allocated Costs Totals: 1,628,222 2,813,008 468,835 2,097,057 $2,805.50 ENDICOIT, ENDICOTT all 91,382,026 271,013,187 45,168,864.50 136,550,891 $182,681.71 ~ Field/Pool Quantities and Allocated Costs Totals: 91,382,026 271,013,187 45,168,865 136,550,891 $182,681.71 ENDICOIT, IVISHAK OIL 3,448,398 64,026 10,671.00 3,459,069 $4,627.64 Field/Pool Quantities and Allocated Costs Totals: 3,448,398 64,026 10,671 3,459,069 $4,627.64 ENDICOIT, UNDEFINED WDSP 325 0 0.00 325 $0.43 Field/Pool Quantities and Allocated Costs Totals: 325 ° ° 325 $0.43 MILNE POINT, KUP ARUK RIVER OIL 33,780,536 13,094,485 2,182,414.17 35,962,950 $48,112.27 Field/Pool Quantities and Allocated Costs Totals: 33,780,536 13,094,485 2,182,414 35,962,950 $48,112.27 MILNE POINT. SAG RIVER OIL 437,237 300,206 50,034.33 487,271 $651.89 Field/Pool Quantities and Allocated Costs Totals: 437,237 300,206 50,034 487,271 $651.89 lvllLNE POINT, SCHRADER BLFF OIL 17,445,698 6,095,224 1,015,870.67 18,461 ,569 $24,698.42 Field/Pool Quantities and Allocated Costs Totals: 17,445,698 6,095,224 1,015,871 18,461,569 $24,698.42 MILNE POINT, TERTI UNDEF WTRSP ~-.::o:~ 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 ° ° ° $0.00 Monday, August 09, 1004 10:38 A Page 2 of 10 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Sib) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC MILNE POINT, UGNU UNDEF WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: ° ° ° ° $0.00 MILNE POINT, UGNU UNDEFINE OIL 2,212 242 40.33 2,252 $3.01 Field/Pool Quantities and Allocated Costs Totals: 2,212 242 40 2,252 $3.01 NORTHSTAR, NORTHSTAR OIL 22,968,022 172,129,811 28,688,301.83 51,656,324 $69,107.32 Field/Pool Quantities and Allocated Costs Totals: 22,968,022 172,129,811 28,688,302 51,656,324 $69,107.32 NORTHSTAR, UNDEFINED WDSP 1,193,004 0 0.00 1,193,004 $1,596.04 ~ Field/Pool Quantities and Allocated Costs Totals: 1,193,004 ° ° 1,193,004 $1,596.04 PRUDHOE BAY, AURORA OIL 11,067,219 12,327,473 2,054,578.83 13,121,798 $17,554.72 Field/Pool Quantities and Allocated Costs Totals: 11,067,219 12,327,473 2,054,579 13,121,798 $17,554.72 PRUDHOE BAY, BOREALIS OIL 28,047,971 9.465,803 1,577,633.83 29,625,605 $39,633.99 Field/Pool Quantities and Allocated Costs Totals: 28,047,971 9,465,803 1,577,634 29,625,605 $39,633.99 PRUDHOE BAY, LIS UNDEFINE WDSP 30,084,377 0 0.00 30,084,377 $40,247.74 Field/Pool Quantities and Allocated Costs Totals: 30,084,377 ° ° 30,084,377 $40,247.74 PRUDHOE BAY, LISBURNE OIL 3,335,277 118,913,584 19,818,930.67 23,154,208 $30,976.37 Field/Pool Quantities and Allocated Costs Totals: 3,335,277 118,913,584 19,818,931 23,154,208 $30,976.37 PRUDHOE BAY, MIDNIGHT SUN OIL 7,428,728 3.499,585 583,264.17 8,011,992 $10,718.67 Field/Pool Quantities and Allocated Costs Totals: 7,428,728 3,499,585 583,264 8,011,992 $10,718.67 PRUDHOE BAY, N PRUDHOE BAY OIL "-~ 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: ° ° ° ° $0.00 Monda)', August 09, 2004 /0:38 A Page 3 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Sib) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC PRUDHOE BAY, NIAKUK OIL 21,869,075 3,385,803 564,300.50 22,433,376 $30,012.02 FieldIPool Quantities and Allocated Costs Totals: 21,869,075 3,385,803 564,301 22,433,376 $30,012.02 PRUDHOE BAY, ORION SCHR BL OIL 368,058 311,963 51,993.83 420,052 $561.96 Field/Pool Quantities and Allocated Costs Totals: 368,058 311,963 51,994 420,052 $561.96 PRUDHOE BAY, POLARIS OIL 1,580,518 999,965 166,660.83 1,747,179 $2,337.43 Field/Pool Quantities and Allocated Costs Totals: 1,580,518 999,965 166,661 1,747,179 $2,337.43 PRUDHOE BAY, PRUD UNDEFIN WDSP 35,836,267 0 0.00 35,836,267 $47,942.79 -"-~- Field/Pool Quantities and Allocated Costs Totals: 35,836,267 0 0 35,836,267 $47,942.79 PRUDHOE BAY, PRUDHOE OIL 618,243,750 5,458,092,755 909,682,125.83 1,527,925,876 $2,044,103.19 Field/Pool Quantities and Allocated Costs Totals: 618,243,750 5,458,092,755 909,682,126 1,527,925,876 $2,044,103.19 PRUDHOE BAY, PT MCINTYRE OIL 61,351,973 116,139,973 19,356,662.17 80,708,635 $107,974.33 FieldIPool Quantities and Allocated Costs Totals: 61,351,973 116,139,973 19,356,662 80,708,635 $107,974.33 PRUDHOE BAY, W BCH TR UN WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 PRUDHOE BAY, W BEACH OIL 1,562,312 201,454 33,575.67 1,595,888 $2,135.02 Field/Pool Quantities and Allocated Costs Totals: 1,562,312 201,454 33,576 1,595,888 $2,135.02 SUn/mal:,,/;,r BP E.\PLOR.1710N (ALASKA) INC (!8 recordsj Operator Quantities and Allocated Costs Totals: 993.395,699 6,195,909,600 1,032,651,600 2,026,047,299 $2,710,504.36 =~-' Monday, Allgust 09,2004 10:38 A Page 4 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPHILLIPS ALASKA INC BELUGA RiVER, UNDEFINED GAS 0 56,252,066 9,375,344.33 9,375,344 $12,542.61 FieldIPool Quantities and Allocated Costs Totals: ° 56,252,066 9,375,344 9,375,344 $12,542.61 BELUGA RIVER, UNDEFINED WDSP 14,165 0 0.00 14,165 $18.95 FieldIPool Quantities and Allocated Costs Totals: 14,165 ° 0 14,165 $18.95 COLVILLE RiVER, ALPINE OIL 69,863,024 77,908,422 12,984,737.00 82,847,761 $110,836.12 Field/Pool Quantities and Allocated Costs Totals: 69,863,024 77,908,422 12,984,737 82,847,761 $110,836.12 COLVILLE RIVER, NANUQ UNDF OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: ° 0 0 0 $0.00 COLVILLE RIVER, UNDEFINED WDSP 407,691 0 0.00 407,691 $545.42 FieldIPool Quantities and Allocated Costs Totals: 407,691 0 ° 407,691 $545.42 KUP ARUK RIVER, CRETACEO U WDSP 552,674 0 0.00 552,674 $739.38 Field/Pool Quantities and Allocated Costs Totals: 552,674 0 0 552,674 $739.38 KUP ARUK RIVER, KUP ARUK RV OIL 267,392,115 193,782,278 32,297,046.33 299,689,161 $400,932.78 Field/Pool Quantities and Allocated Costs Totals: 267.392,115 193,782,278 32,297,046 299,689,161 $400,932.78 KUP ARUK RIVER, MELTWATER OIL 3,863,821 11 ,158,165 1,859,694.17 5,723,515 $7,657.08 Field/Pool Quantities and Allocated Costs Totals: 3,863,821 11,158,165 1,859,694 5,723,515 $7,657.08 KUPARUK RIVER, TABASCO OIL 7,098,455 187,962 31,327.00 7,129,782 $9,538.43 Field/Pool Quantities and Allocated Costs Totals: 7,098,455 187,962 31,327 7,129,782 $9,538.43 KUPARUK RiVER, TARlv OIL 30,149,697 31,270,554 5,211,759.00 35,361 ,456 $47,307.57 Field/Pool Quantities and Allocated Costs Totals: 30,149,697 31,270,554 5,211,759 35,361,456 $47,307.57 Monday, August 09, 2004 } 0:38 A Page 5 0120 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPHILLIPS ALASKA INC KUPARUK RiVER, WEST SAK OIL 9,015,969 979,441 163,240.17 9,179,209 $12,280.21 Field/Pool Quantities and Allocated Costs Totals: 9,015,969 979,441 163,240 9,179,209 $12,280.21 NORTH COOK INLET, TERTIARY GAS 0 17,146,434 2,857,739.00 2,857,739 $3,823.17 Field/Pool Quantities and Allocated Costs Totals: 0 17,146,434 2,857,739 2,857,739 $3,823.17 NORTH COOK INLET, UNDEF WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 S/lmma/")'jÓr CONOCOPlf/U./PS ,fLASK.1/NC 113 records) Operator Quantities and Allocated Costs Totals: 388,357,611 388,685,322 64,780,887 453,138,498 $606,221.72 Monday, August 09, 2004 /0:38 A Page 6 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation o./Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName EVERGREEN RESOURCES (ALAS Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PIONEER, TYONEK UNDEFINED GAS Field/Pool Quantities and Allocated Costs Totals: PIONEER, UNDEFINED WDSP Field/Pool Quantities and Allocated Costs Totals: SumnICII)"!òr EYERGRE/iN RESOURCES (A LrlSKAj CORPORATlON (2 ,.ecordsj Operator Quantities and Allocated Costs Totals: -~~ Monda)'. August 09, 2004 10:38 A 0 2,156 359.33 359 $0.48 0 2,156 359 359 $0.48 80,231 0 0.00 80,231 $107.34 80,231 0 0 80,231 $107.34 80,231 2,156 359 80,590 $107.82 Page 70f20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost FOREST OIL CORP KUSTATAN, UNDEFINED WDSP 411,769 0 0.00 411,769 $550.88 Field/Pool Quantities and Allocated Costs Totals: 411,769 0 0 411,769 $550.88 REDOUBT SHOAL, UNDEFINED GAS 0 461,344 76,890.67 76,891 $102.87 Field/Pool Quantities and Allocated Costs Totals: 0 461,344 76,891 76,891 $102.87 REDOUBT SHOAL, UNDEFINED OIL 910,694 211,827 35,304.50 945,999 $1,265.58 Field/Pool Quantities and Allocated Costs Totals: 910,694 211,827 35,305 945,999 $1,265.58 REDOUBT SHOAL, UNDEFINED WDSP 331,185 0 0.00 331,185 $443.07 .-..:.-~ Field/Pool Quantities and Allocated Costs Totals: 331,185 0 0 331,185 $443.07 W FORELAND, UNDEFINED GAS 0 940,110 156,685.00 156,685 $209.62 Field/Pool Quantities and Allocated Costs Totals: 0 940,110 156,685 156,685 $209.62 W MCARTH RJV UNDEFINED WDSP 1,148,112 0 0.00 1,148,112 $1,535.98 Field/Pool Quantities and Allocated Costs Totals: 1,148,112 0 0 1,148,112 $1,535.98 W MCARTH RIV, W MCARTH RJV OIL 849,195 199,559 33,259.83 882.455 $1,180.57 Field/Pool Quantities and Allocated Costs Totals: 849,195 199,559 33,260 882,455 $1,180.57 Sumn¡(//)'J(¡r FOREST Oil. CORP (7 recnrdsj Operator Quantities and Allocated Costs Totals: 3,650,955 1,812,840 302,140 3,953,095 $5,288.56 Monday, August 09, 2004 10:38 A Page 8 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARATHON OIL CO BEAVER CREEK, BK4VER CREEK OIL 76,134 23,040 3,840.00 79,974 $106.99 Field/Pool Quantities and Allocated Costs Totals: 76,134 23,040 3,840 79,974 $106.99 BEA VER CREEK, BELUGA GAS 0 7,639,494 1,273,249.00 1,273,249 $1,703.39 FieldIPool Quantities and Allocated Costs Totals: 0 7,639,494 1,273,249 1,273,249 $1,703.39 BEA VER CREEK, STERLING GAS 0 104,140 17,356.67 17,357 $23.22 Field/Pool Quantities and Allocated Costs Totals: 0 104,140 17,357 17,357 $23.22 BEA VER CREEK, TYONEK UNDEF GAS 0 124,677 20,779.50 20,780 $27.80 Field/Pool Quantities and Allocated Costs Totals: 0 124,677 20,780 20,780 $27.80 --;;.-~ BEA VER CREEK, UNDEFINED WDSP 39,405 0 0.00 39,405 $52.72 Field/Pool Quantities and Allocated Costs Totals: 39,405 ° ° 39,405 $52.72 FALLS CREEK, TYONEK UNDEF GAS 0 1,088,595 181,432.50 181,433 $242.73 Field/Pool Quantities and Allocated Costs Totals: ° 1,088,595 181,433 181,433 $242.73 G OSKOLKOFF, TYONEK UNDEF GAS 0 1,760,238 293,373.00 293,373 $392.48 Field/Pool Quantities and Allocated Costs Totals: 0 1,760,238 293,373 293,373 $392.48 KENAI, CL. U BELUGA GAS 0 1,116,673 186,112.17 186,112 $248.99 FieldIPool Quantities and Allocated Costs Totals: ° 1,116,673 186,112 186,112 $248.99 KENAI, CL. U STERLING UND GAS 0 3,461,733 576,955.50 576,956 $771.87 FieldIPool Quantities and Allocated Costs Totals: ° 3,461,733 576,956 576,956 $771.87 KENAI, CL. U UPPER TYONEK GAS 0 1,564,964 260,827.33 260,827 $348.94 FieldIPool Quantities and Allocated Costs Totals; 0 1,564,964 260,827 260,827 $348.94 Monda)', August 09, 2004 10:38 A Page 9 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross LÌf¡uid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARA THON OIL CO KENAI, STERLING 3 GAS 0 1,668,534 278,089.00 278,089 $372.04 Field/Pool Quantities and Allocated Costs Totals: ° 1,668,534 278,089 278,089 $372.04 KENAI, STERLING 4 GAS 0 2,911,391 485,231.83 485,232 $649.16 Field/Pool Quantities and Allocated Costs Totals: ° 2,911,391 485,232 485,232 $649.16 KENAI, STERLING 5.1 GAS 0 0 0.00 0 $0.00 FieldIPool Quantities and Allocated Costs Totals: ° ° 0 ° $0.00 KENAI, STERLING 6 GAS 0 11,539,229 1,923,204.83 1,923,205 $2,572.92 FieldIPool Quantities and Allocated Costs Totals: ° 11,539,229 1,923,205 1,923,205 $2,572.92 KENAI, ITONEK GAS 0 1,340,364 223,394.00 223,394 $298.86 Field/Pool Quantities and Allocated Costs Totals: ° 1,340,364 223,394 223,394 $298.86 KENAI, UNDEFINED WDSP 175,315 0 0.00 175,315 $234.54 FieldIPool Quantities and Allocated Costs Totals: 175,315 ° 0 175,315 $234.54 KENAI, UNDEFINED WDSP G&l 282,309 0 0.00 282,309 $377.68 Field/Pool Quantities and Allocated Costs Totals: 282,309 ° 0 282,309 $377.68 KENAI, UPPER TYONEK BELUGA GAS 0 11,126,101 1,854,350.17 1,854,350 $2,480.80 Field/Pool Quantities and Allocated Costs Totals: 0 11,126,101 1,854,350 1,854,350 $2,480.80 S DIONNE, TYONEK UNDEF GAS 0 195,575 32,595.83 32,596 $43.61 Field/Pool Quantities and Allocated Costs Totals: 0 195,575 32,596 32,596 $43.61 STERLING, BELUGA UNDEFINED GAS -0 --- 0 109,674 18,279.00 18,279 $24.45 Field/Pool Quantities and Allocated Costs Totals: ° 109,674 18,279 18,279 $24.45 Monday, August 09, 2004 10:38 A Page 10 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPoo/ Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated CO.'ft MARATHON OIL CO STERLING, TYONEK UNDEFINED GAS 0 6,505 1,084.17 1,084 $1.45 Field/Pool Quantities and Allocated Costs Totals: 0 6,505 1,084 1,084 $1.45 STERLING, UNDEFINED GAS 0 241,846 40,307.67 40,308 $53.92 Field/Pool Quantities and Allocated Costs Totals: 0 241,846 40,308 40,308 $53.92 TRADING BA Y, G-NE/HEMLK-NE OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY, HEMLOCK OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 --~~ TRADING BAY, MID KENAI DOlL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY, MID KENAI E OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BA Y, UNDEFINED GAS 0 100,598 16,766.33 16,766 $22.43 Field/Pool Quantities and Allocated Costs Totals: 0 100,598 16,766 16,766 $22.43 TRADING BAY, UNDEFINED WDSP 20,696 0 0.00 20,696 $27.69 FieldIPool Quantities and Allocated Costs Totals: 20,696 0 0 20,696 $27.69 TRADING BAY, W FORELAND OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 ° $0.00 WOLF LAKE, BEL-TYON UNDEF GAS 0 240,480 40,080.00 40,080 $53.62 -- Field/Pool Quantities and Allocated Costs Totals: ° 240,480 40,080 40,080 $53.62 Monda)', August 09, 2004 J 0:38 A Page J J of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName MARATHON OIL CO Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost ;';"/!/!'!;I/"vlìw MARATHON OIL CO (30 records) Operator Quantities and Allocated Costs Totals: 593,859 46,363,851 7,727,309 8,321,168 $11,132.30 .~ r__~ Monday. August 09, 2004 10:38 A Page 12 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPoo/ Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost NORTH SLOPE BOROUGH BARROW, EAST BARROW GAS 0 92,659 15,443.17 15,443 $20.66 Field/Pool Quantities and Allocated Costs Totals: 0 92,659 15,443 15,443 $20.66 BARROW, SOUTH BARROW GAS 0 88,671 14,778.50 14,779 $19.77 Field/Pool Quantities and Allocated Costs Totals: 0 88,671 14,779 14,779 $19.77 WALAKPA, WALAKPA GAS 0 1,235,479 205,913.17 205,913 $275.48 Field/Pool Quantities and Allocated Costs Totals: 0 1,235,479 205,913 205,913 $275.48 Summaryjàr NORTH SLOPE BOROUGH (3 recordsi Operator Quantities and Allocated Costs Totals: 0 1,416,809 236,135 236,135 $315.91 ."-=>" ~ Monday. August 09,2004 10:38 A Page 13 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PHILLIPS PETROLEUM CO NORTH COOK INLET, TERTIARY GAS 0 30,773,377 5,128,896.17 5,128,896 $6,861.58 Field/Pool Quantities and Allocated Costs Totals: 0 30,773,377 5,128,896 5,128,896 $6,861.58 NORTH COOK INLET, UNDEF WDSP 2,804 0 0.00 2,804 $3.75 Field/Pool Quantities and Allocated Costs Totals: 2,804 0 0 2,804 $3.75 SUlI/nUlIJ'Jòr 1'1111.1.11'8 PIJROLl~U!\.f CO (2 recordsj Operator Quantities and Allocated Costs Totals: 2,804 30,773,377 5,128,896 5,131,700 $6,865.3:3 .",,-.:..~ "-=-~ Monday, August 09, 2004 10:38 A Page 14 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PIONEER NATURAL RESOURCES OOOGURUK, UNDEFINED OIL Field/Pool Quantities and Allocated Costs Totals: Summary/or PIONEU? ;VA TU!?/I/. RESOURCES USA, liVe. (1 deiail record) Operator Quantities and Allocated Costs Totals: 3,828 0 0.00 3,828 $5.12 3,828 0 0 3,828 $5.12 3,828 0 0 3,828 $5.12 "'"~~ Monda)', August 09,2004 10:38 A Page 150/20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Sib) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA GRANITE PT, HEMLOCK UNDEF OIL 41,217 54,336 9,056.00 50,273 $67.26 Field/Pool Quantities and Allocated Costs Totals: 41,217 54,336 9,056 50,273 $67.26 GRANITE PT, MIDDLE KENAI OIL 2,494,887 1,232,872 205,478.67 2,700,366 $3,612.63 Field/Pool Quantities and Allocated Costs Totals: 2,494,887 1,232,872 205,479 2,700,366 $3,612.63 GRANITE PT, UNDEFINED GAS 0 91,232 15,205.33 15,205 $20.34 Field/Pool Quantities and Allocated Costs Totals: 0 91,232 15,205 15,205 $20.34 GRANITE PT, UNDEFINED WDSP G&J 58,262 0 0.00 58,262 $77.94 FieldIPool Quantities and Allocated Costs Totals: 58,262 0 0 58,262 $77.94 =--~ IV AN RIVER, UNDEFINED GAS 0 2,470,717 411,786.17 411,786 $550.90 Field/Pool Quantities and Allocated Costs Totals: 0 2,470,717 411,786 411,786 $550.90 IVAN RIVER, UNDEFINED WDSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 LEWIS RIVER, UNDEFINED GAS 0 575,122 95,853.67 95,854 $128.24 FieldIPool Quantities and Allocated Costs Totals: 0 575,122 95,854 95,854 $128.24 LEWIS RIVER, UNDEFINED WDSP 993 0 0.00 993 $1.33 Field/Pool Quantities and Allocated Costs Totals: 993 0 0 993 $1.33 MCARTHUR RIVER. HEMLOCK OIL 28,488,869 1,415,741 235,956.83 28,724,826 $38,428.90 Field/Pool Quantities and Allocated Costs Totals: 28,488,869 1,415,741 235,957 28,724,826 $38,428.90 MCARTHUR RIVER, MIDKENAI GaIL ~. 7,765,201 616,628 102,771.33 7,867,972 $10,526.00 FieldIPool Quantities and Allocated Costs Totals: 7,765,201 616,628 102,771 7,867,972 $10,526.00 Monday, August 09, 2004 10:38 A Page 16 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperalorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas ROE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA MCARTHUR RIVER, MJDKENAI GAS 0 37,133,934 6,188,989.00 6,188,989 $8,279.81 Field/Pool Quantities and Allocated Costs Totals: 0 37,133,934 6,188,989 6,188,989 $8,279.81 MCARTHUR RIVER, UNDEFINED OIL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MCARTHUR RIVER, W FOREL4ND OIL 1,165,188 49,252 8,208.67 1,173,397 $1,569.80 Field/Pool Quantities and Allocated Costs Totals: 1,165,188 49,252 8,209 1,173,397 $1,569.80 MIDDLE GRO(JND SHOAL, A OIL 24,178 27,915 4,652.50 28,831 $38.57 Field/Pool Quantities and Allocated Costs Totals: 24,178 27,915 4,653 28,831 $38.57 "-:'~ MIDDLE GROUND SHOAL, B,C,D OIL 4,373 18,731 3,121.83 7,495 $10.03 Field/Pool Quantities and Allocated Costs Totals: 4,373 18,731 3,122 7,495 $10.03 MIDDLE GROUND SHOAL, E,F,G OIL 83,898 26,315 4,385.83 88,284 $118.11 Field/Pool Quantities and Allocated Costs Totals: 83,898 26,315 4,386 88,284 $118.11 MIDDLE GROUND SHOAL, UNDEF GAS 0 145,444 24,240.67 24,241 $32.43 Field/Pool Quantities and Allocated Costs Totals: 0 145,444 24,241 24,241 $32.43 PRETTY CREEK, UNDEFINED GAS 0 427,900 71,316.67 71,317 $95.41 Field/Pool Quantities and Allocated Costs Totals: 0 427,900 71,317 71,317 $95.41 STUMP LAKE, UNDEFINED GAS 0 277 46.17 46 $0.06 Field/Pool Quantities and Allocated Costs Totals: 0 277 46 46 $0.06 SWANSON RIVER, GAS STORAGE 0 1,466,572 244,428.67 244,429 $327.00 --""'--~. Field/Pool Quantities and Allocated Costs Totals: 0 1,466,572 244,429 244,429 $327.00 Monday, August 09, 2004 10:38 A Page 170120 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA SWANSON RIVER, HEMLOCK OIL 425,555 7,147,763 1,191,293.83 1,616,849 $2.163.07 Field/Pool Quantities and Allocated Costs Totals: 425,555 7,147,763 1,191,294 1,616,849 $2,163.07 SWANSON RIVER, UNDEFINED GAS 0 1,844,556 307,426.00 307,426 $411 .28 Field/Pool Quantities and Allocated Costs Totals: 0 1,844,556 307,426 307,426 $411.28 SWANSON RIVER, UNDEFINED WDSP 2,720,342 0 0.00 2,720,342 $3,639.35 Field/Pool Quantities and Allocated Costs Totals: 2,720,342 0 0 2,720,342 $3,639.35 TRADING BAY, HEMLOCK OIL 1,212,724 127,641 21,273.50 1,233,998 $1,650.88 FieldIPool Quantities and Allocated Costs Totals: 1,212,724 127,641 21,274 1.233,998 $1,650.88 '~=-' TRADING BAY, MID KENAI BOIL 57,484 19,031 3,171.83 60,656 $81.15 Field/Pool Quantities and Allocated Costs Totals: 57,484 19,031 3,172 60,656 $81.15 TRADING BAY, MID KENAI COIL 793,630 51,309 8,551.50 802,182 $1,073.18 Field/Pool Quantities and Allocated Costs Totals: 793,630 51,309 8,552 802,182 $1,073.18 TRADING BA Y, MID KENAI DOlL 854,447 42,672 7,112.00 861,559 $1,152.62 Field/Pool Quantities and Allocated Costs Totals: 854,447 42,672 7,112 861,559 $1,152.62 TRADING BA Y, MID KENAI E OIL 72,407 18,022 3,003.67 75,411 $100.89 FieldIPool Quantities and Allocated Costs Totals: 72,407 18,022 3,004 75,411 $100.89 TRADING BAY, UNDEFINED OIL 14,613 3,887 647.83 15,261 $20.42 Field/Pool Quantities and Allocated Costs Totals: 14,613 3,887 648 15,261 $20.42 Summary/or UN/ON on co OF CIL1FORN/A (29 records) Operator Quantities and Allocated Costs Totals: 46,278,268 55,007,869 9,167,978 55,446,246 $74,177.58 -~ Monday, August 09, 2004 10:38 A Page 18 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE -Total Volume (Liq+BOE) Allocated Cost XTO ENERGY INC lvJIDDLE GROUND SHOAL, B, CD OIL 5,636 3,154 525.67 6,162 $8.24 Field/Pool Quantities andAllocated Costs Totals: 5,636 3,154 526 6,162 $8.24 MIDDLE GROUND SHOAL, E,F,G OIL 3,939,469 431,019 71,836.50 4,011,306 $5,366.44 FieldIPool Quantities and Allocated Costs Totals: 3,939.469 431,019 71,837 4,011,306 $5,366.44 MIDDLE GROUND SHOAL, UNDF WDSP 16,486 0 0.00 16,486 $22.06 FieldIPool Quantities and Allocated Costs Totals: 16,486 0 0 16,486 $22.06 Summary for xrn FAERC)' INC (3 recordsj Operator Quantities and Allocated Costs Totals: 3,961,591 434,173 72,362 4,033,953 $5,396.74 T~~ -~ Monday, August 09, 2004 10:38 A Page 19 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,420,300.00 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Report Qualltities and Anoeated Costs Totals: I 1,436,324,846 r I 6,721,682,2151[ 1,120,280,3691 I 2,556,605,2151 I $3,420,300.00 I o;;::.~ .~ Mont/ay, August 09, 2004 10:38 A Page 20 of20 .~, ) i t Notice of Proposed RCC October Explanation of Lapse ) ) ¡I' kto ~~~ 0 .ç.p~ po:s..e..d ~lA1a-foYq C05r ~~ FY :u:>Db , C-er+t P~.A r:4íps .~ w re-tLu-n ~ ) ) iii Sender: Please print your . ¡ Fîrst-Cla,~s 1\/1~l¡ . . GF~ "'{-\7'7\..[:r:I.(:-¡f¡')¡;~:"-'" q,,!.--," P '.' )¡ ~l J1!. :l'..,IjJ.t"I:'\'t~.... :1. 'r"'\.. ;:¡!~ .r- l4~f'S . '~¡, ':,: :::~ ì ~~"LI'I'i, ,f;-'¡gnnlt No. G··¡Il~~·' ,p'~ .L ( ',,,:.1 ",'i.' ..I '~~~ \ , ,;,~\"..:i 'I --., 'll'~ I and' è¡.p+4"i'fì-~tta-&&~~,-_._" .. UNITED STATES POSTAL SERVICE AK Oil & Gas Conservation Commissi ¡ . ¡ 333 W 7TH Ave, Ste 100 Anchorage AK 99501 ~3539 ~"'" ii' """"" M ...'~:¡,; ~ OCT 1 9 2004 {', Õ! II d II I d I ¡ d i L n U Ii III fl. dill L fill Hit d II U II IS ,I L I Lilt U1 rr r-=¡ r=J ~ rl1t:'111ì':r.>o; Ìi\;';¡,.ÎÍij:¡;j.':"¡1"1:"'iJ!t!m:'tfl.I'~1L":tl\'(r·' U1 m "'J'j PQstage $ ·3/ ~.30 J . ~_._._ U1 o o Return R0CI~;pt F~)0 CJ (Endorsement Fløquircd) CJ REJstricted D,;¡/ivery Fee 1I1 (Endorsernent ¡::¡equired) ,..::¡ f11 Total Postage 8, Fees I $ Lf. ...,. ;,h Certified Fee ru CJ o ('- ·-----l :tt!.::~¡i~~;/iL~l~.:~:~!.¡~::.~,,~,.,~~,... ,.'W';''-'''--c. .,", '~'...",....&,,,. ..,,' .,~'""";~.:.:.,...:.:~ c::":";.,,',':"."·.." ':~i ;~2 "J _-:"Wi.i!"'":"" ..~> .~\. . ".'.'~·Jf¡~.~;a~"i¡¡\'I. (.:'..··,··.·~·~·'..i~~ ~~.,..;~·i'~·.'·~·,. '~. :'Io¡þ> ~.!' ~-·1'.:~'·~:~· ..~",~(.: '.;i;'~·;'T ..".'.....~ tT: .' . -' " \~. I'. . \ ~.'J"l" '.."1: 011 IJ' II ::t" . II 11,~.. .1;;~~ ",'..,'1.'. '. _ -.1:,. ~,.,~ .., ~.tI!, . I' 'T.t~~"';1;.MI"'i.~.;j"" ..'. \!:¡ijl¡'. . ,,/~, .~~~~. '. CompletE: Items 1, 2, and .3. Also complete" ,Aj),eceived by (Pj;.~set¡int 9/eyrly) B. Date of Delivery ite.m 4ff Restricted Delivery is desired. t(l ~ ~~ /.o,/7.:".Ç2. y · Pnnt your name and addre:ss on the reverse . ' so that we can return thE{card to you. C. ~Slgnature · Attach this car~ to the ba,ç}< ?f the maiJpiece; , X· / ~¿bo/$)z¿) CL- or on the front If space permits. f/ fA 1, Article Addressed to: o Agent o Addressee O. Is delivery address dìfferent from item 1? 0 Yes If YES, enter delivery address below: 0 No Aurora Gas LLC Attn: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 3. Service Type '~ertifìed Mail 0 Express Mail o Registered 0 Return Receipt for Merchandise o Insured Mail 0 C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Copy from service label) 7002 3150 ODDS 3521 1195 -"._. "'''''--''''-''''-'~' - . ,." ~'" ....-----. ~-'-""'_._~--'-'--_...._.._--------,-~--~--,-.._--._.._,--,_.....'"-.-. PS Form 3811 , July 1999 Domestic Return Receìpt 102595-00'M-0952 ) ) UNITED STATES POSTAL SERVIÇ~::;"'t:~·7~7·~t·,,,·,;,,. First-Class Mail . r~,~ . Posl~::tge &, Fees Paic..i \, USPS . I Perroit 1\10. G-lQ '::":, :¡ :"" ", / if : I; · Sender: Please pririt~,e.~."~:§pl~, address, and ZIP+4 in tt:ds"'bbx Iii}....,. " ,,' ~.. \, r. II v¡ . OCT G n 2004- AK 011 & Gas Conservation Commission' ' ð, 333 W 7TH Ave, Ste 100 Ah~sk~ 0i18¿ C:tHl$, Anchorage, AK 99501-3539 ........ ...: ..... . ~ ¡ i I ¡ ¡ ,. . I I ¡. ¡¡ I ¡ ! i!! I I! !. ¡! ¡ ,,¡I,: :!I!! it;! ¡¡¡¡¡Iii:; 1¡!I:,li"! '1'1":: I:: ¡'I :¡I! ". _... H. . . II . .. 1I1 o CertiHed Fee _...__~. 3D o o Return f-1øcit)pt Fee (Endorsemont Roquired) 1 . î 5 D Røstl'Ìc!,¡d Delìvøry Fee 1I1 (Endorsement FlequiroeJ) r=I m Total Postage & Fees $ .&-\. {¿, S- ~ -Sent Tv . BP Exploration (Alaska), Inc. !2 .....m...m.... Attn: Steve Marshall President I - $tl'é1ot, Apt. 1\ P , orPO/3oxN< .0. Box 196612 'ë:Ït}':Štéj¡ë::z Anchorage, AK 99519-6612 Postage $ r=I CJ ru r-=J r=I ru U1 m .,~~~...._¡".;;.J.".;....I¡'~ ....J. .,¡'I....., ~,~",.'...':'~,,;"....,..\',¡:i 11'.~...oiItiI...,..._·_....., _ "'1tIIII·.....,JIIj..w..-n . ~~r~~.~tïJj1¥~-: ;'\¡' · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. . ,.~;~., ·W.'f~'t:!.t¥Î~j;~Tt~~~j~~~"~~l'~trl~r.'t~;f;q' It'"l£:,~~t~~k:~~t¿"il!i~'~~~11~>~~;~. . f'\, Slgzalure AkD o Agent XU' 0 Addressee 8. Re 've -y (Printed Name) C. Date of De~e.o:, . 11') (10--/ D. Is deli add",55 dlff1nt from item 1? 0 Yes If YES, enter delivery address below: 0 No 1. Article Addressed to: BP Exploration (Alaska), Inc. Attn: Steve Marshall, President P.O. Box 196612 Anchorage, AK 99519-6612 \ 3. Service Type ~Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C,O.D, 4, Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number . (Transfer from service label) PS Form 3811 , August 2001 7002 3150 0005 3521 1201 Domestic. Retùm Receipt 102595-02-M-0835 UNITED STATES PO~ I .Jst-GlaSS lVIail . I Postage & Fees Paid USPS Permit No. G-10 ¡:~~~t':' ,""";"",,,.\1; ". " I."·' í" \4 ti~'''' H' ", '" Sender: Please print your name, address, anI ""E11t?#~:!,r¡ ~' b'ì~1· OPJ'- ì· I,J l i~),)O' . ,~~ t.. 04 AK Oil & Gas Conservation com~~~$),cCDílS, 333 W 7TH Ave, Ste 100 .. Ih;'ß¡;~tn:¡:Œl~;¡; Anchorage, AK 99501-3539 )SERVICE II '\ ' h 1 I L i Iii! L ¡ ! L L II j HI ;¡ ¡¡ ¡¡lilt L L L Ii ¡ II L 1 n L í I L I II ì L ì\ U1 o Certified Fee o o F!øturn Reci~¡pt Fee (Endorsement Fiequìreti) o l:¡estrct~Ki Delivery F'ee Ul (Endorsement Flequired) ....=I IT! Postage $ 1~1 ~..3o ). '5 co r-=¡ nJ r1 r1 ru U1 nl Total postaoø 8, Feos $ '1 ,Lf~ ru o sëñT'ï'o'-- ConocoPhillips Alaska, Inc. a f'- -sïr¿ièCAij Production Revenue Accounting orP'OBO)j Attn: Noel Dike ATO-1668 '-ëilÿ~:Štàt6 P.O. Box 100360 [}.I;:;J'tl"'·'~ ,~n9h?~aQe, AK ~.9,510-0~~_O,..., .1." ,,\,1,,, ,.II!.,:;::i"1 ~U.~...LJI.'" ...,'........" 6..'_. '1I.._au....\.,..:L.~,.....:.,¡J,¡.I.t...~.,..,,~~_..;J... ..¿..",:.¡,;,~.....~..,.I~~"":""".""''-LoI'_o.J...'~~~ 'L:."a...l,"'A~L,J¡¡f.J + a1' ~_.... \i-"-~"'~''''ï.~~~' " .,...-. ,·~!'·,·~····,~···OO'··..·',~:I'.::/:,:..·.:.,:I'"'I ¡"~~·"··fJ~-tr·l?m·'''' ~iQ;i.Wtl~'I'~··;.'·!#1~\'~···'····' .,' .:'.:":.,'..,'.,1..:". '~: .. II .fT: - ~ , ~ v;'. ~,~"~.,~~,,,.\....l..~ ~ .H~,:,,7~~, If iJ..:t;t '.".'''''''' I' . '~~··,~r·:..i..·t''.\r: ..... :..rIJ~·#' .... \ . .: " £.~,¡;, , ~'.~' "., ,. ::,;¡¡,. ' '\!l1'~~i~~ $:!r~;o:~";~'" ", . ~,LI~·,"'i,~¡..:.t\II"~~I!~,tl~:::..,:'t¡.J'Ji,~~~·;;¡·~~r):!};d~t;~;~r~~ . Complete items 1 2, and 3. Also complete A. Received by (Please Print Clearly) B. Date of Delivery ite,m 4 if Restricted Delivery is desired. ~LVI/ ~5 ItI"'¿:;'J'77~ II Print your name and address on the reverse /fVv!V so that we can return the card to you. C. Signature . Attach this card to the back of the mail piece, ~ /1/ 0 Agent or on the front if space permits. . ø--- 0 Addressee D delivery address different from item 1? 0 Yes 1. Article Addressed to: If YES, enter delivery address below: 0 No ConocoPhillips Alaska, Inc. Production Revenue Accounting Attn: Noel Dike ATO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 3. Service Type ~ Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.Q,D. 2. Article Number (Copy from $1 4, Restricted Delivery? (Extra Fee) 7 0 ~.~_~_~_~.__D 0 0 5 3 521 1218 -~,.._..._.._...._,~--.,.. DYes PS Form 3811 , July 1999 Domestic Return Receipt 102595-00-M-0952 + ) ) ( ~~~TAL S,~;¡Y:~~E ¡:'I'. '\> ..{\\,,, \'"''t. ....,\" ,iJ . ,'I, r!\·\'¡ ..!\.' .",,\;11'"' (\r . .... "'. d'~'~·.'....·. \..J '\.,,) . \, .., .. ~'¡ ..,~e~~d~~~~i~ÞT~~se print your name, address, and ZIP+4 in this box '" <J.'~ ~;~:,. .' ;"$;, ;0 " f:'- . ~"\'~I.'~' t~~~~ '~. ! 11 ,\ I First·class Mail Postage & Fees [':>aid USPS Permit No, G-10 i ¡ AK Oil & Gas Conservation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 \ \ \ \ ¡ ! l ¡ \ ~ II \ ¡ \ ¡ \ \ \ ¡ ! ¡ ¡ ¡ \ \ \ ¡ \ i ¡ ¡ \ I h \ ¡ I ¡ \ \ i \ I \ ¡ I \ I \ I \ I ì \ ¡ ¡ \ ¡ \.\ Postage $ .31 LJì CertifiEJd FE1e a · '5tJ D CJ F1eturn r1eciept Fee \ .1S D (Emjorsernent ¡:ìøquired) D F1estricted DelivelY I~ee Ul (Enejorsemünt HüquÎrüd) ~ ~.'-' r fTJ lÖtal Postage) & FEjeS $ ru '-sêiJi7ö-- Evergreen Resources Inc. ~ Attn: Mark S, Sexton, CEO I'- "~I~ì~~;~: 1401 1ih Street, Suite 1200 "ëitÿ;'šiãÙ Denver, CO 80202 Ü::~Ð2E'.'"" ~. ,., _h"h" ....h..........·.. .. .,"'...-."...- .... + .~.!!~~í;~~~YJj~~~':'4iI;~ypYJ'~~~¡f~'1Z1;,:;~,),:r)~·,~:;'!,.ri¡l;i~ ·ít.i1,~~fit.~#~:ii~r.~~~.jt~:I.J~Wl~'.~¡:;4':-\:::,(,;j;::...(.\lfi~ iJ¡l.-1ti.JJ~.v~l§¡':r¡~:~,~u.:~\!S¡£",,1>"}l!~<\Þi'tl~.t::r.~lJ~ ~e:"to:.l.!P~.~.:;¡¡,.\i,{,!¡:l£~1¡,¡1~~,~¡,·~\ii··~.j"'-ï~~;.o,,1t~~~M¡¡~~.\:i.~,iI . Complete items 1, 2;' and 3. Also complete A. Received by (Plea.s. e Print ?Iearly) B. Date 0peliVery ¡te.m 4 if Restricted Delivery is desired. ''--'nD ) Q 1\ 1 bg..4;, ID J 12..' } II Pnnt your name and address on the reverse . .-tv Tt I 1 so that we can return the card to you. C. SIgnature ....~-- .. . Attach this card to the back of the mail piece, ~^ _ () ) or on the front if space permits. ~ I f ~ _". D, Is delivery address different from item 1? If YES, enter delivery address below: 1. Article Addressed to: o Agent o Addressee DYes o No Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 1 ih Street, Suite 1200 Denver, CO 80202 3. Service Type .~ Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O,D. 4, Restricted Delivery? (Extra Fee) DYes 2, Article Number (Copy from service label) 7002 3150 0005 3521 1225 -..- ...-..,_._.~".."...._--..._,-...........~---~.._-..._,-~-,~,,~,-,'--"..-.....------,. r'S Form 3811, July 1999 Domestic R~:~tl!m R,>r:eipt 1fì">t::O¡: ('$\ f.A t"\l"\r·· ) -) UNITED STATES POSTAL SERVICE ! II q 1 ¡ ¡.' ~ ; ! Fi;·st-class Mail .. I ! I' ! Postage & FeE;)s fJ;:,icl . I r USPS .,..1. ,. g "' ¡ì . i· . Permit No, G-1\ ,;:: C \:~\ \of . ' . M'der: PI~~~~nt your name, address, and ZIP+,4 in this box ~ (''''f $ . ·"~'\c\\ G v \ (' u~\,\,\\~¡) I" . ~\~. \~ r.. '~,$ ",,0\ Ü~ '& \),Y> " ' e f\\~~\l~' ~ 'Þ.~t~~~6i1 & Gas Conservation Commission 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 ..,. ......,...... . ........ ....~....... .- '·:::';~:·~~j:L ~r·,:::::·.::·:~ jj ¡ I ¡ ¡ 1 ¡ ¡ U I ¡: L n ¡!! I! ¡ j L ¡ Ii 1/ L 1!J ¡ iLL i ¡¡ ¡¡ n ¡ ! ¡ n jj!l if ru TJ ru r-=I :"'it~¡;Y;;i :'(.îl·ì"·f\J~,:rl4·~';1'~¡'1;\':,1'\1 r:1'i,:''':~il~~ :'i;rl!-j:Y'''(~''''''Y::f::\''''¡-;r!'):''J-;r'':~'':'¡'~;' ¡!,...r , I.' '1' .-=I /.\.. J. '.1 'L.",.... ..~.I..,.!, ..).W,....,I,. ,~.,\.1!;;.J...UJ.r..;.l~",,".Jj''''-''';.!~LI':'''!'''' ,; I.·....! ,L',~J"..,' ",11, '" J.....,I"~,, ,. ,,'. ,','.; .,1,.." ru L.I1 m .31 ..-.~ .;;;¡. 3-0 #S:~.st~~"í.9. . \.'5 If: H ~ \u ~ I 1:. U ")... \:?~. i \ ~') _/(.' ~I .." 4 "1 ". <";~~)', / \1.0/ ~" >.. /(./ ~.""""':~"_'_""'" ',0 ,,<,,' ~ Sent To ·"<~2NV,.~,,_"""'·' ~---- CJ ,......,___.._ Forest Oil Corporation I""- ;;r~~,;; Attn: Accts Payable -,(';/(y,'stãï, 310 K Street, #700 Anchorage, AK 99501 [~h;j11!ili6;"~:!~.'.li'.Jj"';:~~~t.~,",,,..;!I..",~.~<~,,:,,,,,,:~~,.¡J~~...,~.:~\' I" '1·r',~j'ti:1:¿,~~:.'!~~r::!'r:~fQ~ Postage $ U1 CJ CJ Return ReGiept F'm;¡ o (Endorsement ReqLlired) Certified Fee o liøstrlctod Delivery Fee U1 (Endorsement Hequired) .-=I T] Total Postage & Fees $ II Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. . Print your name and address on the reverse so that we can return the card to you. iIiI Attach this card to the back of the mailpiece, or on the front if space ,permits. 1. Article Addressed to: ·"~':NÞ.,~'~~·; ."" ':;'\'~ .', ·'.,i·I:· l' ,!~. ,·\LëA&~~J¡~,~r.i!~7":· AIWM;;jt 4JJ!~7 ò7P c (j'ltIAL [~(w¡r¡ ì 0 Agent X ~ ) 0 Addressee D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No 'r'r...','.,' , ,",'~'(. f'I:P;':~'¡'" (" Forest Oil Corpoi:àtion Attn: Accts payaß.le 310 K Street, #700 Anchorage, AK 99501 3. Service Type )Q Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.OD. 4. Restricted Delivery? (Extra Fee) DYes 2, Article Number (Copy from service label) 7002 3150 0005 3521 1232 - '-"-~""_._......~_.-_.- '. PS Form 3811 , July 1999 Domestic Return Receipt 102595-00-M·0952 Fírst-Cìass Mail .. Postage & Fees Paid USPS Permit No. G-10 · Sender: Please print your name, address, and· I /1,-c;:fi£;r OCT 1 2 'DO" ;¡ I ... 4 ,t.¡ii:JS/(;:) OJ AK Oil & Gas Conservation commiSSi~n8t Cons. 333 W 7TH Avel Ste 100 Anchorage, AK 99501-3539 + ') UNITED STATES I-'OSTAL SERVICE ij f f ). ') ¡¡ ¡ ¡ ¡ I j ¡ I H ¡ it! ¡ I L II II ¡ Ill! Ii ¡ I L ¡ \ L \I ¡ilL i Ii ¡ ILL j ¡!! L H rr .::r ru . . M!l';i>-";¡ :'j'ft\'t:')"',,' .. .... . '~¡' ....~.. ' ,,~~. . 'V' ":"" '" "", , , . , ' f¡,,,,"~....~.:,,,.\:.iQ1I'!1ffi'! fr·,1, ,rJ[~¡~¡,¡¡ì, ",'I'!'/:-H\t'fi"'i ;"rr'l '·..rlr"'ìl·~';f't·'i ',"1 ~ ." .~'~~'-""~¡'''"::::~J Postage $ Ul Cl Certífied Fee CJ a Return Rec!ep\ Fee (Endorsement Requíred) , o l' ~trH t~',..! l·rl...Ii'~rl F~(.) lf1 ,.:.1"';1\,( 'A r.1', h ¡:¡, ilIlf<.'J, ' r-1 m Total Postage & Feøs _!_~ ((, if> ru CJ Sent To CJ >.....~...._..... Marathon Oil Company f'-- ~;r~~.:::. Attn: Accounting Analyst -ë;¡i~sì;ji;' P.O. Box 196168 , Anchorage, AK 99519-6168 ~~~. ~:+\n'.'~.'·' "'. ØI1.1Jt-:Þfiijj~. f{4'·tA{~f.t.:~!;,~~&J,:~: ìïii' ,a.:~~¡~111~:ti':J¡t.~· ·;Ü,h,äll.l,ó;~ ~ ~'""'I · Complete items 1, 2, Zlnd 3. Also complete item 4 if Restricted Delivery IS d\:3Slrt':d. · Print your name and address on the reverse so that we can return the card to you, · Attach this card to the back of the maìlpiece, or on the front if space permits. 1. Article Addressed to: Marathon Oil Company Attn: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 2. Article Number (Copy from service label) + ö;::~~~t~~~ Dat~~~_ C. SU;' atur~ ~\¿:, lrf Agent X .~ CÐ 0 Addressee 0, Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No 3. Service Type ç&.,Certified Mail 0 Express Mail o Registered 0 Return Receipt for Merchandise o Insured Mail 0 C.O.D. 4, Restricted Delivery? (Extra Fee) 0 Yes 7002 3150 ~On5 3521 1249 PS Form 3811 , July 1999 .--",....~_.~....."...~-~...._."_.'".'^~,,._," "'" ,," ...". ...,.-..."......-'"------...''.-''' 'j Î 02595·QQ-M·0952 Domestic Return Receipt ) UNITED STATES POSTAL SEI:::(VICE III1 I l ) First-Class Mail Post"lge & Fees Paid USPS ' Permit No, G-' () · Sender: Please print your name, address, and~rEG£if~Je[> OCT 1.1L:2004 ,A/JSI«(;I OJ¡' 8~ GdS Cðfl~' C" ,..". AK Oil & Gas Conservation Commission ,l~. r'" '"., ,,)I, (im¡n¡~;Slon 333 W 7TH Ave, Ste 100 n""hO!dge Anchorage, AK 99501-3539 _, """t 11 ¡ i ¡ II I 11 In '1·1 ¡ I 'II ¡ II 11 n I I ¡ ¡ddnd¡¡¡¡¡;:¡¡dln ¡HI H:!¡¡j¡ ¡¡I! ¡¡¡!i!¡\¡¡!! ....D Ul ru r-=¡ r-=I ru U1 rrJ Posta~le $ U1 o o R~)turn Fleciept Feø o (Endorsement Flequired) D Røstricted Delivery Føø U1 (Endorsement Hequired) r-1 m C~¡rti1i0(j Fl':)e Tbtal Postag(':) & Fees $ ru o "s;;'-:;7ir'fo North Slope Borough ~ ..".,----..., Attn: Dorothy Savok Manager I - Stmet, Apt . or PO Box Barrow Gas Fields 'ëÏtÿ;-ši,~ië, P.O. Box 69 ~ktilli~~~'~i:Þ~~;J~~l~i:.:5~!~'!,J~.~~3~Jii.!';~;':;:;'¡,;:¿;'~~iii"d':LSEi~iÎ;'~;\!":L~:,~;.:.~&tJl~t.Jj . Complete items 1 J 2, and 3. Also complete item 4 if Restricted Delivery is desired. Ii r ¡int your name and address on the reverse ::> that we can return the card to you. 'Ittach this card to the back of the mail piece, jr on the front if space permits. o.\rticle Addressed to: North Slope Borough Attn: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 2. Article Number (Copy from service label) JS Form 3811, July 1999 A. ¡f;ceived by (Please Print Clearly) B. Da}é Ofpelive.ry ~.k C-c<.h2CO /0(..::;/0 ý:- C. Signature o Agent o Addressee DYes o No x~ /Jf!:j'~~:~~e~ff:d::::~~:1? ~! ?\ SE P - 7 2004 J \ j ~"TYÞe "U~U~d Mail 0 Express Mail o Registered 0 Return Receipt for Merchandise o Insured Mail 0 C,O.D. 4. Restricted Delivery? (Extra Fee) DYes 7002 3150 0005 3521 1256 -'~"._"'~ .....,--.- ''''.'-''''- -_._.~---._-~.-..._~-,.,-- Domestic Return Receipt 102595·00·M·0952 UNITED STATES POS ".2 SEFNICE ) First-Class lVIail Postage & ¡:-ees Paid USPS Permit No. G-" 0 ì Sender: Please print your name, address, and ZIP+4 in this box '* i,'~\ ¡I¡¡¡¡~'" ,'" " ..'¡' """""", ,.. \, I, i ,/r """ì AK Oil & Gas Conservation Commission ~,' r: I . t: [) Ocr 1 2 2004 , 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 I It I ¡ ¡ ¡ ì \ II! L I! Ii j ¡ ! ¡ H II ¡! II ¡ ¡ I! I ¡ L \I ì HI! Iii ¡ ì L L L H!! II o RG;>trictød Deliv<'Jry Fee U1 (Endorsemønt Required) M rn Po;>tage $ f11 ....D I1J r4 .-=i ru LI1 f11 U1 Certified Fee o t:::I Return ¡1Gciept Fee CJ (Endorsemøn! fiequired) \l-1 \: Vb ru \,,,,,'~.--:.::ç. ,..¿: o Sont To .............,f..!S~~~· ___m D Phillips Petroleum Company I"'- ·Sfài,e.cÃïiC Attn: Steven Arbelovsky ClOp Mgr or PO Box I ' -cÏtÿ'StiJië: P.O. Box 66 ; . .. ,}~enai" AK 99611 tL:t;':Tt,f[Œ!,'.!!~l;I~,,~;1:H:,. ;,.,~.>L .J., Total Postaoe & Feøs . $ "f. 4- ~ · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the maìlpìece, or on the front if space permits. 1, Article Addressed to: 1Il&;¡_S.~ï.~~I' A. ~~e~ved by (~/easel'tt CIC?arly~ 8, ,~)a~of D,eli~ery ,rtHI'2ól--I'10/tp"-d /Cf ø j/ C. ~tu: ) / iIrJ,""" 0 Agent X L)~'l./Lð- /~/k 0 Addressee D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No Phillips Petroleum Company Attn: Steven Arbelovsky, ClOp Mgr P.O. Box 66 Kenai, AK 99611 3. Service Type ~Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) DYes 2. Article Number (Copy from service label) 7002 3150 0005 3521 1263 ---.,----.,---.~.~..-~~--'~-.-_. I __,_.._,___._""""--___ n_'...,...._._ PS Form 3811, July 1999 Domestic Return Receipt 102S9S-00-M-09S2 UNITED STATES I 'JÀTAL SERVICE n Ii t i I' ¡ ~ , ~ j ¡ d H ¡ ) ~.-.:-_._~--- First-Class Mail Postage 8, Fees Paid USPS Permit No. 8-'10 '---- .. Sender: Please print your nallle, address, and ZIP+4 in this box ill AK Oil & Gas Conservation CommissionOCll ?~ '2004 333 W 7TH Ave, Ste 100 Anchorage, AK 99501-3539 'i I ~ \ ì·ì n nit ~ I, i ,\ ~ì,i, ¡, .~ '\ .~ H ¡ II ¡¡ ¡ ! III! ¡: II ¡ ¡ II I! I Ii 11 11 ¡¡ II ¡ 11',11 U 1111 ¡ I ¡ IH \ Ii 1\ , I t\ l"'- t:(} ru r=I ....:¡ ru U1 Iì1 Certified Fee .31 ~ ~ '30 ).1~ U1 CJ o Return Renlept Fee CJ (Endol'sørnent HeqLlìred) o IlL.,id"r, ,.1 D"ii'.,~n, r'L' U1 it:., II.h,' ..... .-1h,'J'I[ t="k'1IJH1, dJ r=I f11 ru CJ o r- ~2:l~Z~1¿~~1;~:<:ij;~:~."~,:"",w,',~...~.;,.,¡,,..~",.1~~~:~~~":::~Jf:~':;~·~~;:I~SL:C~'~::I::J · Complètè items 1, 2. and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: ,,<,~ ¡'~i!f.f~i~"I~\.~fSmjIt]~:::", -rf ·'-'·"~·-"ì:~' , ¡~ ftl1.w.l'.6i~1IIJ&£æ~~¡,>I~~tlä¡~t ~,J3. eceive, d... bY. (PleaSe, Print C/e., arty) ~. Date of .DeliVery !Litre--r? DyZ/J7¿t5" [ 0' ('ê-~ c, S;g~re ¡(}Il /J II, X r'CVWl7 (j/fvlJ1¿t4 o Agent o Addressee D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No Pioneer Natural Resources Company Attn: Scott D. Sheffield, CEO 5205 N.O'Connor Blvd, Suite 1400 Irving, TX 75039-3746 3. Service Type ]&..Certìfied Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D. 4. Restricted Delivery? (Extra Fee) 0 Yes 2. Article Number (Copy from service label) 7002 3150 0005 3521 1287 ,.,...." ~..-.---..-...,,_. ...,-.-.-.,.....-.-- ----.----.- :JS Form 3811, July 1999 Domestic Return Receipt 1 Q2595-QQ-M-0952 ~ Sender: Please p;i'iìk~:SJ:C:)::léìfne address, andR H t'! /~ ) .' \ ,.,1., '., ,,'. . "',First~Class lVIaiL II '!'¡;:1!i;[,:'rp;!('J~~S~~ge&FeeS Paid , ,.r ,.:,,!,. 1?:,r}1ì:t NO; UNln::D STATES P\""JAL S[:I:1, ¡;tr~.~:~\:;;~ ~l o I;¡_w '~ OC1 0 ß 2004, ": [) '''. Con~' Corn/eoission AK Oil & Gas ConselVation Comf11i~Qa 01\ {~I. GaS . ~,: 333 W 7TH Ave, Ste 1 00 f~nchoragt Anchorage, AK 99501-3539 II i I ¡¡ L ¡ ¡ ! I d ! II II H'I \ II!! ¡ L U ¡ Ii II ¡ L ¡ ¡¡ I! i L H! L II I! ¡ ¡ :r- rr ru .-=t ~ i:·;i2!':t!!¡t!:.¡irti\?:'J1l~Iiti't;::J1J)~'9tÊj.~ Ul /TI Postage $ " ~-o ~.ÔO Ul a o Return Reciept Fee o (Endorser11fJnt Required) _______,,,\ ~ 15 o Restricted Delivery Fee Ul (EndorselrH:Jf1t Høquired) M m Total Postage & Fees $ Jf.G,5 Certified Fe~) ru o '·S"i;;ìíT'Fõ----·-- o f"'- UNOCAL -:Sir(9¿it;Xjjt:'N Att . D I H· M 0'1 & G or eo Box N<: n. a eames, gr I , as -'ëh~':-šiãié:ZI P.O. Box 196247 . ' ,',' Anchorage I AK 99519-6247 {~s~i~li{t'I~::~.!D~':¿',¡,~~J ~,Tr~:'::,~i~L~,...l~~~,:~' L:I~;"':~ 'I~IJ~' .~~~·'.W~6~~·.~~~~·:J ~~.~~!Ð:::,Çl~';:Z:1:r:~¡,,'~: ~~J:~~I~ '~:-mJr,:¡i';":'··"':r:' .~..,."'.. · Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. · Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to: 11i>i')(,'~;~~~r~"*~~:~~'~*.i~~i~';~:;(¡;Ù'~i,¡f;;:f~ pt:tW!!~'II""~\I;J~'JH"~~~ijJI¡¡ti~~~\,~:\Y.~mr.."tJ:"!~~IItmr.,"i~ A Received by (Please Print Clearly) 8. Date of Delivery CcÞ'~ ~~~ C. Signature X'~?" ., /Ý,--- ~,~;,(m Ag~'r:1t,., ~ - /~ /,~)Y/"'-d,f;dd1esie.e D. Is delivery address different fro7\it/1? ¡jI~1; 'j'-;;' "- If YES, enter delivery address ~I w: r:ÞN,o 7- \ , '\ T; I ,', ?!7tll J ~:/ ..'-.' /,¡ .. 'r, '-- /() // . v:-~ 1;/ - -...---- UNOCAL Attn: Dale Haines, Mgr Oil & Gas P.O. Box 196247 Anchorage, AK 99519-6247 3. Service Type 'àCertified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C.O.D, 4, Restricted Delivery? (Extra Fee) DYes 2, Article Number (Copy from service label) 7002 3150 0005 3521 1294 . __ ___....·_..._._..___._ø_,,,.._.... ',"._..~,,_..,._.h"_ PS Form 3811 , July 1999 Domestic Return Receipt 102595-0Q-M-0952 S P ) SI::RVlçc ""'''''''''''<'''''. UNITED TATES O~ IAL .::) ,,'''"'-''/\,,'' .r:"""...., ,'~.;,'.'<:::',«'~.. I'~' '., "'. ,', ¡¡. J. ",'. " "\ I II " I ;1' . k ¡ ¡ r .~;..r .~I ....'::.!. '') Fìrst-Class Mail , PÇlstage&.,..FeesPaid 'USPS, ."':" 'Permit,No. G~10 ~:I Y.. _{,~·I.; ; , " ~ -, j \ I ,,/ "..,-..."....".,."....".."".._. ~" .' ,', ~ ''':' '''', "". .... ,I <II sel)"ø,.:~~Please pr'ìf~~~[,Tlame, address, and ZIJ?±4ìn'¡fhis': bøx ,..._,; J ~~~ -~~ ~~ ',~~ .:.~~{j.' ,!""" (\~'\.J ,,~~\" ~II~ ~ ~),~ "" ~~~ .,' ~ "\.~ ~1-;)' J !\K Oil & Gas Conservation Commission ~<z... .. ,¡-¿,,-;¡'1<~~~~333 W 7TH Ave, Ste 100 ~~~:;.\\~~~~~~'\ Anchorage, AK 99501-3539 ~'k~" ,/ ' ~~;~~,?' '1~ ,,' r::!~:È;Eø i i ·~t':2t~·3:2 JI ¡ ¡ ! L L ¡ ¡ ¡ ¡ I ¡! ¡ ¡ Î L ¡¡ n ¡¡ ¡! Ii II f: 1 ¡ L ¡¡ ¡ Ll L i! í ¡¡ t ¡ i j ¡ L it CJ CJ ITI H .-=t ru Ul ITI Postage $ .ôl _~,~O \ ...,~ Ul CJ CJ Røturn Rí~ciept Fee o (EncJorsernent Hequired) ~~~~A. .~~Sc9æ , ((J Her('J_\~~ " (/:2 ~~ ~ u..l \'I~ ^ V) {:i.~.'Þ Q. TbtalPostaoe&Føes $ Lf..f'..t,,,,,\ \\!" ,0, ""T. 7d'"""t '\. ':" 0 "',-_/'1.) '/ / ~ "šëï1tYõ-"-' ~'YQ,N~_,,/"':"_--"! CJ XTO Energy Inc. ["- "s¡':;Ù5CA):;n Attn' William A. Miller District Adm Mgr or 1-'0 Box f\' 1 --éÏtÿ:-štâ¡è:~ 52260 Shell Road .... . Kenai, AK 99611-9704 " ", '" !¡-~i~~iii"~Œ~i,tLlli!t.à.::Et:~:"";'",L..:".;.o:",c.'J;'"'-':"'~ ,"-.,:i..,~.;".~"'L~.t~J~C~2.ZI:1r:;, \'J:~~U!l'rJJ Certified Fee o Restrictetj Delivery Fee U1 (Endorsement Required) ,..::¡ m DJ·'·..' "". "I ". ", " " ., J~? I _'~m~~:I~îiP'j~1(~d;~~\~~~ ,\ '\'~,,~. , . .~ I'~ n~~~~f~~~~~!1'.~~~~-'l . A. Re~e\ved by (Please Print Clearly) B. , Date of Delivery '\\.. \(\\ ~\\-{-{ \O-~- fJJ-1 C. ~ign ure ~ . .. ~ Agent X ' " Addressee D. Is delivery address different from item 1? 0 Yes If YES, enter delivery address below: 0 No II Complete items 1 2, and 3. Also complete item 4 if Restricted Delivery is desired. ,\11 Print your name and address on the reverse so that we can return the card to you. · Attach this card to the back of the mail piece, or on the front if space permits. 1. Article Addressed to: XTO Energy Inc. Attn: William A. Miller, District Adm Mgr 52260 Shell Road Kenai, AK 99611-9704 3. Service Type o Certified Mail o Registered o Insured Mail o Express Mail o Return Receipt for Merchandise o C,O.D, 4, Restricted Delivery? (Extra Fee) 0 Yes 2, Article Number (Copy from service label) 7002 3150 0005 3521 1300 .. . -"-"---'-~'-~"'~'~- ..... '-"'-~'----'-~--'~-' -..-." ." -.".-. '.... - . ~_.,~""--..-.-_---"_.....__..._._--...,,.-.-,-_...""'-- PS Form 3811, July 1999 Domestic Return Receipt 102595-00·M-0952 ~ U; ~~ r-E' ~ \ ß ; ¡ l) L uì. L IJ , ) rTl ~ ~\ n ¡ßI Cf¡'< ® £ ~ Ln~ Ls Lnh~ llru ) AT,A.~KA. OIL AND GAS CONSERVATION COMMISSION / ! / I I l i I / ( I FRANK H. MURKOWSK/. GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 NOTICE OF PROPOSED REGULATORY COST CHARGES FOR FISCAL YEAR 2005 Pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission proposes to impose Fiscal Year 2005 regulatory cost charges as set out below: Operator Proposed ReQulatorv Cost CharQe Aurora Gas LLC BP Exploration (Alaska) Inc. ConocoPhillips Inc. Evergreen Resources Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Company Pioneer Natural Resources Company UNOCAL XTO Energy, Inc. $280.64 $2,673,094.53 $597,854.76 $106.32 $5,215.57 $10,978.66 $311.55 $6,770.58 $5.05 $73,153.80 $5,322.25 These proposed regulatory cost charges have been calculated using the formula set out in 20 AAC 25.605(a) and using the following values in that formula: v OP for Aurora Gas LLC = 212,703 Bbl VOP for BP Exploration (Alaska) Inc. = 2,026,047,299 Bbl VOP for ConocoPhillips Inc. = 453, 138,498 Bbl VOP for Evergreen Resources Inc. = 80,590 Bbl V OP for Forest Oil Corporation = 3,953,095 Bbl V OP for Marathon Oil Company = 8,321,168 Bbl V OP for North Slope Borough = 236,135 Bbl V OP for Phillips Petroleum Company = 5,131,700 Bbl V OP for Pioneer Natural Resources Company = 3,828 Bbl VOP for UNOCAL = 55,446,246 Bbl VOP for XTO Energy, Inc. = 4,033,953 Bbl VTOT = Bbl A = $4,270,300.00 F = $20,000.00 L = $877,206.29 '\ , .1 ) The attached spreadsheets provide more detail on the production and injection volumes that determine each operator's V OP and on the calculation of the proposed regulatory cost charges. If you are listed above as an operator subject to a proposed regulatory cost charge, you may submit comments on, or request a revision to, the proposed regulatory cost charges by writing the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501-3539. Any comments or requests must be received within 30 days from the date of this notice as shown below. A request for a revision to the regulatory cost charges must be accompanied by an explanation of the basis for the requested revision. A public hearing on the proposed regulatory cost charges will be held in accordance with 20 AAC 25.540 on November 16, 2004, at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission, 333 West ¡th Avenue, Suite 100, Anchorage, Alaska. This notice is not an invoice. After the public hearing, the Commission will issue an order determining actual regulatory cost charges and will notify each operator subject to a regulatory cost charge of the amount of the person's act~ "egulatory cost charge and the payment dates. Operators will be credited for any estimat~ r~ulatory cost charges for the first quarter of fiscal year 2005 that have already be al Date: October 6,2004 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.7J Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost AURORA GAS LLC LONE CREEK, UNDEFINED GAS 0 1,011,382 168,563.67 168,564 $222.40 Field/Pool Quantities and Allocated Costs Totals: 0 1,011,382 168,564 168,564 $222.40 lttfOQUAWKIE, UNDEFINED GAS 0 3,140 523,33 523 $0,69 FieldIPool Quantities and Allocated Costs Totals: 0 3,140 523 523 $0.69 NICOLAI CREEK, UNDEFINED GAS 0 261,696 43,616.00 43,616 $57,55 FieldIPool Quantities and Allocated Costs Totals: 0 261,696 43,616 43,616 $57.55 Summaryfor AUROR4 GAS LLC (3 recordsj $280.6' Operator Quantities and Allocated Costs Totals: 0 1,276,218 212,703 212,703 - / - Monday, September 27,20 2:16 PM Page I of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC Monday, September 27,20 2:17PM BADA_MI, BADAlvfl OIL 281,552 7,061,053 1,176,842,17 1,458,394 $1,924.15 FieldIPool Quantities and Allocated Costs Totals: 281,552 7,061,053 1,176,842 1,458,394 $1,924.15 BADAMI, UNDEFINED WDSP 52,942 0 0.00 52,942 $69,85 Field/Pool Quantities and Allocated Costs Totals: 52,942 0 0 52,942 $69.85 ENDICOTF, EIDER OIL 1,628,222 2,813,008 468,834.67 2,097.057 $2,766.78 Field/Pool Quantities and Allocated Costs Totals: 1,628,222 2,813,008 468,835 2,097,057 $2,766.78 ENDICOTT, ENDICOTT OIL 91,382,026 271,013,187 45,168,864,50 136,550,891 $180,160.37 FieldIPool Quantities and Allocated Costs Totals: 91,382,026 271,013,187 45,168,865 136,550,891 $180,160.37 ENDICOTT, IVISHAK OIL 3,448,398 64,026 10,671.00 3,459,069 $4,563,77 FieldIPool Quantities and Allocated Costs Totals: 3,448,398 64,026 10,671 3,459,069 $4,563.77 ENDICOTT, UNDEFINED WDSP 325 0 0.00 325 $0.43 Field/Pool Quantities and Allocated Costs Totals: 325 0 0 325 $0.43 AlILNE POINT. KUP ARUK RIVER OIL 33,780,536 13,094,485 2,182,414,17 35,962,950 $47,448,23 Field/Pool Quantities and Allocated Costs Totals: 33,780,536 13,094,485 2,182,414 35,962,950 $47,448.23 AfILNE POINT. SAG RIVER OIL 437,237 300,206 50,034,33 487,271 $642,89 FieldIPool Quantities and Allocated Costs Totals: 437,237 300,206 50,034 487,271 $642.89 AlILNE POINT, SCHRADER BLFF OIL 17,445,698 6,095,224 1,015,870,67 18,461,569 $24,357,54 Field/Pool Quantities and Allocated Costs Totals: 17,445,698 6,095,224 1,015,871 18,461,569 $24,357.54 lvIILNE POINT, TERTI UNDEF WTRSP 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 Page 2 of 20 ,~~~ .T ........-.. .... 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC ÞfILNE POINT, UGNU UNDEF WTRSP 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 MILNE POINT, UGNU UNDEFINE OIL 2,212 242 40.33 2,252 $2.97 Field/Pool Quantities and Allocated Costs Totals: 2,212 242 40 2,252 $2.97 NORTHSTAR, NORTHSTAR OIL 22,968,022 172,129,811 28,688,301.83 51,656,324 568,153.51 Field/Pool Quantities and Allocated Costs Totals: 22,968,022 172,129,811 28,688,302 51,656,324 $68,153.51 NORTHSTAR, UlvDEFINED WDSP - 1,193,004 0 0,00 1,193,004 51,574.01 Field/Pool Quantities and Allocated Costs Totals: 1,193,004 0 0 1,193,004 $1,574.01 PRUDHOE BAY, AUROR4 OIL 11,067,219 12,327,473 2,054,578,83 13,121,798 $17,312.43 Field/Pool Quantities and Allocated Costs Totals: 11,067,219 12,327,473 2,054,579 13,121,798 $17,312.43 PRUDHOE BAY, BOREALIS OIL 28,047,971 9,465,803 1,577,633.83 29,625,605 $39,086,97 Field/Pool Quantities and Allocated Costs Totals: 28,047,971 9,465,803 1,577,634 29,625,605 $39,086.97 PRUDHOE BAY, LIS lJNDEFINE WDSP 30,084,377 0 0,00 30,084,377 $39,692.25 Field/Pool Quantities and Allocated Costs Totals: 30,084,377 0 0 30,084,377 $39,692.25 PRUDHOE BAY, LISBURNE OIL 3,335,277 118,913,584 19,818,930,67 23,154,208 $30,548,84 Field/Pool Quantities and Allocated Costs Totals: 3,335,277 118,913,584 19,818,931 23,154,208 $30,548.84 PRUDHOE BAY, MIDNIGHT SUN OIL 7,428,728 3,499,585 583,264,17 8,011,992 $10,570,74 Field/Pool Quantities and Allocated Costs Totals: 7,428,728 3,499,585 583,264 8,011,992 $10,570.74 PRUDHOE BAY, N PRUDHOE BAY OIL 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 Monday, September 27,20 2:17 Pil..! Page 3 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost BP EXPLORATION (ALASKA) INC PRUDHOE BAY, NIAKUK OIL 21,869,075 3,385,803 564,300.50 22,433,376 529,597.80 Fie/d/Poo/ Quantities and Allocated Costs Totals: 21,869,075 3,385,803 564,301 22,433,376 $29,597.80 PRUDHOE BAY, ORION SCHR BL OIL 368,058 311,963 51,993.83 420,052 $554,20 Fie/d/Poo/ Quantities and Allocated Costs Totals: 368,058 311,963 51,994 420,052 $554.20 PRUDHOEBAY, POLARIS OIL 1,580,518 999,965 166,660.83 1,747,179 52,305,17 Fie/d/Poo/ Quantities and Allocated Costs Totals: 1,580,518 999,965 166,661 1,747,179 $2,305.17 PRUDHOE BAY, PRUD UNDEFIN WDSP -.. 35,836,267 0 0,00 35,836,267 $47,281.09 Fie/d/Poo/ Quantities and Allocated Costs Totals: 35,836,267 0 ° 35,836,267 $47,281.09 PRUDHOE BAY, PRUDHOE OIL 618,243,750 5,458,092,755 909,682,125.83 1,527,925,876 $2,015,890.89 Fie/d/Poo/ Quantities and Allocated Costs Totals: 618,243,750 5,458,092,755 909,682,126 1,527,925,876 $2,015,890.89 PRUDHOE BAY, PT lvlCINTYRE OIL 61,351,973 116,139,973 19,356,662,17 80,708,635 $106,484,09 Field/Poo/ Quantities and Allocated Costs Totals: 61,351,973 116,139,973 19,356,662 80,708,635 $106,484.09 PRUDHOE BAY, W BCH TR UN WTRSP 0 0 0,00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 ° 0 ° $0.00 PRUDHOE BAY, W BEACH OIL 1,562,312 201,454 33,575.67 1,595,888 $2,105,56 Field/Poo/ Quantities and Allocated Costs Totals: 1,562,312 201,454 33,576 1,595,888 $2,105.56 SummGiy/Ùr BP EXPLORATION (,iLASKAj liVC (28 records) S2,673,094.5r Operator Quantities and Allocated Costs Totals: 993,395,699 6,195,909,600 1,032,651,600 2,026,047,299 .r- Monday, September 27, 20 2: 17 P.~l Page 4 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation o/Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPHILLIPS ALASKA INC BELUGA RIVER. UNDEFINED GAS 0 56,252,066 9,375,344.33 9,375,344 $12,369.49 Field/Pool Quantities and Allocated Costs Totals: 0 56,252,066 9,375,344 9,375,344 $12,369.49 BELUGA RIVER, UNDEFINED WDSP 14,165 0 0.00 14,165 $18,69 FieldIPool Quantities and Allocated Costs Totals: 14,165 0 0 14,165 $18.69 COLVILLE RIVER, ALPINE OIL 69,863,024 77,908,422 12,984,737.00 82,847,761 $109,306,38 Field/Pool Quantities and Allocated Costs Totals: 69,863,024 77,908,422 12,984,737 82,847,761 $109,306.38 COLVILLE RIVER, NANUQ UNDF OIL c- O 0 0,00 0 $0,00 FieldIPool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 COLVILLE RIVER. lJNDEFINED WDSP 407,691 0 0,00 407,691 $537,89 FieldIPool Quantities and Allocated Costs Totals: 407,691 0 0 407,691 $537.89 KUP ARUK RIVER. CRETACEO U WDSP 552,674 0 0.00 552,674 $729,18 FieldIPool Quantities and Allocated Costs Totals: 552,674 0 0 552,674 $729.18 KUP ARUK RIVER. KUP ARUK RV OIL 267,392,115 193,782,278 32,297,046.33 299,689,161 $395,399,19 Field/Pool Quantities and Allocated Costs Totals: 267,392,115 193,782,278 32,297,046 299,689,161 $395,399.19 KUPARUK RIVER, AfELTWATER OIL 3.863,821 11,158,165 1,859,694,17 5,723,515 $7,551.40 Field/Pool Quantities and Allocated Costs Totals: 3,863,821 11,158,165 1,859,694 5,723,515 $7,551.40 KUP ARUK RIVER, TABASCO OIL 7,098,455 187,962 31,327.00 7,129,782 $9,406,78 Field/Pool Quantities and Allocated Costs Totals: 7,098,455 187,962 31,327 7,129,782 $9,406.78 KUPARUK RIVER, TAR1V OIL 30,149,697 31,270,554 5,211,759.00 35,361,456 $46,654,64 Field/Pool Quantities and Allocated Costs Totals: 30,149,697 31,270,554 5,211,759 35,361,456 $46,654.64 Monday, September 27,20 2:17PM Page 5 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation 0.( Regulatory Cost Charge For FY 2005 $3,373,093.7] Finalized Budget OperatorName Field/Pool Name Gross Liquid (SIb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost CONOCOPIDLLIPS ALASKA INC KUPARUK RIVER, WEST SAK OIL Field/Pool Quantities and Allocated Costs Totals: NORTH COOK INLET, TERnARY GAS 9,015,969 9,015,969 Field/Pool Quantities and Allocated Costs Totals: NORTH COOK INLET,UNDEF WDSP Field/Pool Quantities and Allocated Costs Totals: Summary/or CONOCOPHfLLlPS AL4SKA fiVC (13 records) ,-, Operator Quantities and Allocated Costs Totals: 388,357,611 ,- Monday, September 27,20 2:17 Pi"'! o o 979,441 163,240.17 979,441 163,240 17,146,434 2,857,739.00 17,146,434 2,857,739 ° 0,00 0 0 388,685,322 64,780,887 9,179,209 $12,110.72 9,179,209 S12,110.72 2,857,739 $3,770,40 2,857,739 $3,770.40 0 $0,00 0 so. 00 453,138,498 $597,854.7; o o Page 6 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost EVERGREEN RESOURCES (ALAS PIONEER, TYONEK UNDEFINED GAS FieldIPool Quantities and Allocated Costs Totals: PIONEER, UNDEFINED WDSP FieldIPool Quantities and Allocated Costs Totals: Summal)'jàr EVERGREEN RESOURCES (.4L4SKAj CORPORATION í2 /'ecordsj Operator Quantities and Allocated Costs Totals: /--- /-- Monday, September 27,20 2:17 Pl'rJ 0 2,156 359,33 359 $0.47 0 2,156 359 359 SO.47 80,231 0 0,00 80,231 $105.85 80,231 0 0 80,231 $105.85 ~ 80,231 2,156 359 80,590 $106.¥ Page 7 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost FOREST OIL CORP SummwJ')()r FOREST OIL CORP (7 records) KUSTATAll/, UNDEFINED WDSP 411,769 0 0.00 411 ,769 $543.27 FieldIPool Quantities and Allocated Costs Totals: 411,769 0 0 411,769 $543.27 REDOUBT SHOAL, UNDEFINED GAS 0 461,344 76,890.67 76,891 $101.45 FieldIPool Quantities and Allocated Costs Totals: 0 461,344 76,891 76,891 $101.45 REDOUBT SHOAL. UNDEFINED OIL 910,694 211,827 35,304,50 945,999 51,248.12 FieldIPool Quantities and Allocated Costs Totals: 910,694 211,827 35,305 945,999 $1,248.12 REDOUBT SHOAL. UNDEFINED WDSP 331,185 0 0.00 331,185 $436.95 FieldIPool Quantities and Allocated Costs Totals: 331,185 0 0 331,185 $436.95 W FORELAND, UNDEFINED GAS 0 940,110 156,685,00 156,685 $206,72 Field/Pool Quantities and Allocated Costs Totals: 0 940,110 156,685 156,685 $206.72 W 1VICARTH RIV lJJo.lDEFINED WDSP 1,148,112 0 0,00 1,148,112 $1,514,78 FieldIPool Quantities and Allocated Costs Totals: 1,148,112 0 0 1,148,112 $1,514.78 W lvlCARTH RIV, W A1CARTH RIV OIL 849,195 199,559 33,259.83 882.455 51,164,28 FieldIPool Quantities and Allocated Costs Totals: 849,195 199,559 33,260 882,455 $1,164.28 Operator Quantities and Allocated Costs Totals: 3,650,955 1,812,840 302,140 3,953,095 $5,215.57 /- .-. Monday, September 27,20 2:17PM Page 8 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARATHON OIL CO BEA VER CREEK, BEA VER CREEK OIL 76,134 23,040 3,840.00 79,974 $105.51 Field/Pool Quantities and Allocated Costs Totals: 76,134 23,040 3,840 79,974 $105.51 BEA VER CREEK, BELUGA GAS 0 7,639,494 1,273,249.00 1,273,249 $1,679.88 FieldIPool Quantities and Allocated Costs Totals: 0 7,639,494 1,273,249 1,273,249 $1,679.88 BEA VER CREEK, STERLING GAS 0 104,140 17,356,67 17,357 $22,90 FieldIPool Quantities and Allocated Costs Totals: 0 104,140 17,357 17,357 $22.90 BEA VER CREEK, nrONEK UNDEF GAS ,--- 0 124,677 20,779,50 20,780 $27.42 FieldIPool Quantities and Allocated Costs Totals: 0 124,677 20,780 20,780 $27.42 BEA VER CREEK, lJNDEFINED WDSP 39,405 0 0.00 39,405 $51.99 Field/Pool Quantities and Allocated Costs Totals: 39,405 0 0 39,405 $51.99 FALLS CREEK, nrONEK UNDEF GAS 0 1,088,595 181,432.50 181,433 $239.38 FieldIPool Quantities and Allocated Costs Totals: 0 1,088,595 181,433 181,433 $239.38 G OSKOLKOFF, TYONEK UNDEF GAS ° 1,760,238 293,373.00 293.373 $387.07 Field/Pool Quantities and Allocated Costs Totals: 0 1,760,238 293,373 293,373 $387.07 KENAI, C.L. U. BELUGA GAS 0 1,116,673 186,112,17 186,112 $245.55 FieldIPool Quantities and Allocated Costs Totals: 0 1,116,673 186,112 186,112 $245.55 KENAI, c.L. U. STERLING UND GAS 0 3,461,733 576,955,50 576,956 $761,21 Field/Pool Quantities and Allocated Costs Totals: 0 3,461,733 576,956 576,956 $761.21 ~~ KENAI, c.L.u. UPPER TYONEKGAS 0 1,564,964 260,827,33 260,827 $344,13 Field/Pool Quantities and Allocated Costs Totals: 0 1,564,964 260,827 260,827 $344.13 Monday, September 27,20 2:17 P,+l Page 9 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARATHON OIL CO KENAI, STERLING 3 GAS ° 1,668,534 278,089.00 278,089 $366.90 FieldIPool Quantities and Allocated Costs Totals: 0 1,668,534 278,089 278,089 S366.90 KENAI, STERLING 4 GAS ° 2,911,391 485,231.83 485,232 $640,20 Field/Pool Quantities and Allocated Costs Totals: 0 2,911,391 485,232 485,232 S640.20 KENAI, STERLING 5.1 GAS 0 0 0,00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 SO. 00 KENAI, STERLING 6 GAS /-., 0 11,539,229 1,923,204.83 1,923,205 $2,537.41 FieldIPool Quantities and Allocated Costs Totals: 0 11,539,229 1,923,205 1,923,205 S2,537.41 KENAI, TYONEK GAS 0 1,340,364 223,394.00 223,394 $294,74 FieldIPool Quantities and Allocated Costs Totals: 0 1,340,364 223,394 223,394 S294.74 KENAI, UNDEFINED WDSP 175,315 0 0.00 175,315 $231.30 FieldIPool Quantities and Allocated Costs Totals: 175,315 0 0 175,315 S231.30 KENAI, UNDEFINED WDSP G&J 282,309 0 0.00 282,309 $372.47 Field/Pool Quantities and Allocated Costs Totals: 282,309 0 0 282,309 S372.47 KENAI, UPPER TYONEK BELUGA GAS 0 11,126,101 1,854,350.17 1,854,350 52,446.56 Field/Pool Quantities and Allocated Costs Totals: 0 11,126,101 1,854,350 1,854,350 S2,446.56 S DIONNE, TYONEK UNDEF GAS 0 195,575 32,595,83 32,596 $43,01 FieldIPool Quantities and Allocated Costs Totals: 0 195,575 32,596 32,596 S43.01 STERLING, BELUGA UNDEFINED GAS 0 109,674 18,279.00 18,279 $24.12 Field/Pool Quantities and Allocated Costs Totals: 0 109,674 18,279 18,279 S24.12 Monda)', September 27,20 2:17PM Page 10 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost MARATHON OIL CO STERLING, TYONEK [JNDEFINED GAS 0 6,505 1,084.17 1,084 $1.43 FieldIPool Quantities and Allocated Costs Totals: 0 6,505 1,084 1,084 $1.43 STERLING, UNDEFINED GAS 0 241,846 40,307.67 40,308 $53,18 FieldIPool Quantities and Allocated Costs Totals: 0 241,846 40,308 40,308 $53.18 TRADING BA Y, G-NE/HEMLK-NE OIL 0 0 0.00 0 $0,00 FieldIPool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAJr, HEi'vlLOCK OIL <"-~~ 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY, MID KENAI DOlL 0 0 0.00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BAY, j\1ID KENAI E OIL 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 TRADING BA Y, UNDEFINED GAS 0 100,598 16,766.33 16,766 $22.12 FieldIPool Quantities and Allocated Costs Totals: 0 100,598 16,766 16,766 $22.12 TRADINGBAJr, UNDEFINED WDSP 20,696 0 0,00 20,696 $27.31 FieldIPool Quantities and Allocated Costs Totals: 20,696 0 0 20,696 $27.31 TRADING BAY, W FORELAND OIL 0 0 0,00 0 $0.00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 ,.- WOLF LAKE, BEL-TYON UNDEF GAS 0 240,480 40,080.00 40,080 $52,88 Field/Pool Quantities and Alloctited Costs Totals: 0 240,480 40,080 40,080 $52.88 Monday, September 27,20 2:17 Plyl Page 1/ of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName MARATHON OIL CO FieltVPool Name Gross Liquid (Sib) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost Summaryfor MAR4THON OIL CO (30 records) Operator Quantities and Allocated Costs Totals: 593,859 46,363,851 7,727,309 8,321.168 $10,978.6; /.- ~ Monday, September 27,20 2:17PM Page 12 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.7] Finalized Budget OperatorName FieldIPoo/ Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost NORTH SLOPE BOROUGH BARROW, EAST BARROW GAS 0 92,659 15,443.17 15,443 $20,38 Field/Pool Quantities and Allocated Costs Totals: 0 92,659 15,443 15,443 $20.38 BARROW, SOUTH BARROW GAS 0 88,671 14,778,50 14,779 $19,50 Field/Pool Quantities and Allocated Costs Totals: 0 88,671 14,779 14,779 $19.50 W ALAKP A, WALAKPA GAS 0 1,235,479 205,913,17 205,913 $271,67 Field/Pool Quantities and Allocated Costs Totals: 0 1,235,479 205,913 205,913 $271.67 Summary/or NORTH SLOPE BOROUGH (3 recordsi Operator Quantities and Allocated Costs Totals: 0 1,416,8{}9 236,135 236,135 $311.55 /- Monday, September 27, 20 2:17PM Page 13 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PHILLIPS PETROLEUM CO NORTH COOK LlI/LET, TERTIARY GAS 0 30,773,377 5,128,896,17 5,128,896 $6.766.88 Field/Pool Quantities and Allocated Costs Totals: 0 30,773,377 5,128,896 5,128,896 $6,766.88 NORTH COOK INLET, UNDEF WDSP 2,804 0 0,00 2,804 $3,70 Field/Pool Quantities and Allocated Costs Totals: 2,804 0 0 2,804 $3.70 Summaryjòr PHILLIPS PETROLEUJJ CO f2 I'ecorásj Operator Quantities and Allocated Costs Totals: 2,804 30,773,377 5,128,896 5,131,700 $6,770.58 ~ /r::-~. Monday, September 27,20 2:17PM Page 14 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName Field/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost PIONEER NATURAL RESOURCES OOOGURUK, UNDEFllvED OIL Fie/d/Poo/ Quantities and Allocated Costs Totals: Summaryfor PIONEER NATUR4L RESOURCES USA, JiVe (1 detail record) Operator Quantities and Allocated Costs Totals: 3,828 0 0.00 3,828 $5.05 3,828 0 0 3,828 $5.05 3,828 0 0 3,828 $5.05 ,..-~-, ,-"""~. Monday, September 27,20 2:17PM Page J5 0/20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Totai Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA GRAllfITE PT, HE".1LOCK UNDEF OIL 41,217 54,336 9,056.00 50,273 $66.33 Field/Pool Quantities and Allocated Costs Totals: 41,217 54,336 9,056 50,273 $66.33 GRANITE PI. lì1lDDLE KENAI OIL 2.494,887 1,232.872 205,478.67 2,700,366 $3,562.77 Field/Pool Quantities and Allocated Costs Totals: 2,494,887 1,232,872 205,479 2,700,366 $3,562.77 GR4NITE PT, UNDEFINED GAS 0 91,232 15,205,33 15,205 $20,06 Field/Pool Quantities and Allocated Costs Totals: 0 91,232 15,205 15,205 $20.06 GRANITE PT, UNDEFINED WDSP G&I -- 58,262 0 0.00 58,262 $76.87 Field/Pool Quantities and Allocated Costs Totals: 58,262 0 0 58,262 $76.87 IV AN RIVER, UNDEFINED GAS 0 2,470,717 411,786,17 411,786 $543,30 Field/Pool Quantities and Allocated Costs Totals: 0 2,470,717 411,786 411,786 $543.30 IVAN RIVER, úWDEFLlIfED WDSP 0 0 0.00 0 $0,00 Field/Pool Quantities and Allocated Costs Totals: 0 0 0 0 $0.00 LEWIS RIVER, UNDEFINED GAS 0 575,122 95,853.67 95,854 $126.47 Field/Pool Quantities and Allocated Costs Totals: 0 575,122 95,854 95,854 $126.47 LEWIS RIVER, UNDEFINED WDSP 993 0 0.00 993 $1.31 Field/Pool Quantities and Allocated Costs Totals: 993 0 0 993 $1.31 ~MCARTHUR RIVER. HEJvlLOCK OIL 28,488,869 1.415,741 235,956,83 28,724,826 $37,898,51 Field/Pool Quantities and Allocated Costs Totals: 28,488,869 1,415,741 235,957 28,724,826 $37,898.51 .-- lvlCARTHUR RIVER, MIDKENAI GaIL 7,765,201 616,628 102,771.33 7,867,972 $10,380.72 Field/Pool Quantities and Allocated Costs Totals: 7,765,201 616,628 102,771 7,867,972 $10,380.72 Monday, September 27,20 2:17PM Page 16 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName Fie/d/Pool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA iVICARTHUR RIVER, A1IDKENAI GAS 0 37,133,934 6,188,989,00 6,188,989 $8,165,53 FieldIPool Quantities and Allocated Costs Totals: 0 37,133,934 6,188,989 6,188,989 $8,165.53 lvfCARTHUR RIVER, l1NDEFINED OIL 0 0 0,00 0 $0,00 FieldIPool Quantities and Allocated Costs Totals: 0 0 0 0 SO. 00 MCARTHUR RiVER, W FORELAND OIL 1,165,188 49,252 8,208.67 1,173,397 $1,548,14 Field/Pool Quantities and Allocated Costs Totals: 1,165,188 49,252 8,209 1,173,397 S1,548.14 MIDDLE GROUND SHOAL, A OIL /...... 24,178 27,915 4,652,50 28,831 $38,04 FieldIPool Quantities and Allocated Costs Totals: 24,178 27,915 4,653 28,831 S38.04 Jv[JDDLE GROUND SHOAL, B,C,D OIL 4,373 18,731 3,121,83 7.495 $9,89 Field/Pool Quantities and Allocated Costs Totals: 4,373 18,731 3,122 7,495 $9.89 l\llDDLE GROUND SHOAL, E,F, G OIL 83,898 26,315 4,385,83 88,284 $116.48 Field/Pool Quantities and Allocated Costs Totals: 83,898 26,315 4,386 88,284 $116.48 .MIDDLE GROUND SHOAL, UNDEF GAS 0 145,444 24,240.67 24,241 $31,98 Field/Pool Quantities and Allocated Costs Totals: 0 145,444 24,241 24,241 S31.98 PRE17Y CREEK, UNDEFINED GAS 0 427,900 71,316,67 71,317 $94,09 Field/Pool Quantities and Allocated Costs Totals: 0 427,900 71,317 71,317 $94.09 STUll-·f]> LAKE, UNDEFINED GAS 0 277 46,17 46 $0,06 FieldIPool Quantities and Allocated Costs Totals: 0 277 46 46 $0.06 /'- SW AlvSON RIVER, GAS STORAGE 0 1.466,572 244,428.67 244,429 $322.49 Field/Pool Quantities and Allocated Costs Totals: 0 1,466,572 244,429 244,429 $322.49 Monday, September 27,20 2:17 PM Page J 7 of 20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas BOE Total Volume (Liq+BOE) Allocated Cost UNION OIL CO OF CALIFORNIA SWANSON RIVER, HEivILOCK OIL 425,555 7,147,763 1,191,293.83 1,616,849 $2,133.21 Field/Pool Quantities and Allocated Costs Totals: 425,555 7,147,763 1,191,294 1,616,849 $2,133.21 SWANSON RIVER. UNDEFINED GAS 0 1,844,556 307,426,00 307,426 $405.61 Field/Pool Quantities and Allocated Costs Totals: 0 1,844,556 307,426 307,426 $405.61 SWANSON RIVER. UNDEFINED WDSP 2,720,342 ° 0,00 2,720,342 $3,589,12 Field/Pool Quantities and Allocated Costs Totals: 2,720,342 0 0 2,720,342 $3,589.12 TR4DING BAJ" HEÎVlLOCK OIL - 1,212,724 127,641 21,273.50 1 ,233,998 $1,628,09 Field/Pool Quantities and Allocated Costs Totals: 1,212,724 127,641 21,274 1,233,998 $1,628.09 TRADING BAY, MID KENAI BOIL 57,484 19,031 3,171.83 60,656 $80,03 Field/Pool Quantities and Allocated Costs Totals: 57,484 19,031 3,172 60,656 $80.03 TRADING BAY, MID KENAI COIL 793,630 51,309 8,551.50 802,182 $1,058,37 Field/Pool Quantities and Allocated Costs Totals: 793,630 51,309 8,552 802,182 $1,058.37 TRADING BA Y, }ýfID KENAI DOlL 854,447 42,672 7,112,00 861,559 $1.136,71 Field/Pool Quantities and Allocated Costs Totals: 854,447 42,672 7,112 861,559 $1,136.71 TR4DING BA Y, lvfID KENAI E OIL 72,407 18,022 3,003.67 75,411 $99.49 Field/Pool Quantities and Allocated Costs Totals: 72,407 18,022 3,004 75,411 $99.49 TR4DING BAY, [INDEFINED OIL 14,613 3,887 647,83 15,261 $20,13 Field/Pool Quantities and Allocated Costs Totals: 14,613 3,887 648 15,261 $20.13 ~1immaryfor UNION OIL CO OF CALiFORNIA (29 recordsj Operator Quantities and Allocated Costs Totals: 46,278,268 55,007,869 9,167,978 55,446,246 $73,153.80 Monday, September 27, 20 2:17 PM Page 18 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName FieldIPool Name Gross Liquid (Stb) Gross Gas (Mscf) Gas ROE Total Volume (Liq+BOE) Allocated Cost XTO ENERGY INC l"'JIDDLE GROUND SHOAL, B,C,D OIL 5,636 3,154 525,67 6,162 $8,13 Field/Pool Quantities and Allocated Costs Totals: 5,636 3,154 526 6,162 $8.13 A-flDDLE GROuND SHOAL, E,F,G OIL 3.939,469 431,019 71.836.50 4.011,306 $5,292.37 Field/Pool Quantities and Allocated Costs Totals: 3,939,469 431,019 71,837 4,011,306 $5,292.37 MIDDLE GROUND SHOAL, UNDF WDSP 16,486 0 0,00 16,486 $21,75 Field/Pool Quantities andAllocated Costs Totals: 16,486 0 0 16,486 $21.75 Summary for XTO ENERGY ¡XC (3 recordsj /-~ Operator Quantities and Allocated Costs Totals: 3,961,591 434,173 72,362 4,033,953 $5,322.25 ~. Monday, September 27,20 2:17 PlI'J Page 19 of20 2004 Annual Production/Injection/Disposal Volumes For Allocation of Regulatory Cost Charge For FY 2005 $3,373,093.71 Finalized Budget OperatorName Field/Pool Name Report Qualltities and Allocated Costs Totals: -- ~. Monday, September 27,20 2:17PM Gross Liquid (Stb) Gross Gas (lJlscf) Gas ROE Total Volume (Liq+BOE) Allocated Cost 1,436,324,846 ¡ 2,556,605,215/ r $3,373,093.71 ¡ 6,721,682,21511 1,120,280,369/ i Page 20 of 20 ) FY 05 Regulatory Cost Charges Estimate FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Estimated 2004 Lapse $ Total to use for Reg Cost Chgs $ Final FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Actual 2004 Lapse $ Total to use for Reg Cost Chgs $ ') ) 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000 830,000 3,420,300 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000.00 877,206.29 3,373,093.71 ) ') FYvs PROCESSED CC ACCT ACTIVITY FOR 06/18/2003 THRU 10/04/2004 PAGE: 3 LINE AMOUNT TRANS DESCRIPTION L1 ONLINE AUDIT TRAIL ---------- -------- --------------- -------~--------------------------- 08/18/2004 02140100 51079 1,322.14- TO RECORD RC 08/18/2004 02140100 51079 2,783.08- TO RECORD RC 08/18/2004 02140100 51079 78.98- TO RECORD RC 08/18/2004 02140100 51079 1,716.33- TO RECORD RC 08/18/2004 02140100 51079 1.28- TO RECORD RC 08/18/2004 02140100 51079 18,544.40- TO RECORD RC 08/18/2004 02140100 51079 1,349.19- TO RECORD RC 08/31/2004 02140100 51079 1,100.00- 08/30/04 08/31/2004 02140100 51079 3.84- INCREASE RC 0258009 FY05 RCC 09/03/2004 02140100 51079 500.00- 09/02/04 - 09/08/2004 02140100 51079 236.93- TO INCREASE RC 0258007 09/13/2004 02140100 51079 200.00 TJE 1770640-2 SUB 0060 NSF 09/24/2004 02140100 51079 1,200.00- 09/23/04 09/27/2004 02140100 51079 200.00- 09/24/04 09/30/2004 02140100 51079 877,206.29- CARRYFORWARD AOGCC FY04 RECEIPTS TO 09/30/2004 02140100 51079 213.42- TO INCREASE RC 0258001 AURORA GAS, DP CC AC LA TD NEXT-> Enter-PF1---PF2-==PF3-==PF4-==PF5-==PF6-==PF7-==PF8-==PF9-==PF10--PF11--PF12--- CONT QUIT PGUP PGDN TCODE FCODE RERUN PFKYS LEFT RIGHT HELP 0258005 0258006 0258007 0258008 0258009 0258010 0258011 FOR FOREST OIL FOR MARATHON 0 FOR NORTH SLOP FOR PHILLIPS P FOR PIONEER NA FOR UNION OIL FOR XTO ENERGY ) ') Ro~ PROCESSED CC ACCT ACTIVITY FOR 06/18/2003 THRU 10/04/2004 PAGE: 1 LINE AMOUNT TRANS DESCRIPTION L1 ONLINE AUDIT TRAIL ---------- -------- --------------- ~---------------------------------- 07/27/2004 02140100 10603 1,236.00- CORRECT FY FOR B#0000402/01& 07/27/2004 02140100 10603 435.00- AP02911064 TO ALLOCATE PURCH FROM F 07/28/2004 02140100 10603 672.40- CORRECT FY FOR AP0291106/05 07/28/2004 02140100 10603 685.40- CORRECT FY FOR AP0291106/06 09/30/2004 02140100 51079 877,206.29 CARRYFORWARD AOGCC FY04 RECEIPTS TO 07/29/2004 02140100 66190 169.80- 07/26/2004 02140100 73402 903.30 07/26/2004 02140100 73402 903.30- 09/30/2004 02140100 73422 109.00- 07/13/2004 02140100 74222 30.00 07/13/2004 02140100 74222 30.00- 07/13/2004 02140100 74229 142.78 07/13/2004 02140100 74229 142.78- 07/26/2004 02140100 74233 29.99 07/26/2004 02140100 74233 29.99- 07/16/2004 02140100 74560 476.10 DP CC AC LA TD NEXT-> Enter-PF1---PF2-==PF3-==PF4-==PF5-==PF6-==PF7-==PF8-==PF9-==PF10--PF11--PF12--- CONT QUIT PGOP PGDN TCODE FCODE RERUN PFKYS LEFT RIGHT HELP 9/30/2004 4: 15 PM 1 of 1 Dave Please confirm that $881,697.29 is available to transfer to the FY05 operating appropriation per CCSHB375, section I, page 6 lines 4-7. Upon our approval we will process the transfer. dave blaisdell wrote: wait on that just a bit. I will let you know. I have a $109 encumbrance that can be released. Linda Linda Berg wrote: Thanks, Dave Just an FYI, I received a request from DOP to get it done today. I fell asleep at the wheel on this one and some DMV receipts so I am trying to get it cleaned up. dave blaisdell wrote: Linda I have been working on this all week.. ..1 had a crazy problem with the EPA Grant and we only just solved that this morning. Thanks for the email!! $3,240,386.26 $115,507.86 ($115,616.86-$109) $4,237,700.41_ $881,806.29 Actual expenditures Plus Encumbrances Less Actual revenues Subtotal Less excess EPA Grant receipts Excess AOGCC Receipts *Dave, Linda Laasch is you for certification. $4,600.00 *_ $877,206.29 processing that Change Encumbrance and will fax it directly to These are my figures for FY2004... OK \ } ) Re: Carryover FY04 excess collections INQ-OI: ENCUMBRANCE SOURCE RD CODE ORIGINAL PLACED ADJUST TO PLACED TOTAL LIQUIDATIONS CURRENT BALANCE DESCRIPTION SHORT DESCRIPTION LONG ') DETAIL INQUIRY 02911 97,796.00 0.00 0.00 97,796.00 BLASKOVICH BLASKOVICH SERVICES INC PROFESSIONAL SERVICES RESERVOIR TECHNICAL SERVICES TYPE NUMBER AMOUNT PVN BLS01353 UDR AOGCC CO 2004-0200-4690 REF 1 2 3 4 FIN 1 CURRENT-BALANCE 97,796.00 CA SY 04 04 CC 2140100 PGM } 09/27/2004 ENCUMBRANCE NUM 0248021 DATE ESTABLISHED 06/23/2004 DATE LAST ACTIVITY 06/24/2004 DATE DUE 06/30/2004 RETENTION? YES LIQ RULE LN DENOM 0 DATE COMMENTS (TRUNCATED) LC ACCT FY NMR 73270 04 FOR LINE DETAIL ENTER==>FIN FOR NEXT 01 ENTER==> 01 TYPE/NUM Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT ACTVY BASE FINS REFS PFKYS COMNT HELP ) INQ-OI: ENCUMBRANCE SOURCE RD CODE ORIGINAL PLACED ADJUST TO PLACED TOTAL LIQUIDATIONS CURRENT BALANCE DESCRIPTION SHORT DESCRIPTION LONG DETAIL INQUIRY 02911 2,094.00 0.00 1,796.00- 298.00 JUNEAU ELECTRONICS JUNEAU ELECTRONICS INFOCUS PROJECTOR, ENCUMBRANCE NUM DATE ESTABLISHED DATE LAST ACTIVITY DATE DUE RETENTION? LIQ RULE DENOM 09/27/2004 0248025 06/29/2004 08/18/2004 06/30/2004 YES LN o REPLACEMENT LAMP REF TYPE NUMBER AMOUNT DATE COMMENTS (TRUNCATED) 1 PVN JUE84701 2 UDR AOGCC 3 DO 02-14-0019-04 4 FIN CURRENT-BALANCE CA SY CC PGM LC ACCT FY NMR 1 298.00 04 04 2140100 75830 04 FOR LINE DETAIL ENTER==>FIN FOR NEXT 01 ENTER==> 01 TYPE/NUM Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT ACTVY BASE FINS REFS PFKYS COMNT HELP ,) ~ ~ Cf ~t () y- ) ') INQ-OI: ENCUMBRANCE SOURCE RD CODE ORIGINAL PLACED ADJUST TO PLACED TOTAL LIQUIDATIONS CURRENT BALANCE DESCRIPTION SHORT DESCRIPTION LONG DETAIL INQUIRY 02911 539.19 0.00 0.00 539.19 DATA BANK COMPUTER DATA BANK COMPUTER SERVICES EPSON EXPRESSION AUTO DOCUMENT ENCUMBRANCE NUM DATE ESTABLISHED DATE LAST ACTIVITY DATE DUE RETENTION? LIQ RULE DENOM 09/27/2004 0248028 06/29/2004 06/30/2004 06/30/2004 YES LN o FEEDER REF TYPE NUMBER AMOUNT 1 PVN DBC92013 2 UDR AOGCC 3 DO 02-14-0022-04 4 FIN CURRENT-BALANCE CA SY CC PGM 1 539.19 04 04 2140100 DATE COMMENTS (TRUNCATED) LC ACCT FY NMR 74560 04 FOR LINE DETAIL ENTER==>FIN FOR NEXT 01 ENTER==> 01 TYPE/NUM Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT ACTVY BASE FINS REFS PFKYS COMNT HELP ~~~ , /\JO+ \Y\VOlU& c;- ~ ~~ r lI\;VUt9i, [JL" ) FY 05 Regulatory Cost Charges Estimate FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Estimated 2004 Lapse $ Total to use for Reg Cost Chgs $ Final FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Actual 2004 Lapse $ Total to use for Reg Cost Chgs $ ) 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000 830,000 3,420,300 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000.00 877,206.29' 3,373,093.71 ) ) MANAGEMENT REPORTING MENU REPORT REQUEST NUMBER 168080 FISCAL PERIOD CODE or COA YEAR 2004 AIH900MO REPORT AR APPROPRIATION SECTION AC ACCOUNT ACCOUNT EX EXPENDITURES NUM 3558 YR 2004 AOGCC NUM 70000--- YR TOTAL EXPENDITURES LOG LEVEL-¡Q ONLY (Y/N) N DETAIL/SUMMARY/BOTH (D/S/B) PRINT DECIMAL/CENTS (Y/N) PRINT COMMAS (Y/N) ROUNDING FACTOR (0-9) S Y Y o SECTION LINE TYPES (Y/N) ** *E *1 C* CE CI p* PE PI Y N N N N N N N N -~----SELECTION----------- ---------------REQUEST DATA------------------- DEPARTMENTAL REPORTS...... DEPT DIV COA YR MANAGEMENT REPORT LIST.... RD CODE CLASS (All are optional) (All are optional) Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT IEINQ RFRSH RR IOINQ PFKYS HELP ) ) RRN:0168080 RSN:05939 09/24/2004 ITD ACTUALS & ENCUMBRANCES THRU MO 18 APPROPRIATION EXPENDITURES BY ACCOUNT 3558-04 AOGCC ORIG:04 COA:2004 APPROPRIATIONS ITD MO 18 ACTUALS (T B S R) FN:III00 ITD MO 18 ENCUMB ENTITY NUMBER - DESCRIPTION ------------------------------------- ----------------- ----------------- S** 70000 TOTAL EXPENDITURES S** 70009 TOT EXPS-PRECLOSING S** 70008 OPERATING ACCT TOTAL S** 70100 GROUP CTRL-PER SER S** 71000 PERSONAL SERVICES S** 70200 GROUP CTRL - OTHER S** 70201 GC-OTHER-NONGRANT S** 72000 TRAVEL S** 73000 SERVICES S** 74000 SUPPLIES S** 75000 CAPITAL OUTLAY 3,240,386.26 3,240,386.26 3,240,386.26 2,463,953.50 2,463,953.50 776,432.76 776,432.76 91,793.20 651,194.60 30,493.98 2,950.98 115,616.86 115,616.86 115,616.86 .00 .00 115,616.86 115,616.86 .00 98,808.30 1,454.06 15,354.50 FOR NEXT SECTION ENTER==> NUMBER YEAR LEVEL LIMIT Enter-PFI---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PFI0--PFII--PF12--- CONT QUIT RR PFKYS HELP A C,:T-lA C\ L-, ~ X P Ë-'J--,) c. ....-~s~ Ç\C\CA A L- R. E>l, LQ,SS : U-C..e.M-Ç t:,cle-nt--L 3 <:~ q-D 3B~ :L~" ) ) . ~, \ S,) S0"7, ~tf? '"' ., ) l ' \ 5/..(e_L~ · '3~-,~~ '3 "3 C'-- '5 ,,~.J~ j.,:)fð,;) ì-f ':;h '3 , '100. ý- , /23 ,~o¡¡, ;¡(i " 8ß~ß~ / 4- &;00.00 J - ~-O (¡,J ~ ~~ll ) .G'.Ifr. )-<-1 e.;'f.-c.J:.. S S o ¿. \l-e-1 \. u.. í?..- S P«J 6.[.l/ ('{c-. ~s. .fù'f--~) ) MANAGEMENT REPORTING MENU REPORT REQUEST NUMBER 168080 FISCAL PERIOD CODE or COA YEAR 2004 REPORT AR APPROPRIATION SECTION XL EXTENDED NEXT LOWER LEVEL ACCOUNT EX EXPENDITURES DETAIL/SUMMARY/BOTH (D/S/B) PRINT DECIMAL/CENTS (Y/N) PRINT COMMAS (Y/N) ROUNDING FACTOR (0-9) S Y Y o AIH900MO NUM 3558 YR 2004 AOGCC NUM 70000--- YR TOTAL EXPENDITURES LOG LEVEL-rG ONLY(Y/N) N SECTION LINE TYPES (Y/N) ** *E *I C* CE CI p* PE PI Y N N N N N N N N ------SELECTION----------- ---------------REQUEST DATA------------------- DEPARTMENTAL REPORTS...... DEPT DIV COA YR MANAGEMENT REPORT LIST.... RD CODE --CLASS (All are optional) (All are optional) Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT IEINQ RFRSH RR IOINQ PFKYS HELP ) ) ITD ACTUALS & ENCUMBRANCES THRU MO 18 RRN:0168080 RSN:05939 09/24/2004 APPROPRIATION EXPENDITURES BY EXTENDED NEXT LOWER LEVEL 3558-04 AOGCC ORIG:04 APPROPRIATIONS COA:2004 ITD MO 18 ENTITY NUMBER - DESCRIPTION ACTUALS (T B S R) FN:III00 ITD MO 18 ENCUMB ------------------------------------- ----------------- ----------------- ** 03558-04 AOGCC 3,240,386.26 115,616.86 ** 02140100-04 AOGCC 2,782,997.69 115,616.86 S** 70000 TOTAL EXPENDITURES 2,782,997.69 115,616.86 ** 02140101-04 EPA GRANT 336,205.10 .00 S** 70000 TOTAL EXPENDITURES 336,205.10 .00 ** 02140102-04 DNR-WEB ENBLD OIL PJ 114,096.05 .00 S** 70000 TOTAL EXPENDITURES 114,096.05 .00 ** 02140105-04 GRI WELL ABANDONEMEN 7,087.42 .00 S** 70000 TOTAL EXPENDITURES 7,087.42 .00 ** 02140191-04 DOA-AOGCC CTA .00 .00 S** 70000 TOTAL EXPENDITURES .00 .00 ** 02140192-04 DOA-AOGCC TRVL DVR .00 .00 S** 70000 TOTAL EXPENDITURES .00 .00 FOR NEXT SECTION ENTER==> NUMBER YEAR LEVEL LIMIT Enter-PFI---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PFI0--PFII--PF12--- CONT QUIT RR PFKYS HELP ) ) MANAGEMENT REPORTING MENU REPORT REQUEST NUMBER 168080 FISCAL PERIOD CODE or COA YEAR 2004 AIH900MO REPORT AR APPROPRIATION SECTION AC ACCOUNT ACCOUNT RR RESTRICTED REVENUES NUM 3558 YR 2004 AOGCC NUM 50000--- YR TOT RESTRICTD REVENU LOG LEVEL-¡Q ONLY (Y/N) N DETAIL/SUMMARY/BOTH (D/S/B) PRINT DECIMAL/CENTS (Y/N) PRINT COMMAS (Y/N) ROUNDING FACTOR (0-9) S Y Y o SECTION LINE TYPES (Y/N) ** *E *1 C* CE CI p* PE PI Y N N N N N N N N ------SELECTION----------- ---------------REQUEST DATA------------------- DEPARTMENTAL REPORTS...... DEPT DIV COA YR MANAGEMENT REPORT LIST.... RD CODE --CLASS (All are optional) (All are optional) Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT IEINQ RFRSH RR IOINQ PFKYS HELP ') ) / ITD ACTUALS & ENCUMBRANCES THRU MO 18 APPROPRIATION RESTRICTED REVENUES BY ACCOUNT 3558-04 AOGCC ORIG:04 APPROPRIATIONS COA:2004 ITD MO 18 ENTITY NUMBER - DESCRIPTION ACTUALS RRN:0168080 RSN:05939 09/24/2004 (T B S R) FN:III00 ITD MO 18 ENCUMB ------------------------------------- ----------------- ----------------- S** 50000 TOT RESTRICTD REVENU S** 50006 REST REVS-PRECLOSING S** 50007 OPERATING REST REVS S** 54005 PROGRAM RECEIPTS TOT S** 51079 OIL & GAS CONSERVATN S** 57002 FED GRANTS IN AID S** 51010 FEDERAL RECEIPTS 4,237,700.41- 4,237,700.41- 4,237,700.41- 4,113,200.41- 4,113,200.41- 124,500.00- 124,500.00- .00 .00 .00 .00 .00 .00 .00 FOR NEXT SECTION ENTER==> NUMBER YEAR LEVEL LIMIT - - Enter-PFI---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PFI0--PFII--PFI2--- CONT QUIT RR PFKYS HELP ) ) MANAGEMENT REPORTING MENU REPORT REQUEST NUMBER 168080 FISCAL PERIOD CODE or COA YEAR 2004 REPORT AR APPROPRIATION SECTION XL EXTENDED NEXT LOWER LEVEL ACCOUNT RR RESTRICTED REVENUES DETAIL/SUMMARY/BOTH (D/S/B) PRINT DECIMAL/CENTS (Y/N) PRINT COMMAS (Y/N) ROUNDING FACTOR (0-9) S Y Y o AIH900MO NUM 3558 YR 2004 AOGCC NUM 50000 YR TOT RESTRICTD REVENU LOG LEVEL-rD ONLY(Y/N) N SECTION LINE TYPES (Y/N) ** *E *1 C* CE CI p* PE PI Y N N N N N N N N ------SELECTION----------- ---------------REQUEST DATA------------------- DEPARTMENTAL REPORTS...... DEPT DIV COA YR MANAGEMENT REPORT LIST.... RD CODE --CLASS (All are optional) (All are optional) Enter-PF1---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PF10--PF11--PF12--- CONT QUIT IEINQ RFRSH RR IOINQ PFKYS HELP ) \ J ITD ACTUALS & ENCUMBRANCES THRU MO 18 RRN:0168080 RSN:05939 09/24/2004 APPROPRIATION RESTRICTED REVENUES BY EXTENDED NEXT LOWER LEVEL 3558-04 AOGCC ORIG:04 APPROPRIATIONS (T COA:2004 ITD MO 18 ENTITY NUMBER - DESCRIPTION ACTUALS B S R) FN:I1100 ITD MO 18 ENCUMB ------------------------------------- ----------------- ----------------- ** 03558-04 AOGCC ** 02140100-04 AOGCC S** 50000 TOT RESTRICTD REVENU ** 02140101-04 EPA GRANT S** 50000 TOT RESTRICTD REVENU 4,237,700.41- 4,113,200.41- 4,113,200.41- 124,500.00- 124,500.00- .00 .00 .00 .00 .00 FOR NEXT SECTION ENTER==> NUMBER YEAR LEVEL LIMIT Enter-PFI---PF2---PF3---PF4---PF5---PF6---PF7---PF8---PF9---PFI0--PFII--PFI2--- CONT QUIT RR PFKYS HELP ) ',1"'1 J Record of Payments Address Changes (ñ).' ~, 'r' ,{'7\, 1:, .' r: r~·,1 . \!~,¡ ¡: ifJ"\ ::, :'~ '\\''\!i :f\'. ': ¡.. '.' '. ¡ .., ,: 1,1'1 'I t11) ~; /- \'\" ::' j!:.-~ 19J ~,~' iJ~,j I___¡ ) ,:,:i~.rJ.. \'. '.~n'I,.,:::::J, i ill'l ¡ : '\ i!: il:~ i ill ! l: ·1 I, ! ' .I ¡ : "\ ' i:, ) ,r; II : !j i i : ~..::::::J FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276·7542 NOTICE OF LATE PAYMENT TO: Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 Anchorage, Alaska 99519-6168 YOU ARE NOTIFIED that the Alaska Oil & Gas Conservation Commission has not received third and fourth quarter payments of the Regulatory Cost Charges for Fiscal Year 2005. The total now due at this time is $5,463.72. Please make your check payable to: Mail or delivery payment to: Date: May 10, 2005 ) @T1í\11'iÞíñìUnïEíü \Im ~ lE\ ~ In~\ Æ\ cQ) u U11 U ~ lJ1J If LrJ ~LJïu cQ) w~u U ) AI1ASKA. OIL AND GAS CONSERVATION COMMISSION ¡ / / l i / / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)27~7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Marathon Oil Company Attention: Accounting Analyst P.o. Box 196168 Anchorage, AK. 99519-6168 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $1 0,978.66. Your estimated regulatory cost charge of $2,783.08 has not yet been paid and is due immediately. Upon payment of the estimated regulatory cost charge the remainingba,lance will be $8,19.5~58. One third of this balance, $2,731.86, is due no later than December 15,2004. A second payment of$2,731.86 is due no later than January 15,2005. A third payment of $2,731.86 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16, 2004 f@ "Ji j~:~ \, ~ n,:;J \,\~ ~: I '¥\rl " I: 'j II \,., i i /,)j¡'\ [: i :! @ :1: L-1J U u: ') '-'1-::; :~UU1. I:,:¡ !,lr~,: : I , 11 : I ~~u ~, ~ } FRANK H. MURKOWSKI1 GOVERNOR Al'fASIiA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. 7fH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 NOTICE OF LATE PAYMENT TO: Phillips Petroleum Company Attention: Steven Arbelovsky, Cook Inlet Ops Mgr P.O. Box 66 Kenai, Alaska 99611 YOU ARE NOTIFIED that the Alaska Oil & Gas Conservation Commission has not received third and fourth quarter payments of the Regulatory Cost Charges for Fiscal Year 2005. The total now due at this time is $3,369.50. Date: May 10, 2005 ./ hn 7:.. N onnan, Chairman \..-.-' ') ~1r~1JŒ (ID~ L%~ffi~~~L% ') , AI~A.SKA OIL AND GAS CONSERVAnONCO~SSION I J/ / / l / FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'H AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steven Arbelovsky, Cook Inlet Ops Mgr P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $6, 770.58. You previously paid an estimated regulatory cost charge of$I,716.33, leaving a balance of$5,054.25. One third of this balance, $1,684.75, is due no later than December 15,2004. A second payment of$I,684.75 is due no later than January 15,2005. A third payment of$I,684.75 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on ~~ described in the October 6, 2004, Notice of Proposed Regulatory C~-ges for ~2005. ____ Date: November 16,2004 (,/II) __ ~ ~an, Chairman ) FY 2005 Regulatory Cost Charges Operator: Aurora Gas LLC RC#: 0258001 Payment . Qtr 1 Qtr2 Qtr3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 71.14 $ 284.56 $ 71.14 $ 284.56 Date Rcvd 09/27/04 ) Check # 5496 ) FY 2005 Regulatory Cost Charges Operator: BP Exploration (Alaska) Inc. RC#: 0258002 Payment Qtr 1 Qtr2 Qtr3 Qtr4 Total Pmt Due Amt Due Pmt Rcvd 09/15/04 $ 677,626.09 $ 677,626.09 $ 677,626.09 $ 677,626.09 Date Rcvd 09/07/04 ) Check # P055276 ) FY 2005 Regulatory Cost Charges Operator: ConocoPhilips Alaska, Inc. RC#: 0258003 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due Amt Due Pmt Rcvd 09/15/04 $ 151,555.43 $ 151,555.43 $ 151,555.43 $ 151,555.43 Date Rcvd 09/07/04 ) Check # 13969 ') FY 2005 Regulatory Cost Charges Operator: Evergreen Resources RC#: 0258004 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 26.96 $ 26.96 $ 26.96 $ 26.96 Date Rcvd 09/20/04 ) Check # 77001178 ) FY 2005 Regulatory Cost Charges Operator: Forest Oil Corporation RC#: 0258005 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 1,322.14 $ 1,322.14 $ 1,322.14 $ 1,322.14 Date Rcvd 09/07/04 ') Check # 445306 ') FY 2005 Regulatory Cost Charges Operator: Marathon Oil Company RC#: 0258006 Payment Pmt Due Amt Due Pmt Rcvd Date Rcvd Qtr 1 09/15/04 $ 2,783.08 Qtr2 Qtr 3 $ Qtr4 $ Total $ 2,783.08 $ - \ } Check # ), FY 2005 Regulatory Cost Charges Operator: North Slope Borough RC#: 0258007 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 78.98 $ 315.91 $ 78.98 $ 315.91 Date Rcvd 08/30/04 ) Check # 1162986 ) FY 2005 Regulatory Cost Charges Operator: Phillips Petroleum Company RC#: 0258008 Payment Qtr 1 Qtr 2 Qtr 3 Qtr 4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 1,716.33 $ 1,716.33 $ 1,716.33 $ 1,716.33 Date Rcvd 09/07/04 '\ , Check # 12937 ") FY 2005 Regulatory Cost Charges Operator: Pioneer Natural Resources RC#: 0258009 Payment Qtr 1 Qtr2 Qtr3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 1.28 $ 5.12 $ 1.28 $ 5.12 Date Rcvd 08/23/04 ) Check # 972551 ') FY 2005 Regulatory Cost Charges Operator: UNOCAL RC#: 0258010 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 18,544.40 $ 18,544.40 $ 18,544.40 $ 18,544.40 Date Rcvd 09/14/04 ) Check # 6548615 ') FY 2005 Regulatory Cost Charges Operator: XTO Energy Inc RC#: 0258011 Payment Qtr 1 Qtr 2 Qtr 3 Qtr4 Total Pmt Due 09/15/04 $ Amt Due Pmt Rcvd 1,349.19 $ 1,349.19 $ 1,349.19 $ 1,349.19 Date Rcvd 08/18/04 ) Check # 1772 $ 78.98 $ $ $ 26.96 $1,322.14 $1,322.14 $ 2,783.08 $ $ - $ - $ - $ $ - $ - $ - $ $ - $ - $ - $ 26.96 $ $ $ $ 284.56 $ 677,626.09 $ 677,626.09 $ 151,555.43 $ 151,555.43 $ $ - $ - $ - $ - $ $ - $ - $ - $ - $ $ - $ - $ - $ - $ 71.14 $ $ $ $ ) 1 ) $ $ $ $ Qtr1 Qtr2 Qtr3 Qtr4 Total Ph·'llip·' .":'p t'·'o'·I"· ',....",:,:.-.·;,......:·'P¡.. ".,,:0', 'N" 't" 'I' R.."·Ä',·:' ..,', ':.":~:' .,<':.',.,..," ¡\,··:",:,,·;,,·,U' 'N: OCA":,:' ,è':::,:':,,·". ._:,;, :«;., ,f:,~"",", ·'<"'·'::'XTO'E'o.;'" '. 'û:;"':"'":,;:,,,,;:,;,1:.;'C:' ""J1:,.,::,..",,~"C"}:":''';:i,·t~>.';:i~~t'' 'I' 'i~,:,'::..:,!\t'0,'''',; ;:'-""-'i,: I se r eu...,..·o...." oneer a uraesuurces' .; .',...'" d", ""<'., ' "~"" h","," .,'d,· ".. ""<.",,,. " . uerg,,:· ....'?', -'..."" """'""" co.,," . '"... ,,~ aw as '.. -"~' , " , , ': 0 '""" $ 1,716.33 $ 1,716.33' $ 1.28 $ '5.12 $ 18,544.40 $ 18,544.'40 $ 1",349.19 $' 1,349.19' $' 855,075.02 $ 852,741.01" $ - $ - $ - $ - $ - $ - $ - $ - $ - $ $ - $ - $ - $ - $ - $ - $ - $ - $ - $ $ - $ - $ - $ - $ - $ - $ - $ - $ - $ $ 855,075.02 $ 852,741.01' \ ¡, ) ) f_~~:~i'~~~:~· $ 315.91 $ $ $ ) ') Other Reports & Info FY05 AOGCC Regulatory Cost Charges Final November 9, 2005 Total Due First Payment Remainder Due 2nd Payment 3rd Payment 4th Payment Aurora Gas LLC $ 280.64 $ 284.56 $ (3.92) $ $ $ BP Exploration (Alaska), Inc $ 2,673,094.53 $ 677,626.09 $ 1,995,468.44 $ 665,156.15 $ 665,156.15 $ 665,156.14 ConocoPhillips Alaska Inc $ 597,854.76 $ 151,555.43 $ 446,299.33 $ 148,766.44 $ 148,766.44 $ 148,766.45 ), Evergreen Resources (Alaska) $ 106.32 $ 26.96 $ 79.36 $ 26.45 $ 26.45 $ 26.46 Forest Oil Corporation $ 5,215.57 $ 1,322.14 $ 3,893.43 $ 1,297.81 $ 1,297.81 $ 1,297.81 Marathon Oil Company $ 10,978.66 $ 2,783.08 $ 8,195.58 $ 2,731.86 $ 2,731.86 $ 2,731.86 North Slope Borough $ 311.55 $ 315.91 $ (4.36) $ $ $ Phillips Petroleum Company $ 6,770.58 $ 1,716.33 $ 5,054.25 $ 1,684.75 $ 1,684.75 $ 1,684.75 Pioneer Natural Resources $ 5.05 $ 5.12 $ (0.07) $ $ $ Union Oil Company of California $ 73,153.80 $ 18,544.40 $ 54,609.40 $ 18,203.13 $ 18,203.13 $ 18,203.14 XTO Energy $ 5,322.25 $ 1 ,349.19 $ 3,973.06 $ 1,324.35 $ 1,324.35 $ 1,324.36 Totals $ 3,373,093.71 $ 855,529.21 $ 2,517,564.50 $ 839,190.94 $ 839,190.94 $ 839,190.97 Regulatory Cost Charge 6 year Comparison FY 2000 FY 2001 FY 2002 FY 2003 FY 2004 FY 2005 Aurora Gas LLC $ $ $ $ 79.44 $ 150.59 $ 280.64 BP Exploration (Alaska), Inc $ 839,499.00 $ 1,960,829.69 $ 2,475,365.81 $ 3,248,915.69 $ 2,865,857.42 $ 2,673,094.53 ConocoPhillips Alaska Inc $ 1,955,178.00 $ 441,678.51 $ 499,158.60 $ 783,548.36 $ 675,978.22 $ 597,854.76 Evergreen Resources (Alaska) $ $ $ $ $ $ 106.32 Exxon Corporation $ $ $ $ 11.09 $ $ Forest Oil Corporation $ 2,616.00 $ 2,369.06 $ 2,616.38 $ 3,981.96 $ 2,496.19 $ 5,215.57 Marathon Oil Company $ 3,494.00 $ 2,990.72 $ 4,979.44 $ 9,775.34 $ 9,794.09 $ 10,978.66 North Slope Borough $ 255.00 $ 243.78 $ 300.30 $ 421.95 $ 349.55 $ 311 .55 Ocean Energy $ $ 2.81 $ $ $ $ Phillips Petroleum Company $ 10,326.00 $ 8,631.55 $ 10,728.63 $ 15,880.91 $ 13,585.72 $ 6,770.58 Pioneer Natural Resources $ $ $ $ $ $ 5.05 "=-~-/ $ $ 87,313.06 $ 95,304.39 $ 136,111.66 $ $ Union Oil Company of California 96,319.00 99,327.77 73,153.80 XTO Energy Inc (Cross Timbers) $ 5,513.00 $ 4,589.68 $ 5,330.66 $ 7,473.60 $ 6,333.46 $ 5,322.25 Totals $ 2,913,200.00 $ 2,508,648.86 $ 3,093,784.21 $ 4,206,200.00 $ 3,673,873.01 $ 3,373,093.71 A $ 2,923,200.00 $ 2,768,300.00 $ 3,317,300.00 $ 4,336,200.00 $ 4,162,900.00 $ 4,270,300.00 F $ 10,000.00 $ 15,000.00 $ 20,000.00 $ 20,000.00 $ 20,000.00 $ 20,000.00 L $ $ 244,651.14 $ 203,515.79 $ 121,200.74 $ 469,027.42 $ 877,206.29 Totals $ 2,913,200.00 $ 2,508,648.86 $ 3,093,784.21 $ 4,194,999.26 $ 3,673,872.58 $ 3,373,093.71 Volume Comparison FY 2000 FY 2001 FY 2002 FY 2003 FY 2004 FY 2005 Aurora Gas LLC 46,300 100,842 212,703 BP Exploration (Alaska), Inc 733,160,591 1,955,645,281 2,031,974,546 1,893,461,508 1,919,138,727 2,026,047,299 ConocoPhillips Alaska Inc 1,707,517,109 440,510,715 409,748,558 456,650,405 452,672,899 453,138,498 Evergreen Resources (Alaska) 80,590 Exxon Corporation 6,464 Forest Oil Corporation 2,285,027 2,362,800 2,147,731 2,320,679 1,671,589 3,953,095 Marathon Oil Company 3,051,478 2,982,808 4,087,519 5,697,046 6,558,673 8,321,168 North Slope Borough 222,636 243,135 246,507 245,912 234,080 236,135 Ocean Energy 2,800 Phillips Petroleum Company 9,018,029 8,608,731 8,806,902 9,255,360 9,097,757 5,131,700 Pioneer Natural Resources 3,828 Union Oil Company of California 84,118,134 87,082,204 78,233,323 79,325,599 66,515,440 55,446,246 XTO Energy Inc (Cross Timbers) 4,814,465 4,577,548 4,375,826 4,355,603 4,241,237 4,033,953 Totals 2,544,187,469 2,502,016,022 2,539,620,912 2,451,364,876 2,460,231,244 2,556,605,215 AOGCC FY2004 Lapsed Appropriation Personal Services Savings from vacancies:Commissioner - 9 mos.; Accounting Clerk III; Natural Resource Manager; Petroleum Inspector & Seasonal Petroleum Inspector) Overtime Savings Travel No technical staff slope travel Inspector Travel- 6 months use of shared services charters & travel savings resulting from Inspector vacancies Instate Administrative Travel Savings Outside Travel Savings { $ 877.2 I $ 299.5 $ 271.2 $ 28.3 $ 95.4 $ 5.0 $ 65.4 $ 5.9 $ 19.1 $ 425.8 Contractual Services Technical & Consultant contracts - less than anticipated use $ 368.5 Other contractual services - cost savings and less than anticipated use Supplies Savings from less than anticipated safety equipment purchases Equipment Savings due to position vacancies and less than anticipated equipment purchases $ 57.3 $ 3.7 $ 3.7 $ 52.8 $ 52.8 #4 ) ') ) 1 ALASKA OIL AND GAS CONSERVATION COMMISSION 2 PUBLIC HEARING 3 4 In Re: 5 Proposed Regulatory Cost Charges for Fiscal Year 2005 6 7 8 TRANSCRIPT OF PROCEEDINGS 9 Anchorage, Alaska November 16/ 2004 9:00 o/clock a.m. 10 11 12 COMMISSIONERS: 13 ) 14 JOHN NORMAN, Chairperson DAN SEAMOUNT 15 16 17 18 * * * * * 19 20 21 22 23 2004 24 25 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ^ ^ ^ ORIGINAL v v y ) ) ) ) 1 TABLE OF CONTENTS 2 3 OPENING REMARKS BY CHAIRPERSON NORMAN . Page 3 Page 4 Page 9 4 DISCUSSION 5 END OF PROCEEDINGS 6 7 8 * * * * * 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 1 2 3 4 5 6 7 8 9 10 11 12 13 ) 14 15 16 17 18 19 20 21 22 23 24 25 ) ) PRO C E E DIN G S (On record) COURT REPORTER: We're on record at 9:02 a.m. CHAIRPERSON NORMAN: Good morning, this is a hearing before the Alaska Oil and Gas Conservation Commission. The hearing is being held on the morning of Tuesday, November 16th, 2004, beginning at 9:00 o'clock a.m. We are located at the Commission's offices at 333 West Seventh Avenue, Suite 100. I will begin by introducing myself. I'm John Norman, Chairman of the Alaska Oil and Gas Conservation Commission and to my left is Commissioner Dan Seamount, also of the Commission. With us today is Jerri Young of Metro Court Reporting who will be recording and preparing a transcript of these proceedings. The purpose of this hearing today is to review and take comments, if there are any, concerning the Alaska Oil and Gas Conservation Commission's 2005 regulatory cost charges and this is for the fiscal year 2005, which began on July 1 of 2004. In the file it shows that notice of this hearing was duly published and notice was sent to all of the parties who will have responsibility for paying a portion of the regulatory cost charge during the year in question. No objection or comments have been received. METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 3 ) ) ') 1 This proceeding is being held in accordance with the 2 provisions of 20 AAC 25.540 and this is the provision of the 3 regulations applicable to the Alaska Oil and Gas Conservation 4 Commission, governing public hearings. Any persons wishing to 5 testify today will be allowed to do so. Persons giving 6 testimony will be placed under oath. Commissioner Seamount, 7 before we begin, do you have any introductory comments? 8 COMMISSIONER SEAMOUNT: I have none at this 9 time, Mr. Chairman. 10 CHAIRPERSON NORMAN: Very well. I think 11 perhaps maybe principally for my own benefit, I'm going to 12 review the applicable section of the regulations and would ) 13 invite anyone, if there is some interpretation or 14 clarification, to let me know. 15 The regulation says that after the later of the 16 beginning of a fiscal year or date of enactment of an 17 appropriation for the operating costs of the Commission for 18 that fiscal year, the Commission will provide to persons, 19 subject to a regulatory cost charge, written notice of the 20 proposed charges and the basis for the charges, in accordance 21 with 20 AAC 25.605. I'm interpreting this that the later of 22 the two dates would be the beginning of the fiscal year for 23 2004, which began on July 1 of 2004. 24 Within 30 days after the notice has been issued, under 25 the section that I just read, a person subject to a regulatory ) METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 4 1 2 3 4 5 6 7 8 9 10 11 12 13 ) 14 15 16 17 18 19 20 21 22 23 24 25 ) ') cost charge may submit comments on or request revisions to the regulatory cost charges, proposed by the Commission. A request for revision must be accompanied by an explanation of the basis for the provision. Before a hearing is held under this section, the Commission will provide all persons subject to a regulatory cost charge with copies and comments and requests for revision, received by the Commission, or with notice of the persons right to inspect those comments. And as I earlier noted, the record does not reflect that there have been any comments or requests for revisions, nor have there been any requests to inspect such documents. Continuing on with the regulation, within 60 days after notice is issued, the Commission will hold a public hearing under 20 AAC 25.540, on the proposed regulatory charges and that is the purpose of this hearing today and this hearing is being held in compliance with 20 AAC 25.615, subsection (c). Continuing on, the next step is that within 90 days after the notice is issued, the Commission will issue an order determining the regulatory cost charges to be paid and the dates by which the charges must be paid. The Commission will provide written notice to each person, subject to a regulatory cost charge, of the persons regulatory cost charge and payment dates. And then the final sections discuss the formula under METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ' 5 1 2 3 4 5 6 7 8 9 10 11 12 13 ) 14 15 16 17 18 19 20 21 22 23 24 25 ) ') which the cost charges are calculated. As we have previously reviewed in a prior hearing¡ these are done based upon volumes of fluid produced by the various operators¡ conducting operations in the state of Alaska. COMMISSIONER SEAMOUNT: I believe it¡s produced and injected -- produced and injected. CHAIRPERSON NORMAN: Produced and injected¡ than you Commissioner Seamount. The the operators this year that will be subject to payment of a regulatory cost charge¡ based on their pro rata share of the total amount to be paid are as follows¡ and I will read only the amounts¡ not the fluid amounts¡ upon which the allocations are made. Aurora Gas LLC¡ $280.64¡ BP Exploration Alaska¡ Inc.¡ $2¡673¡094.53¡ ConocoPhillips Alaska¡ Inc.¡ $597¡854.76¡ Evergreen Resources¡ Inc.¡ $106.32¡ Forest Oil Corporation¡ $5,215.57, Marathon Oil Company¡ $10¡978.66, the North Slope Borough¡ $311.55¡ Phillips Petroleum Company, $6¡777.58, pioneer Natural Resources Company, $5.05, Unocal¡ $73,153.80¡ XTO Energy, $5,322.25. I have before me an order ready for adoption by the Commission formally establishing the regulatory cost charges for fiscal year 2005. The order recites the fact that public notice has been given, references the total costs of the Commission¡ notes that elapsed amount for fiscal year 2004¡ which will carry forward as a credit is $877¡206.29. And METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 6 7 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 MS. BERG: lId just like you to reread the 25 24 the numbers and office manager Ms. Berg will.. ... 23 before we go there Mr. Chairman I you miss-spoke on a couple of COMMISSIONER SEAMOUNT: WeIll first of all 22 21 and move approval. Is there a second? 20 followed by discussion would be in effect and 1/11 go ahead SOl at this point a motion to approve the order 19 18 payment is made I leaving three more payments. 17 here. SOl we are already beyond the first quarterl that 16 amount owed by each payment date. I see what we are doing 15 less credit for previously paidl by paying one-third of the 14 previously been paid by paying one-third of the amount -- or 13 me states that they will pay their charges that have CHAIRPERSON NORMAN: Okay. The order before 12 11 weIll yes quarterlYI four payments. MS. BERG: The payments are done quarterly 10 CHAIRPERSON NORMAN: The payments. 9 MS. BERG: The payments? 8 7 quarterly Ms. Berg? 6 theylre done on a tri- -- a three times a year basisl or is it 5 which are done on a quarterly basis. Correction. It appears 4 paidl based upon the estimates that the Commission sent outl 3 less estimated fiscal year charges that they have previously 2 be required to pay their respective regulatory cost charges I 1 finallYI the order provides that the designated operators will 1 2 3 4 5 6 7 8 9 10 11 12 13 ( 14 15 16 17 18 19 20 21 22 23 24 25 ( (' numbers for Aurora Gas. CHAIRPERSON NORMAN: Yes. Oh, I'm so- -- the numbers for Aurora Gas, LLC are $280.64. MS. BERG: And then Petroleum or Phillips Petroleum Company. CHAIRPERSON NORMAN: And the numbers for Phillips Petroleum Company, $6,770.58. MS. BERG: That's correct. CHAIRPERSON NORMAN: Thank you for that clarification. COMMISSIONER SEAMOUNT: And I have a question on making a motion¡ do we do that in a hearing or - - okay, because I thought we had 30 days to get the decision out. CHAIRPERSON NORMAN: We do -- we do have 30 days to get the decision out but it would need to be approved in a public meeting.. . . . COMMISSIONER SEAMOUNT: Okay. CHAIRPERSON NORMAN: .... .if we wanted further time to study it, then we could reconvene. We could do it at one of our next public meetings. COMMISSIONER SEAMOUNT: No, I have no problems, I second the motion. CHAIRPERSON NORMAN: Very well, a motion has been made and seconded to approve the order establishing fiscal year 2005 regulatory cost charges. This is identified METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 8 9 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 ( 25 24 23 22 21 * * * END OF PROCEEDINGS * * * 20 19 (Off record) 18 17 9:15 a.m. 16 hearing? Okay. Hearing nothing, we will stand adjourned at Is there any further business to come before the 15 14 Commissioners Norman and Seamount. ( 13 be signed, effective as of today, November 16, 2004, by 12 fiscal year 2005 regulatory cost charges is approved and will 11 that the motion unanimously carries and the order establishing CHAIRPERSON NORMAN: Aye. The chair notes 10 COMMISSIONER SEAMOUNT: Aye. 9 8 call the question. All in favor of the motion. CHAIRPERSON NORMAN: Very well. Then, I will 7 MS. BERG: No, Commissioner, no. 6 5 clarification? 4 on the motion? Are there any points that require 3 Before we call the question, is there any discussion 2 16, 2004. 1 under other orders Number 030 and the order is dated November f ( 10 METRO COURT REPORTING 745 West Fourth Avenue, Suite 425 Anchorage, Alaska 99501 (907) 276-3876 25 24 23 22 21 20 19 18 SIGNED AND CERTIFIED TO BY: \.\\\\\\\1 1111111/ '--~'\ ð ~\ Y OlJ:l'q~ ~ &~.......... JiIì. ~ ~ 'S....... .......... Q ~ ;:: l OTA~ \ ~ :1+ J..\~ = ¡ -*- ! = - . ^ . - :::. \ If't'(,ISL\C, ¡ ::: ~....... ." ~ ~...... ..+~ ~ ~.'... ...' 'It. ~ ~ f1. ..~.......... tb~~ ~~e of A\~ ~ ~/II/II"\\\\~ 17 ~, U;~1~ Jerri Young Not~ in anb for AI ka My Commission Expires: 11-03-07 16 15 14 ( 13 12 2004. 11 DATED at Anchorage, Alaska this 30th day of November, 9 THAT the Transcript has been prepared at the request of the Alaska Oil and Gas Conservation Commission, 333 West 10 Seventh Avenue, Anchorage, Alaska. THAT the annexed and foregoing pages numbered 2 7 through 9 contain a full, true and correct transcript of the Public Hearing before the Alaska Oil and Gas Conservation 8 Commission, taken by me and transcribed by me. 6 5 I, Jerri Young, Notary Public in and for the State of Alaska, do hereby certify: 4 STATE OF ALASKA ) 3 )ss. THIRD JUDICIAL DISTRICT ) 2 C E R T I FIe ATE 1 (' #3 ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West Seventh Avenue, Suite 100 Anchorage Alaska 99501-3539 Re: Regulatory Cost Charges for Fiscal Year 2005. ) ) Other No. 030 November 16,2004 ORDER ESTABLISHING FISCAL YEAR 2005 REGULATORY COST CHARGES IT APPEARING THAT: 1. On October 6, 2004, pursuant to 20 AAC 25.615 the Commission gave written notice of proposed fiscal year 2005 regulatory cost charges under AS 31.05.093 to operators subject to those charges. 2. Notice of public hearing on the proposed fiscal year 2005 regulatory cost charges was published in the Anchorage Daily News on October 8, 2004. 3. A public hearing was held at the Commission's offices on November 16,2004. FINDINGS: 1. The appropriation, other than of federal receipts, made for the operating costs of the Commission for this fiscal year is $4,270,300.00 2. The lapsed amount of the fiscal year 2004 appropriation that is included in this fiscal year's appropriation under AS 31.05.093(d) is $877,206.29. 3. A reasonable estimate of the total fees to be collected under AS 31.05.090 during this fiscal year is $20,000.00. 4. The amounts constituting V OP under 20 AAC 25.605(a) for the operators subject to a fiscal year 2005 regulatory cost charge are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. Evergreen Resources, Inc. Forest Oil Corporation 212,703 2,026,047,299 453,138,498 80,590 3,953,095 Bbl Bbl Bbl Bbl Bbl .. , ') RCC FY 2005 Page 2 of3 Marathon Oil Company North Slope Borough Phillips Petroleum Co. Pioneer Natural Resources Company UNOCAL XTO Energy Inc. 8,321,168 236,135 5,131,700 3,828 55,446,246 4,033,953 CONCLUSIONS: ) November 16,2004 Bbl Bbl Bbl Bbl Bbl Bbl 1. The Commission chooses not to include in its calculation of fiscal year 2005 regulatory cost charges an allowance to cover charges that the Commission may be unable to collect. 2. Using the fonnula set out in 20 AAC 25.605, the fiscal year 2005 regulatory cost charges for the operators subject to those charges are as follows: Aurora Gas, LLC. BP Exploration (Alaska) Inc. ConocoPhillips Alaska, Inc. EvergreenResources Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Co. Pioneer Natural Resources Company UNOCAL XTO Energy Inc. $280.64 $2,673,094.53 $597,854.76 $106.32 $5,215.57 $10,978.66 $311.55 $6,770.58 $5.05 $73,153.80 $5,322.25 3. Appropriate payments dates under 20 AAC 25.620 are December 15, 2004, for the second quarter of the fiscal year; January 15,2005, for the third quarter, and March 15,2005, for the fourth quarter. ... RCC FY 2005 Page 3 of3 ) ) November 16,2004 NOW THEREFORE IT IS ORDERED that the operators listed in Conclusion 2 of this order shall pay their respective regulatory cost charges set out therein, less their respective estimated fiscal year 2005 regulatory cost charges that have previously been paid, by paying one third of the amount owed by each payment date set out in Conclusion 3 of this order or sooner. ~:'t,,-:""""~ "~.:z':;.:- -..:, '''t ;...:~ ~ , t:: Daniel T. Seamou , Jr., Commissioner Alaska Oil and as Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it may file with the Commission an application for rehearing. A request for rehearing must be received by 4:30 PM on the 23rd day following the date of the order, or next working day if a holiday or weekend, to be timely filed. The Commission shall grant or refuse the application in whole or in part within 10 days. The Commission can refuse an application by not acting on it within the 10-day period. An affected person has 30 days from the date the Commission refuses the application or mails (or otherwise distributes) an order upon rehearing, both being the final order of the Commission, to appeal the decision to Superior Court. Where a request for rehearing is denied by nonaction of the Commission, the 30-day period for appeal to Superior Court runs from the date on which the request is deemed denied (i.e., lOth day after the application for rehearing was filed). ') ~lT &\ 1TŒ (ill &\~!A\~ FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA OIL AND GAS CONSERVATION COITJ..LTJiSSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Aurora Gas LLC Attention: Ed Jones, Vice President 10333 Richmond Avenue, Suite 710 Houston, TX 77042 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $280.64. You previously paid an estimated regulatory cost charge of $284.56, leaving a credit balance of$3.92. Your refund will be issued to you before December 31, 2004. Your regulatory cost charge has been calculated 0 2004, Notice of Proposed Regulatory ~ges ¡sea e Date: November 16,2004 ( is described in the October 6, 2005. lrman ~ ') ~1f~1TŒ lID ~~ FRANK H. MURKOWSKI, GOVERNOR AT/ASIiA OIL AND G~4¡ CONSERVATION COl1'J.J.1'...SSION 333 W. JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: BP Exploration (Alaska), Inc. Attention: Steve Marshall, President P.O. Box 196612 J\nchorage,AJ( 99519-6612 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $2,673,094.53.Y ou previously paid an estimated regulatory cost charge of $677,626.09, leaving a balance of $1,995,468.44. One third of this balance,-$665,156.15, is due noJater than December 15, 2004. A second payment of $665,156.15 is due no later than January 15,2005. A third payment of$665,156.14 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 J\nchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on sis described in the October 6, 2004, Notice of Proposed Regulatory C/.7eSVoyfi~al /; 2~05. Date: November 16,2004 (( l/ tAf/. ./ ~~~an,c~ ') ~~!A\J! :2r ~~!A\~æ ) ALASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSK/, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: ConocoPhillips Alaska, Inc. Attention: Noel Dike, Prod Rev Acctg Accounts Payable, A TO-1668 P.O. Box 100360 Anchorage, AK 99510-0360 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $597,584. 76. You previously paid an estimated regulatory cost charge of $151 ,555.4 3, leaving a balance of $446,029.3 3. One third of this balance, $148,676.44, is due no later than December 15,2004. A second payment of $148,676.44 is due no later than January 15,2005. A third payment of $148,676.45 is due no later than March 15, 2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated o~~s described in the October 6, 2004, Notice of Proposed Regulatory C~fiarges [ :;d"!:1~2005. Date: November 16,2004 \.. VIJ..(/ K.~,Cha~n -') ) ffiJ~ FRANK H. MURKOWSKI, GOVERNOR AI¡ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Evergreen Resources Inc. Attn: Mark S. Sexton, CEO 1401 17th Street, Suite 1200 Denver, CO 80202 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $1 06.32. You previously paid an estimated regulatory cost charge of $26.96, leaving abalance of $79.36. One third of this balance, $26.45, is due no later than December 15, 2004. A second payment of $26.45 is due no later than January 15, 2005. A third payment of $26.46 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16, 2004 ") ~r!ÆuŒ (J)~ !Æ æ FRANK H. MURKOW5KI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Forest Oil Corporation Attn: Accounts Payable 310 K Street, #700 Anchorage, AK 99501 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5,215.57. You previously paid an estimated regulatory cost charge of$I,322.14, leaving a balance of $3,893.43. One third of this balance, $1,297.81, is due no later than December 15,2004. A second payment of$I,297.81 is due no later than January 15,2005. A third payment of$I,297.81 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. . described in the October 6, 005. Date: November 16, 2004 ') ) Œ lID ~ !A\ FRANK H. MURKOWSKI, GOVERNOR A1tASKA OIL AND GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Marathon Oil Company Attention: Accounting Analyst P.O. Box 196168 Anchorage, AK 99519-6168 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $10,978.66. Your estimated regulatory cost charge of $2,783.08 has not yet been paid and is due immediately. Upon payment of the estimated regulatory cost charge the remaining balance will be $8,195.58. One third of this balance, $2,731.86, is due no later than December 15,2004. A second payment of$2,731.86 is due no later than January 15, 2005. A third payment of $2,731.86 is due no later than March 15, 2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part· of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16,2004 ) ) ®~ LnJ~1 FRANK H. MURKOWSKI, GOVERNOR A1tASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: North Slope Borough Attention: Dorothy Savok, Manager Barrow Gas Fields P.O. Box 69 Barrow, AK 99723 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $311.55. You previously paid an estimated regulatory cost charge of$315.91, leaving a creditbªlanceQf$4.36. Your refund will be issued to you before December 31,2004. Your regulatory cost charge has been calculated on t 2004, Notice of Proposed Regulatory cos:;~~!1~/~s Date: November 16,2004 (JV ) 1f LÄ\ ìJ Œ (ill~ !A\ ~ AIfASKA OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7tH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Phillips Petroleum Company Attention: Steven Arbe1ovsky, Cook Inlet Ops Mgr P.O. Box 66 Kenai, AK 99611 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $6,770.58. You previously paid an estimated regulatory cost charge of$I,716.33, leaving a balance of $5,054.25. One third of this balance, $1,684.75, is duenolaterth&lD~cember 15, 20Q~.Asecond payment of$1,684.75 is due no later than January 15,2005. A third payment of$1,684.75 is due no later than March 15,2005. Under 20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated on t 2004, Notice of Proposed Regulatory c/<tCges :l;)r tis Date: November 16,2004 (,/AJ ~ ~an, ChaÌnnan ~ fA /A~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION / f 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: Pioneer Natural Resources Company Attention: Scott D. Sheffield, CEO 5205 N O'Conner Blvd, Suite 1400 Irving, TX 75039 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5.05. You previously paid an estimated regulatory cost charge of$5.12, leaving a credit balance of $0.07. Your refund will be issued to you before December 31,2004. Date: November 16, 2004 / ') ~1~rŒ ]~ ~~~~~«!Æ Al"tASIiA OIL A1ft) GAS CONSERVATION C01YJJ.y....SSION FRANK H. MURKOWSKI, GOVERNOR 333 W. "{TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: UNOCAL Attention: Martin Morell, Mgr Oil & Gas P.O. Box 196247 l\nchorage,AJ( 99519-6247 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 AAC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $73,153.80. You previously paid an estimated regulatory cost charge of $18,544.40, leaving a balance of $54,609.40. One third of this balance, $18,203.13, is due no later than December 15,2004. A second payment of$18,203.13 is due no later than January 15,2005. A third payment of$18,203.14 is due no later than March 15,2005. Under20 AAC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska! AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 l\nchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Date: November 16, 2004 basis described in the October 6, 2005. Your regulatory cost charge has been calculated 2004, Notice of Proposed Regulatory Cost g DISC ) !A\~!A\~ FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AlWD GAS CONSERVAnONCO~SSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 INVOICE AND NOTICE OF REGULATORY COST CHARGE To: XTO Energy Inc Attn: William A. Miller, District Admin Mgr 52260 Shell Road Kenai, AK 99611-9704 YOU ARE NOTIFIED that, pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission has determined your regulatory cost charge and payment dates for the current fiscal year 2005. A copy of the Commission's order determining regulatory cost charges and payment dates is enclosed. Your regulatory cost charge is $5,322.25. You previously paid an estimated regulatory cost charge of$I,349.19Ieaving a balance of $3,973.06. One third of this balance, $1,324.35, is due no later than December 15,2004. A second payment of$I,324.35 is due no later than January 15,2005. A third payment of$I,324.36 is due no later than March 15,2005. Under 20 MC 25.620, you are required to pay each payment by its specified payment date. (Note: you may prepay all or part of the regulatory cost charge at any time.) Please make your checks payable to: State of Alaska/AOGCC Mail or deliver payments to: AOGCC 333 West 7th Avenue, Suite 100 Anchorage, AK 99501-3539 If you prefer to make a wire transfer payment, please call the Commission for instructions. Your regulatory cost charge has been calculated o~ )asis described in the October 6, 2004, Notice of Proposed Regulatory cost~; ij{~ ar 2005. Date: November 16, 2004 ( .! '/ ~ ~~an, Cha. 'In #2 ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 2005 REGULATORY COST CHARGE November 16,20049:00 AM NAME - AFFILIATION ADDRESS/PHONE NUMBER TESTIFY (Yes or No) (PLEASE, PRI,NT) / 1_ ", I _, ~J~ ~- ~~. C~J- '1:vù~~ ~ ----blt ~) ~ No t\.. D l'> ~'r) ) ) FRANK H. MURKOWSK/, GOVERNOR AI1A.SIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 NOTICE OF PROPOSED REGULATORY COST CHARGES FOR FISCAL YEAR 2005 Pursuant to AS 31.05.093 and 20 MC 25.615, the Alaska Oil and Gas Conservation Commission proposes to impose Fiscal Year 2005 regulatory cost charges as set out below: Operator Proposed Regulatory Cost Chan:;Je Aurora Gas LLC BP Exploration (Alaska) Inc. ConocoPhillips Inc. Evergreen Resources Inc. Forest Oil Corporation Marathon Oil Company North Slope Borough Phillips Petroleum Company Pioneer Natural Resources Company UNOCAL XTO Energy, Inc. $280.64 $2,673,094.53 $597,854.76 $106.32 $5,215.57 $10,978.66 $311.55 $6,770.58 $5.05 $73,153.80 $5,322.25 These proposed regulatory cost charges have been calculated using the formula set out in 20 MC 25.605(a) and using the following values in that formula: v OP for Aurora Gas LLC = 212,703 Bbl VOP for BP Exploration (Alaska) Inc. = 2,026,047,299 Bbl VOP for ConocoPhillips Inc. = 453,138,498 Bbl VOP for Evergreen Resources Inc. = 80,590 Bbl V OP for Forest Oil Corporation = 3,953,095 Bbl V OP for Marathon Oil Company = 8,321,168 Bbl V OP for North Slope Borough = 236,135 Bbl V OP for Phillips Petroleum Company = 5,131,700 Bbl V OP for Pioneer Natural Resources Company = 3,828 Bbl VOP for UNOCAL = 55,446,246 Bbl VOP for XTO Energy, Inc. = 4,033,953 Bbl VTOT = Bbl A = $4,270,300.00 F = $20,000.00 L = $877,206.29 ) ) The attached spreadsheets provide more detail on the production and injection volumes that determine each operator's VOP and on the calculation of the proposed regulatory cost charges. If you are listed above as an operator subject to a proposed regulatory cost charge, you may submit comments on, or request a revision to, the proposed regulatory cost charges by writing the Alaska Oil and Gas Conservation Commission at 333 West 7tt1 Avenue, Suite 100, Anchorage, Alaska 99501..3539. Any comments or requests must be received within 30 days from the date of this notice as shown below. A request for a revision to the regulatory cost charges must be accompanied by an explanation of the basis for the requested revision. A public hearing on the proposed regulatory cost charges will be held in accordance with 20 AAC 25.540 on November 16, 2004, at 9:00 am at the offices of the Alaska Oil and Gas Conservation Commission, 333 West th Avenue, Suite 100, Anchorage, Alaska. This notice is not an invoice. After the public hearing, the Commission will issue an order determining actual regulatory cost charges and will notify each operator subject to a regulatory cost charge of the amount of the person's a~u "egulatory cost charge and the payment dates. Operators will be credited for any estimat r89ulatory cost charges for the first quarter of fiscal year 2005 that have already ~ Date: October 6, 2004 C ( f , Ynl ) FY 05 Regulatory Cost Charges Estimate FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Estimated 2004 Lapse $ Total to use for Reg Cost Chgs $ Final FY2005 Operating Appropriation $ FY2005 Capital Appropriation $ FY2005 Appropriation $ Less Federal Receipts $ Total Designated Program Rec $ Less Estimated Permit Fees $ Less Actual 2004 Lapse $ Total to use for Reg Cost Chgs $ ) 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000 830,000 3,420,300 4,136,300 260,000 4,396,300 126,000 4,270,300 20,000.00 877,206.29 3,373,093.71 #1 ..---' 1 05 02140100 2 3 4 (\" i\ REQUISITIONED øç:~,,"'. ¡~\ ; " i¡ ,'. / 1i' A \ . VI ,1,- ,,~ \..:' '. . DIVISION APPROVAL: NMR FY ACCT 73451 LC PGM CC SY REF TYPE 1 VEN 2 ARD 3 4 FIN AMOUNT DIST UQ 02910 TOTAL OF ALL PAGES$ PAGE 1 OF 2 PAGES COMMENTS SEND INVOICE IN TRIPLICATE' AOGCC, 333 W. 7th Ave., Suite 100 TO Anchorage, AK 99501 NUMBER AMOUNT DATE SEE ATTACHED Advertisement to be published was e-mailed D Classified DOther (Specify) D Display Type of Advertisement X Legal THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: October 8,2004 ¿ Anchorage Daily News PO Box 149001 Anchorage, AK 99514 (907) 793 -1 ??1 DATES ADVERTISEMENT REQUIRED: October 6, 2004 PCN lody Colombie PHONE F AOGCC R 333 W 7th Ave, Ste 100 o Anchorage, AK 99501 M DATE OF A.O. AGENCY CONTACT AO-02514018 INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS ADVERTISING ORDER NO. ) NOTICE TO PUBLISHER ') STATE OF ALASKA ) Notice of Public Hearing STATE OF ,ALASKA Alaska Oil and Gas Conservation Commission Re: Proposed Regulatory Cost Charges for Fiscal Year 2005 The Alaska Oil and Gas Conservation Commission ("Commission") will hold a public hearing on November 16, 2004 at 9:00 am at the Commissions offices, 333 West ih Avenue, Suite 100, Anchorage AK 99501. The purpose of the hearing will be to receive testimony and statements on the final calculation of the fiscal year 2005 regulatory cost charges that the Commission proposes to impose on operators pursuant to 20 AAC 25 540. Copies of the Commission's proposal may be obtained from the Commission at the address set out above. Published Date: 10/8/04 AO#02514018 ) Anchorage Daily News Affidavit of Publication ) 1001 Northway Drive, Anchorage, AK 99508 PRICE OTHER OTHER OTHER OTHER OTHER GRAND AD# DATE PO ACCOUNT PER DAY CHARGES CHARGES #2 CHARGES #3 CHARGES #4 CHARGES #5 TOTAL 308418 10/08/2004 02514018 STOF0330 $70.()8 $70.08 $0.00 $0.00 $0.00 $0.00 $0.00 $70.08 STATE OF ALASKA THIRD JUDICIAL DISTRICT OdohU2A 8( P--{JøLj I NoticeofPubHcKecu'ing , STATE OF ALASKA , ,Alaska Oil and Gas , Conservation Commission [e~;=:~~:;~ I Gas Cón~etvatioìt comJ! mission ("Commission")' will hold a pUblic hearingl I On November 16,2004 atl 9:00 am at the COfJ1mis-: : sions offices, 333 West 7th I I Avenue, Suite 100, An- chorage AK 99501. The purpose of the hearing will be to receive testi- mony and statements on the final calculation of the fiscal year 2005 regu- latory cost charges that the Commission proposes to impose on operators pursuant to 20 AAC 25 540. C..' o:p'i),~.s()f. ,J!Þ~,. I ~gZ~i~~r~!~~d;~~~~~~j , dress set out above. If You a reél~ersøn: with o.cl.isQbility WhorTICl.V : needeJ $i):edcH, mOC!lf!cQ-: rion In order io cornmen; or TO otH:,nd rho?- Dublic tie-Dring pleo!.e conloc! Jodv Colombie 01 193,12':11. Teresita Peralta, being first duly sworn on oath deposes and says that she is an advertising representative of the Anchorage Daily News, a daily newspaper. That said newspaper has been approved by the Third Judicial Court, Anchorage, Alaska, and it now and has been published in the English language continually as a daily newspaper in Anchorage, Alaska, and it is now and during all said time was printed in an office maintained at the aforesaid place of publication of said newspaper. That the annexed is a copy of an advertisement as it was published in regular issues (and not in supplemental form) of said newspaper on the above dates and that such newspaper was regularly distributed to its subscribers during all of said period. That the full amount of the fee charged for the foregoing publication is not in excess of the rate charged private individuals. Signed ( ~f~PÞ£oJ Subscribed and sworn to me before this date: JohnK, Norman Chairman Notary Public in and for the State of Alaska. Third Division. Anchorage, Alaska MY COMMISSION EXPIRES: 0 q lu /gCO I Æ ¿~ '/ ~ Il"lUl(((((f;. , . \.\ \ ~'f:~~y ,~. ./"¡-....'/ LiM ð. Æ~~~~!~~!~~ _~ . b, ;'i~a ~P> _ _ ,,' ""li!M. ..~~~ . .... ....' . U1' ' '-'-~-~ "~- . ~ -.. -~~., "''''''''' .ð'" .¡..;;~ "::. '. . ~. ,q" : 1# "- -;:., . " . ~ Q:: AUA;'.· :)):\' ...;,.. , ~,\}.~, ' ~';';; .~ ~d,.> ... "\, :\ ""'..., L" 3'!' '.."....., ..... ,..,....' G'(FA!"?t~', <'"7' ,,"\' I'/l/¡)})U\) AD# 02514018 Publish:Octbber 8,2004 RE: Public Notice ) '\ ) Subject: RE: Public Notice From: legalads <legalads@adn.com> Date: Wed, 06 Oct 2004 15: 18:23 -0800 To: lody Cololnbie <jody _ colombie@admin.state.ak.us> Hi Jody: Here is the information on your first legal notice. I will have the second one shortly. Please let me know if you have any questions or need additional information. Account Number: STOF 0330 Legal Ad Number: 308418 Publication Date(s): October 8, 2004 Your Reference or PO#: 02514018 Cost of Legal Notice: $70.08 Additional Charges Web link: E-Mail Link: Bolding: Total Cost to Place Legal Notice: $70.08 Your Legal Notice Win Appear On The Web: www.adn.com: XXXX Your Legal Notice Win Not Appear On The Web: www.adn.com: Thank You, Kim Kirby Anchorage Daily News Legal Classified Representative E-Mail: legalads@adn.com Phone: (907) 257-4296 Fax: (907) 279-8170 ---------- From: Jody Colombie Sent: Wednesday, October 6, 2004 11 :57 AM To: legalads Subject: Public Notice «File: Ad Order form.doc»«File: ReQulatory Cost HearinQ 2005.doc» Thank you 1 of 1 1 0/6/2004 3 :24 PM 02-902 (Rev. 3/94) Publisherl )inal Copies: Department Fiscal, Departmer )eceiving AO.FRM STATE OF ALASKA ADVERTISING ORDER SEE BOTTOM FOR INVOICE ADDRESS NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02514018 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West ih Avenue, Suite 100 o ilnchorage,AJ( 99501 M 907-793-1221 AGENCY CONTACT DATE OF A.O. R JoCl)' Colombie October 6, ?004 PHONE PCN (907) 793 -1 ??1 DATES ADVERTISEMENT REQUIRED: T o ilnchorage Daily News PO Box 149001 ilnchorage, AK 99514 October 8,2004 THE MATERIAL BETWEEN THE DOUBLE LINES MUST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COpy OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of , 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires 02-901 (Rev. 3/94) AO.FRM Public Notice ') ) Subject: Public Notice From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 06 Oct 2004 11:57:15 -0800 To: Legal Ads Anchorage Daily News <legalads@adn.com> Thank you Order Cont~nt- Typ~: application':l11s\\'ord Content-Encoding: base64 __.·__"'_,·_M·_·_._·__"'_.·____.M~_..~_..""~._,.__~,."'.____,_.____~.._. .........................................., ---_._~_.._~~-- . . : : :: . . . Content-Type: applicationlmsword II ,Regulatory _ Cost_ Hearing_ 2005.doc I : : Content-Encoding: base64 , , :....................................................,........................................................................................................... .: ·_·__··_·····_·~~·...·~·,_··_.·_,w"'_··.,,_·.·.___·._.·~.·_n.·.".~___.,,__,___..........__._~_~_~_~_~______..._.___.__~w~_ .. ......................................................................................................................................................................................,: _""_·_·__~_··~,~_~··~,_¥_.._~_·_·~_._.._·__.._m_·~m_m....~.~~___,..'~_..~"'_~,_.._____."'m__.nn_m__."~~~.~.......;. 1 of I 10/6/2004 12:08 PM Notice of Public Hearing ) Subject: Notice of Public Hearing From: Jody Colombie <jody_colombie@admin.state.ak.us> Date: Wed, 06 Oct 2004 11 :53:40 -0800 To: undisclosed-recipients:; lof2 10/6/2004 12:08 PM Notice of Public Hearing 20f2 J ) Content-Type: application/ms\vord Regulatory_Cost _ HearinlL 2005.doc Content-Encoding: base64 10/6/2004 12:08 PM Citgo Petroleum Corporation PO Box 3758 Tulsa, OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth, TX 76102-6298 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 Jerry Hodgden Hodgden Oil Company 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 Kay Munger Munger Oil Information Service, Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland, OR 97201 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage, AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage, AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Gordon Severson 3201 Westmar Cr. Anchorage, AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage, AK 99519 James Gibbs PO Box 1597 Soldotna, AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna, AK 99669-2139 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 ) David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston, TX 77056 George Val:Jght, Jr. PO Box 13557 Denver, CO 80201-3557 John Levorsen 200 North 3rd Street, #1202 Boise, I D 83702 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 Penny Vadla 399 West Riverview Avenue Soldotna, AK 99669-7714 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks, AK 99711 111 Iv / >~ <:L /o/7/0cj