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Home My WebLink AboutCO 358Conservation Order Cover Page XHVZE This page is required for administrative purposes in managing the scanning process. It marks the extent of scanning and identifies certain actions that have been taken. Please insure that it retains it's current location in this file. ~-,~_~Z_ Conservation Order Category Identifier Organizing RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED (Scannable with large plotter/scanner) [] Other items OVERSIZED (Not suitable for plotter/scanner, may work with 'log' scanner) k~~~ofl~ of various kinds r-] Other ' BY: ,/"~~ARIA Scanning Preparation · . /si ' BY: ,~ MARIA DATE:/'(,_C,~ ~ ~'-(~.~ Production Scanning Stage I PAGE COUNT FROM SCANNED DOCUMENT: d'~(~ ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' YES NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: (SCANNING IS COMPLL~OINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES)- Ill General Notes or Comments about this Document: 5/21/03 ConservOrdCvrPg.wpd STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 The Application of Lapp Resources Inc. requesting pool roles for the development of a sequence of coalbeds in the vicinity of Houston, Alaska as a commercial methane reservoir. Conservation Order No. 358 Houston Gas Field Houston Coalbed Gas Pool July 6, 1995 IT APPEARING THAT 1. By letter dated April 25, 1995 Lapp Resources, Inc. requested a public hearing to establish pool rules for a new coalbed gas pool located in the area of Houston, Alaska. 2. A notice of opportunity for public hearing was published May 2, 1995. 3. A public hearing was held at the Oil & Gas Conservation Commission office on June 2, 1995. 4. The hearing record was held open until June 9 to allow for the submission of additional information from Lapp Resources, Inc. FINDINGS: 1. The project area is confined to one State of Alaska oil and gas lease, ADL 374135. Lapp Resources is 100% working interest owner in ADL 374135. , Previous exploratory drilling activity in the general vicinity of the proposed project area includes five petroleum exploratory wells and three coal coreholes. The five exploratory wells are the Rosetta No. l, 2, 3, 4, and 4A. Drilling occurred in the middle to late fifties. None of the exploratory wells encountered other than trace mounts of oil. 3. The prospective section for which development is proposed by Lapp Resources is best represented in the Rosetta 3 well between the surface and 2200 feet measured depth. 4. The distribution and quality of aquifers in the project area has not been established. 5. Lapp Resources' proposal is the first coalbed methane project planned for development in Alaska. Coalbed reservoirs have been commercially exploited as gas reservoirs worldwide for several decades. 6. Spacing requirements for coalbed reservoirs are generally less than conventional sandstone gas reservoirs due to the low permeabilities of coal. 7. Lapp Resources requests 40 acre spacing units and a 330' location offset from the spacing unit boundary. Conservation Order 358 Houston Gas Field i lr Page 2 8. Coalbed spacing requirements vary in the lower 48 states. At least three states, Alabama, Utah, and Wyoming, have established 40-acre spacing per well. Alabama prohibits opening the well bore to production within 330 feet of a spacing trait boundary. 9. Commercial coalbed methane production may require &watering coal seams using a downhole pump until gas begins to flow at an economic rate. It may be necessary to vent or flare some gas during the dewatering phase. 10. Water produced from the coal seams will require disposal. Lapp Resources has yet not finalized disposal plans, but may propose injecting produced water into receiving formations. 11. Previous drilling in the project area vicinity encountered gas beating sandstone at depths proposed for development by Lapp Resources. 12. AOGCC statewide oil and gas regulations are applicable to conventional oil and gas reservoirs in the absence of specific pool rules. 13. Lapp resources proposes to drill it's typical coalbed methane well as follows: a. drill eight inch surface hole to approximately 300 feet. b. set six inch surface casing to 300 feet and cement to surface, install blowout preventer equipment. c. deepen hole to approximately 2100' with a coiled tubing unit using gelled water with bentonite for fluid control. d. set 3.5 or 4 inch production casing to T.D. and cement to surface. e. log production hole using standard oil field logging tools. f. complete each well with a downhole pump, either a progressive cavity or jet pump, suspended from tubing. 14. Lapp Resources identified six locations for possible development, and plans to drill three wells during the first year of development and evaluation. 15. Lapp Resources submitted separate estimates from Schlumbeger and Haliburton, ranging from $8,400 to $10,000, for plugging and abandoning each well. 16. Lapp Resources estimates rates of approximately 200,000 cubic feet of gas per day from the project area. 17. Lapp Resources estimates reserves at approximately 2 billion cubic feet per 40 acre spacing unit assuming 300 cubic feet of methane per ton of coal. The estimated recovery factor is 50% of the gas in place. Conservation Order 3 58 Houston Gas Field Page 3 CONCLUSIONS 1. Pool rules for the initial evaluation and development of the Houston Coalbed Gas Pool are appropriate at this time. . Previous drilling in the immediate vicinity of the proposed project area has substantively delineated the potential resource and local drilling hazards. The project wells are not anticipated to encounter liquid hydrocarbons. 3. Forty acre spacing units with a 330 foot standoff from drilling unit boundaries are appropriate for initial drilling and evaluation of the coalbed gas seams expected to be productive in this pool. 4. Statewide spacing requirements are appropriate for any sandstone reservoirs that may be encountered. 5. Ultimate field development plans will be predicated on evaluation of initial wells. 6. Flaring or venting gas during coal seam dewatering and gas flow rate evaluation may be appropriate and necessary. 7. Underground disposal of produced water must comply with statewide regulations, 20 AAC 25. 8. Bond requirements may be reduced to cover the lower costs of plugging shallow coalbed gas wells. 9. The operator's plans for well construction should adequately protect any freshwater aquifers from possible contamination. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth, in addition to state-wide requirements under 20AAC 25 (unless revised by this order), apply to the following described area referred to in this order as the affected area: SE1/4 NE1/4, N1/2 SE1/4, SW1/4 SE1/4, El/2 SW1/4, Section 21; T18N, R3W, SEWARD MERIDIAN Rule 1. Field and Pool Name The field is the Houston Gas Field. The hydrocarbons contained within coal seams within 2200 feet of the surface in the affected area constitute a single coalbed gas reservoir called the Houston Coalbed Gas Pool. Rule 2. Pool Definition The Houston Coalbed Gas Pool is defined as the accumulation of coalbed methane found in coal seams common to and correlative with the surface to 2200' MD interval in the Rosetta 3 well. Rule 3. Well Spacing A coalbed methane drilling unit will consist of 40 acres. No coalbed methane wellbore may be opened to production within 330 feet of a spacing unit or property ownership boundary. Conservation Order 358 Houston Gas Field Page 4 Rule 4. Bond Requirement A bond in the amount of $10,000 for each well drilled will be required to cover the cost of plugging and abandoning the well. The bond must be filed in accordance with 20 AAC 25.025. Rule 5. Diverter Requirement A diverter is not required while drilling surface casing hole. Rule 6. Gas Flaring Gas may be temporarily flared or vented during periods of dewatering coal seams and while evaluating a coalbed gas well commercial rate, or for no more than 6 months, whichever is less, without specific authorization from the Commission. Gas disposition must be reported according to 20 AAC 25.235 on a monthly basis. Rule 7 Development and Depletion Plan Within one year after the start of test production, the operator shall present to the Commission a more definitive development and depletion plan for this pool. Thereafter an annual reservoir surveillance report will be required. Rule 8 Administrative Action Upon request by the operator or upon its own motion, the Commission may administratively amend this order if the revision does not promote waste, jeopardize correlative rights, and is based on sound engineering principles. David W. ~l~Ch~~-~an Russell A. Douglass, Comndtssioner 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 ifa 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 mm from the date on which the request is deemed denied (i.e., 10th day after the application for rehearing was filed). TONY KNOWLES, GOVERNOR 5L&SKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: .,907) 276-7542 August 10, 1998 ADMINISTRATIVE APPROVAL NO. 358.04 Re: The application of GRl. Inc. to reduce well spacing in thc Houston Gas Field from 40 acres to 10 acres per well. David W. Lappi GRI, Inc. 4900 Sportsman Drive Anchorage, Ak. 99502 Dear Mr. Lappi: In correspondence dated July 23, 1998, GRI, Inc. requested reduction of well spacing within the Houston Gas Field from 40 acres to 10 acres per well. Thc Commission notes that five and 10 acre spacing units are common in coalbed methane fields elsewhere in the countw because of the typically low pem~cability in these unconventional reservoirs. The Alaska Oil and Gas Conservation Commission hereby authorizes thc reduction of spacing units within the Houston Gas Field from 40 acres to 10 acres pursuant to Rule 8 of Conservation Robea N Clmstcnson, P E Camill60echsli Chainnafi~ Commissioner Co~mnissioner BY ORDER OF THE COMMISSION ~ f:' AA358-,11 )(:)C dr' TONY KNOWLE$, GOVE~tNOi~ ALASKA OIL AND GAS CONSERVATION COMMISSION December 15, 1997 ADMINISTRATIVE APPROVAL NO 358.2 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re: The application of LAPP Resources, Inc. to revise the affected area of Conservation Order No. 358 Mr. David W. Lappi LAPP Resources, Inc. 4900 Sportsman Drive Anchorage, AK 99502-4169 Dear Mr. Lappi: The Alaska Oil and Gas Conservation Commission ("AOGCC") has received your correspondence dated November 25, 1997 requesting expansion of the affected area of Conservation Order No. 358 to include the SE¼SE¼, Section 21, T18N, R3W, Seward Meridian. The proposed expansion of the Houston Coalbed Gas Pool area will occur entirely within the boundaries of state oil and gas lease ADL 374135. You are the current and sole owner of the lease. Expanding the area will allow you to locate a proposed well in an area previously disturbed by surface activities. Your primary consideration in selecting the well location is to reduce the surface impacts of your project. The AOGCC agrees that minimizing the footprint of oil and gas development is desirable and that the proposed expansion will not cause waste nor violate correlative rights. The affected area of Conservation Order No. 358 is amended to: SE¼NE¼, N½SE¼, SW¼SE¼, E½SW¼, SE¼SE¼, Section 21, T18N, R3W, Seward Meridian. David W Joh Chairi~ tston Robert N. Christenson Commissioner Commissioner ALASI~& OIL AND GAS ~ CONSERVATION COM~HSSION Administrative Approval No. 358.1 TONY KNOWLE$, GOVEF~NOFt 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ The application of LAPP Resources Inc. to amend spacing requirements of Conservation Order No. 358. David W. Lappi LAPP Resources Inc. 4900 Sportsman Drive Anchorage, Alaska 99502-4169 Dear Mr. Lappi: The Alaska Oil and Gas Conservation Commission (AOGCC) has received your letter of July 11, 1995, requesting modification of the well spacing requirements of Conservation Order No. 358. Specifically, you have requested that the 330 foot offset from the drilling unit boundaries be removed in favor of establishing a 500 foot offset between producing wells. The AOGCC agrees that minimization of the footprint of oil and gas development is desirable and that the 330 foot setback from a 40 acre drilling unit boundary is unduly restrictive. Accordingly, Rule 3 of Conservation Order 358 is amended to read: A coalbed methane drilling unit will consist of 40 acres. No coalbed methane wellbore [nay be opened to production within 330 feet of the affected area boundary or within 500 feet of another well drilling to or capable of producing from the same pool. DONE at Anchorage~ Alask David W. Johnston Chairman ~ ~ 'Russell A. Douglass Commissioner Tuckcrman Babcock Commissioner TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279~1433 FAX: (907) 276-7542 July 14, 1998 Mr. David W. Lappi GRI, Inc. 4900 Sportsman Drive Anchorage, AK 99501 Dear Mr. Lappi' Your request to pump formation waters derived from coal seams into a deeper interval without producing the water to the surface was requested and approved for the Houston Gas well No. 3 by Disposal Injection Order No. 14. Accordingly, we are returning the enclosed three Applications for Sundry Approvals for the Houston 1, 2 & 3 wells. We also understand that you do not plan to use the Houston No. 1 and No. 2 for subsurface disposal. Si David W,<. Johnston ~ -"---.~.~'~,, Chairman "~ Enclosures Lappi conversation Subject: Lappi conversation Date: Wed, 17 Jun 1998 10:09:47-0800 From: dave_johnston~admin.state.ak.us (David W Johnston) Internal Organization: DOA-AOGCC To: Camille Oechsli <cammy_oechsli@admin.state.ak.us>, Robert Christenson <robert_christenson@admin.state.ak.us> Dave Lappi called me yesterday to inquire about the status of his disposal orders for the Houston gas field. He stressed his need for the surface disposal order because he has already has produced water to the surface, which is being held in a surface containment area measuring 100 ft by 100 ft by 10 feet deep. Also, the Houston 1 and 2 wells are drilled only to the producing coal seam, no deeper. Consequently, the subsurface water transfer option is not feasible for Houston 1 and 2. He must produce water to the surface in order to dewater the coal in these wells. He does not believe expanding the disposal zone to include sand layers higher in the section will solve his problem. Apparently, he wants to maintain flexibility in well depth (i.e., he doesn't necessary want to drill all wells with a rat hole below producing formation) and is concerned about charging up coal seams lower in section that he may later want to produce. As his development currently stands, he wants approval to use Houston 3 for subsurface water transfer as well as for disposing produced waters and other wastes from Houston 1 and 2. 1 of 1 7/14/98 8:28 Ai~ '98-06-19 1B:40 +1 90? 248 ?2?8 LRPP RESOURCES ~-) GRI, Inc. 4~0 S~sman Drive An~omge, Alaska U~ 99502~69 Telephone: 1 (~ 24~7188 ~mail: lapres~alaska.~t Facsimile: I (907)248-7278 DAT~ ? TOTAL # OF PAGES TO_ FAX NUMBER FROM REGARDING PLEASE CONTACT US IF YOU HAVE QUESTIONS ON THIS FAX. RFGFiVFO Exploration and Development J u~ 1 9 1998 AIm~Oil&GasC(ms.~n JUN '1 9 ~998 AlaSka Oil & Gas,Cons. Commi,~sion '9B-06-i9 1B:~l +1 907 E~B 7ETB L~P ~E$OU~CKS P-B 1850 1900 ~ .... .~0~ Sand 16 GR O.H. Zone below 1886 fl. appsars to be severely washed out and cement filled. c_: I Cement behind pipe is consistent with an apparent neutron porosity of 48%, denstly reading of 2.4 g/cc, and GR of 40 APl. These readings contrast with the wellslte geologist's cuttings description, which shows a fairly clean conglomeritlc send beginning at 1885 ft. No quantitative analysis Is possible In the washed out Intewal. .. _ .N~.u !r?.n..(.s.pl_ic' .... .M.?.t. IA48;.940~J ........ _vv_~_t _e S _8_n_~ u.,? t_i _o _n ..... 0.6 0 2 200 1 -1 Density (splic 1.5 3,5 2 .... .N...P.!i.U...-,2F, l~.e. ?. .... 0.6 0 ILD IA4_89._399_.]__.__ P.._o_r.,.osi?__~_._~__. 200 0.5 0 .... { ohm .~i_) ..... ~_~ Water Hydrocarbon X Zone Water (/) C :x --t --I ~ 0 0 z z 0 0 Z o. C m o9 z .r- 'T' ~ 0 ~ ' [1'1 I=":: l.['! .ir.: ~-,i" l t'm w~,h '~,.~me lo,: al~on ,~nd [',nt¢,hoh, r¢..h:r,.,n,.~., .dat',-~ 'w,,,,,.', hjr n,.",l~n,'¢ i~'me All irlt~21llrf,l,.lh, lllr.¢ ~,.~ Prloo · . , {.'~r~ (') II. t~ ~';A:. I 16 ', 1ri .I Moved I iydrocarbon __ X Zone Water C)uartz' --f TONY KNOWLE$, GOVE. RIVOFt ALASKA OIL AND GAS CONSERVATION COMMISSION June 11, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 David W. Lappi GRI, Inc. 4900 Sportsman Drive Anchorage, AK 99502-4169 Dear Mr. Lappi: CONFI~ ::~.. Z iON COPY THIS IS THE ORIGINAL, FOR YOUR RECORDS, OF A FACSIMILE TRANSMIS,~N SEISin. TO. /._~..~'~ /.~_ You have filed applications for approval of subsurface transfer of water from coal seams in the Houston 1, 2 and 3 wells and approval of an area injection order for the Houston Gas Field. Both these applications require that you comply with the provisions of 20 AAC 25.252. The Commission has a number of questions. l. . . . 10. Which well(s) does GRI, Inc. propose to usc for disposal operations of surface fluids? Is GRI, Inc. proposing the same injection zone for thc subsurface transfer of water and other injection operations? Please provide thc name, description, depth, and thickness of the formation into which the fluids arc to be injected and provide appropriate geological data on thc injection zone and confining zones, including lithologic description and geologic name. Your well casing information dcscribcs thc Houston 3 well with thc subsurface pump that GRI, Inc. proposes to use for the subsurface transfer of water. Is GRI proposing this well design for the wells disposing of fluids from the surface'? If so, is GRI, Inc. proposing to use the well as both a producer and for disposal'? If not, why isn't there a proposal for a dedicated injector equipped with proper tubing and packer as provided for in the regulations? How will the fluids at the surface reach the subsurface pump at the rate of 1 barrel per minute, for an average of 1130 barrels per da5'? Will the well be equipped with a surface pump? Please describe thoroughly what thc surface operation will look like. With respect to thc subsurface transfer of water, is there an estimated maximum amount to be injected dailv? Please provide the commission with evidence and data to support a finding that both proposals will not initiate or propagate fractures through the confining zones. Please provide an analysis of thc water within thc formation into which fluid injection is proposed. If the analysis GRI, Inc. has already provided addresses the specific disposal zone, please identify the disposal zone. Will all the proposed wells in the Houston Gas Field be equipped with a subsurface pump? Will some water still conic to thc surface'? Please explain v,h.x., some documents use GRI, Inc. and other documents use Growth Resources, Inc.'? The Commission understands thc5' arc two separate entities. David W>J~hnston Chairman GRI, Inc. 4900 Sportsman Drive Anchorage, Alaska USA 99502-4169 Telephone: 1 (907) 248-7188 e-mail: lapres@alaska.net Facsimile: 1 (907) 248-7278 June 15, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ORIGINAL Attn: The Commissioners Re: Justification for Ten-Acre Spacing - Houston Gasfield, Houston Coalbed Gas Pool Dear Commissioners: The Houston Coalbed Gas Pool currently has a minimum 40-acre spacing requirement for production wells. This spacing was set prior to drilling our three production wells. Our drilling since January this year showed more than 100 feet of coal exists per 1000 feet of section, giving about 200 feet of coal in each well. It was anticipated prior to drilling that our wells would encounter only 40 feet of coal per 1000 feet of section. Given the greater coal thickness in our wells (more than double what we anticipated), we believe that it is now appropriate to reduce the well spacing. The greater coal thickness means that our wells could each produce for a much longer period of time by producing one set of seams at a time. As the production from one set of seams declines, new seams can be perforated and the production rate from the well maintained. This will allow for a greater ultimate recovery of gas from all the seams than sizing the production equipment for the maximum possible production rate from all seams, leading to a shorter well life and lower ultimate recovery of gas. A smaller well spacing will also allow us to equip the field for production more economically and with less environmental impact, and reduce the number of access roads, power lines, and flow lines needed for a given volume of production. Given the large number of coal seams in the wells, a ten-acre well spacing would also allow for simultaneous production from multiple seams at different depths. For example, five seams could be produced in one well from 1500 to 2000 feet, while in another well, five more seams could be produced from 1000 feet to 1500 feet. Sincerely, David W. Lappi - President Exploration and Development GRI, Inc. 4900 Sportsman Drive Anchorage, Alaska USA 99502-4169 Telephone: 1 (907) 248-7188 P.1 e-mail: lapres(~alaska.net Facsimile: I (907)248-7278 June l S, 1998 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 Attn: The Commissioners Re: Justification for Ten-Acre Spacing - Houston Gasfield, Houston Coalbed Gas Pool Dear Commissioners: The Houston Coalbed Gas Pool currently has a minimum 40-acre spacing requirement for production wells. This spacing was set prior to drilling our three production wells. Our drilling since January this year showed more than 100 feet of coal exists per 1000 feet of section, giving about 200 feet of coal in each well. It was anticipated prior to drilling that our wells would encounter only 40 feet of coal per 1000 feet of section. Given the greater coal thickness in our wells (more than double what we anticipated), we believe that it is now appropriate to reduce the well spacing. The greater coal thickness means that our wells could each produce for a much longer period of time by producing one set of seams at a time. As the production from one set of seams declines, new seams can be perforated and the production rate from the well maintained. This will allow for a greater ultimate recovery of gas from all the seams than sizing the production equipment for the maximum possible production rate from all seams, leading to a shorter well life and lower ultimate recovery of gas. A smaller well spacing will also allow us to equip the field for production more economically and with less environmental impact, and reduce the number of access roads, power lines, and flow lines needed for a given volume of production. Given the large number of coal seams in the wells, a ten-acre well spacing would also allow for simultaneous production from multiple seams at different depths. For example, five seams could be produced in one well from 1500 to 2000 feet, while in another well, five more seams could be produced from 1000 feet to 2000 feet. Sincerely, David W, Lappi- President/// U U N ' 1 b 998 aska 011 & GasCms. Commit'on Exploration and Development ORIGINAL ........ HA¥-19-'98 TUE li:51 ID:LAPP RESOUECES INC TEL NO:i 987 248 ?278 ~316 P01 ....... GRI, Inc. 4900 Sportsman Ddve Anchorage, Alaska USA 99502-4169 Telephone: 1 (907) 248-7188 e-mail: lapres(~alaska.net Facsimile: I (907) 248-7278 May 18, 1998 The Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Atto: The Commissioners Re: Houm)n Gasficld Spacing Reduction Dear Commissioners: GRI, lnc. has drilled three wells in thc Houston Gas Field. Based on thc drilling results from these three holes, we believe that sufficient coal and gas reserves exist in the field to justify a reduction in well spacing from 40 acres per well to 20 acres per well. In addition, a reduction in well spacing will allow us to place more wells on production with fewer miles of roads and gas gathering system, resulting in greater operating economies. David Lappi and Steve Thomas (both directors of GRI, Inc.) are both available to answer any question that you may have on this proposal. Sincerely, David W. I~ppi President ORIGINAL Exploration and Development DEC-04-'97 THU 15:35 ID:LAPP RESOURCES INC TEL NO: i 90? 248 '72?8 LAPP Resources, Inc. 4900 Sportsman Drive Anchorage, Alaska USA 99502-4169 e-mail: lapres@alaska.net ~092 P01 Telephone: I (907) 248-7188 Facsimile: 1 (907)248-7278 December 4, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Attn: Mr. David Johnson - Chairman Re: Area Expansion Request - Houston Oasfield, Houston Coalbed Oas Pool Dear Dave: Thank you for your letter of November 25, which I received yesterday, You have requested two additional items of information in relation to our request to expand the affected area: Doct~mentafion of Ownership, We have previously submitted a change in ownership form for the lease, a copy of which is attached. Also enclosed is the first page of the lease, and a map and legal description from the lease, and the DNR-approved transfers from Unocal and Marathon to LAPP Resources, Inc. . Information about the Productive Limits of the Pool. The numerous coal seams in the Tyonek formation which are present in the area of the Houston Oasfield are regionally oxten0ive. Reoont worlc done by our company ha~ ehown that the coale encountered in the State's 1994 Wasilla corehole, AK-94-CBM1, can be reliably correlated with the corns encountereo m ttosetta ~, a~mougn me eqmvmem section at t~osetta ~ is auout 40% thicker. A copy of the well-to-well correlation is enclosed for your review. Since the new area requested lies between Rosetta 3 and AK-94-CBM1, we believe it is reasonable to conclude that the new area is underlain by the same clastic reservoirs and coal seams as the rest of the Houston Gasfield. Based on the results of prior drilling, we believe that the coal seams in this area are gas productive. Profitable gas production will depend on the cost of drilling, development, and operation. We request that the SEll4 of the SEll4 of Section 21 T18N R3W Seward Meridian be included by Administrative Approval within the Houston Gasfield, Houston Coalbed Gas Pool. Thank you. Sincerely, David W. Lappi President Exploration and Development TEL NO: 1 909 2z~8 92?8 "il STATE OF ALASKA . ~ . A' ~KA OIL AND GAS CONSERVATION COMMISSt NOTICE OF CHANGE OF OWNERSHIP 20 AAC 25.022 ~092 P02 1. Name of Operator UNION OIL COMPANY OF CALIFORNIA Address P.O. BOX 196247 ANCBORAGE, AK 99519-6247 3. Notice Is hereby given that the owner IM, landowne~ [] of record for the oll and gas property hae assigned or transferred Interest In the property indicated below: described b~ow Property designation: PIONEER U~IT Legal description of property: T~ACT 18 ~10.11~~ RA~G~- 3 WEST, SEWAI{D M]~IBIAN, ALASKA (Containing 2,765.22 acres more or T~ACT 67A-135 Seetio~"19: Section Section 21: Section 28: Section 29: Section 30: Section 31: Section 32: Section 33: less.) Surveyed, Fractional, Ail, 620.92 acres; Surveyed, SW/4 NE/4, S/2, S/2 NW/4, NW/4 NW/4, 480 acres; S,rveyed, SE/4 NE/4, SE/4~/2 SW/4, NE/4 SW/4, 320 acres; Surveyed, NE/4, 160 acres; Surveyed, SE/4, W/2, 480 acres; Surveyed, Fractional, Lots 2 and 3; NE/4, 231.62 acres; Surveyed, Fractional, Lots 1 and 2, NE/4, E/2 NW/4, 312.68'acres; Surveyed, N/2 NE/4, 80 acres; Surveyed, E/2 NE/4, 80 acres. Property Plat A~ached~ 4, EffectNe date ofasslgnmentortransfer April 3, 1995 5. Percentagelnterestasslgnedortransferred I00% 6. Assignee or Transferee: LAPP RESOURCES INC. Address: 4900 Sportsman Drive Anchorage, AK 99502-4169 7. Assignor or Transferor: UNION OIL COMPANY OF CALIFORNIA Address: P.O. BOX 196247 (909 WEST 9TH AVENUE) Anchorage, AK 99519-6247 8, I hereby certify that the foregoing is true and correct to the best of my knowledge Date JUNE 30. 1995 _ Form 10.417, 12-1-85 Submit In Oupltcale DEC-04-'97 THU 15:37 ID:LAPP RESOURCES INC TEL NO:i 987 248 7278 : OMPETITIVE OIL AND GAS LEASE) NR I0-4037 (ReviseO 9/90) STA3~ OF ALASKA DEPARTMENT OF NATURAL RESOURCES C. om~ Oil and Ga~ ~ ADL No. 374135 Union Oil Company Of California 50% Marathon Oil Company 50% 'the la,mae,' whether one or more, whoso sole address for purposes of notification is under Paragraph 25, In consideration of the cash payment made by the lessee to the state, which payment includes the flat year's rental and any required cash bonus, and subject to the provisions of this lease, including applicable ettpulatk:m(s) and mitigating measures attached to this lease and by this reference incorporated in this lease, the state and the lellll agree as follows: 1. GRANT. (a) Subiect to me ~ovlstons in this lease, the state grants and teases to the lasses. without warranty, the exclusive right to drill for, ex,'act, remove, clean, process, and dispose ct oil. gas, and a~xHated substances in or unoer the followincJ described tra~ of lan(t: Tract 67A-135 T. 18 N., R. 3 W., Seward Meridian, Alaska Section 19, Surveyed, Section 20, Surveyed, Section 21, Surveyed, Section 28, Surveyed, Section 29, Surveyed, Section 30, Surveyed, Section 31, Surveyed, Section 32, Surveyed, Section 33, Surveyed. Fractional, All, 620.92 acres; SWI/4NEI/4, Sl/2, S1/2NW1/4, NWI/4NWI/4, 480 acres; SEI/4NE1/4, SE1/4, S1/2SW1/4, NE1/4SW1/4, 320 acres; NEll4, 160 acres; SE1/4, W1/2, 480 acres; Fractional, Lots 2 and 3, NE1/4, 231.62 acres; Fractional, Lots I and 2, NE1/4, E1/2NW1/4, 312.68 acres; E1/2NElI4, 80 acres. ~ ri~.'l.' ~' ' containing approximately 2765.22 acres, more or less (relenTed to In this lease as the "leased area'); the nonexclustva right to conduct within the leased area geological and geophysical exploration lot oil, gas, and substances; and the nonexdusive right to install pipelines and bui|d structures on the leased area to find, prm:luoe, save, store, treat, process, transport, take oars of, an(t market all oil, gas, and associated at~.b?tances a. nd .to. house and board employees ~n its operations on the leased wen. The right~ granted by this lea?e are. ~o be. e. xerctae?_._m_? which will not unreasonably Interfere with the rights of any permittee, levee or grantee el me stats consmtem w~ me pdncip{® of rsasona01e concurrent uses as set out in article VIII. section 8 of the Alaska Constitution. (b) For the ~urposes of this lease, the leased area contains the legal subdivlsion~ al shown on the attached plat marked Exhibit . (~) If the leased ~rea is described by prolracted legat subdivisions and, after the effective date this lease, Ihs leased area is surveyed under the public land reclangulw' system, the boundaries of the lela~d area are those established by that survey, when approved, subject however, to the provisions of applicable regulations relatl.ng to those sur~eys. If for an~ reason the leased area {~cludes more acreage than the maximum pemlffteci under applicable law ('including the rule of approximatfon" authorized in AS 38.05. ! 4~ and defined in AS 38.05.965 (17)), this le~ is not void and the e~reage in<:i~ed in the leased area must be reduced to the pe~mitted maximum. If determines that the llaemd m'e. exceede the permitRed acreage and..no~lea the I.eseee in wrlfl~l? ,o_~_t_,he_..~m~le~tol a~eage that mu~t be eliminated, the lessee has ~0 days after ~at noires [o. s.urrencl.er, ans..or..m_.o_r~ ~e~a_~. ir~uded in the leased area com0ristllg at least the amour~t el ac~asge ~a! mu~t De ellm~nateo. /~n~/ surrendered must be lo~ate~i on the perimeter of the leased area a.~ originally described. If a surrender ia not filed DEC-04-' 9? THU 15:~8 I D: LAPP RESOURCES INC ~09~ P04 EXHIBIT A II Tract 67A-135 T. 18 N., R. 3 W., Seward Meridian, Alaska Section 19, Section 20, Section 21, Section 28, Section 29, Section 30, Sccfion 31, Section 32, Sec6on 33, Surveyed, Fractional, All, 620.92 acrcs; Surveyed, SWI/4NEI/4. S1/2, S1/2NWI/4, NWI/4NWI/4, 480 acres; Surveyed, SE1/4NEI#;, SE1/4, $1/2SW1/4, NE1/4SWI/4, 320 ac-rcs; Surveyed, INEI/4, 160 acrcs; Surveyed, SEll4, Wl/2, 480 acres; Surveyed, Fractional, Lots 2 and 3, NE1/4, 231.62 acres; Surveyed, Fractional, Lots I and 2, NEI/4, E1/2NWI/4, 312.68 acres; Surveyed, NI/2NEI/4, 80 ac'rcs; Surveyed, EI/'2NE1/4, 80 acres. This tract contains 2765.22 acres more or lcss. DEC-04-'97 THU 25:39 ~D:L~PP ~ESQURCES INC t' , TEL 1'40:1 9~'7 248 ,,:,'8 \ ~092 P85 DEPARTMENT OF NATURAL RESOURCES TO: Houston DIVISION OF OIL AND GAS 3601 c STREET. SUITE I3,~0 ANCHORAGE, ALASi~4 ggSO$.Sg4~ PHONE: (907') 752-2549 APR ;. 1995 Assignor: Union Oil. Company of California Attn: Land Manager P.O, Box 196247 Anchorage, AK 99519-6247 Assignee: Lapp Resources Inc. 4900 Sportsman Dr. Anchorage, AK 99502-4169 DECISION APR 2 1 1995 OII and Gas Lease ADL 374135 Assiqnment ..Application Aooroved Application for approval of assignment of 50.0 percent working interest from Union Oil Company of California to Lapp Resources Inc. is hereby approved effective April 3, 1995. This assignment is approved as to the working interest only and does not constitute approval or acceptance el any stipulations or attachments to the assignment instrument, An approved assignment is enclo_~.ed with this decision. Kenneth A. Boyd Acting Director Enclosure KB/dS/c~3?4135. I TEL NO: 1 90? 248 ?2?8 ~092 P06 DO&G 25-84 (LEASE ASSIGNMENT) Revised 7/91 DNR #10-113 LEASE ADL: _374135 EFFECTIVE DATE OF LEASE: 4/1/91 STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS ASSIGNMENT OF INTEREST IN OIL AND GAS LEASE The undersigned assignor Union Oil. Comp_a..ny of California whose address.is P~O. Box 1.962.47, Anchora,qe, Alaska 995'19-6247 as owner of Fifty (50.%) percent of the lease's working interest Zero ¢0%~ .. percent overriding royalty interest does hereby assign to LAPP Resources Inc. , the assignee, whose address is ._ _4900_Sportsman Drive, Anchorage. AK 99502-4169 . 1 .... Fifty ¢5_0%) _ _ percent working interest; 2. Ze. ro {0.%) . _ percent overriding royalty interest. 3. The assignor is retaining .Zero (0%) percent of the lease's working interest. 4. The assignor is retaining ,Zerq (0%) percent overriding royalty interest. 5. The assignor previously reserved Zero (0_%) percent overriding royalty interest. '6. The assignor previously conveyed Zero (.0%) percent overriding royalty interest. 7. LANDS AFFECTED by this assignment of interest T 18 North, R 3 Wes._..._._.Lt, Seward Meridian Tr'ac '67A,-13~'"" ' ' '. " · ~ Se_c. tion 19:. Sectiorf "20f-. section 21: , Section 28: Surveyed, Section 29: Surveyed, Section 30: Su.rveyed, Section. 31: Surveyed, Section 32: Surveyed, Section 33: Surveyed, Surveyed, .Fractional, All, 620.92 acres; 8.~ryeyl~l. ','~S~'1~4 NE1/4, S1/2, S1/2 NWl/4, NWl/4 NWl/4; 48Q acres; Surveyed, SE1/4 NE1/4, SEt/4, S1/2 SW1/4, NE1/4 SW1/4, 320 acres; NE1/4, 160 acres; SE1/4, W1/2, 480 acres; Fractional, Lots 2 and 3, NE1/4, 231.62 acres; Fractional, Lots 1 and 2, NE1/4, E1/2 NWl/4, 312.68 acres; Nll2 NE1/4, 80 acres; EI/2 NE1/4, 80 acres. containing. 2.765,2~ acres, more or less. :['he Notific~iion Lessee for the purpose of receiving any and all notices from the Slate of Alaska in connection with the lease will be: Name .I~PP _Resources Inc. Address 4900...Spo.rtsman Drive City, State, Zip Attn: David Lapl:)i Anchora_~e. AK 99502-4169 We, the undersigned, request the approval of this assignment application. We attest that this application discloses all parties receiving an interest in the lease and that it is filed pursuant to 11 AAC 82.805 and 11 AAC 82.615. We further attest that alt parties to this agreement are qualified to transfer or hold an interest in oil and gas leases pursuant to 11 AAC 82.200 and 11 ,AAC 82.205. Whether approved in whole or in part, the assignee agrees to be bound by the provisions of said lease. Ase~nor's $1gna{ure TEL NO:I 90? 248 ?2?8 Kevin A. Tabler. Att. orPe¥-in-Fact .Assignor's Name (Print or Type) & Title THE UNITED STATES OF AMERICA STATE OF ALASKA ~092 PO? Date 3--.gl- %-_.._ Union Oi[. Company .of California~ Company Name 6 This certifies that on the 31st day of March. , 1995, before.me, a notary public in and for the State of Alaska, duly commissioned and' sworn, personally appeared Kevi .n A. T.abler, to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day an~ year in this certificate first above written. OFFICIAL ,~_..A L Stmte of Alaska NOTAR¥ PUBLIC I Roxanne M. Sinz ... Assignee's Sighature 1 / Notary Public ~" My Commission Expires~..,_./~./?~,'~ ' Date / / Assignee's Name (print or Type) & Title Company Name THE UNITED STATES OF AMERICA STATE OF ALASKA ) ) ss. ) Qualification File fl~:,2 ~_..~___.~~ This certifies that on the~_...~day of _~,,¢.,~.,~. , 1995, before me, a nRtary public in and for the State of Alaska , duly commissioned ahd sworn, personally appeared,~~..._,~,/u', to me known and known to me to be the person described in, and who executed the foregoing assignment, who then after being duly sworn according to law, acknowledged to me under oath that he executed same freely and voluntarily for the uses and purposes therein mentioned. WITNESS my hand and official seal the day and year in this certificate first above written. ! o.,,o,,,. [ State of Alaska / i ~oT^~¥ eu~.i¢ / J Fioxanne M. Sinz J My Commillton ExplrM Augu$11 1997 Notary Public ~ ~) My Commission Expires /"/-~?._ APPROVAL The foregoing assignment is approved as to the lands described in item 7 thereof, effective as of the date set forth below. ~ .Sta'fe~f Alaska Effective Date of Assignment KENNETH A. BOYD ACTING DIRECTOR DIVISION OF OIL S GAS DEC-04-'97 THU 15:4~ ID:LRPP RESOURCES DEPARTMENT OF NATURAL RF_~OURCES DIVISION OF OIL AND GAS TEL NO:i 987 248 7278 {" "092 P08 TONY KNOWLES, GOVERNOR 3601 C STREET. SUITE I380 ANC, HORAGE. ALASKA 99503.594~ PHONE: (907) 762.2549 Assignor: Marathon 011 Company Attn: Contract and Division Order P.O. Box 2069 Houston, TX 77252-2069 Assignee: Lapp Resources Inc. 4900 Sportsman Dr. Anchorage, AK 99502-4169 DECISION APR 1.1995 Oil and Gas Lease ADL 374135 Assianment Application Approved Application for approval of assignment of 50.0 percent working interest from Marathon Oil Company to Lapp Resources Inc. is hereby approved effective April 3, 1995. This assignment is approved as to the working interest only and does not constitute approval or acceptance of any stipulations or attachments to the assignment instrument. An approved assignment is enclosed with this decision. Acting Director Enclosure Kl~JS/di/3?4135.2 ..................... D~C-84-'~? THU ~5:4~ ~:LRPP ~ESOU~CES ,~' TEL NO: 1_ 90'7 248 ,772?8 .092 P09 DO&G 2544 LF_.A$E DNR #10-113 LEASE ADL, 374135 STATE OF ALASKA DEPART~{ENT OF NA~ D~ION OF O~ ~ND GAS ASSIGNMENT O? INTEREST L~ OIL AND GAS LEASE ~t~or Marathon Oil Company _P.O. Box_ 196168 Anchorage, AK 9g'519-616~I' , i m ii i i i i i m ~s ownerof , Fifty f50%) ........ ~ Of~ l~w~m~'s WOr~lg m~mm~ do~~~m LAPP,Resources.,., ,, Inc.,, , , _ , .~~. w~~~~ 4900 Sportsman Drive Anchorage, AK 99502-416~ m mm m mm m ' t. Fifty (50%) m in i · ,11 2. Zero (0%) iii i i i i : ~ mi i !. Th~ tssi_mor ts rctamm~ Zero l O,~o') 4, The assillfior is reaming One (1%) percent working ~rra:nt ovcrnomg mymy inmrcs~. 5. The~ip~orpmviousty rescrveci ZERO (0%) , 6. The m.m~or lm:viousty convcyeO Zero (0%) 7. ~S ~~D by ~s ~si~ent of in~ T 18 NoPth. R m _3 ¥~est~ . Seward Mendi~ ~rcent of the lea.se's woming mmrcst. ~r=nt ovemding royalty interest. percent ovemdin~ royalty interco. pemcnt overriding royalty inmmst. Section lg: All Section 20: SWtNEt,St ,S½NWt,HWiNWt Section 21: SEtNEt, SEi,S½SWi,NEtSWi Section 28: Section 29: SEt, Wi Section 30: Lots 2 and 3, NE¼ Section 31: Lots I and 2, NE½, E½NWI Section 32:Ii½NE¼ Section 33; EiNE¼ 620.92acres 231.62 acres 312.68 acres comaining: 2,765,22 , acres, mom or less. - i mi m i i i I mi, mi Ji I , i £L , mL i I I - Tho Notifimtion ~ for the purpose of receiving any and all nouces from mc Sram of Ala.s~ in connection Nmme LAPP Resources Inc. Amn: 'David Lapp½ " ' .~dd:S4~ou SPO~{sman O6'~ve ..... I m --- i i -kCitT, S=m. Zip.Anchor...age,, AT-aSkj '~]gbOz'q~b~ ~.. I-7~ mi ~t/~. ~ ~le~~, ~ ~ aPProval of this ass, Bnm:m appUcaUon. Wc a~.st rim mrs appUr,~on Ui,~r, loses all 9atUe~ receivin~ an mmm.~ m tim lease ami that it is flied purmam to l I AAC 87.605 and 11 AAC 82.615. We furtll~ au~t ~ all parties ua tttis agreement ar~ .qualLQed to transI~ or hold an ~ in oil ami gall lr, a,w,s pmlmam~a 11 MC112.2~ ami 1I AAC g2_2Q& Whettmr ,appmv~ ~w~ or ~~ ~ ~~~ m b¢ boun{l ty ~ provisions of said l~ase, L.R. Dartez , Production Manager _ TEL NO: 1 987 248 7278 ~092 PlO Harathon 0il Company Company N~n~ THE UN171ED STATES OF AMERICA) )SS. Thi~~:ttmtonth: ,:.2~-~ clayo£ /¢74'~'~ L~ for ~ ~t~ of A1 aska ~~~m~ L.R.'"Da~tez, Production Manager Qualificanon File (~ 10 ,19 ~-~', ~forc mc. a rmtary ~ublic , , duly com3n~tone4 and s~vorn, , to mc known and known to mc to bc th-, P~$on'flemmibed m. and who cxccuted ~c foregoing a.~i~cnu w~o ~n ~r ~mt d~y ~om ~m~ to, law. ~w~d m mc ~dcr o~ ~t hc cxc~ s~c ~civ ~d vot~y for ~ u~ m~~. ~S my h~Q ~ off~ci~ s~ ~= day ~ vc~ m ~s ~c~ ~t a~vc ~n. ,,,% G. 7.. , , .. .C~ / , - ' ~?~-. ~: ~,' .~. $igna m / I Company Nm,,e Assi~'s Name (IMn( ~r ~f~tl~) & Title 1' _ff_~. b~for= me. a notary. ,uubti¢ in and fo: · Quiy comm'-_cq~ argl sworn. Dcr~oixaL 7 . to Ir.'.. I~0w lh'ld la~o~ tO rn~ to t~ tn-. I~rac: {teacflbed m. and wino cxrx:uted th-.. xo~gomg ~m~cnt. who men ~r ~mg o~y s~m ~mmg m ~. ~w~ to me ~er oa~ ~ he cxc~m s~c f~ly ~ yolky for ~c ~ ~d ~s~ ~c~, mm~d. ~S my h~O md o~]ci~ ii I ,i I OCFIOIAL 8F'AL State of Alaska NOTARY' PUBLIC Roxanno M. Sinz kt~ Comml~ion Explrel August 1,1997 · II I IIII seal thc nay ann ),car m r~Us cc~,~ first above wrincn. // APPROVAZ Thcbejov/~tot~-om~/.,t ' a~st m'Lrn tnt ts apomvcci asto~ds S~at~ of ~ KENNETH A. BOYD ACTING DIRECTOR DIVISION OF OIL & GAS ocscnu,.~d in item 7 tn-~rcof, eff-.zUvc as of mc oate set for'.' APR 0 3 1995 160.5 TEL NO:i 90~ ? ~ 72_?8 Resistivity (ohm metres) 322.5 403.5 484.5 525.0 606.0 646.5 727.5 808.5 849.0 889.5 930,0 970.5 1011,0 1092.0 1132.5 1173.0 1213.5 ~.g4 1375.5 1456.5 1537.5 -ID 1618.5 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION November 25, 1997 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 David Lappi Lapp Resources, Inc. 4900 Sportsman Drive Anchorage, Alaska 99502-4169 Dear David, We have reviewed your correspondence dated November 21, 1997 in which you identify three proposed well locations for coaibed methane development on ADL 374135. You asked if the proposed locations conform to the spacing requirements of Conservation Order No. 358 ("CO 358"), as modified by Administrative Approval No. 358.1. The CO 358 spacing rule, as modified, reads as follows: "A coalbed methane drilling unit will consist of 40 acres. No coalbed methane wellbore may be opened to production within 330 feet of the affected area boundary or within 500 feet of another well drilling to or capable of producing from the same pool." The rule does not compel the drilling unit boundaries to conform to governmental section lines. Normal practice, however, is to create drilling units that are uniform in shape and aligned with section lines. The proposed well location for the Houston #1 well appears to be within 330 feet of the affected area boundary of CO 358. You will need to relocate the well or, alternatively, request an expansion of the affected area to include the SE~A, SEV4, Section 2'1, TI 8N, R3W, Seward Meridian. A request to expand the affected area should include documentation of ownership and information about the productive limits of the pool within the proposed ex'3ansion area. Chairman ......... 248 7278 ~073 P01 .. NOU-21-'97 FRI 15:02 ID:LRPP RESOURCES INC TEL NO: i 907 LAPP Resources, Inc. 4gO0 Sportsman Ddve Anchorage, Alask~ USA 99502-4169 Telephone: ~ (907) 248-7'188 e-mail: lapres~alaska.net Facsimile: I (907)248-7278 November 21, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchor~e, AK 99501-3192 Mtn: Mr. David lohnson - Chairman Re: Proposed Coalbed Gas Ddllin8 Project, Houston Alaska Dear Dave: Enclosed is a survey plat ofthe area of our three proposed Houston drill sites, and an enlargement of the most pertinent area. The entire area of the plat is within our existing oil and gas lease, and within the Houston Crazfield. Drilling and production activities in the Houston Gasfield, Houston Coalbed Gas Pool, are resulated by a set of Pool Rules (Conservation Order No. 358) established by the Commission on July 6, 1995. The Pool Rules were amended by the Commission on July 18, 1995 to accommodate more flexible well pla~ment within the field to minimize surface disturbance at drill sites. The enclosed plat shows our proposed well sites which have been selected in consultation with the private landowners who own the surface estate at the drill sites, and each drill location is in an area previously disturbed by development. Our goal in selecting these sites is to minimize any possible disruption to local residents and landowners, and avoid disturbinl~ new sites in this wooded area. We are ready to prepare (clear brush, level, and grade) the drill sites for these wells, and would like you to confirm that the selected locations conform to the setback requirements of Conservation Order No. 358, as modified by Administrative Approval No. 358.1. Although we intend to use existing surface land surveys where possible, please also confirm that there is no requirement for drilling unit boundaries to be necessarily coincident with existing governmental land surveys and subdivisions. Thank you, Sincerely, David W. Lappi President RECEIVED NOV 1997 · aska 011 & Gas Cons. Commission Anchorage Exploration and Development LEGEND: I"IoNU~ENT NE 1/4~ :S~ 114 HEATH HEIGHTS SUBDIVISION NW ]/4, SE 1/4 0 ~-I.L , / cev~ 0 ~2' b4~' - ~t ~ECT~DN S:W ~I4, ~E 114 SECT[DN 88 HOU~,TGN e3 LAPP Resources lnc, 4900 Sportsman Drive Anchorage, AK U.$,A. 99502 Ph: 90%248-7188 Lot: 61-38-14 Lat: 61-38--11 Lot: 61-&8-12 Long: 149-50-27 Long: 14g-50-41 Long: 149- 50-54 ~ ~. Pn~<~ mw,. ~1% leS,, w~a~.~. ~ m~ ~D-O3.Bq I"~ bO ~F TLN ~PROPOU~D ~gLL LOCATg~ NE 1/4, S'w' 1/4 HE:ATH HFIGHT2 SUBDIVISION SE: 1/4, N~t 1/4, ,SE 1/4 ! 1~i~ W~TG~ . "'"' ' 0 ~LL ..' "" : 0 -. ~0- ' "~'~ ~2 64~' - ~~ ~ ~P, ~LL RECEIVED NOV ~ ~ 199~ ~ 0ii & Gas ~ns. ~mmi~on Anchoraoe ~A~ ~o~ Inc. 4g~ S~~ D~vc ~cho~ge, AK U,S.A. 99~02~169 Lot' SECTI:DN 61-38-14 6i-438-11 61-38-12 Long: Long: Long: 149--50--27 14.9-50-41 149-50-54 LAPP Resources Inc. 4900 Sportsman Drive Anchorage, Alaska U.S.A. 99502-4169 Telephone + 1 (907) 248-7188 Facsimile + 1 (907) 248-7278 July 11, 1995 The Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Sirs: Thank you for executing Conservation Order No. 358 on Thursday, June 6, 1995. I request that the Commission modify the Order (by administrative action under Rule 8 of the Pool Rules) to eliminate the 330 foot offset from the boundary of the 40 acre drilling units. The 330 foot offset eliminated much of the flexibility for the selection of drill sites on these small spacing units. Some of our proposed drill sites are located in previously disturbed areas with the appropriate access roads already in place. The 330 foot offset from drilling unit boundaries would require us to build new access roads, disturbing new areas. Eliminating the offset from drilling unit boundaries gives us the flexibility to use the previously-built access and previously-disturbed sites for our project, reducing costs and environmental impact. Although otherwise implied by the 40 acre spacing, units, the minimum distance between gas wells under current statewide regulations is 1500 feet. I suggest that a minimum spacing be specified, appropriate for our small drilling units, at a minimum of 500 feet between wells producing from the same pool. Thank you. Sincerely, David W. Lappi President R"ECEIVED jUL 1 3 1995 Alaska Oil & Gas Cons. Commission Anchow,L? ~UL-11-'95 TUE 15:29 ID:LAPP RESOURCES INC TEL NO:i 90? Tale~hone + 1 1907) 24B-7188 LAPP Resources Inc. 4900 Sportsman Drive Anchorage, Alaska U,S.A, 99502-4,169 Facsimile .t-1 (907)248-7278 July 11, 1995 T~e Commis~ionmz Alaska Oil sad Oa~ Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Sirs: Thank you for executing Conservation Order No, 3:58 on Thursday, ~'une 6, 1995, I request that the. C.ommission modify the Order (by administrafiv, e action under Rule 8 of the Pool Rules) to chromate the 330 foot off{et fro ,m..t.h.e boundary of the. 40 acre drilling units. The 330 foot offset eliminated much of the flex,blhty for the selection of drill sites on these small spavin8 units. gome of our proposmd drill sites ar~ locat~ in pr~iously disturbed areas with the al)pwpriat~ access wads ah',ady in place. The 330 foot offset fro,.m, d~illi,ng unit boundaries would re. quire us to build n?w aceel{a roads, disturbing n,w areas, l~hm~.n, atm8 the offset imm drillln8 unit boundari.s g,ves us the flexibility to use the. previously-bruit access and previously-disturbed mime for ou~ proj~t, ~:tuoing costs and enwronmentalimpaet. Although othcrwi~ impli ,~. by the 40 acre spacing units, the minimum distan, e betwmmn gas wells under current statew~de regulations is 15,0.0 feet. I suggest that a minimum spacing be slx~cif'_,~_, approprlat, for our small drilling units, at a minimum of $00 f~t betw~n wells pmdu¢,ng from the ~am¢ pool, Thank you, S~cei'dy, David w, Lappi Presider R££ IVI D '~' 1995 Gas Cons. Commission Anchorage COOK INLET REGION, INC. June 8, 1995 Mr. David W. Johnston Chairman/Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RECEIVED JUN -9 1995 Alaska Oil & Gas CoDs. Commission ltnchore:;;,? Subject: Lapp Resources, Inc. Request for Spacing Exception Coalbed Methane Production - ADL-374135 Dear Commissioner Johnston: In the matter of the public hearing held on June 2, 1995, at the AOGCC office regarding the above, Cook Inlet Region, Inc. (CIRI) has the following comments relating to the testimony presented by Lapp Resources, Inc. (LRI) for a spacing exception on state lease ADL-374135. CIRI is the subsurface estate owner in Township 18 North, Range 3 West, Section 21, SW/4NW/4, SW/NE/4 which is adjacent to the proposed development of the above lease. LRI has requested 40-acre spacing and a 330' surface location restriction from the drilling unit boundary for coalbed methane development. Further, LRI indicated that up to six wells will be drilled in Section 21, SE/4NE/4, N/2SE/4, SW/4SE/4, E/2SW4. In support of LRI's application, Texas and Alabama state regulations concerning setbacks and spacing applicable to coalbed methane production were entered into the record. CIRI does not object to the spacing exception requested by LRI for coalbed methane development. In addition to the proposed coalbed methane development, LRI expresse6 that production from gas sands may occur and requested that the rules for proposed coalbed methane development apply to gas sand production as well. CIRI, as the adjacent mineral owner, is concerned that detrimental effects may be incurred with having the rules for the proposed coalbed methane development apply to gas sand production. Drainage is likely to occur and, in such event, CIRI's mineral estate and correlative rights would be directly affected. Economic and physical waste is also likely to occur if the adjacent landowners are forced to drill unnecessary wells to protect their mineral estates from drainage. CIRI strongly objects to having the rules for the proposed coalbed methane development apply to production from gas sands. There is currently a 1500' surface location restriction from the drilling unit boundary when drilling for gas sands which CIRI BUILDING 2525 "C" STREET P. O. BOX 93330 ANCHORAGE, ALASKA 99509-3330 (907) 274-8638 FAX (907) 279-8836 Mr. David W. Johnston ., Alaska Oil and Gas Conservation Commission June 08, 1995 Page 2 should apply to any potential gas sand drilling and/or production within the boundaries of the proposed coalbed methane development. Additionally, CIRI notes that the regulations for coalbed methane production in Texas and Alabama do not appear to cover production from gas sands. As an active royalty and working interest owner in oil and gas leases in the state, CIRI is supportive of oil and gas exploration activities. CIRI does not object to the spacing exception requested by LRI for the proposed coalbed methane development but strongly objects to having such rules apply to drilling and/or production from gas sands. CIRI respectfully requests that AOGCC consider the above issues in the matter of this application. Please contact me if you need further information. Thank you. Sincerely, COOK INLET REGION, INC. Lease Administration Officer RECEIVED d UN - 9 1995 Alaska Oil & Gas Cons. Commission Anchor~,:'~ie ALASKA OIL AND GAS CONSERVATION COMMISSION Lapp Resources Pool Rules Public Hearin¢l - June 2, 1995 NAME - COMPANY - PHONE (PLEASE PRINT) SIGN IN PLEASE Testify/yes or no d 4 ~ot_ ~A OG c c. /bo 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 ALASKA OIL AND GAS CONSERVATION COMMISSION PUBLIC HEARING JUNE 2, 1995, 9:00 O'CLOCK A.M. TRANSCRIPT OF PROCEEDINGS RE: THE APPLICATION OF LAPP RESOURCES INC. FOR PUBLIC HEARING TO PRESENT TESTIMONY FOR CLASSIFICATION OF A NEW GAS POOL AND PRESCRIBING POOL RULES FOR ITS DEVELOPMENT IN SECTION 21, T18N R3W SEWARD MERIDIAN HELD AT THE ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA RECEIVED ,IUN -9 1995 Alaska Oil & Gas Cons. Commission Anchorage R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 P R O C E E D I N G S CHAIRMAN JOHNSTON: I'd like to call this hearing to order. I note the time is approximately five after 9:00, the date is June 2, 1995. We are located in the offices of the Alaska Oil & Gas Conservation Commission, located at 3001 Porcupine Drive, Anchorage, Alaska. To begin, I'd like to introduce the head table. My name is Dave Johnston, Chairman. To my right is Commissioner Russ Douglass, to my left is Tuckerman Babcock. Laurel Evenson, of R & R Court Reporters will be making the transcript of these proceedings. Should you desire a copy of the transcript, please contact Ms. Evenson or R & R Court Reporters directly. The purpose of this hearing is to define and establish pool rules for a coalbed methane project near Houston, Alaska, as proposed by Lapp Resources Inc. At this time Commissioner Douglass could establish more specifically the subject matter and date of publication of notice. COMMISSIONER DOUGLASS: I'd like to enter into the record the Notice of Public Hearing, published by the Oil & Gas Conservation Commission regarding the application of Lapp. Resources Inc. for a public hearing to present testimony for classification of a new gas pool and prescribing pool rules for its development in Section 21, Township 18 North, Range 3 West, R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 Seward Meridian. And this notice was published on May 2, 1995. CHAIRMAN JOHNSTON: Thank you. These proceedings will be held in accordance with Commission regulations, 20 AAC 25.540. Those regulations provide for sworn testimony or unsworn statements. Greater weight will be given to sworn testimony. If you wish to be considered an expert witness~ in this matter, we would ask that you state your qualifications and the Commission will rule as to whether we will consider you an expert witness. The Commission will ask questions, from time to time. Members of the audience, however, will be precluded from asking questions, although if you do have a question you can write them down on a piece of paper, forward it to the front desk here, and if we feel it is germane to the topic, the Commission will ask that question. At tD. is time I'd like to request the applicant Mr. Lappi to step forward and address the Commission. Mr. Lappi, do you wish to provide sworn testimony today? MR. LAPPI: Well, I've never -- I'm Dave Lappi, Lapp Resources, Inc., and I'm a geologist and geophysicist by education. I have never participated in a public hearing at the AOGCC before, and so I'm not exactly sure how to answer that question. CHAIRMAN JOHNSTON: Normally individuals testifying, of course it's at their discretion as to whether they wish to give sworn testimony or unsworn statements. As I R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 indicated, greater weight will be given to sworn testimony. Normally the applicant in these proceedings do swear themselves. MR. LAPPI: Okay. That's fine with me. COMMISSIONER DOUGLASS: Please raise your right hand. (Oath administered) MR. LAPPI: Yes, I do. COMMISSIONER DOUGLASS: Please state your name and spell your last name for the record. MR. LAPPI: Dave Lappi; L-a-p-p-i. COMMISSIONER DOUGLASS: Thank you. CHAIRMAN JOHNSTON: And, Mr. Lappi, do you wish to be considered an expert witness? MR. LAPPI: Yes, I do. CHAIRMAN JOHNSTON: Would you please state your qualifications. MR. LAPPI: I have a degree in geology from the University of Alaska in Fairbanks, Alaska in 1974, and a post graduate diploma in geoscience, mineral exploration, a specialty from McQuarry University in Sydney, Australia in 1977. COMMISSIONER DOUGLASS: And how specifically does this experience relate to coalbed methane? MR. LAPPI: It doesn't relate specifically to R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 coalbed methane. My education -- educational background relates in general terms to natural resource exploration extraction. Natural resources -- mineral resources, I should say, of all kinds. CHAIRMAN JOHNSTON: Have you specifically worked on coalbed methane projects in the past? MR. LAPPI: Yes, I have, in western Australia I headed a couple of companies that were involved in coalbed methane exploration projects, and coming back to Alaska I'd like to continue that kind of operation. CHAIRMAN JOHNSTON: Have you done or had experience with coalbed methane exploration in Alaska at all? MR. LAPPI: No, except to say that I was involved in looking over the state's shoulder on their coalbed methane resource evaluation well at Wasilla last year. CHAIRMAN JOHNSTON: You participated as an observer in that activity then? MR. LAPPI: That's right. CHAIRMAN JOHNSTON: Thank you. COMMISSIONER. BABCOCK: I move the Commission recognize Dave Lappi as an expert witness on his application. COMMISSIONER DOUGLASS: No objection. CHAIRMAN JOHNSTON: Thank you, Mr. Lappi. The Commission will accept you as an expert witness in this matter. Please proceed. R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/Fax 274 - 8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 MR. LAPPI: Okay. I want to thank the Commission for calling this hearing promptly on my request. The object of Lapp Resources Inc. is to drill three gas development wells in the Houston area and produce, hopefully, economic quantities of gas from those wells. The drilling is scheduled to take place when the permit is completed this summer, and we would like to put those wells on long-term production test and produce water and, hopefully, economic quantities of gas. Having proven economic quantities of gas exist, we'd like to put in a distribution system and sell that gas in the City of Houston. And also the company has obtained a gas sales contract with one of the major gas consumers, an industrial gas consumer, based in Kenai to sell a minimum of a million cubic feet a day and eventually more. The purpose of the hearing would be to establish a new gas pool to allow these gas -- these gas wells to be drilled on 40-acre spacings instead of the normal 640-acre spacings that the state rules call for, and also to classify these wells as production wells so that we can go about producing and completing them for production and producing them forthwith. COMMISSIONER BABCOCK: Are there any other exceptions tc statewide regulations that you see necessary for pursuing this? MR. LAPPI: One of the issues that the company is interested in in pursuing is a reduction in AOGCC bonding, R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 which is currently 100,000 per well or $200,000 for a statewide bond. These wells will cost somewhere between 130 and $150,000 each to drill, and completion costs will be a little bit more than that, but certainly we expect the well costs to be under $200,000 each. And to require a $100,000 bond for each -- or, well, $200,000 for a statewide bond for the drilling would certainly increase the cost of the drilling program to the point where we think it might be uneconomic, even if we were successful in discovering kind of commercial rates of gas. CHAIRMAN JOHNSTON: I -- go ahead. MR. LAPPI: So what we'd like to do is propose that the bonding cost reflect the cost of plugging and abandoning the wells. I have obtained two quotes from Dowell Schlumberger and Halliburton, which are both $10,000 or less, and I would propose that the Commission accept those quotes for plugging and abandonment by those third parties as the amount of the P & A bond that the Commission'required. CHAIRMAN JOHNSTON: Have you submitted that information to the Commission? MR. LAPPI: Yes, I have. CHAIRMAN JOHNSTON: Do you have copies of that with you today? MR. LAPPI: I've got the Dowell Schlumberger quote with me, and I have previously sent the Halliburton quote also. Halliburton's quote was $10,000; Dowell Schlumberger's R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 is 8,000-something -- $8,365.75. CHAIRMAN JOHNSTON: Okay. I think it would be appropriate to enter the two quotes as exhibits into the record. I think we'll have to locate -- let's see, the Halliburton -- you indicated that has been sent to us previously? a better date? MR. LAPPI: Yes, probably two weeks ago. CHAIRMAN JOHNSTON: Two weeks ago. Do you have MR. LAPPI: No, I'd have to look at my records. I will certainly send another copy of that along. CHAIRMAN JOHNSTON: Why don't we indicate the Dowell Schlumberger as Lapp Exhibit 1 and the Halliburton will be Lapp Exhibit 2. MR. LAPPI: Okay. Another issue that may arise is the possibility of finding gas reservoired in sandstone instead of -- or in addition to coal, and my analysis of the geology in that area, based on the limited information that we have of the geology of that area, indicates that it's -- the environment of deposition there was a fluvial -- that is a river environment. The sandstones are likely to be small sandstone bodies of limited areal extent. And we expect that if a sandstone body was discovered that contained gas, that that gas would be that gas field or that gas pool. It also would be of fairly limited areal extent. Therefore, we'd like R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 the Commission to consider the possibility of producing sandstone gas along with coalbed methane. If the production history shows that the reservoir is a very large reservoir, certainly we can look at changes in the production regime. But I think at this point the 40-acre spacings are probably equally applicable to sandstone or coalbed methane. CHAIRMAN JOHNSTON: Would the way you drill these wells change, whether you encountered the ..... MR. LAPPI: No. CHAIRMAN JOHNSTON: ..... coal or sandstone? MR. LAPPI: No, we would be ..... CHAIRMAN JOHNSTON: Basically the same proposal then? MR. LAPPI: Our plan is to use a water well rig to drill the first 300 feet, set six-inch steel casing cemented from bottom to surface, and that operation would take one or two days per well. Then the Dowell Schlumberger coil tubing unit, which is a skid mounted unit, basically would be trucked to the site. There would be about five truck loads of material at the site when the drilling was proceeding. We would then continue the well from 300 feet on down to 2100 feet, and that would be with five-inch open hole, and a 3-1/2-inch production tubing would be cemented into place, top to bottom. And then provided we saw things of interest on the wire line logs, we R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/Fax 274- 8982 272 - 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 10 would perforate those sandstones or coals that we thought were productive and go about production testing. CHAIRMAN JOHNSTON: In terms of any special blow-out prevention equipment and mud systems could you describe how you propose to maintain well control? MR. LAPPI: Yes. The coil tubing unit is essentially a closed system in that the -- well, first of all, the BOP would be Dowell Schlumberger's BOP system, and it would be bolted on the top of the six-inch production casing set at 300 feet -- or the surface casing set at 300 feet. That would provide the primary well control during the drilling of the deeper parts of the hole. The mud system would be a gelled water, basically, mud system with small amounts of bentonite. The cuttings would be separated by a shaker screen, and the cuttings would be -- we're planning to haul those cuttings away from the site and we're trying to get DEC permission to store them in the -- or dispose of them in their borough landfill. As we're not using any exotic materials down the hole, just water -- gelled water and bentonite, there shouldn't be a problem as far as the materials we're using down the hole to dispose of them in the Wasilla landfill. But we have not yet received permission from DEC to do that. Although talking to both the borough and DEC, no one seems to think that it's going to be a major problem. The mud would be contained in a mud R & R COURT REPORTERS 810 N STREET 1007 tJEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 11 tank, not a mud pit, and hauled from well to well, and at the end of the project there should be no reserve pit left at the site and certainly nothing disposed of at the site. So it should be a fairly clean operation. CHAIRMAN JOHNSTON: Is there any evidence within this area of any shallow over-pressure zones? MR. LAPPI: Not that I'm aware of. Not over-pressure zones. Even the water wells in that area, in many cases, produce gas, but certainly not as far as I can tell over-pressured -- as far as I can tell no water well drillers have encountered any over-pressure gas zones in that area. CHAIRMAN JOHNSTON: And what depths have these water wells drilled to normally? MR. LAPPI: I think generally less than 300 feet. CHAIRMAN JOHNSTON: Less than 300. Do you have any evidence deeper than 300 feet? MR. LAPPI: Well, the -- in the mid-'50s there were four or five wells drilled in that area; Rosetta's 1 through 4A, and during the drilling they encountered flows of water and -- salt water and gas, and I think in the case of Rosetta 3 there were a slight over-pressuring according to one report. And I really can't confirm that because the records are fairly sketch as far as what they were actually doing down the hole, what their flow rates were, what the test results R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 12 were, and in fact in the case of Rosetta 3 we don't even have adequate wireline logs for the well. CHAIRMAN JOHNSTON: In terms of your proposed project relative to the area that the Department of Natural Resources drilled, can you establish any -- on a map how far away you're talking about? Is the DNR well in any proximity to your project? MR. LAPPI: It's about eight miles, if my memory serves me correctly. It was drilled on 1-1/2 miles north of the Parks Highway on Church Road, and just outside of Wasilla. CHAIRMAN JOHNSTON: Did they encounter any shallow over-pressure zones? MR. LAPPI: No. As far as we're aware there was no -- in fact there was no gas production from the well, only -- the only samples that were recovered were -- well, it was a fully cored well from 354 feet to 1245 feet, and there was no indication of any water or gas flow during the drilling, that I'm aware of. The coals that -- the clean coals that were sampled were placed in containers for gas desorption tests, and indicated that the shallowest samples, from about 400 feet, had about 50 cubic feet per ton of methane gas in the deepest sample from about 12 -- a little over 1200 feet had about 245 cubic feet per ton in gas. Which, according to our research, is an economic quantity for coalbed methane production. R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 13 CHAIRMAN JOHNSTON: Well, maybe you could establish where this project is, referring us to a map. We ca~ ..... MR. LAPPI: The acreage -- here, you can find Wasilla. You follow the Parks Highway west of Wasilla until it crosses the Little Susitna River, and right at -- just north of the Little Susitna River crossing is the downtown Houston area, and our drilling project is basically north of the highway and very close to the commercial center of Houston. CHAIRMAN JOHNSTON: Perhaps you could, on this map -- can we use this as an exhibit? MR. LAPPI: Yes, if you like. CHAIRMAN JOHNSTON: Okay. Why don't you locate us on this map and then we can have it for the record as to where your project is, or just designate it with a pen. MR. LAPPI: (Pause - witness complies) CHAIRMAN JOHNSTON: And this is on a State of Alaska lease? that lease? MR. LAPPI: Yes. CHAIRMAN JOHNSTON: Do you have the number of MR. LAPPI: Yes, I do. CHAIRMAN JOHNSTON: Go ahead and pen it in on this map as well. MR. LAPPI: The lease -- the State of Alaska R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 1¸5 16 17 18 19 20 21 22 23 24 25 14 lease number is 67-A/374135. COMMISSIONER DOUGLASS: And this is the oil and gas lease? MR. LAPPI: Yes, it's ..... CHAIRMAN JOHNSTON: So it would be ADL 374135? MR. LAPPI: Yes. And Lapp Resources is the sole working interest owner on that lease. Marathon Oil Company has a 1 percent overriding royalty, and the State of Alaska has a 12-1/2 percent royalty. CHAIRMAN JOHNSTON: We'll designate the map with your project area and lease number as Lapp Exhibit Number 3. Perhaps you can describe for us a little bit of the geology of the area? MR. LAPPI: Certainly. The roCks in that area determined from drilling dip about five to seven degrees to the north, away from the Castle Mountain Fault, which trends east-northeasterly through the area, basically along the Little Susitna River. We think the fault zone is about a mile wide and occupies that portion on the ground from the Little susitna River Bridge for the entire mile to the south of the bridge, and it's a fairly wide fault zone. It's not usually shown as a wide fault zone on maps, but we have evidence to believe that it is a fairly wide fault zone. It's got many,thousands of feet of vertical relief. It's a reverse fault. And on the south side of the Castle Mountain Fault we've got most of the R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/Fax 274- 8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 15 rocks that are present -- most of the formations are present that are present in other parts of the Cook Inlet basin. The Tyonek, being the uppermost unit, and that is the succession of rocks that was drilled most probably in the state's well at Wasilla. Now, there are conflicting opinions about what formation is present on the north side of the fault. Many people believe that it is the Chickaloon Formation, which also contains coal in the Matanuska Valley to the east in the Sutton Eska area where commercial coal mining has taken place in the past. Other people believe that is it probably the Tyonek Formation, which is also present on the south side of the fault. On the north side of the fault, from previous drilling, we know that the Tyonek Formation is about 2000 feet thick. And below that the cretaceous Matanuska Formation is present. The Matanuska Formation probably forms economic basement in this area in that it is highly altered and metamorphosed and structured in that previous drilling has shown that the beds are at high angles and fairly faulted. CHAIRMAN JOHNSTON: So what do we know about the coals in this particular area? MR. LAPPI: Well, we know that the coals contain gas because the first interest in hydrocarbon exploration in this area was at the Houston Coal Mine in the 1950s. In the -- let me back up here, the coal in this area R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 16 was first discovered in the railway cut through the Houston area in 1916 and 1917. And between 1920 and 1956 coal was mined sporadically in this -- from that particular coal mine at Houston, and sold via the railway to the Anchorage markets. In the '50s, at the bottom of the open pit mine they discovered methane gas bubbling out of one of the coal seams, and this interested the coal mine owners in trying to develop an oil reserve in that area. There was no market for gas, it was a curiosity, but certainly it was an indicator that hydrocarbons might be present. Subsequently, they formed a company, Anchorage Gas and Oil Development Company and drilled five wells, Rosetta 1 through 4A, and failed to find an oil reserve, but they did encounter several zones that flowed salt water and gas. So we certainly are aware that there is gas present in the section. The drilling that was done last summer indicates that the coal seams do contain what appear to be economic quantities of gas, and certainly the gas flowing out of the coal seams in the bottom of the open cut mine indicated the same is true right at the surface. Homeowners in the areas report that the coals in that area are aquifers, and many of the homeowners have completed their water wells in coal seams. Subsequently on producing water from those coal seams their wells also produce small quantities of gas, and in some cases that gas is a little bit R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 17 of a hazard to the homeowner. COMMISSIONER DOUGLASS: Would you have the analysis or backup data to confirm these? MR. LAPPI: The only gas analysis we have was done on gas collected from coal cores at the state's resource appraisal well at Wasilla that indicated that the gas was more than 98 percent methane, less than 1 percent CO2 and 1 percent nitrogen. COMMISSIONER DOUGLASS: Could you provide us with this analyses? MR. LAPPI: Yes. I think they're -- are they published then? MR. SMITH: Yes. I will send them a copy of the paperwork. They're in a ..... MR. LAPPI: Yes, I can certainly supply that. COMMISSIONER DOUGLASS: But I would assume it would also show the relative quantities of gas produced in the reservoir? MR. LAPPI: Yes. That information is published. I can supply that. CHAIRMAN JOHNSTON: So that's a copy of the coal analysis, is that how we'd properly refer to it? MR. LAPPI: Yes, the gas content and the coal analysis are both available. CHAIRMAN JOHNSTON: Okay. And when could we R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 18 expect receiving those? MR. LAPPI: Today. CHAIRMAN JOHNSTON: Why don't we go ahead then and we'll designate that in the record as Lapp Exhibit Number -- what, 4? Now, these coal seams, are we talking just a single coal stream or seam or we have numerous? MR. LAPPI' We have the drillers log from Rosetta 3 down to a depth of about 1300 feet, and I brought that today. It indicates there are about 40 feet of coal -- no, about 50 feet of coal in that first 1300 feet. You're welcome to have that copy. I've highlighted all the coal seams in pink with a pink highlighter. CHAIRMAN JOHNSTON: And what is this a log from? MR. LAPPI: This is Rosetta 3, which is ..... CHAIRMAN JOHNSTON: Rosetta 3, okay. MR. LAPPI: ..... very close to the area that we're planning to drill. CHAIRMAN JOHNSTON: We'll designate this Lapp Exhibit Number 5. MR. LAPPI: This correlates very closely with the quantities of coal that were found in the state's drilling in Wasilla where they had about 46 feet of coal per 1000 feet of section. This correlates to about 43 feet per 1000 feet of R & R CouRT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 19 section. CHAIRMAN JOHNSTON: So what is the shallowest depth that you would expect to encounter these coals? MR. LAPPI: These coals -- well, the homeowners that I've talked to recently, in the locations that we're planning to spud the well, indicate that their water well, which is very close to one of the drill sites, spudded in 10 feet of coal. So there is bedrock right at the surface in at least that drill site, and coal exists right at the surface. CHAIRMAN JOHNSTON: But you were proposing to drill down to, what, 2100 feet. Where do you -- will you be producing at any particular horizon or do you have a target location that you would be preferred to ..... MR. LAPPI: We don't have a specific target horizon yet. We would like to do the drilling and see what the wireline logs show as far as the quantities of coal. The logging information that we have is not as good as logging information t~.at we would obtain today. Certainly the wireline logs from Rosetta 3 are not available. But that driller's log, for instance, is probably accurate, but it was done in the mid-'50s, and we really don't have a good handle on the quantities of coal that exist, although it indicates there's 50 feet of coal in the first 1300 feet. We don't know -- we don't have the driller's log below 1300 feet and so we don't know what's -- what -- we know that the section, the same Tyonek or R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 20 Chickaloon section exists down to about 2000 feet, but we don't have an accurate picture of the coal seams encountered below 1300 feet. COMMISSIONER BABCOCK: Since you haven't identified where you might intend to produce within a particular well, what possible impacts on the homeowners' source of drinking water might your development have? MR. LAPPI: I would think that there would be no impact at all on water wells in the area. We're not planning to produce coalbed methane or gas shallower than -- well, certainly shallower than 500 feet, and I wouldn't think that there would be economic quantities of gas present in the section above 1000 feet. That remains to be seen, but that's my expectation, at this point. The shallower the gas reservoir is the less gas there is in the reservoir, just because of pressure differences. So certainly above a 1000 feet there are going to be small quantities of methane. And in this area fresh water seems to occur above 300 feet approximately, and salt water seems to occur below 300 feet. CHAIRMAN JOHNSTON: How are you defining salt water? Do you have a -- have you looked at the total dissolved salts? MR. LAPPI: No, I don't have a good handle on what -- the cnly records that we have on this are not lab analyses but references and drillers logs to salt water. So if R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 21 the driller thought it was salt water, he called it salt water on the log; if he thought it was fresh water, he called it fresh water. So I don't really know what criteria they were using for that. Probably a taste test is what they were using. CHAIRMAN JOHNSTON: Just for your own personal reference the Commission defines fresh water as anything above (sic) 10,000 parts per million. MR. LAPPI: Okay. CHAIRMAN JOHNSTON: Excuse me, below. I'm thinking in the opposite direction. Anyway, on the good side. MR. LAPPI: Certainly with modern logs we can probably get a good handle on what's fresh and what's salt water. CHAIRMAN JOHNSTON: Right. COMMISSIONER DOUGLASS: So you would propose as your productive interval the section in your well from 500' to 2100' then? MR. LAPPI: That's correct. COMMISSIONER DOUGLASS: Possibly. MR. LAPPI: That's correct. And it remains to be seen which seams out of that interval are the best producers, and no one i~ the state of Alaska has tried to produce gas from coal before, so this is a test case basically, and we don't know exactly what completion techniques are going to work best. R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 22 In other parts of the country, however, many coalbed methane wells are completed in all of the coals and not just a single coal. And, for instance, in some wells they perforate every coal seam from top to bottom and place a pump at the bottom of the well and pump the water out of the well as it's produced out of the perforations and gas is produced up the annulus then so that you can have multiple completions in multiple zones and produce more gas per well that way. COMMISSIONER BABCOCK: What are your plans with the produced water? MR. LAPPI: At this point we're expecting to reinject it, and since we're drilling three wells, what we'd like to do is evaluate the logs on those three wells and choose an interval for disposal after we've done the drilling. CHAIRMAN JOHNSTON: Have you contemplated possible service disposal of this well? MR. LAPPI: We have contemplated that. Under current state regulations that would be difficult, but it's certainly being done in the Lower 48, and it's apparently being done with very little environmental downside. So we can only look at what they've done in the Lower 48 and try to take the things that work and reject the things that don't work. CHAIRMAN JOHNSTON: It's something that you may want to give some consideration to, at least I would encourage you to look into that, the underground injection option is R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 23 available, although it is not the easiest option in the world to work through. It is a -- the Underground Injection Control Program is regulated under federal regs, or at least the authorizing statutes are federal in orientation, and there are certain requirements that if we're going to authorize a UIC type activity there are certain requirements that need to be clearly established in the record: You will need to identify a proper receiving zone, a proper confining zone. Your wells will have to be cased, they'll have to establish mechanical integrity, et cetera. So it's not the easiest option in the world, and you may run into some difficulty establishing clear, confining and receiving zones at these shallow depths that you're proposing. The other alternative, of course, is the surface disposal, but that will require you to get authorization, I presume, from the Department of Environmental Conservation. Although you may look into the recent bill that's been passed, H.B. 28 to see if that has any bearing on your ability to dispose on the surface. MR. LAPPI: Yes. In some parts of the world even produced waters are evaporated at the surface ..... CHAIRMAN JOHNSTON: Right. MR. LAPPI: ..... in a holding pond, and that could be done in Alaska if you wanted to heat the water in the wintertime. Certainly the air is dry enough you could probably R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 24 dispose of large quantities of water by evaporation, and it would tend to create ice fog in your cold conditions, but it's certainly an option. Probably an expensive one though because of the cost of heating the water. CHAIRMAN JOHNSTON: So do you wish to pursue an underground disposal option, I would refer you to our regulations 20 AAC 25.252, and under those you'll find certain criteria that we'll have to establish before we could authorize an injection -- an underground injection type program. Generally, we authorize underground injection through an area injection auger, and that would be another process very similar to this. You would come before us to testify and establish those criteria that are outlined within the body of those regulations. So I would encourage you to review those and think about it as to what your best alternatives are. I would think disposal of this produced water is one of the things that are going to be better addressed sooner than later, and so I would encourage you to spend some time with it and then consult with us at your earliest convenience about what the best way of disposing of this produced water is. MR. LAPPI: Okay. There are other wells in the area, too, that -- for instance, Beaver Lake State 1, which was drilled 8000 feet -- plus feet, which could be used as a disposal well, under the right conditions. So there are other R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 25 wells available. That one's in this oil and gas lease, so its well bore is available to us. CHAIRMAN JOHNSTON: And that's an abandoned well? MR. LAPPI: Yes. CHAIRMAN JOHNSTON: That may be a real option. It would certainly hold down your costs a bit if you have a well already drilled for yourself. What was the name of that well? MR. LAPPI: Beaver Lake State 1. CHAIRMAN JOHNSTON: Beaver Lake State 1. Mr. Lapp, could you -- have you had any experience with the drainage patterns that would exist in the coalbed methane type development? You're basically suggesting or requesting a 40-acre spacing. Could you address the why a 40-acre spacing would be appropriate for a coalbed methane project? MR. LAPPI: Certainly. My request for this hearing had some backup information included, and that backup information justified that 40-acre spacing by showing several maps of coalbed methane development operations in the Lower 48, some of which were drilled on even closer spacings than 40 acres. The other justification for this closer spacing is that while in the lower 48 stimulation techniques are -- while expensive, they're much cheaper than they are in the state of R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 Alaska, and what I'm expecting is that the cost of drilling another well is going to be not cheaper than a stimulation operation but certainly viewed with more favor than engaging in expensive fracking operations to extend the reach of the well. So what I'm basically proposing is that rather than spend money on the stimulation of an existing well, that we just drill a new well to get that stimulation to drain the reserves that exist. In the Lower 48 where the stimulation operations are cheaper, they routinely engage in large frack jobs. Those frack jobs would be prohibitively expensive in Alaska. Just the cost of the sand, if you wanted 100,000 pounds of sand delivered to a site in Houston, just the cost of the sand would be well over $100,000. So if it only costs us $100,000 to drill a well, it sounds to me like it would be much better money spent to drill another well. COMMISSIONER BABCOCK: I would note, Mr. Chairman, that in the State Oil and Gas Court of Alabama's Administrative Code, November 1994, that their statewide -- that their permitting process for coalbed methane well, Section 400-4.202 dealing with spacing of wells establishes 40-acre spacing with 330' setback. It's on page D-2 of their regulations. CHAIRMAN JOHNSTON: Why don't we enter the Alabama -- it was Alabama you said? R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 1'4 15 16 17 18 19 20 21 22 23 24 25 27 governing ..... COMMISSIONER BABCOCK: Yes. CHAIRMAN JOHNSTON: A copy of the Alabama regs COMMISSIONER BABCOCK: Permitting, Drilling and Production of Coalbed Methane Gas, Section 400-4. CHAIRMAN JOHNSTON: We'll designate that is Lapp Exhibit Number -- what are we up to, 6 now? COMMISSIONER BABCOCK: Well, perhaps Mr. Lappi would -- would you like to submit that as an exhibit or would wonderful. MR. LAPPI: Yes, that would be -- that would be CHAIRMAN JOHNSTON: It's amazing how you're on the same page of music here. Do you think the -- you know, spacing is -- and offsets from property boundaries are one method by which the Commission would protect the correlative rights of adjacent property owners. Do you think the 300 and -- what is it, 330' setback that Alabama has adopted is a reasonable setback? MR. LAPPI: I think we will only know with production history, but I think at this point it's a reasonable first step. CHAIRMAN JOHNSTON: So you would have no problems living with the 330' setback? MR. LAPPI: No, that would be much better than R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/F ax 274 - 8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 28 the 1500 that currently exists. CHAIRMAN JOHNSTON: Ail right. Now that works for coalbed gas. MR. LAPPI: I think that the production history, again, and drilling experience will indicate that sandstone reservoirs will also have similar size drainage areas, but I think only sufficient drilling and production history will show that one way or another. When we finish our drilling project here we'll have five -- well, we'll drill three wells ourselves and we'll have two wells -- well, three wells -- two wells that are Rosetta 4 and 4A, and Rosetta 3 that are in the same general area, and we'll be able to tell from the minimally sketchy information that we have from the first two wells and the three wells that we drill, how laterally extensive the sandstones are and therefore how much of a problem protecting those correlative rights might be. CHAIRMAN JOHNSTON: We may have to invite you back in once you have a little bit more knowledge of the general area to describe any sandstone reservoirs that may exist in the area. MR. LAPPI: I'd be happy to do that. CHAIRMAN JOHNSTON: And it may be appropriate just to establish this type of space and just solely for the coal seams that you'd be acquiring the gas from, rather than R ;% R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 29 any sandstone, because statewide regulations, as you noted, which have generally been written for our sandstone type accumulation would establish 1500 feet as a setback, and I think we'd need some really hard evidence to suggest that your area would be -- would justify an exception to the 1500 feet when it came to a sandstone type reservoir. MR. LAPPI: One way to establish the boundaries of the reservoir would be to do a long-term production test, for instance, though, and that would give you some indication of the actual size of the reservoir. And while I'm happy to come back in after we've gotten some experience with the drilling, it may be beneficial to allow some production to occur from sandstone to more or less quantify the volume of gas present in that particular sand and thereby get a little more information. So I would hope that the Commission would allow Some production to occur from sandstones al'ong -- if we find any productive sandstones, along with our coalbed methane operation. CHAIRMAN JOHNSTON: How do you propose abandoning your wells? MR. LAPPI: Well, Dowell Schlumberger's and Halliburton's quotes have assumed that we just pump the wells full of cement. · CHAIRMAN JOHNSTON: From top to bottom? R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 30 MR. LAPPI: Top to bottom. Although I think that that's probably a short-sighted way to abandon the well. It's certainly the cheapest way to do it, and the experience with coalbed methane operations in the Lower 48 indicates that these wells are particularly longlived wells. Some of them produced for 20 to 40 years. We certainly have sufficient coal and have present in the section -- and if there's 40 feet of coal per 1000 feet of section, we've probably got 80 feet of coal in that 2000 feet. So 80 feet of coal is quite a bit more than, for instance, they're used to dealing with in Black Warrior Basin where they're after less than 20 feet cumulative thickness. So I think that we'll find with our production history that these wells will last quite a long time. So I'm not, at this point, particularly concerned about the abandonment method for the well. CHAIRMAN JOHNSTON: Looking down at your request for pool rules, it appears that you are asking for an exception to the diverter requirements. MR. LAPPI: That's right. The water well drillers in the Matanuska Valley typically drill with a downhole hammer system. Modern water well rigs are -- don't use mud much these days. They are drilling with air with a downhole hammer, and have drilled wells in the Matanuska Valley to seven or 800 feet with no particular problems as far as R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/Fax 274- 8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 31 diverters go. I don't see any reason why a 300' well in this location should require a diverter. CHAIRMAN JOHNSTON: Okay. And then venting or flaring of gas to be allowed during dewatering phase. Can you describe that process? MR. LAPPI: Yes. When a coalbed methane well is produced -- well, when a coalbed methane well is drilled into a coal seam the way to get the gas to flow from the coal is to reduce the pressure in the coal seam. I like to think of that as similar to taking the top off a Coke bottle; there's no gas in the Coke until you actually remove the top. And dewatering the coal seam is similar to removing the top on the Coke bottle. Once you start pumping water out of the coal seam the internal pressure in the coal seam is reduced and gas starts to flow out of the coal and through the natural fractures in the coal seam toward the well where it can be produced and sold. The water that's produced has to be pumped to the surface and disposed of either downhole or by surface method, and the dewatering phase may take several months before significant gas production occurs. And by significant I mean commercial rates. And we're expecting these wells to require about 200,000 cubic feet a day to be commercial. That number could go up or down depending on our experience with operating costs; the cost of lifting and the cost of maintaining the R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 27/,-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 32 pumps and so forth. But the gas that's produced during the testing phase, I call that basically the dewatering or testing phase. Usually is at increasing rates until you achieve a commercial rate, and that gas, until you prove that the well is commercial by the dewatering and gas production process, that gas has to be disposed of. So it may take several months of venting or flaring of gas before you actually achieve a commercial rate or rates sufficient to justify putting in a gas gathering and distribution system for selling the stuff. CHAIRMAN JOHNSTON: While you are dewatering and flaring tkis gas do you have a flare system that you'll be employing or can you give us an idea of how this process is done? MR. LAPPI: I haven't sat down and designed a flare system, but in many cases gas from the low production wells is vented rather than flared, and basically you'd have to vent it at an elevation above the ground surface where it's not going to become a hazard to people or animals or structures at ground level. So that would depend on the area where the venting is taking place, how high that actually would be, and the meteriorological conditions and a number of other factors. COMMISSIONER BABCOCK: Are the neighboring property owners in the City of Houston or the Matanuska-Susitna Borough aware of your plans on venting or flaring gas during R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277- 0572/F ax 274- 8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 33 the dewatering phase? MR. LAPPI: I haven't specifically talked to people about venting or flaring, but they are aware of the project. I've given presentations on the project to the Houston City Council and the Houston Chamber of Commerce and also the Matanuska Resource Conservation and Development Council, and everyone seems fairly supportive. There are -- we talked about venting. Now let me just talk about flaring. There are flared systems that are probably going to be safer. If you're in a hazardous scenario where venting can be a hazard, flaring would be a better option. CHAIRMAN JOHNSTON: What kind of volumes are we talking about? MR. LAPPI: Well, the venting would -- or flaring would be up in -- until we achieve a commercial rate, and a commercial rate at this point, we think, would be about 200,000 cubic feet a day. So it's a fairly small quantity of gas per day. CHAIRMAN JOHNSTON: That was 2000 cubic feet a day? right? COMMISSIONER BABCOCK: 200. CHAIRMAN JOHNSTON: 200. And that's per well, MR. LAPPI: Yes. CHAIRMAN JOHNSTON: So is a permit to do this R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 34 project required from the City of Houston at all? MR. LAPPI: I've talked to the City of Houston about the project, and at this point the only permits -- well, the City of Houston permits are administered by the Matanuska-Susitna Borough, and at this point the borough's only concern with the project is the issues relating to flood plains -- federally mandated flood plain areas along the Little Susitna River. And their only concern is that large quantities of fill aren't used in the flood plain that would impede the flow of water during flood conditions. But at this point I haven't specifically addressed the topic of flaring or venting of gas with any of the agencies. CHAIRMAN JOHNSTON: Who would you have the Commission define the pool in this particular case? MR. LAPPI: That's an interesting question because we are breaking new ground here in the state of Alaska. I would think that the pool would be defined as those intervals which are being produced, and I'm not familiar with what other states are doing as far as their regulations are concerned, but that seems to be a logical course of action to me. COMMISSIONER BABCOCK: I'd like to give you a copy of Lapp Exhibit 6. CHAIRMAN JOHNSTON: In terms of those intervals being produced I think that takes -- that can be more easily applied with depth in mind, but~how would we define it areally? R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 35 MR. LAPPI: Oh. Areally, I think that the drill's spacing unit would be the area of the pool or -- sorry, let me back up here -- the developed area of the lease. And the developed area of the lease, developed area being defined as those areas being drained by a well or by the wells, and in our case we're expecting those areas being drained by the wells to be the 40-acre drilling units around the wells. So in this case if we drill three wells there'd be 120 acres in the pool, and as people drill more wells and expand the producing area the pool definition would change over time. CHAIRMAN JOHNSTON: This is all on one lease, so there is no concerns for integration of interests, right? MR. LAPPI: That's correct. CHAIRMAN JOHNSTON: Are there any other exceptions to the statewide regulations that you are aware of that you might require? MR. LAPPI: Not that I'm aware of, but I'm sure as we progress down this new path of coalbed methane development other issues will come up that none of us have the forethought to see, and I'd be happy to work with the Commission to address those at the time they come up. CHAIRMAN JOHNSTON: Okay. Now you're the owner of the lease; is that correct? MR. LAPPI: That's correct. CHAIRMAN JOHNSTON: Will you also be the R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 36 operator of the wells? MR. LAPPI: That's correct. The appropriate paperwork will be filed with the Commission to signify that operatorship ..... CHAIRMAN JOHNSTON: Right. MR. LAPPI: ..... in the near future. CHAIRMAN JOHNSTON: Why don't we take a short recess at this time, and that will give us a bit of opportunity to consult to see if there's any additional questions we may desire to ask at this time. MR. LAPPI: Okay. (Off record - 10:06 a.m.) (On record - 10:19 a.m.) CHAIRMAN JOHNSTON: I'd like to go back on record. Mr. Lappi, we have just a few more questions for you. Do you have a typed log that you would like to submit for us so we could refer to it in the record? MR. LAPPI: The best lithological log that we've got is the first 1300 feet of Rosetta 3, which I've given you a copy of. We've got another log that was done by American Stratigraphic Company at some point after the well was drilled, and I have produced a copy for you at one inch equals 50 feet scale, which we can submit into the record. CHAIRMAN JOHNSTON: And that's also from R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 23 24 25 37 Rosetta 3? deep? MR. LAPPI: That's right, Rosetta 3. CHAIRMAN JOHNSTON: And this log is down to how MR. LAPPI: It goes to -- well, the log is on the entire well. I've given you the first 2200 feet of the well. CHAIRMAN JOHNSTON: Thank you. And can you give us a legal description of your project area? MR. LAPPI: Yes. CHAIRMAN JOHNSTON: And for the record I would like to label the Rosetta Number 3 log that is at a scale of 1 inch to 50 feet as Lapp Exhibit Number 7. MR. LAPPI: It's the legal description of the 40-acre -- of the areas which we're contemplating drilling would be the southeast quarter of the northeast quarter, and the northeast half of the southeast quarter, and the southwest quarter of the southeast quarter, and the east half of the southwest quarter of Section 21, Township 18 North, Range 3 West, Seward Meridian. And I'll certainly give you a copy of that along with the other information that I've given you today. That legal description describes the six drilling locations, three of which we might drill this summer. And the three that we're contemplating drilling would partly be R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 38 dictated by access and surface owner considerations. COMMISSIONER BABCOCK: So is it your intent to have these pool rules apply to your entire lease or to those sections upon which you think you may drill? MR. LAPPI: What I would -- well, that's a good question. What I'd suggest is that these pool rules apply to the areas where drilling actually takes place. They could apply to the entire lease but I don't see any reason -- well, here's a question. Can additional areas be incorporated into these pool rules easily or does it require another public hearing? CHAIRMAN JOHNSTON: I think we can do it administratively, don't you? COMMISSIONER DOUGLASS: It would depend. Most often, more often than not, I think we could probably do it without going to hearing, but it would depend on the circumstances. Normally the circumstances are such that it would not have to go to public hearing. COMMISSIONER BABCOCK: But if there were any objections we would ..... COMMISSIONER DOUGLASS: But there might be objections. MR. LAPPI: Okay. Well, I guess the question would be which option would be better for the Commission? As far as I can see as long as there is some flexibility in that R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272- 7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 39 other areas could be incorporated into these pool rules from the operator's point of view, I don't think it makes a big difference. But from the Commission's point of view, it may. So, you know, I guess ideally we'd like to see the entire lease -- the pool rules apply to the entire lease, and that would preclude any further action as far as the Commission is concerned, if at some point we wanted to drill more production wells. COMMISSIONER BABCOCK: The Commission will take that under advisement. COMMISSIONER DOUGLASS: But at this point you have no definite plans beyond the six wells you've ..... MR. LAPPI: We don't have any definite plans beyond the three wells that we're proposing to drill this summer. However, if we're successful in establishing commercial production, we'd like to continue drilling new production wells to satisfy the markets that we've got. COMMISSIONER DOUGLASS: So I guess I need some clarification now. Your application showed six locations, and what you're proposing now is that you limit your development to three wells at this time? MR. LAPPI: We're proposing to drill three wells this summer, that's correct, and the reason that we've got six locations chosen is that in some cases we may find surface access problems or problems relating to getting permits R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 40 in flood plains and so forth. So the reason we got six locations is to give us some flexibility as far as actual drilling locations that we use, if one or more locations become unpermittable, for some reason. COMMISSIONER DOUGLASS: Okay. So you're going to pick your three locations out of the six you have in your application? MR. LAPPI: That's correct. COMMISSIONER BABCOCK: I heard clearly about cementing back from the 300 feet back to the surface. What is your intent regarding from the bottom back to the surface? MR. LAPPI: We intend to cement the entire production casing, from the bottom to the surface. CHAIRMAN JOHNSTON: And could you forward us a copy of the legal description for your lease? MR. LAPPI: Yes. I'll submit that with the other information that I promised earlier. CHAIRMAN JOHNSTON: And generally how much water do you think you'll be dealing with for disposal purposes? MR. LAPPI: We don't know until we drill and start producing actual quantities of water we will be producing, but the upper limit is dependent on the kind of pump that we install, and generally the kind of pump that we think we'll be installing would produce less than 1000 barrels a day. R & R C O U R T R,E P 0 R T E R S 810 N STREET 1007 UEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 41 Now we expect that the actual water production rate to be far less than that. We're hoping it's almost zero, but we don't know that until we start producing. There are some places in the U.S. that produce coalbed methane with almost no water production. If we're lucky, we'll be in one of those spots. CHAIRMAN JOHNSTON: I think earlier you said that some of the residents out in this area actually have their wells in coal seams and they're extracting their drinking water from it? MR. LAPPI: That's correct. CHAIRMAN JOHNSTON: Are you proposing on dewatering any coals that may be a source of drinking water for people in the local area? MR. LAPPI: No. As I said, the general geology ,, is that the surface 2000 feet is -- the section from 0 to 2000 feet is fairly flat-lying. It dips about five to seven degrees to the north, and the coal seams that we're planning on dewatering are at -- probably at more than a 1000 feet depth, so they're vertically and -- vertically separated from and probably discontinuous with any sources of fresh water that homeowners may have. CHAIRMAN JOHNSTON: And~do you have any difficulty with providing us with an annual update on your project? MR. LAPPI: No, none at all. R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 42 COMMISSIONER DOUGLASS: Mr. Lappi, earlier I asked about the data from the state's well and some yields, et cetera. Could you also -- would you have any difficulty, I guess, with providing us with an estimate of what kind of resource you're expecting or would hope to see in your development, along with that information? MR. LAPPI: Well, the actual gas content depends on depth. The gas content of coal depends on depth, and in the State's well we saw about 50 cubic feet per ton at around 400 feet, and 245 cubic feet per ton at 1200 feet. And for reserves numbers, I'm using around 300 cubic feet per ton as an average figure. And it really depends on the volume of coal present what the resource actually is. Now we've seen from the surface down to 1300 feet about 50 feet of coal. If that number is accurate we could have 80 feet of coal in that first 2000 feet. And it's just a matter of doing a little mathematics to come up with reserve figures then on a given volume of coal -- a given area. COMMISSIONER DOUGLASS: That's sort of what I'm looking for, your set of assumptions and what you would see ..... MR. LAPPI: Each ..... COMMISSIONER DOUGLASS: ..... as your expected resource. MR. LAPPI: Yeah, under my set of assumptions R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 , ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 43 each well would be drilled to 2000 feet should give us reserves of about 2 BCF of which probably 1 BCF is recoverable, assuming 50 percent recovery. COMMISSIONER DOUGLASS: All right. CHAIRMAN JOHNSTON: Okay, Mr. Lappi, I don't believe the Commission has any other questions of you today, and we appreciate you attending and letting us know about your project and wish you a world of success. We should have some rules out for you probably within 30 days. MR. LAPPI: Great. I appreciate the Commission's efforts in helping along this brand new resource, and hopefully we'll have a new source of royalty income for the State and a new source of income for my company. Thank you. CHAIRMAN JOHNSTON: Do you see any need to hold the record -- I think we need to hold it open for a few days anyway until this information comes in. (Commissioners confer in whispered tones) CHAIRMAN JOHNSTON: Is there anybody wishing in the audience to make a statement or address the Commission? Seeing none, What we'd like to do then is to hold the record open in this matter one week and that will allow us the opportunity to have this information that we've requested be forwarded to us, and if in that time we see any other additional concerns, we'd like to call you back in, but I don't anticipate that. If you do not hear from us we'll be closing R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8982 272-7515 ANCHORAGE, ALASKA 99501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 44 the record then at the close of business next Friday ..... COMMISSIONER DOUGLASS: That would be the 9th. CHAIRMAN JOHNSTON: ..... on the 9th. Thank you. (Off record - 10:32 a.m.) (END OF PROCEEDING) R & R COURT REPORTERS 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274-8082 272-7515 ANCHORAGE, ALASKA 00501 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 45 CERTIFICATE UNITED STATES OF AMERICA) ) SS. STATE OF ALASKA ) I, Laurel L. Evenson, Notary Public in and for the State of Alaska, residing at Anchorage, Alaska, and reporter for R & R Court Reporters, Inc., do hereby certify: THAT the annexed and foregoing Public Hearing of the Alaska Oil and Gas Conservation Commission Re: The application of Lapp Resources Inc. for a public hearing to present testimony for classification of a new gas pool and prescribing pool rules for its development in Section 21, T18N Seward Meridian, was taken before me on the 2nd day of June 1995, commencing at the hour of 9:00 o'clock a.m., at the offices of the Alaska Oil & Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska, pursuant to Notice; THAT this Transcript, as heretofore annexed, is a true and correct transcription of the testimony given at said Public Hearing, taken by myself and thereafter transcribed by myself; THAT the original of the Transcript will be lodged with the Alaska Oil & Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska; IN WITNESS WHEREOF, I have hereunto set my hand and affixed my seal this 7th day of June 1995. Notary Public in and for Alaska STATE OF ALASIC~ NOTARY PUBLIC LAUREL L. EVENSON RECEIVED JUN - glasS.oil .& Gas Cons. Commi~mon ., R ,% R COU R T R E P O R T E R S 810 N STREET 1007 WEST THIRD AVENUE 277-0572/Fax 274- 8982 272-7515 ANCHORAGE, ALASKA 99501 IUN-02-'95 FRI 14:54 ID:LAgP RESOURCES TEL NO:! 907 249 ?278 'l'ele~one + 1 i907) 248-71 $8 ~415 PO1 .................... LAPP Resources Inc, 4900 $por~sman Drive Anchoraae, Alaska U.$.A. 99502-416~ F&csimil~ + I (907} 24,8-7278 'The Comml~innars Alnske 041 ~d O~ Con~a~on Commis~on 3~1 P~~ D~ve ~ gift: ~k you for your at,non ~ our Sas devel~ment drillin~ p~j~t a~ Houston du~ng our pubic h~ ~s m~, P~or ~ ~ h~n~, ~e follewin~ pi~s of informa~on w~e A le~ d~p~on of thc p~pos~ d~?lopment ~ which consists of six 40-~ sp~in$ uni~ ~ o~ whi~ will ~ dflll~ th~s summer: SE1/4 ~1/4, Nl/l SB1/4, SW1/4 SB1/4, Bl/2 SW1/4 S~on 21 ~e 3W ~wnshlp 18N 8owed A ~ M~ a~ ~e ~e of two inches ~as 1~ f~t: ~ have suppli~ ~h~ only lo~ availabl~ al this ~ime for th~ betw~ ~e s~rface ang 11~ f~ which Is ~ Amcflcan S~d~raphic Comply culgn~s lo~ which I have reprgduc~ at ~wi~ l~s natu~l s~c. It Is a,~r ph0~py which I a~logl~ for, ~ut ~ repr~ucible copy is own~ by a m~or ~m~y ~d is unavailable ~ Ano~er, probably more a~ura~e log, ~as also b~n suppii~ ~o Anchor~e ~as ~d Oil D~v~lopmen~ Comply mu~ log ~owing li~h01ogy ~llin~ m~,f~r ~e in~e~ b~tw~n 120 f~t and 13~0 f~t, Approxiaa~ly ~t o~ co~ ~s m~~ f~om this lo~ in ~ai inca. During ~e h~ng, s~er~ ~dition~ pi~es of inbrmation were r~uest~ ~d ~ey ~~h~wlth, C~I analysls showin~ ~as ~ntents from ~h= S~te's AK-94CBM-1 w~l n~ ~silla, Gas analysis of th~ cosl~m ~ss from A~.94CRM-1 and ~ local w=ter well. Quotation from ~alliburton tn plug ~nd abandon our ~ouston gas wells. Sincerely, David W. Lapps President RECEIVED JUN 02 1995 Alaska Oil & Gas Con~. Commi~sion Anchora,.;~ ZMN-02-'95 FRI 14:55 ID:LAPP RESOURCES INC TEL NO:i ~415 P02 temperatures (permafrost), they have low potential t'or codbed meUmtne prmltx:uon, COOK I~L.E'r-su~"I'N,~ ~'ROVI:NCE With hypothetical resources exceeding 1,5 trillion short ton~, the Cook Inlet. iusltaa Province (FiSures 2 a.,ul G) constitute thc tccond iarsest coal resour~ in the state, The province covets afl ~r~a or approximately 14,000 scpu~ mib (36,000 sci {au), which Ls bounded by ~ ~nai extends north to the Alaska Range and the ?alkcetna lviott~tttns, Unlike many other areas of the state, portions ~fl~e ~ Inlet*$usitna Province arc road ~ccessible, Tl~ t'lz~t m&Jo~ commer~l~I otl clJscove,y ia Al~k~ $~tnlon River Field in 1~S9, Subsequent ell and di~o~ have produ~d over 1.2 hiliinn ha~ls of nil t,S tcf of ~as. Seismic, well and production data from wltb~ the basin provide an extensive data base which 8maUy ~a~s coalbed exploration risk. Additioflall~, COOk Inlet oil and Sas production has created ~t~ w~ch may enable ne~ ~ ~ ~velopmenL Cook hdvt 'l~e amok Znlet Basin is located in ~c ~c-Lrcnch Gnp betwe~ ~e voleafl~A or thl Al~ka-Aleu~an A~Se and the ~tl~ ~neh. Over ~S.~0 feet (7,6~ m) of Te~ ~flfl~ntM deposiu unconfe~ably nverlia mn. fly madn~ M~o~c MC~ [16~, ~tbouth coal Is found in thc enU~ ~ ~on, ~ O~g~n~ ~o Mi~ene Tyun~k ~d thc Pgeo~nt Chl~katoon Formations (Fisure 7) have the is ~spmad across Cook Inlet B~Ln. ~ ~oal reeds ha~ ~n mapp~ wher~ It ;reps out on ~c west silo of Cook hill ~c Chivkalvvn Fv~nd~n i~ llmi~d to the fl~ ~o~ Of~e Cook Inlet D~, Cook {ItJ~t {latin forms a l~r~ tenth with the basin asia loosed Just ~st nf Eeest and roughly upBfl ~ ~ bu~ m~ifls, older ~s ~t~gty ~ txp0~d ou the b~in m~gins, whUe mc~ of ~ ~ ~d ~ rustily ~ur it ai~ficant ~p~ g00{ ~ ~k of ~ b~ln, Per ex.pie, the b~n ara at 5,0~ feet (l,~00 m) ne~ toe b~in ease ~lum ~), Hul~n= upl~t h~ brousht th6 ~lck co~a of m~{ ~e of ~e o~hom ~u of ~e Cook Inlet buiu In 1994, the Sate of Alaska funded a core horn to mampl~ Tyontk Formation co~ nc. ar Wuilla, I~a=d in the northers portion of Cook Inlet Basin, The core hole ~CB~-i) wo dallied on & previously identified pro~pcct tiT] (Filure ii) IO~ated ~tween the towns of Palmer and Not~10n and n~m* roa~ and {lo pipeline, in ~U It~a, Ty~nr, k Itmmumtion is e~timatmd to have a toutl ~lclatcSS in exce~s of 4.000 feet (1,220 m) with cumulative coal thickness excee{lin{ 100 feet (30 fit). Hi~{h,vr~lntiic t)ttumtnous coals are expcc~ to Om present at 0~pth{ AK. D4CBM. 1 w~ dH{led to a total depth of 1 feet (3Ri m), cnntinuottsly corin8 the Tyonek l~orm~tion from the surface caslnj shoe at 354 feet (~SO m) ,o depth. Elfhteen ~ams o~ hiih-volatile C bituminous coal w~re encounter~ with the thickest bcini 6.5 feet {3,0 m] mod ~ cumulative thtc~e~ of 41 feet (11.5 m). Th~een of t~ coal seams we, re sm'npled for la{ content using 38 las d~orptton canisters. Ou content ran~s from 63 scl/ton [I,96 cc/s) to 245 scflton (7.66 cc/8), Gas content and vitrinite reflectance {enerai{,y increase with depth, while · oistur¢ decreases, Coal m0tSt0re conte~ts arc low, r~Bins t~om 9.02~t at~21 feet (1~9 m) tu 4.82~ lit rcct (~t?? m), Oaa aflatya~a ahow that carbon [{otopc5 ~come sUeht{y heavier with depth tndi~tin{ an tncr~ in the the. rmi)gcnic/bioscnic Su rntin. Tha range of-g.q~ to - 43,2 8*SC for methnne encountered here ts indicative nf coalbed gas uhat has both bio,chic an4 thermo{eflic sources, Oas composition is 99~ methans with' minor amount{ o[ ¢O~ and N2. Due to cost constraints, the ({rlllin{ pilgrim ~-' was dcs~fl~d solely to a~luire C0ai samples for analysis therefore the well was not fl0w teste~l, Porosity and permeability measurements hive not teen obtained, From visual analysis, coal cleat arid fHteture density is w~dely ~pm:cd with wrti~ai fractures uccuntng t to ;{ inches (2.5 to 7,6 em) ap~t, CaI;it~ cantina was noted ~n aunm uf thc fraoture 9urfaaom which may lower cff¢¢tiYc pcrmoability, Al~o~t no fr~mre{ were noted in the ~{amtie tonka, Pi{sure .9 outlines the cost analyses from e~re samples for tJ'Js well. Tho coai-I~arlng Chickaloon Formation occurs only in ~he Matanuska Yalicy area north o~ Palmer (Piiture These coals {mare been mince from 1~14 to 1968, Oeolosiats with the B~{eau of Mines and the U, Oeoloiical Survey [181 ,have slipped the extent of these ~oals tn detail ustn{ outcrop, miata{ an({ cart hole data, Moat of tim coal is ¢o~ghted tu thc ~pp~ 1,400 reel (42~ m) o~ the{ Cht~ke.loon Formation, which im {treater thin 3,000 i'est ({)t4 m) thick Lit{l. The noel in thc l~ormatiotm rs, ns}es in rank f~oru htBh-volatJle bitunltn~us to anthracite, Coal beds up to ii fee! (10 m) !hick {nd laterally continuous for up tn .~ mii~.s (8 ks) have been mapped in faulted syrtclines that increase in structural severity to the east LiB and Ii)l, The preson¢c of coalbed Sas ham been documented by mine exploiioas which occurred in i937 tad in ILg~{"/, In the ii){? incident, a ViOLent me~ane and eust explosion in tl~ Bv~ Jonea Mine, loeaum~J 12 ,nil~ (i~ ks) north of Palmer, ~illea 14, men. Tim 191f'7 inoideot wu mmOth~ methane and dust explosion tn the same mine, ir, LIUnit 5 men, Barnes and Payne [18] estimm that over half of the coal rtserves lie beneath 1,000 to 2.000 feet (305 to 610 m) of overburden. Bituminous rank coal at shallow depths and the methane Su Pr°bios' ass°cia'd it~i~n§°mbine REeE' i-' , J U N O 2 Alaska Oil & Gas Cons. Commission Anchora~ JUN-02-'95 FRI 14:56 ID:LRPP RESOURCES INC {' TEL NO:i 98? 248 ?2?8 {' ~415 P03 United Sta es Department of the Interior Thoma~ N. State of Divt~lon P,O. ~ox ~07034 Your two Baa ~amples went the lon~ way arounci, ti~ough Lea and ~n Bird and ~a P~ before ~ey made ~ete way to me! ~Uma~y I ~y to ~aly~e ~ampl~ a~ noon a~ t~y are received be~a~e t~re is always ~ ehane~ ~ey ie~ and there is alto a g~ ?vs~bi~ o~bJoge~ c ~teta6on ff a d~e~t ~ u.~. ~ere was ve~ li~lc g2 ~ ~ ~ample, ,o t feel c~ffident sample die ~ leak. ~a you by my ~ance u~ ~ ai~e~em ~o ~at ~e wa~ ~t you bubbled ~ ga~ ~ough when ~e sample wa~ ?listed? I u~ zepharm c~o~de (about 1.2 drapers ~ll ~ a two gel.ton bt~cke~ fiD. ed ~ water, Z reuae · e buret of ~en~d water ~or a days w~ of collecffon). A~ you p~bably ~ If ~gm' are present ~ the ~ample, ~y will ~ter ~ re~utung i~tope due ~ biogemc activin. Xeep ~ in ~td when you l~ et the lSotop~ V~Ue r~por~d below; ~e &13C ~.at I ~ re,orang l~ks reasonable ~om my also ~e 81~C of ~e me~e ~ac~on of t~ gas; the res~ a~ giv~ below. 1 ga~red ~at ~e ~o ~es contained the same gas, ~xd so o~y one was ~, X 8a~t t~t a GC was done somewhere else, and they re,fred appre~ably more N~ I am a.~~ that Ihs disparity ia due ~ ei~e: the other laborato~es a~plag tee~ique, or e~ the split of gas ~ey receiv~ ~d mom N2 ~ ~ I reeetved, gtand~d &via~on o~ &e 81.5C ts ~ .10 pe~; ~ ~ot~e rmm~ ere tcpor~d r~ta~v, to ttw PD~ ~t~ndard. you l~ave any questiom, plsaa~ contact me at (303) 236.9375. Holm the data are RECEIVED JUN 02 1995 oil & ~as cons. commission Anchora,? LITHOLOGY Legend · - = -~ · ~ SiH~onenndmud~tone ~.0~'.': ~ Sandstone ~o~:~2... %. ~ Glacial deposits .................... :::.:-~.:. -: :-:-:-:-:*:-:-?:~-:-:-?: :::::::::::::::::::::::::::::::::::::__ · _.~...-~ ........-.-....-..~...- .~ ~_~._...z.,.-_..~.._..._-_.~_._. _~ 1 1.~ ~ ~.02 8.47 ~ ~.Zl 0_~ ' ::~:::~::::::: :Z:::: :::::::-:::: cL::::~:::::: x:::-:::::::::::::; ~ 4.14 182 7.13 i 9.~ 8~.78 40.49 :C-:CC-:-:-: - :-:-: :-:-:-:-:-:-:~ ='~ ..... : ....... 3 4.99 1~0 7.~ 11.80 ~.~ 46143 -~.9 ¢~:]:~:~:~::: :~:~:: ~:~ :~:~:~:_:~ - 4 ~.31 1~ 7.96 8~ ~ ~.~ 0.47 ~-----~'-~--='~'-'-'-'-'-'-'~. ~ 5.16 1~ ~06 49.~ 21.93 ~.21 ~9.3 6 ~.~ 1~ 6.02 14.~ 88.~ ~.~ 0.56 ~8.3 ::::::::::::::::::::::::::::::::::::: ,:.:.:.:.:+:.:.:.:.:.:~_:+ .:_:.:.:, ~ '~"'"~='"'":"='~'='=': 12 [7~ 1~ 5.23 ~.74 ~ E. I9 O~ ~.3 ]:igure 9. Coal analys~s For AK-94CBM- 1. F --~ 1-11 U-] CZ} I-- C-) m OH,LLIIORTON TEL NO:i gE)? 248 ?2?8 I I III II ................. IIII '2JIpmm _ I II ..... II I - I~415 PE)5 F',~. Lapp Resources, Inc. Houston Area Alaska Cementing PTA Recommendation Prepared for: Dave Lappi 4900 Sportam,'m Drive Anchorage, Alaska 9950;~ Fax: (~7} 24B-727S 4128195 Prepared by: Mark Wedman 14alllbunen ]gnerg? ,~ervice~ 6900 Areli¢ Blvd. ~UN-02-' 95 FRI 14:57 ! D: LAPP RESOURCES ! NC TEL NO:i 987 248 7278 ~415 PO~ HALLIBURTON Plug to Abandon Iqalliburton l~n~r~ Sct'vi~:a ~ppr~ia/e$ t~iS oppo~nit)' to be of service to you. The ~n~los~fl cost est~ate ~s 5used on E~lliburton Energy Services m~bUiz~g out of our K~i/N~isM l~ation. Cemem is ~o ~ pumped via tl~e 1-i.'2" CT and circulated to ~urface, ~p R.~souree, to provide the mixing ~ater required and sufficiem mixi~ wager tO ¢le~ cemem pumping e~uipm~n/. Lapp Rcsoumes to provide a mean, to stor~ ~xces~ cement slu~' and wstet' used to clean up l~ z,m~ml, ng unit and m dispose of said material: I apologize for 11o[ getting' this information to you sooner, but I wa~ out oI: town until ~ts we~k. If you hav,~ any questions or need any a~dillon,~l :nfc, nnation, please ~eei free to ¢o~t~ct mc ~nyrimc. M~z.lt W~Iman, T~tcal Specialist 'V' ~TUN-02-'95 FRI 14:5B ID:L~PP RESOURCES INC i TEL NO:i gO? 248 ?2?8 { ~415 P0? O~ 'HALLIBURTON -- Il II[-~'~- '--Innlllll ]'lug to Abandon Well Infun~a ffen ...... Existing Surface 300 ft. Bx~Stin$ Produ~;tiun Ca$i~: ~100 f[ .. 4" C~.~ing Tubin~ PTA Cmm~nt lnt;~al 0-zl(X) fl Inside 1-1/2" CT and 1.t/2" CT x 4" Casing Annulus Caie~ffons ....... ___. _ . ~. , ,m ~,..,.,: ..... PREMIUM CEMENT: (2100 ft fill) 2100 ft * 0.0345 t't:,tft * TOTAL. PREMIUM CEMENT Job R~,omm~~on ........ ._ .... I:LUID 1' FRt/SH WATER Fr~h Wator FLUID 2: PREMIUM CEMIiNT PTA Cemem $1ur~ 2 ~ Calcium Chlorid~ - ^.rlhy (Accelerator) Mixed Wi~ Pres]~ Water - 114,54 = 114.54 fO -- 20.40 bbls Top of Fl[lid: Circulated Fluid Volume: $ bbl~ Pluid Weight: Fluid Yield: Fluid Water Ratio: Total Mixing Fluid: Top of C~4culat~d Fill: Fluid Volume: CalCulated Volume: Propo~,cl Volume; 15.8 lb/gal 1.15 ff.Vsk 5,0 gal/sk 11,? bl~ls 2100 ti ~0.40 bbb 100.0 sks 100 ~ks RECEIVED jUN cz 995 hla~a 0il & Gas Cons. Commi~qion ^nehora? ~UN-O~-~ FRI 14:5~ ID:L~PP ~ESOLJ~CES INC TEL NO: 1 98? 248 ?P?B ~415 POB OtH~,LLISORTON _ Cent 6 tfft ate _._. I J I MILEAGE CEMENTING ROUND TRIP $60 MI t UNT UNT OPERATOR ~ff. ~EMffNTING 2 MAN t9 HR lo HR FOOD AND ~DOINO AND TRAVEL ~XP~NSES Z DAY 3 MAN PLUOO{NO BK ~T CEMENT OR MUD l i UNT CF.M~T · PREMIUM tOO ANHYDROUS CA~IUM CIILORID~ 3 ~V~ ~VIC~ C~AROE ~06 CFT · tOO $ 2,2,$0,oo 3.00 1,6S0,00 i. 1:5 I,~52.50 13.00 1 ,$00.00 70.00 700.00 ~j0,0o ! 3s0.oo 22.00 2,200.00 ~4,05 192,15 1,55 18~.'~0 1,00 10~.00 TOTAL CO.ST gSTIMA'['E $ DI~OUN'rt/D I"O'rAL COST ESTIMATE $ 10,000.00 NOTE,: ...'~ervlc¢ [,O~ation - Kens/, Conait t ... Th~ cost in this analysis i$ good for the materiats and/or services outlined within. These prices are bas~d on Hallibu~on Services being awarded the work. on a first call basis. ~ic. es will b~ t~vi~w~d for adjusm~ents if awa~d~ on 2nd ar Ard c.~l baals aM/or after ~0 days of thia wriu~a a~ly~B, ~is i~ i~ ~n ~ffon ~o schedule our work and maintain a high qualiW of p~on~a~e fo~ o~r cu~tom~rs. ThC unit prices stated ia ~¢ proposal are based on ,.',ur current published prices. The projected equipment, perso~el, and ~terial nee,'l~ are o~y e~ti~ate~ based on ido~afion a~ut ~e work presently ~vaflable ~o us. At ~e :~le ~e ~,ork is actually performed, condiaom ~en exi~ti~ ~y ~qu~:e a~ incr~a~ or dcc~as~ in :he equipment, perso~el, and/or material needs. ~r~oa will b~ based upo, uzm pc~s la effect at ~a t~e ~e work is ~rfo~ed and ~c amount of equipment, persomol, andto~ ~terial actually util~z~ in ~e worg, Taxes, if any, ate not include. Appli~abl~ taxes, if any, will be added to the aaual invoice. It i~ ur. derstood and agreed between thc parties that with exception of t.h¢ subject discounts, all ~id ~rviccs a~ materials will be ~mishe~ in a~z'dm~e wi~ ~e ~ a~d condkiom of ~lll~on ~e~i~s' re~lar work oMers appliaable to the panicu~ item. con~tion, it is also understood and agreed the) Customer will continue to execu~ Hallib~n Servi~s usual field work oMers and/or tickets customarily requffcd by Halltbullon Sc~i~a in conn~tion wi~ ~e ~sMng of said ~i¢~s and Telephone + 1 (907) 248-7188 LAPP Resources Inc. 4900 Sportsman Drive Anchorage, Alaska U.S.A. 99502-41 69 Facsimile + 1 (907) 248-7278 June 23, 1995 The Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Sirs: Thank you for conducting the public hearing on our proposed pool rules and gas pool at Houston on June 2, 1995. In an effort to supply the Commission with thoughts which have occurred to me since the hearing, I offer the following comments. During the hearing, Mr. Johnston asked me if I knew of any occurrences of overpressuring in the project area. At the time, I replied that I was not aware of any overpressured zones, except that one DST conducted over thirty years ago reported gas pressures slightly above normal, but that records are sketchy. In fact, the documentation for this test is not in the public record and may have been lost. Reflecting on Mr. Johnston's question later, I realized that artesian water flows which were reported in the area during deep coal exploration drilling could be construed as evidence of overpressuring. In the strictest sense therefore, overpressuring has been reported in the area during previous drilling. Enclosed is the US Bureau of Mines report on their early 1950s drill- ing program where artesian water was encountered. After the public hearing, Mr. Tom Smith (DNR Div of Oil and Gas), who was at the hearing, reported to me that he had heard of a report that a man was killed during a coal drilling opera- tion in the Mat-Su Valley. He and I tried to track down this report during the next week by we were unsuccessful in locat- ing the source of the rumor, or verifying it. We believe that it may be a report of a problem encountered in one of the many coal mines in the Sutton region northeast of Palmer. I look forward to your decision in the near future. Sincerely, David W. Lappi President INVESTIGATION OF SUBBITUMINOUS-COAL BEDS NEAR HOUSTON, WESTWARD EXTREMITY · OF MATANUSKA COALFIELD, ALASKA BY R. R. MAY AND R. S. WARFIELD , o o , . . ~ . . Report of Investigations 5350 UNITED STATES DEPARTMENT OF THE INTERIOR Fred A. Seaton, Secretary BUREAU OF MINES Marlins; J. Ankeny, Director Work ~ aanuscript completed Noven~er 1956. The Bureau of Mines will welcoae reprinting of this paper, provided the followinl[ footnote acknowledgment is made: "Reprinted from Bureau of Mines Report of Investigations 5350? RECEIVED JUN 2 ~ 1995 Alaska 0il & Gas Cons. Commission Anch,~:"~',,",? August 1957 INVESTIGATION OF SUBBITUMINOUS-COAL BEDS NEAR HOUSTON, WESTWARD EXTREMITY OF IvlATANUSKA COALFIELD, ALASKA by R. R. /Vlay~/ and R. S. Warfield~/ CONTENT S Page Summary ....................... ~- Ackr~owledgment s ........................ 2 Location and access ........................................ 2 Topography ................................................. 2 Climate (as it affects operations) ......................... 2 History and production .......................................... 4 Geology ......................................................... 4 The coal ........................................................ 5 Coal sampling and analysis ................................. 5 Mining and preparation ..................................... 7 Work by the Bureau of Mines ..................................... 7 Preliminary examination .................................... 7 Diamond drilling ........................................... 7 Interpretation of drilling results ......................... 9 Appendix ............................................ 12 .ogs &giii' ; 2; .... '.'"'"".'"'."'.".'"'"'"'." 1/ Solid fuels mining engineer, Bureau of Mines, Region I, Alaska district, Anchorage, Alaska. ~/ Mine examination and exploration engineer, Bureau of Mines, Region I, Juneau, Alaska. Report of Investigations 5350 R £CrclV F.l) JUN 2,~ 1995 OiJ & Gas Cons. Commission ii ILLUSTRATIONS Fig. Pa~5e 1. Location map~ Houston coal-drilling project ................. 3 2. Plan, Houston coal-drilling project ......................... 8 3. Section A-A' and graphic logs, Houston coal-drilling project 10 TABLES 1. Section in strip mine near old Evan Jones slope ............. 6 2. Section in strip mine 1,200 feet northeast of old Evan Jones slope ............................................... 6 3. Analyses of face samples from section 1,200 feet northeast of old Evan Jones slope ................................... 6 4. Analyses of diamond-drill core samples from Houston coal- drilling project .......................................... 11 SUMMARY A preliminary examination of the Houston strip-coal mine, situated on the Alaska Railroad at milepost 175 (61 rail miles north of Anchorage, Alaska) and a review of all available information resulting from early coal exploration activities in the area resulted in plans to investigate the coal-bearing formations at depth by means of diamond core, drilling to indicate the existence of additional reserves of coal in close proximity to railroad transportation, where it would be quickly available to meet rapidly expanding military and civilian fuel requirements. From the da. re of mobilization of equipment, August 28, 1951, until date of sus- pension, August 18, 1952, 2.,010 feet of diamond drilling was completed. Ten defin- able coal beds were cut, of which 2 appear to be persistent and minable over an area of approximately 1/2 square mile. Within this area the 2 minable beds contain approximately 5,000,000 tons of coal in place. Of the remaining beds, at least two others may be minable to the eastward near their projected outcrops; however, these and deeper beds (at least in the vicinity of the drill holes) lie beneath a zone of pressurized gas and brackish water. From a practical standpoint, continued develop- ment and utilization of the coal in this vicinity will depend on the operators' in- genuity in developing cheap mining methods and on diligent prospecting for strippable coal under the comparatively light glacial cover. INTRODUCT I ON Since the advent and expansion of military installations in south central Alaska, coupled with the resultant rapid growth of population, the delineation and development of the Matanuska coal field have assumed considerable importance, particularly in those parts of the field that are accessible by existing transportation facilities. Little work of an evaluating nature had been done before this project was undertaken at the western end of the Matanuska field, which abuts the main line of the Alaska Railroad at Houston, approximately 60 miles north of Anchorage. Although the rank of the exposed beds in the immediate vicinity of Houstin is subbituminous, recent exploration by the Federal Geological Survey indicated a defi- nite tie with the extensive bituminous beds of the Chickaloon coal-bearing formation now in production a few miles eastward. Discovery of additional minable beds not only would augment the Houston-area reserve but might lead to the discovery of nearby reserves which, because of closer proximity to the Talkeetna Mountain uplift, might have bituminous rank. From observation of past and present workings and of the indicated geological attitude of the coal-bearing formation, it appeared that a very limited drilling pro- gram would procure the desired information. The following report presents the data obtained by the drilling program and an interpretation of the data. ACKNOWLEDGMENT S Many of the historical data, as well as cooperation in appraisal and sampling before initiation of the project, were furnished by Dr. George Gates and Dr. Farrell Barnes of the Alaskan Geology Branch, Federal Geological Survey° Core and face sam- ples of coal taken before and during the work were analyzed by the Bureau of Mines Coal-Analysis Section, Pittsburgh, Pa., under the direction of R. F. Abernethy, chief° The engineering department of the Alaska Railroad furnished basic alinement and ele- vation details upon which the survey of the drilling area was based. Tucker & Peter- son, lessors, and Duck Flat Co., production contractors, assisted the work by fur- nishing housing and messing facilities and the occasional use of heavy equipment. DESCRIPTION OF AREA Location and Access The limited area covered by the activities described in this report is within 2 miles of Houston, a station at 240 feet altitude on the main line of the Alaska Rail- road at mile 175 (fig. 1). Houston is 61 miles north of Anchorage, near the western toe of the Talkeetna Range, on the edge of the broad Susitna River ~alley. When this project was in progress there was no highway access, but a road from Pittman (mile 167 on the Alaska Railroad) has since made the mine accessible over the Alaska high- way system. Topography The Houston-project area is on the eastern edge of the Susitna River Valley, which is essentially a broad tundra flat cut by many, very small, meandering creeks. The Alaska Railroad follows the toe of the foothills that slope gently upward toward the mountains in an undulating series of benches; the project area is beside the rail- road and at the base of this terraced slope. The Susitna Valley, which at this point is fully 25 miles wide, appears to be covered with a semisubmerged, recessional moraine. Tundra areas on this moraine consist of grassy swamps and pools, with patches of scrubby spruce and brushy willow. The rising ground to the eastward is covered by glacial de- posits of various types and by a thick forest growth; spruce and'birch predominate. As'might be expected in an area where bedrock is almost completely concealed, the orig- inal coal discovery was made in a cut incidental to railroad construction. Climate CAs It Affects Operations~ The climate here is suitable for outside operations during only about 6 months of the year, unless shop facilities are heated and insulated and unless all-weather roads are constructed and at considerable expense. January and February are the coldes~ months, with an average daily low of minus 20°.· During June, July, and August the daily high usually is in the 60's, but during calm, clear days the temperature often is in the 80's. Annual precipitation records for the immediate vicinity of Houston are not available, but estimates indicate a combined rain and snow content of about 50 inches. Except where it is drifted, winter snows seldom accumulate to depths of more than 3 feet. Summer rains generally are unpredicatable as to monthly intensity; they seldom are heavy but often are persistent enough during early and late summer to hamper hauling and road-maintenance work with heavy equipment. The outdoor working season for stripping overburden usually is mid-May to mid- October, although much subsidiary work can be done a month or so before and after these dates; however, unless expensive methods are adopted, mining operators seldom Houst'on poll'fie Wishbone 0 Scole of Miles Figure 1. - Location map, Houston coal-drilling proiect. strip overburden until June, because the ground usually freezes to a depth of 5 to 7 feet; thawing produces a tremendous amount of surface water, which bogs down most heavy equipment. HISTORY AND PRODUCTION Coal was discovered in a right-of-way cut on the Alaska Railroad at Houston station in 1917. Although the early history of the development is somewhat clouded, it is known that, between 1917 to 1920, a coal-prospecting permit was granted on the 10-acre tract at the discovery site and that 2 slopes were driven on the coal meas- ures. According to reports, the slopes entered 2 beds of coal, which were 3-1/2 and 5 feet thick, respectively; the beds dipped 6° to 15° northeasterly. Production dur- ing this period is estimated at 10,000 to 15,000 tons of coal, which was sold to the Alaska Railroad and to the domestic market in Anchorage. Ail of the original work- ings have long been caved; even the caves are completely obscured by brush and slides. The site of this early activity is approximately one-half mile southeasterly of the present workings, from which it is separated by a low-lying muskeg swamp; therefore correlation of the discovery beds with beds in the project area would require consid- erable prospecting work beyond the scope of this project. Between 1920 and 1934 no mining or development work of consequence was done near Houston. In 1934 Arthur Heaven was granted a 160-acre homestead, which included patent rights to underlying coal. In 1935 Evan Jones obtained prospecting permits for 874.82 acres adjoining the homestead in sections 17, 18, and 20; in the same year he started a slope mine near the present position of the southeast corner of the strip pit. About 12,000 tons of coal was produced from the slope and from a few rooms before the operation was suspended in 1940. Between 1938 and 1940 Jones joined in partnership with George Tucker and Ralph Peterson; during this period the Heaven patent was purchased and became the nucleus of later operations. This partnership was terminated in 1940; thereafter permits were allowed to lapse until a revival of interest in 1948, when an expanding military market became apparent. In 1948 Tucker and Peterson organized the Houston Coal Co. and acquired a permit for access to an additional 1,800 acres next to the Heaven patent; from 1949 through the 1952 season approximately 65,000 tons of coal was marketed. Most of the coal was passed through a crushing, screening, and washing plant, which contained a Forrester- type jig capable of handling 15 to 25 tons per hour. Productio~ during 1951 and 1952 was under a management-sales agreement with the Duck Flat Co., a Los Angeles organi- zation. Virtually all production went to the military installations at Anchorage. GEOLOGY The geology of the Matanuska coal field is best known from the writings of Go C. Martin of the Federal Geological Survey, who first made a general reconnaissance of the region in 1905 and subsequently made detailed studies of the lowerS/ and upper~/ parts of the field in 1910 and 1913, respectively. As defined in early descriptions, the upper or eastern part of the Matanuska field included the Anthracite Ridge and Chickaloon districts; the lower or western part included the Eska and Moose Creek areas, as well as Wishbone Hill. Recent reconnaissance by the Geological Survey along the lower reaches of the Little Susitna River and its tributaries and the work at Houston by the Bureau of Mines indicate that the Matanuska field extends westward 3/ Martin, G. C., and Katz, F. J., Geology and Coalfields of the Lower Matanuska Valley, Alaska: Geol. Survey Bull. 500, 1912, 98 pp. 4/ Martin, G. C., and Mettle, J. B., Jr., Mineral Resources of the Upper Matanuska and Nelchina Valleys: Geol. Survey Bull. 592, 1914, pp. 273-299. from Moose Creek and includes the northern edge of the lowlands lying north of Knik Arm. Barnes designates these lowlands as the Little Susitna district of the Matanuska coalfield; Houston and the project area are in this district.~/ The following generalized description of the geology of the Matanuska coalfield is summarized from the above-cited publications, to which the reader is referred for detai is: Ail coal measures in the field occur in the Chickaloon formation (Tertiary), which is composed of 3,000 to 5,000 feet of claystone, siltstone, sandstone, thin beds of fine-grained conglomerate, and many beds of coal. The Chickaloon formation is overlain by the Eska conglomerate (Tertiary) and underlain by the Matanuska and Arkose ridge formations (Upper Cretaceous). The Eska conglomerate is not present in the stratigraphic section at Houston. Neither the Matanuska formation nor the Arkose ridge formation is exposed near Houston. At Houston and throughout the field individual beds in the Chickaloon formation, including the coal, tend to thin out or intergrade within relatively short distances. These changes in bed thickness are believed to be due primarily to the original len- ticular structure of the sedimentary deposits but also may be due in part to the crumpling and pinching out of the soft shales incident to folding of parts of the region; correlation of individual beds (including coal) for more than short distances is therefore uncertain or impossible. Correlation of the coal measures between districts, and often between mines in the same district, is complicated further by differences in the character of the coal that result from differences in the amount of faulting and folding from place to place. The coal at Houston is subbituminous; it occurs in relatively flat lying beds that have suffered little or no deformation. THE COAL Coal Sampling. and Analysis The following sections and samples were taken by R. R. May, Bureau of Mines min- ing engineer, and F. F. Barnes, geologist, Geological Survey, September 26, 1950. Sections and samples were taken in accordance with Bureau of Mines standard procedure and forwarded to Pittsburgh for analysis. Barnes, Farrell Fo, and Payne, Thomas G., The Wishbone Hill District, Matanuska Coal Field, Alaska: Geol. Survey Bull. 1016, 1956, p. 2. TABLE 1. - Section in strip mine~ near old Even Jones slop. e (top bench of strip-mine bed) Roof: Gray claystone, silty. Coaly shale to bone ........................................ Coal ....................................................... Coaly shale ................................................ Coal ....................................................... Bone ................................... o ................... Coal, bright ............................................... Bony coal .................................................. Coaly shale-i/ .............................................. Claystone, thin coal stringers-i/ ........................... C lays t one~l / ................................................ Bony coal (top of lower bench~ ............................. 1/ Denotes parting between upper and lower benches. Feet Inches 0 2-1/2 i-i/2 1 10 ? I 1-1/2 3-1/2 2 8 2 0 Partly exposed. TABLE 2. - Section in strip mine 1;200 feet northeast of old Even Jones slope (full section, both benches) Roof: Floor: Gray shale, coaly at base. Coal, dull glossy_i/ ......................... .............. Bone, bright-coal streaks ................................. Coal, bright~1/ ............................................ Coaly she le~2/ ............................................. Coaly shale and bone~2/ ..................................... Coal3_/ ...... i Coaly shale~3; .............................................. I Coal, clay sli~_~[[[[] ................................... Bone ....................................................... Coaly shale ................................................ 1/ Included in analysis, lab. No. D-51894 (table 3). 2/ Denotes parting between benches. ~/ Included in analysis~ lab. No. D-51895 (table 3). Feet Inches 0 9 7 i o-1/2 1 4 2 4 1 0 4 6 2 Partly exposed. TABLE 3. - Analyses of face samples from section 1;200 feet northeast of old Even Jones slope Air-drying Vol. Fixed Sample loss Condition Moisture matter Carbon D-51894 7.6 D-51895 6.7 20.3 13.7 17.4 11.5 31.6 34.2 39.6 44.8 32.5 34.8 39.3 47.0 38.9 42.1 48.9 55 o2 36.6 39.3 44.4 53.0 A 9 10 11 13 14 16 Sulfur B.t.u. 0.4 .5 .5 .6 .4 .5 .5 .6 9,210 9,970 11,550 13,060 9,160 9,820 11,090 13,250 Condition: A - as received. B - air-dried. C - moisture-free. D - moisture- and ash-free. Analyses by H. M. Cooper~ Bureau of Mines~ Pittsbursh~ Pa. Minin~ and Preparation Coal at the Houston mine (see table 1 for average section) is stripped and then mined in successive benches by drilling vertical blast holes with a portable electric auger on 5-foot centers; these holes are blasted lightly with 20-percent gelatin. After being broken, the coal is loaded by power shovel onto trucks~ which haul it to the washing plant approximately 1 mile from the pit. The raw coal tends to be coarse and slabby~ with many iron-silica-sulfur concretions; therefore it requires prelimi- nary breaking before being fed to the rolls. This breaking is accomplished by using a small crawler tractor to crush oversize through an 8-inch grizzly into the roll- crusher feed bin. Crushed coal for jig feed is sized to suit current contract spec- ifications, which usually require 2-1/2 inches top size. This product is fed either directly to through surge bins to a steam-driven Forrester-type coal jig with a 4- by 4-foot plunger section and a 4- by 6-foot bed section. The washed-coal discharge passes over a double-deck shaker sizing screen, with impinging sprays. Screen sizing varies with contract purchase specifications; fines may be optionally recovered in an Esperanza-type classifier in closed circuit with washer and screen or discarded sepa- rately. Because the plant level at the screen discharge is 30 feet or more above the car-loading siding, gondolas are loaded by chuting the coal to the cars. For best washing results plant capacity is 15 to 20 tons per hour, but careful mining often permits considerable overloading without appreciable detriment to the quality of finished coal. Observation of the plant operation under varying conditions indicates that the Forrester jig is not an ideal medium for separating this coal and its inherent impu- rities. Although the tendency of this coal to break in thin slabs undoubtedly af- fects jigging separation, it is apparent that there is a rather narrow differential in specific gravity between the shale-bone-coal components in this particular bed. system. WORK BY THE BUREAU OF MINES Preliminary Examination In September 1950, accompanied by F. F. Barnes of the Geological Survey, the writer inspected the mining activity at Houston. Bed sections were recorded, and samples were taken from the strip pit (see tables 1, 2, and 3). After the prevalent strike and dip of the measures (which were partly exposed for nearly a mile along the railroad) were ascertained, it was tentatively concluded that numerous beds on very moderate dips probably were present in the area. Before this examination the current lessors had put down several shallow auger holes in a mile-long area that extended a half mile or so from the railroad; these holes penetrated the overburden into bedrock until coaly material was found° Be- cause this coaly material was encountered within narrow ranges in a high percentage of the holes, it was assumed that the coal bed was undulating in some conformance with the existing topography and that the bed would be strippable throughout a large area. However, later evidence disproved this assumption; consequently, it was decided that a core-drilling pattern that would consist of 2 or 3 holes at intervals downdip would be required to clarify the situation. Diamond Drillin5 A Bureau of Mines diamond drill was shipped to Houston in late August 1951. The first hole was started near the strip pit highwall. This location (see fig. 2) was L.e~lend Diomond drill hole o . 4oo ~oo lFoo i/soo Figure 2. - Plan, Houston coal-drilling project. chosen to establish initial correlation of the coal measures with reference to the existing mine workings. Drilling conditions were difficult from the start; conse- quently, progress was slow. A heavy flow of gas and brackish water, which was en- countered during freezing weather, caused a shutdown November 10 at a hole depth of 481 feet 7 inches. The condition of the hole precluded resumption of drilling at this location at the beginning of the next season. Hole 2 was started May 29, 1952, at a new location; it reached a depth of 1,142 feet, which was considered sufficient to intercept any coal beds likely to outcrop or to come within practical mining depth within a radium of a mile or so. Hole 2 was completed August 5, 1952, and the drill was moved to the third location farther downdip, where drilling was resumed August 10. Hole 3 was completed August 18 at a depth of 386 feet. Termination at this relatively shallow depth was decided upon as soon as it appeared that a positive point of correlation with beds in hole 2 had been reached. Holes 2 and 3 were spaced at intervals of 2,050 and 2,910 feet, respectively, which was considered the maximum distance allowable for accurate correlation. Depths were governed by practical considerations of possible future mining operations within the immediate Houston area. The locations of the Rrill holes, pit, and washing plant and the topography of the Houston area are shown in figure 2. Graphic logs and a section through the drill holes are shown in figure 3. Analyses of core-drill samples are presented in table 4. Detailed descriptive logs of the drill holes and the results of megascopic examina- tion of coal core sections are given in the appendix. Interpretation of Drillin~ Results The area of conclusive results, particularly with regard to estimation of re- serves, should be limited to no more than a rectangular area, approximately 1 mile by 1/2 mile, whose long axis is roughly along the line of the 3 holes drilled. A number of thin coal beds dip 5° to 10° northwesterly; these beds may overlie or underlie the strip bed. Within this area no appreciable faulting or folding is apparent, but some minor folds or displacements may be concealed by the cover of glacial deposits and forest growth° Although several beds appear to be minable and an appreciable tonnage is in- dicated, it would be inadvisable to accept the reserve estimates without careful consideration of local peculiarities. Some of the factors that might modify the reserve estimates follow: (1) Washer recovery varies widely according to the type of cleaning equipment and mining practice. (2) It has been many years since underground mining has been practiced at this location; consequently, no accurate recovery factor is assignable. (3) Because of adverse drilling conditions, friability of the cored material, and the haphazard distribution of concretions in the coal measures, considerable difficulty was experienced in recovering core samples for other than visual inspec- tion and for comparison with coal currently being mined; therefore, core-drill sam- ples may not be exactly representative of the thickness and character of the coal beds drilled. 10 Collar El. ?_49 ® Collar El. 330 Collar El. 303 300 2OO lO0 -lO0 -200 -300 -4OO -500 -600 -7O0 -800 T J SECTION A-/~ 2900' 'Gas ~ water 1660' ~Strong gasiflow with brackish wirer' ~. 0 5,00 I000 15( Horizontal Scale in Feet 0 2000 0 o~ o o Figure 3. - Section A-A' and graphic logs, Houston coal-drilling project. TABLE 4. - A. nalyses of diamond-drill core samples from Houston coal-drilling project proxi~a'~e analysis, " 'Ultima~te analysis, Fus'ab'ility of ash, percent percent · OF Lab o o ~ .~ ~ ~ ~ .~ m ~ ~ o ~ ~ No 1/ o ~ ~ ~ ~ ~ ~ o ~ o ~ ~ o ~ o ~ ~ ' ' 1 ~10'.8" 32.9 37.3 19'.0"' 5.3 53.1 1.4 20.8 0.4 19.0 9,290 2,310 2,620' ' 2,740 D-74890 2 13.0 32.1 36.4 18.5 5.4 51.8 1.3 22.7 .3 18.5 9,070 (Hole 1) 3 36.9 41.8 21.3 4.6 59.5 1.5 12.7 .4 21.3 10,420 4 46.9 53.1 5.8 75.6 2.0 16.1 .5 13,240 1 9.5 30.9 33.2 26.4 4.9 48.0 1.2 19.2 .3 26.4 8,400 2,330 2,620 2,840 1.61 D-74891 2 12.1 30.0 32.2 25.7 5.0 46.7 1.2 21.1 .3 25 7 8,160 (Hole 1) 3 34.1 36.7 29.2 4.2 53.1 1.4 11.8 .3 29.2 9,280 4 48.2 51.8 5.9 75.0 1.9 16.8 .4 13,100 1 D-99651 2 10.2 30.9 38.1 20.8 .2 9,140 2,570 2,690 2,890 (Hole 2) 3 34.5 42.3 23.2 .3 10,180 ..... 4 44.~8 55.2 ... .3 1~250 1/ Pittsburgh laboratory number; see table following and logs for description of samples. 2/ 1, Air-dried; 2, as received; 3, moisture-free; 4, moisture- and ash-free. 3/ Determined by modified method. Description of drill-core samples, Houston project: Lab. No. D-74890: Hole 1; core logged 27 feet 3 inches to 30 feet 3 inches; core received 32 inches; 3-3/4 inches bone rejected; 4 inches coal loss in drilling; 28-1/4 inches coal in this sample. Lab. No. D-74891: Hole 1; core logged 33 feet 1 inch to 35 feet 8 inches; core received 30 inches; 6-1/2 inches bone rejected, 1 inch bone loss in drilling; 23-1/2 inches coal in this sample. Lab. No. D-99651: Hole 2; core logged 437 feet 6-1/2 inches to 441 feet 0 inch; core received 41-1/2 inches; 8-1/2 inches bone rejected; 33 inches coal in this sample. 12 As a basis for calculating tons of coal in place, the common factor for Alaskan subbituminous coals is 1 ton of mined raw coal (plan~ feed) per cubic yard in place in the mine. Two beds known to average 42 inches and more are the "pit" bed and a bed lying approximately 250 feet (stratigraphically) below. Other beds are simply grouped in the category "14 inches and more"; 2 of these may be 42 or more inches thick; however, the minability of the beds should not be inferred without more thorough investigation. On the above basis, the total amount of coal in the drilled area is estimated to be as follows: Tons in place Pit bed, average 5 ft. of coal .................... 2,580,000 250 bed, average 4 ft of coal .................... 2,000,000 Other~/, average total, 19 ft., 6 in ............. 10~000;000 Total ........................................ 14,580,000 1/ Appearance and specific gravity comparable to pit product. Study of the drilling logs, projection of the limited geologic evidence, and consolidation of known historical evidence in this locality indicates that investi- gation to the southeast for 1/2 to 1 mile might expose strippable beds amenable to more economical mining. As noted in the logs and elsewhere in this report, a con- siderable quantity of gas was encountered at a well-defined horizon in holes 1 and 2. Study of this phenomenon was beyond the scope of this investigation. The gas was predominantly methane. APPENDIX Lo$, Drill Hole 1 Location: 832.5 feet S. and 1,080 feet W. of NE. corner, sec. 20, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole - 303 feet. Depth " From- To- Thickness Ft. In. Ft. In. Material Ft. In. Remarks 0 0 11 0 Clay overburden. 11 0 Thin glacial cover previously stripped. 11 0 22 9 Interbedded fine sandstone and 11 9 silty claystone. 22 9 23 1 Ironstone. 4 23 1 27 3 Interlaminated fine sandstone 4 2 Roof, "Pit" bed. and silty claystone. 27 3 27 4~ Bone. 1~ 27 4~ 30 ~ COAL, dull; thin anthraxylon 2 8~ Core loss, 4 in. bands and lens es. 30 ~ 30 3 Bone. 2 ~ 30 3 30 9 Shale, dark gray, coaly streaks. 6 30 9 31 6 ClaYstone, dark gray, coaly I 9 Core loss, 7 in. 31 6 31 9 Shale, dark gray, carbonaceousj 3 31 9 32 2~ COAL, dull, thin anthraxylon I 5 ~ lenses. 32 2~ 32 4 Shale, dark gray, carbonaceous. 1~ 32 4 33 1 Claystone, coaly. 9 33 1 35 ~ COAL, dull; thin anthraxylon 1 11~ streaks and lenses. 13 Hole 1 (Con.) Depth From- To-' Thickness , , Ft. In. Ft. In. Material Ft. In. Remarks 35 ~ 35 3 Bone, broken. 0 2~ Core loss, i in, 35 3 35 8 Bone. 5 35 8 38 0 Claystone, few coaly streaks. 2 4 Floor, "Pit" bed. 38 0 39 4 C laystone, coaly. 1 4 39 4 43 7 Claystone. 4 3 43 7 46 8 Claystone, silty streaks. 3 1 46 8 47 0 Ironstone. 4 47 0 49 2 Claystone. 2 2 49 2 52 2 Claystone, silty streaks. 3 0 52 2 52 5 Ironstone, concretionary. 3 52 5 53 3 C laystone, silty. 10 53 3 53 8 Bone. 5 53 8 75 2 Claystone, silty. 21 6 Bedding almost hori- 75 2 77 2 Sandstone, medium, grading into 2 0 zontal; infrequent upper and lower strata. I crossbedding. 77 2 80 10 Claystone, silty. 3 8 80 10 81 8 Sandstone, silty. 10 81 8 82 1 Claystone, silty. 5 82 1 86 2 Sands tone, silty. 4 1 86 2 86 5 C laystone, silty° 3 86 5 87 9 Sandstone, silty. 1 4 87 9 90 5 Claystone. 2 8 90 5 92 1 Claystone, silty; sandy streaks 1 8 and coal fragments. 92 1 99 6 Claystone, silty; occasional : 7 5 coaly fragments 99 6 109 6 Sandstone, clayey matrix. 10 0 Core loss, 2 ft. 5 ir 109 6 242 0 Sandstone, soft, medium to '132 6 Core loss, 111 ft. fine, containing multiple bedsi of hard pebbles (quartz, chert', rhyolite, felsite, basalt) and occasional coal fragments. 242 0 243 9 Claystone, bone streaks. 1 9 243 0 258 9 Claystone, silty 15 0 Core loss, 2 fg. 258 9 296 9 Interbedded fine sandstone, 38 0 Core loss, 1 ft. siltstone, and claystone; occasional coaly streaks. 296 9 300 5 Claystone, coaly; many bright- 3 8 Core loss, 2 in. coal bands. 300 5 302 6 Claystone, coaly; few bright- 2 1 coal bands up to 1 in. thick. 302 6 312 8 Interbedded claystone and silt- 10 2 stone; occasional coaly fragments. 312 8 322 11 Siltstone, sandy streaks. 10 3 322 11 323 7 Claystone, coaly. 8 323 7 332 2 Interbedded silts, tone and 8 7 fine sands tone. 332 2 333 10 Interbedded siltstone and 1 8 clays tone. 14 Hole 1 (Con.) Depth From- To- Thickness Ft. In. Ft. In. Material Ft. In. Remarks 33~' 10 334 5 ~iltstone. 0 7 334 5 334 9 Shale, soft, dark. 4 334 9 335 2 Claystone. 5 335 2 336 0 Shale, soft, dark, occasional 10 coal fragments. 336 0 341 2 Interbedded siltstone and fine 5 2 sandstone. 341 2 341 9 Sandstone, soft. 7 341 9 342 3 Interbedded siltstone and fine 6 sandstone. 342 3 345 2 Sandstone, soft. 2 11 345 2 351 5 Interbedded siltstone and 6 3 claystone. 351 5 353 0 Claystone, soft, dark. 1 7 , 353 0 353 6 Siltstone. 6 353 6 372 0 Interbedded claystone, silt- 18 6 stone, and fine sandstone. 372 0 376 9 Sandstone, soft. 4 9 Core loss, 6 in. 376 9 387 6 Interbedded claystone and 10 9 shale, silty streaks. 387 6 387 7 COAL, hard, bright; conchoidal 1 fracture. 387 7 388 8 Claystone, coaly. 1 1 388 8 393 8 Claystone, silty streaks. 5 0 393 8 394 4 COAL, hard, bright, bony 8 streaks. 394 4 402 1 Interbedded claystone and 7 9 siltstone. 402 1 403 4 Sandstone, medium fine. 1 3 403 4 435 10 Sandstone, medium fine; soft 32 6 layers and occasional coaly streaks. 435!10 453 4 Sandstone, soft, few pebble 17 6 Core loss, 16 ft. 2 in. bands. 453 4 456 4 Sandstone, soft, medium fine. 3 0 456 4 4711 1 Sandstone, porous, poorly 14 9 Core loss, 8 ft. 9 in. cemented. Gas flow accompanied by brackish water, static pressure in excess of 15 lb. per sq. in. 471 1 481 7 Sandstone, alternating soft 10 6 Bedding remains almost and dense, pebble bands, bot- horizontal; little dis- tom of hole in hard, fine tortion evident. sandstone. 15 Lo~: Drill Hole 2 Location: 710 feet S. and 2,150 feet E. of NW. corner, sec. 20~ T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole - 330 feet. Depth F~o~f To- Thickness ,, ~t:. In. Ft. In. Material Ft. In. Remarks O 0 19 0 Over'burden, soil and gravel. 19 6 19 0 21 6 Sandstone, medium coarse; iron 2 6 stains. 211 6 21 11 Shale, carbonaceous. 5 21i 11 33 6 Interbedded silty claystone 11 7 and siltstone. 33i 6~ 80 0 Sandstone, soft, occasional 46 6 Bedding, where seen, pebble bands and coaly almost horizontal. streaks. 801 0 105 2 Claystone, occasional iron- 25 2 stone nodules, coal fragments. 105 2 106 0 Siltstone, dense 10 1061 0 115 9 Claystone. 9 9 115i 9 116 3 Siltstone, dense. 6 1161 3 126 2 Claystone. 9 11 1261 2 129 0 Claystone, coaly, frequent 2 10 Core broken, pseudo- coal bands, coal bed. 129 0 173 3 Interbedded claystone, silt- 44 3 Roof, "Pit" bed. stone, and very fine sand- stone; occasional pebbles and coaly streaks. 173i 3 175 1 Interbedded bony coal and coaly 1 10 claystone. 175 1 176 7 COAL, dull; bony streaks. 1 6 176 7 181 9 Claystone; coal streaks and 5 2 fragments. 181 9 182 3 Claystone, coaly. 6 182 3 183 7 COAL, dull; bony streaks. 1 4 183 7 184 9 Shale, dark, coal streaks. 1 2 Floor, "Pit" bed. 184; 9 186 4 Claystone. 1 7 1861 4 186 11 Claystone, coal streaks. 7 186i 11 204 5 Claystone, siltstone bands, 17 6 and very fine sandstone bands. 2041 5 205 2 Shale, dark; coal streaks. I 9 205i 2 241 2 Interbedded claystone, silt- I 36 0 stone and very fine sandstone~ 241' 2 244 2 Sandstone, soft. I 3 0 244 2 260 9 Claystone, silty; few sandy [ 16 7 streaks. 260 9 310i 3 Sandstone, soft, occasional ! 49 6 pebble bands. 310 3 313 4 Conglomerate, pebble; soft 3 1 Core loss, 2 ft. 3 in sandstone matrix. 313 4 320 9 Sandstone, soft to dense. 7 5 16 Hole 2 (Con. De ~th F rom- T o - Thi c knes s Ft. In. Ft. In. Material Ft. In. _ Remarks 320 9 340. 6 Sandstone, soft; few pebbles 19 9 and occasional claystone bands and coaly fragments. 340 6 3421 11 Sandstone, soft. 2 5 342 11 372 7 Conglomerate, pebble and 29 8 cobble, soft sandstone matrix. 372 7 376 10 Sandstone, dense; few pebbles 4 3 Bedding where seen and cobbles, nearly horizontal. 376 10 383 7 Conglomerate, pebble, in soft 6 9 sands tone matrix. 383 7 399 0 Claystone, silty bands, 15 5 occasional ironstone concre- tions and coaly streaks. 399 0 412 4 Sandstone, soft, fine to 13 4 Core loss, 2 ft. medium. 412 4 432 2~ Claystone to silty claystone, ~ 19 10~ occasional ironstone con- cretions. 432 2~ 435 4 Claystone, carbonaceous; coal 3 1~ Roof of bed cortes- fragments, ponding to log, hole 1, 296 ft. 9 in. to 302 ft. 6 in. 435 4 435 9 COAL. 5 435 9 435 10~ Siltstone. 435 10~ 436 ~ Bone. 2 436 ~ 437 1~ COAL. 1 437 1~ 437 6~ Bone. 5 437 6~ 438 0~ COAL. 6 438 ~ 438 3 Bone. 2~ 438 3 440 2 Bone, coal streaks. 1 11 440 2 440 8 Boneo 6 440 8 441 0 COAL. 4 441 0 441 3 Bone. 3 441 3 445 7 Claystone, coal streaks. 4 4 Floor. 445 7 461 3 Interbedded claystone, silt- 15 8 stone, and very fine sand- . S tone. 461 3 461 9 Sands tone. I 6 461 '9 461 11 Claystone. ' 2 461 11 462 1 Sandstone, soft. 2 462 1 462 11 C laystone. 10 462 11 463 8 Claystone, coaly. ! 9 463 8 477 0 Claystone, occasional sandy 13 4 Bedding nearly flat. streaks. 477 0 484 0 Sandstone, crossbedded, fine to 7 0 medium, few clay streaks. 484 0 508 1 Claystone to silty claystone. 24 1 508 1 509 10 Sandstone, soft. 1 9 509 10 511 5 Claystone. 1 7 511 5 511 8 Claystone, coaly. 3 17 Hole 2 (Con.~ , , Depth From- To- Thickness Ft. In'. F't. In. Material Ft. In. Remarks 511 8 533 0 Claystone and fine sandstone, 21 4 interbedded and crossbedded. 533 0 533 8 COAL, bony. 8 533 8 543 0 Interbedded clays tone and fine 9 4 sandstone. 543 0 545 3 Sandstone, claystone inclusions. 2 3 Transition. 545 3 571 11 Sandstone. I 26 8 Bedding 15°, brackish water with evident ~ gas pressure. 571 11 605 0 Conglomerate, pebble to cobble, 33 1 Core loss, 28 ft. 8 in soft sandstone matrix. | 605 0 610 4 Sandstone, soft.J 5 4 Core loss, 2 ft. 1 in. 610 4 648 4 Conglomerate, pebble to cobble 38 0 Core loss, 30 ft. 9 in soft sandstone matrix. 648 4 652 10 Sandstone, dense; calcite- 4 6 Slickensides. filled fractures. 652 10 666 3 Conglomerate, soft matrix. 13 5 Core loss, 12 ft. 11 i 666 3 675 0 Dense sandstone, coaly 8 9 Core~ loss, 7 ft. 1 in. fragments. 675 0 692 0 Conglomerate, soft matrix. 17 0 Core loss, 12 ft. 9 692 0 697 0 Claystone, silty. 5 0 Core loss, 7 in. Gas water increasing dow~ to this stratum. Stat i pressure up to 45 lb. 6971 0 726 3 Claystone, silty; few bands of i 29 3 fine sandstone and occasionalI ironstone concretions and coaly streaks. 726; 3 728 2 Claystone, coaly, i 1 11 728! 2 729 7 C laystone. I 1 5 7291 7 730 11 Claystone, coaly. 1 4 730 11 733 7 Interbedded claystone and fine 2 8 sands tone. 733 7 735 7 Claystone, coal streaks. 2 0 735i 7 740 7 Claystone, sandy streaks, and i 5 0 lenses. 740 7 742 8 Sandstone, fine to medium cross- 2 1 bedded; coaly streaks and occasional included pebbles. 742 8 744 6 Claystone, coaly. 1 10 744 6 753 3 Interbedded claystone and fine 8 9 sandstone. 753 3 805 11 Sandstone, fine to medium and 52 8 Another gas channel dense to porous, occasional apparent at 775 ft.; claystone blebs, and pebble not measurable. band at 794 ft. 805 11 832 9 Claystone, silty and sandy 26 10 streaks. 832 9 8371 0 Sandstone, soft; claystone and 4 3 coaly streaks. · and 18 Hole 2 (Con.> Depth F r om- T o - Thi cknes s Ft. lin. Ft. In. Material Ft. In. Remarks ,_ 837 0 840 9 Claystone: sandy and coaly 3 9 streaks. 840 9 843 3 Claystone, coaly; many bright 2 6 coal bands. 843 3 847 10 Sandstone, soft; occasional 4 7 claystone streaks. 847 10 848 3 Claystone. 5 8481 3 850 8 Claystone, dark; bright coal 2 5 s tr eaks. 850 8 876 0 Interbedded claystone and silt- 25 4 stone. 876 0 876 6 Sandstone, crossbedded; 6 streaks of iron carbonate. 876 6 880 8 Claystone, dark; occasional 4 2 coal streaks. 880 8 895 8 Interbedded ¢laystone and 15 0 silty c laystone. 895 8 897 10 Sandstone, fine, dense. 2 2 897 10 903 8 Interbedded claystone and 5 10 siltstone. 903 8 906 1 C lays tone, coaly. 2 5 906 1 913 6 Interbedded claystone, silt- 7 5 stone, and fine sands tone. 913 6 917 8 Claystone, coaly; bright 4 2 str eaks. 917 8 937 7 Interbedded claystone and silt- 19 11 stone; occasional ironstone concretions. 937 7 943 7 Claystone, coaly; many bright 6 0 coal bands and streaks. 943 7 979 0 Interbedded claystone, silt- 35 5 Bedding of all above stone, and fine sandstone; strata varies from occasional ironstone con- to 15°. cretions. 979 0 985 0 Sandstone. 6 0 985 0 985 9 COAL, bony and bright. 9 985 9 986 2 Claystone, coaly. 5 986 2 987 2 COAL, bright. 1 0 987 2 987 5 COAL, bony and bright. 3 987 5 988 1 COAL. 8 988 1 988 6 Claystone, coaly. 5 988 6 1,013 8 Interbedded claystone and silt- 25 2 stone; 3-ft. zone of ironstone concretions at 994 ft. 1,013 8 il,044 6 Sandstone, fine to medium; 30 10 occasional claystone streaks. 1,044 6 1,072 0 Sandstone; frequent conglom- 27 6 Core mangled; no loss erate lenses of indeterminate thickness. 19' Hole 2 (Con.) Depth F r om- T o - Thi cknes s Ft. In. Ft. In. Material Ft. In. Remarks 1,0721 0 1,097 1 Interbedded claystone and 25 1 silty claystone. 1,097i 1 1,105 10 Claystone, dark; frequent 8 9 bright-coal streaks and scattered sandstone con- cretions. 1,105 10 1,106 2 Claystone. 4 1,106 2 1,112 3 Interbedded claystone, silt- 6 1 stone, and fine sandstone. 1,112 3 1,142 0 Sandstone, occasional clay- 29 9 stone streaks. Log, Drill Hole 3 Location: 920 feet N. and 265 feet W. of SE. corner, sec. 18, T. 18 N., R. 3 W., Seward Meridian, Houston, Alaska. Elevation: Collar of hole - 249 feet. 43 48 5O 51 53 53 53 55 58 60 87 87 9O 96 103 103 122 123 125 126 126 Overburden, glacial sand, gravel, and boulders. Sandstone, dense, few inc pebbles and cobbles. C lays tone. Claystone, soft. Shale, dark. Claystone, coaly. Claystone, coaly streaks. C lays tone, coaly. Claystone, dark, silty; occasional coaly streaks. COAL, bony. Interbedded claystone, silty claystone and siltstone. Sands tone. C lays t one. Sandstone, porous, fine to medium, frequent clay bands. Sandstone, dense, fine. Claystone, silty, grading down to stltstone. COAL, bony. Interbedded claystone and silty claystone; occasional sandy streaks. Shale, carbonaceous. C lays tone. Claystone, coaly. Clays tone. C laystone, coaly. Core loss, 3 ft. 4 in. Core loss, 9 in. Core loss, 1 ft., 2 in. 2O Hole 3 (Con° Depth From- To- Thicknes s Ft. In. Ft. In. Material Ft. In. Remarks 126 6 127 0 Claystone. 0 6 127 0 127 11 Claystone, coaly. 11 127 11 133 5 Claystone, dark; frequent coaly 5 6 str eaks. 133 5 142 10 Claystone to silty claystone, 9 5 occasional coaly fragments. 142 10 145 8 Interbedded coaly claystone 2 10 and carbonaceous shale. 145 8 177 3 Interbedded claystone, silty 31 7 claystone, and very fine sands tone. 177; 3 181 8 Interbedded claystone and 4 5 Core loss, 1 ft. soft, porous sandstone. 1811 8 182 6 Claystone, coaly. 10 182 6 196 1 Claystone, frequent silty and 13 7 coaly streaks. 196 1 199 4 Claystone, coaly. 3 3 199 4 217 6 Claystone, occasional silty 18 2 str eaks. 217 6 224 0 Sandstone, fine. 6 6 224 0 233 4 Claystone. 9 4 233 4 236 9 Claystone, coaly. 3 5 236 9 243 0 Claystone, occasional thin 6 3 coaly streaks. 243 0 244 0 COAL, bony. 1 0 244 0 244 3 Shale, carbonaceous. 3 244 3 256 1 Claystone, occasional coaly 11 10 i fragments and ironstone i nodules. 256 1 258 8 Claystone, coaly. 2 7 258 8 260 4 Shale, dark; few thin coaly 1 8 str eaks. 260! 4 333 1 Interbedded c lays t one ,' silt- 72 9 stone, and very fine sand- stone. 333 1 337 0 Sandstone, soft. 3 11 Core loss, 1 ft. 2 in. 337 0 386 0 Sandstone, soft, few pebbles 49 0 Core loss, 42 ft. included. Bedding throughout is 0° to 15°, with mod- erate crossbedding. Regular bedding seldo~ exceeds 5°. ,,, INT.. BUoOF MI NE:S ,PGH.. PA. 848S " .... L ..¥.."! TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May ! 2, 1995 Mr. David Lappi, Prcsidcnt LAPP Resources 4900 Sportsman Drive Anchorage, AK 99502-4169 Dcar Mr Lappi: After a review of your application for pool rules, the AOGCC staff has advised the Commission of tile following spccific information which was not included in your request, and some clarification's to statcmcnts in your request which could be asked of you at the June 2 hearing. 1) A legal description of your presently proposcd development area. This should include a description of thc area ~vithin Section 21 you intend to develop. 2) The ownership of thc subsurface estate of proposed development area, broken down by fee parcel or state oil and gas lease.. This includes working interest and royalty owners. If you have been designated opcrator of land you do not own, or if you have acquircd ownership of property from anothcr operator, then a designation ofopcralor, or change of ownership form, as applicable (20 AAC 25.020 & 20 AAC 25.¢)22, page 3 of our regulations) should be filed with us. Thc protection of correlative rights within the pool will be a ccntral issue of the hearing (20 AAC 25.517 & 20 AAC 25.520, pp. 33 & 34 of the fogs). 3) Even though there's bccu a fair amount of drilling adjacent to your projcct area, due to the vintage of thc data. thc control it represents is poor. This impacts three factors: 1) thc distribution of freshxvatcr aquifers, an important consideration here due to proximity of private wells; 2) the designation of a type log: and 3) estimation of an appropriate well spacing for coal reservoirs. Thc protection of aquifers can bc insured if the 3 1/2" or 4" production casing will be cemented Io surface. Thc wording in 3'our application does not specifically state this. Duc lo the polcntial risk your project could pose to drinking water in the area, this procedure is, in our view, appropriate. David Lappi i, p. 2 The designation of the Rosctta 3 as the best available type log at this time is a good decision. We will need a copy of this data. at a scale of 2" = 100', as an exhibit. The data you will obtain during your initial drilling will be much more meaningful and a type log should be rcdcsignatcd once this information becomes available. Several points relative to well spacing will be discussed at the hearing: !) Thc selection of an appropriate spacing and standoff for these wells can at this time be estimated through comparison with other coalbed producing areas. The selection of 40-acrc spacing and a 330' standoff are typical sorts of values. 2) With the acquisition of engineering and performance data. these spacing criteria will be reexamined and may be subsequently modified. 3) If gas is encountered in a sandstone reservoir, it will be developed under statcwidc rcgulatious until a separate set of pool rules are written. The rcquirclncnt for this prqjcct to produce and dispose of water and vent or flare gas for an as yet undetermined period prior to production will be discussed. Your specific plans to vent or flare gas and dispose of water will be reviewed. lf you would like clarification or assistance with any of these points, please contact either Jack Hartz, Blair Wondzell or Bob Crandall of this office. Sincerely, Robert P. Crandall Sr Pctr Geologist ,! LAPP Resources Inc. ~900 S0ortsman Drive 99~02-4169 Telephone + 1 (907) 248-7188 E&X TRANSMISSION gII~ET Fec$imil$ + 1 (907).248-727~ DATR t'~/~--~l ~' ~' TOTAL # O1~ PAGES -- FROM PLEASE CALL OR FAX IF YOU HAVE QUESTIONS ON THIS FAX, APR 28 4/a'~ka Oil & ooas Cons. Cornmissio,~ Anchorage ]IIBI · ....... Lapp Resources, Inc. Houston Area Alaska Cementing PTA Recommendation Pr~ared for: Sportsman Drive ~orage, ~~ 99~02 , RECEIVED Gas Cons. Commi~sio~I Anchora~ P1u~ to ~b~don H~Hburto~ l~r~ Services appr~iates ~is opp~mnity to be ~t' s=m~ to y~. ~1~ ~ ~t~ is b~ on ~alli~on ~ergy Sex~'J~S mobilizing out of K~i/N~s~ lo2sfion. ~e~t is to ~ pun~ed via ~ 1-I!2' CT a~ ctreula~ ~p ~s~s to provide ~e mai~ water ~qu[~ ~d sufficient ~xing water to clan ~~ ~ing e~ipmcm, ~p ~:sources to provt~ a means co ;~om ~ess ~ment sl~ a~ w~r ~ to clem up ae g~menti~ ~ and to di~Ose of ~d mterifl. I apologize for not g~ttin~ this information to you sooner, bu; I was out of town until this w~elL If lttm have any questions or need any additionsl information, plea,~ feel free to RECEIVED APR 28 }995 Na~..0il .& 6as Cons. ' :A]lfliorag8 A__PR-28-' 95 FR I 09: 2~ l O: LA~J~ RESOURCES I NC .... I II III [ '-II. in PI~g to Abandon 1-112" Coiled 'tubin~ - Opon-~mded ac 2100 ff 0-~100 ft Inside 1-1/2" CT and I-1/2" CT x 4' Casiug Annulus PRP, MIUM CEMENT: (zmo'n fill) 2100 ~ * 0.0~4~ fl~/f~ * TOTAL PREMIUM CEMi~NT 20.40 bbls PLU1D 1: Fl~g.~H WATF.~ FLUID 2: ~ CP2vl~NT PTA Ore. ut Slurry 2~ Calcium Chloride - Auhy (Ac~lera~or) Mixed With Fmh Wmr Toy of Fluid: Fluid Volu~"l¢; Fluid W~ight; Fluid Yielcl: Fluid Water Ratio: Total Miai~ Fluid: Calculat~ Mill: F]uid Voltuue: Calculated Volume: Proposed Volume: Circulatefl out $ bbl~ $,0 gaI/$k i1.7 bbl,~ Oft 20.40 100.0 RECEIVED APR 28 }995 ~/a$~,,Oil .& Gas Cons. Commiss~u,' Anchorago ~ ~,~ ...... _.~PR-28-' 95 FR I 09::30 I D: LAPP RESOURCES I h, IC , , ,,, TEL NO: 1 90? '248 ~360 P05 Plus to Abandon MILI~b, OE CEMENTINO ROUND TRIP 560 MI 1 MIL]L, kO]g FOR CR~V $60 MI M[~I/CM'I~ MAT DEL OR RJETURN 13~0 TMI OPE~A~R TIMI~ - CEMI~NTtNC 2 MAN 10 HR ]~UIPME~T O~F.A~TOR- ~ HOUR ! ,MAN FOOD AND IA)DOING AND TRAVEL EXPENSES 2 DAY PLUOQINO 3K SPOT C~MEHT OR MUD t FT ~H~ROU$ CA~IUM ~LOR~ . ~ BU~ ~R~ICE ~ARG~ 106 BU~ BL~NDINO CHbRO~ 106 4.tX) $ 2,~-40,00 3.00 1,680.00 l. J :~ 1,552/{0 '~.00 1,$00,00 ?0,00 700.0o 130.00 1,$80.00 2,0~.00 2,090.00 22.0O 'l,~.00.01'1 64.05 I0'~. 1S i,~ tc~.{0 1.00 lo6.0o TOTAL CO~'i' ~II'I'I{',IATI~ $ 13,801 ,)il DIIICOUNTItD TOTAL COST ESTIMATE 5 I0,000,00 OondMona , lime cost in this anaiysi,', is go~ for the mate.rials and/or ,,',ervice~ outlined within. 'These pri~s are bascd on Halliburton go, vices beth8 awarded the work on a fir~c call basis. Prie.,s will lm mvi~w~l for adjusunenu if awm~fl on 2nd or 3rd call basis an{i/or alter 30 days of thb wriueu analysis. This is in an effort to schedule our work arid maintain a high quality of pe, rl'orman~ fur out- cmiomcrs. The ~ prices ~t~ted in the proposal are based on our current publi~l',ecl pfi~-~. Thc proj~ted equipment, permmaei, and material nee, ts at~e only estimarzs based on information abou~ the work pr,~.atly available ~o us. ~.t the fim~ ihs work {s actually perfoumed, condifio~ then existin8 ma)' re4luir, an increase or &re'ease in tt~ equipment, p~.r,~t.vnne.1, and/or rnat~.rial atl~ls. CI~8e$ will I~ ba!{~l upon unit prices in effcct at the time t~e work i~ p~fo,'med arid the amount ofmclulpn~ui, personnel, and/or material actually tlttlizud in the wurk. T~e$, if any, are not lnuludmd. Applicable taxes, if any', will be added to {he actual invuice. It b ar/~rstood and agreed bet-,v~n the parties that with ~ception of ~e sub, Cci d~, aH ~d ~~ ~ ~at~rial~ will 1~ ~n~hcd in a~co~a~ with the te~ ~d co~o~ 0f ~b~on Services' r%~lar work orders ap9lica~le ~o ,ac pm~¢alar i~. ~ eo~fion, it is ~ ~de:st~fl ~¢ agreed t~t ~tomer will couQnu~ tO ex~u~ ffallibu~on ~~$ ~ ~lfl wo~ ordez~ and/or ti~ts mmmmariiy requ~'~ by Hall~on ~iees ~ R E C ElM E D Alaska 0ii & Gas Cons. 'Anchorage STATE OIL AND GAS BOARD OF ALABAMA ADMINISTRATIVE CODE OIL AND GAS REPORT 1 (Supplemented through November 1994) RULES AND REGULATIONS GOVERNING THE CONSERVATION OF OIL AND GAS IN ALABAMA and OIL AND GAS STATUTES OF ALABAMA with OIL AND GAS BOARD FORMS s. Marvin Rogers, Attorney for Board Tuscaloosa, Alabama November 1994 Rule Rule Rule Rule Rule Rule Rule CO NTE NTSmCO NTI N U ED Rule Rule Rule Rule Rule Rule Rule Rule 400-1-1 Rule 400-1-1 Rule 400-1-1 Rule 400-1-1 Rule 400-1-1 Rule 400-1-1 Page 400-1-12-.10. Notice ..................................................... A-41 400-1-12-.11. Contents of notice of hearing ................................ A-43 400-1-12-. 12. Preparation of notice ........................................ A-43 400-1-12-.13. Continuance of hearing without new notice ................... A-43 400-1-12-.14. Conduct of hearing ......................................... A-43 400-1-12-.15. Power of board to require attendance of witness and production of evidence ............................................. 400-1-12-.16. Rules of evidence ........................................... 2-. 17. Affidavits .................................................. 2-.18. Copies ..................................................... 2-.19. Order of docket of hearing .................................. 2-.20. Place of hearings ............................................ 2-.21. Preparation of proposed orders .............................. 2-.22. Determination of rulings upon evidence ...................... Rule 400-1-12-.23. Entry of rules, regulations, and orders ........................ 400-1-13. Orders Providing for Forced Integration or Forced Pooling .............. Rule 400-1-13-.01. Forced integration or forced pooling ......................... 400-1-14. Appointment of a Hearing Officer .................................... Rule 400-1-14-.01. Appointment ............................................... Rule 400-1-14-.02. Powers of the hearing officer ................................. Rule 400-1-'14-.03. Report of hearing officer .................................... Rule 400-1-14-.04. Communication with hearing officer ......................... Rule 400-1-14-.05. ProCedure .................... .............................. 400-2. Natural Gas Policy Act of 1978 (NGPA) Well Status Determination Rules and Procedures ........................................................ Rule 400-2-X-.01. Definitions .................................................. Rule 400-2-X-.02. Applicability of other rules ................................... Rule 400-2-X-.03. Application and filing procedure .............................. Rule 400-2-X-.04. Evidence by affidavit .................. ....................... Rule 400-2-X-.05. Intervention ................................................. Rule 400-2-X-.06. Attesting of written orders ................................... Rule 400-2-X-.07. List of participants ............... ~ ........................... Rule 400-2-X-.08. Forms ....................................................... Rule 400-2-X-.09. Notice of determination .... . .................................. 400-3. Rules and Regulations Governing Permitting, Drilling and Producing Operations in Submerged Offshore Lands in Alabama ................ 400-3-1. General Rule 400-3-1-.01. Definitions ' Rule 400-3-1-.02. Application of other rules and orders of the board .............. Rule 400-3-1 -.03. Exceptions to rules ........................................... Rule 400-3-1-.04. Equipment and materials ..................................... 400-3-2. Well Permit ........................................................... Rule 400-3-2-.01'. Permitting of wells ......... : ................................. Rule 400-3-2-.02. Rule 400-3-2-.03. 400-3-3. Drilling Rule 400-3-3-.01. Rule 400-3-3-.02. Rule 400-3-3-.03. Rule 400-3-3-.04. Spacing of wells .............................................. Bond ....................................................... General ..................................................... Well casing and cementing ................................... Drilling mud ................................................. Blowout prevention equipment ............................... A-44 A-44 A-44 A-44 A-44 A-44 A-44 A-44 A-44 A-45 A-45 A-46 A-46 A-46 A-46 A-46 A-46 B-1 B-1 B-1 B-1 B-1 B-1 B-1 B-1 B-2 B-2 C-1 C-1 C-1 C-1 C-1 C-1 C-1 C-1 C-2 C-2 C-3 C-3 C-3 C-5 C-5 CONTENTS--CONTINUED Page Rule 400-~-3-,05. Plugging and abandonment of wells ........................... C-7 Rule 400-3-4. Producing ........................................................... C~8 Rule 400-3-4-.01. General C-8 Rule 400-3-4-.02. Subsurface safety devices and surface safety valves .............. C-9 Rule 400-3-4-.03. Wellhead equipment and testing procedures ................... C-10 Rule 400-3-4-.04. Procedures for multiple completions ........................... C-10 Rule 400-3-4-.05. Platforms and fixed structures .................... : ............ C-10 Rule 400-3-5. Safety and Environment .............................................. C-13 Rule 400-3-5-.01. Survey of shallow hazards ...' .................................. C-13 Rule 400-3-5-.02. Pollution prevention and control .............................. C-13 Rule 400-4. Rules and Regulations Governing the Permitting, Drilling, and Production of Coalbed Methane Gas ................. · .......................... D-1 Rule 400-4-1. General ........................ : ..................................... D-1 Rule 400-4-1-.01. Applicability ................................................. D-1 Rule 400-4-1-.02. Definitions .................................................. D-1 Rule 400-4-1-.03. Application of other rules and orders of the board .............. D-1 Rule 400-4-1-.04. Forms ....................................................... D-2 Rule 400-4-1-.05. Determining and naming coalbed methane gas fields and pools ...................................... . ........................ D-2 Rule 400-4-2. Well Permit: .......................................................... D-2 Rule 400-4-2-.01. permitting of wells ........................................... D-2 Rule 400-4-2-.02. Spacing of wells ........ .' ..................................... D-2 Rule 400-4-3. Drilling .............................................................. D-3 Rule 400-4-3-.01. Notice of activities ........................................... D-3 Rule 400-4-3-.02. Casing requirements ......................................... D-4 Rule 400-4-3-.03. Plugging methods and procedures ............................. D-4 Rule 400-4-3-.04. Drilling fluid ................................................. D-4 Rule 400-4-3-.05. Cleaning wells ............................................... D-4 Rule 400-4-4. Producing ........................................................... D-5 Rule 400-4-4-.01. Commingling ................................................ D-5 Rule 400-4-5. Safety and Environment .............................................. D-5 Rule 400-4-5-.01. Produced water .............................................. D-5 Rule 400-4-5-.02. Pits ......................................................... D-5 Rule 400-4-5-.03. Venting and/or flaring of coalbed methane gas ................. D-5 Rule 400-4-6. Testing and Allowable ................................................ D-5 Rule 400-4-6-.01. Coalbed methane gas production test .......................... D-5 Rule 400-4-6-.02. Co'albed methane gas allowable ............................... D-5 Oil and Gas Laws of Alabama - Sections 9-17-1 through 9-17-88 ....................... E-1 Article 1. Conservation and Regulation of Production ................................ E-2 Section 9-17-1. Definitions .................................................... E-2 Section 9-17-2. Declaration of public policy; purpose of article ................... E-3 Section 9-17-3. Oil and gas board--C~reated; composition, qualifications appointment, terms of office, compensation and expenses of members; vacancies; meetings or hearings .................... E-3 Section 9-17-3. Oil and gas board--Created; composition, qualifications appointment, terms of office, compensation and expenses of members; vacancies; meetings or hearings .................... E-3 400-4. RULES AND REGULATIONS GOVERNING THE PERMITTING, DRILLING AND PRODUCTION OF COALBED METHANE GAS 400-4-1. General 400-4-1-.01. Applicability. The following rules and regulations have been adopted by the Board and are general rules of statewide application in regard to the permitting, drilling and production of coalbed methane gas. These rules explicitly exclude and except operations of coal mining where it is necessary for safety or efficient operations of the mine to vent coalbed methane gas and where capture and sales of coalbed methane gas is not a part of the operations. 400-4-1-.02. Definitions. Except where the same conflict with or are inconsistent with these definitions pertaining specifically to coalbed methane gas, all definitions found in Rule 400-1-1-.03 shall remain effective with regard to coalbed methane gas, unless excluded by Rule 400-4-1-.03. (1) Cased completion shall mean a coalbed methane gas well in which production casing is set through the productive coalbed or coalbeds. (2) Cased/open hole completion shall mean a coalbed methane gas well in which at least one coalbed is completed through casing and at least one coalbed is completed open hole. (3) Coalbed methane gas shall mean occluded natural gas found in coalbeds. (4) Coalbed methane gas field shall mean the area as defined by the operator and approved by the Board which is underlain or appears to be underlain by at least one coalbed, capable of producing ' occluded natural gas. (5) Coalbed methane gas well shall mean a well capable of producing occluded natural gas from a coalbed or coalbeds. (6) Open hole completion shall mean a coalbed methane gas well in which no production casing is set through the productive coalbed or coalbeds. (7) Produced water shall mean water produced from a coalbed methane gas well as a necessary by-product of drilling, completing and/or producing methane gas from a coalbed or coalbeds. 400-4-1-.03. Application of Other Rules and Orders of the Board. All General Rules and Regulations of the Board shall be applicable to the permitting of coalbed methane gas wells and to the installations and operations for the drilling and production of coalbed methane gas with the exception of the following: (1) Rule 400-1-1-.03. Definitions. (those listed below will not apply to coalbed methane gas wells) (a) (b) (c) (d) (e) (O (2) (3) (4) (5) (6)' (7) (8) (9) (10) (11) (12) (13) (14) (15) 400-1-1-.03(10) Common Source of Supply. 400-1-1-.03(12) Condensate. 400-1-1-.03(24) Illegal Oil. 400-1-1-.03(27) Lease Tank. 400-1-1 -.03(30) Oil. 400-1-1-.03(31) Oil Well. Rule 400-1-1-.05. Determining and Naming Fields and Pools (Common Sources of Supply). Rule 400-1-2-.02. Spacing of Wells. le 400-1-3-.02. Notice of Activities. le 400-1-3-.03(2) & (3). Casing Requirements. le 400-1-3-.05. Plugging Methods and Procedures. Ru Ru Ru Rule 400-1-3-. 12.1 Rule 400-1-3-. 17. Rule 400-1-4-.01. Rule 400-1-4-.02. Rule 400-1-4-.03. Rule 400-1-4-.08. Rule 400-1-4-.09. Rule 400-1-4-.10. Rule 400-1-5-.02. Drilling Fluid. Cleaning Wells. Protection of Oil and Gas. Multiple Completions. Tubing. Location of Fired Vessels. Notice of Recompletion and/or Rework. Permit to Clean Tank Bottoms. Hydrogen Sulfide Gas. D-2 (16) Rule 400-1-5-.03( (17) Rule 400-1-6-.01. (18) Rule 400-1-6-.02. (19) Rule 400-1-6-.03. (20) Rule 400-1-6-.04. (21) Rule 400-1-6-.05. (22) Rule 400-1-6-.06. (23) Rule 400-1-6-.07. (24) Rule 400-1-7-.01. (25) Rule 400-1-7-.02. (26) Rule 400-1-7-.05. 1). Pits Oil Production Tests. Oil Allowable. Witnessing of Tests. Oil to be Measured. Oil Measurements. Gas-Oil Ratio. Permissible Tolerance in Production Volumes Allowed for Oil Wells. Gas Production Test and Capacity Test. Gas Allowable. Condensate to be Measured. (27) Rule 400-1-7-.07. Permissible Tolerance in Production Volumes Allowed for Gas Wells. 400-4-1-.04. Forms. All forms set forth in Rule 400-1-1-.04(1) shall be applicable to the coalbed methane gas rules with the exception of the following: (1) OGB-10, Multipoint Back-Pressure Test Report for Gas Wells (2) OGB-10A, One-Point Back-Pressure Test Report for Gas Wells (3) OGB-14, Producer's Monthly Reportfrom Oil Wells (4) OGB-18, Gasoline or Other Extraction Plant Monthly Report (5) OGB-19, Refiner's Monthly Report (6) OG8-21, Permitto CleanTank (7) OGB-22, Well Capacity Test (8) OGB-23, Unit Reserve Calculation 400-4-1-.05. Determining and Naming Coalbed Methane Gas Fields and Pools. Coalbed methane gas fields and pools shall be determined and named by the Board, provided that in the event any person is dissatisfied with any such classification or determination, an application may be made to the Board for such classification or determination deemed proper and the Board will hear and determine the same. In naming fields, reference shall be given to common usage and geographic names. Each pool within the same field shall preferably be named according to the producing horizon. 400-4-2. Well Permit 400-4-2-.01. Permitting of Wells. (1) All coalbed methane gas wells shall be permitted in accordance with the procedures and requirements of Rule .400-1-2-.01. (2) Each permit application to drill a coalbed methane gas well shall be accompanied by a check or bank draft in the sum of One Hundred and Fifty Dollars ($150.00) payable to the State Treasurer, State of Alabama, which sum is fixed by the Alabama Coalbed Methane Gas Well Plugging Fund Act. Rule 400-4-2-.02. Spacing of Wells. A coalbed methane gas well shall be spaced on a unit based upon the maximum area which may be efficiently and economically drained by one well. A unit shall not include any part of another unit established for the same pool. The spacing for a coalbed methane gas well to be drilled to a pool in an established field shall be governed by special field rules for that particular field. With respect to a coalbed methane gas well to be drilled to a pool that is not governed by special field rules, the following shall be applicable: (1) Each coalbed methane gas well shall be drilled on a unit consisting of a governmental quarter- quarter section (approximately 40 acres). Such well shall be located at least three hundred thirty (330) feet from every exterior boundary of the unit. (2) The Supervisor, upon receipt of written justification from an operator, may approve a permit application under paragraph (1) for a unit consisting of approximately 40 contiguous surface acres other than a governmental quarter-quarter section as set forth herein. (3) The Supervisor may require that a coalbed methane gas well to be drilled on a unit contiguous with an existing field be drilled and completed as an extension of the field, in accordance with field spacing provisions in the special field rules thereof. If, however, an operator provides written justification that such proposed well will likely be completed in a pool or pools not defined in the D-3 special field rules for said field, the Supervisor may approve the drilling and completion of such well in compliance with the spacing provisions as set forth herein. (4) Pursuant to Section 9-17-12(c) of the Code of Alabama (1975), the Board may grant an exception to the spacing rules as may be reasonably necessary where it is shown, after notice and hearing, and the Board finds, that the unit is partly outside the pool, or for some other reason, that a coalbed methane gas well located in accordance with applicable rules would be nonproductive, would not be at the optimum position in such drilling or production unit for the most efficient and economic drainage of the unit, or where topographical conditions are such as to make the drilling at an authorized location on the unit unduly burdensome or where an exception is necessary to prevent confiscation of property. (5) No coalbed methane gas well shall be located within 200 feet of any permanent residence, unless otherwise approved by the Board. (6) For a coalbed methane gas well completed in a pool for which special field rules have not been adopted, the Board shall determine, in conjunction with the establishment of special field rules after notice and hearing, the proper spacing for the production unit for said well. Subject to the approval of the Supervisor, the drilling of additional wells for development of a pool may continue prior to the establishment of special field rules for the pool. No well shall produce, other than on a test basis authorized by the Supervisor or Board, until special field rules applicable to the well are established. In order to obtain sufficient technical information to establish the proper spacing, a coalbed methane gas well may be produced on a test basis pursuant to Rule 400-4-6-.01. (7) If any coalbed methane gas well drilled in conformity with the provisions of paragraph one (1) · above, or in conformity With the special field rules for a particular field is completed as other than a coalbed methane gas well, said well shall not be produced other than on a test basis until authorization has been granted by the Board after notice and hearing, This rule shall not apply to vent holes drilled for safety purposes in conjunction with coal mining operations. 400-4-3. Drilling 400-4-3-.01. Notice of Activities. (1) The status of each well or any operations performed on such wells shall be reported orally or in writing to the appropriate Board office from the time the permit is approved or pits are constructed, whichever occurs first, until such well is plugged and abandoned or tested. Such status report shall be due by 10:00 a.m. on the first working day of each week. In addition, the Supervisor or one of his agents shall be notified and approval obtained thereof prior to performing any of the following operations: ~ (a) Construction of any pit, (b) Spudding, (c) Setting surface casing, (d) Slotting casing, (e) Running intermediate or production pipe, (f) Cleaning, : (g) Perforating, (h) Chemical treatment or fracturing, (i) Logging, (j) Attempting to recover a radioactive logging source, (k) Testing of well, (I) Disposing of pit fluids, (m) Plugging, (n) Recompleting or reworking (See Rule 400-1-4-.09), (o) Restoration of location (See Rule 400-1-5-.07), and (p) Any other operations the Supervisor may designate. (2) The Supervisor may send a duly authorized representative to the location to witness such operations. D-4 400-4-3-.02. Casing Requirement. (1) Surface casing for ¢oalbed methane gas wells shall be set in accordance with Rule 400-1- 3-.03(1). (2) All producing wells shall be completed with a production string of casing that shall be properly cemented at a sufficient depth adequate to protect the methane bearing coalbeds. (a) For cased hole completions of cased/open hole completions of coalbed methane wells, casing shall be cemented in place with a sufficient amount of cement to fill the calculated annular space to a point at least two hundred (200) feet above the top of the uppermost coalbed which is to be completed, except that the annular space adjacent to a coalbed or coalbeds may be left uncemented. (b) For open hole completions of coalbed methane wells, the bottom of production casing shall be set not more than one hundred (100) feet above the depth of the uppermost coalbed which the operator intends to complete, unless prior approval is granted by the Supervisor. The casing shall be cemented to fill the calculated annular space to a point at least two hundred (200) feet above the base of the casing. (c) In completing all coalbed methane gas wells, after cementing, all wells shall be tested at a pressure of six hundred (600) psi before drilling the plug, if the plug is to be drilled. If at the end of thirty (30) minutes, the pressure gauge shows a drop of ten percent (10%) of the test pressure or more, such corrective measures shall be taken to insure that the producing string of casing is so set and cemented that it will hold the pressure for thirty (30) minutes without a drop of more than 10 percent (10%) of the test pressure on the gauge, unless otherwise specified by the Supervisor. Cement shall be allowed to stand 12 hours before continuing operations. (d) Other methods of setting production casing shall be subject to approval by the Supervisor. (e) The operator shall report casing tests on Form OGB-7. 400-4-3-.03. Plugging Methods and Procedures. The methods and procedures for plugging a coalbed methane gas well shall be as follows: (1) Plugging a coalbed methane gas well shall include setting a cement plug across each productive interval or intervals. A cement plug shall extend at least twenty-five (25) feet above and twenty-five (25) feet below each interval. (2) Cased hole completions or cased/open hole completions. A cement plug not less than one hundred (100) feet in length shall be placed immediately above the top of the uppermost completed coalbed. (3) Open hole completions. A cement plug of not less than one hundred (100) feet in length shall be placed fifty (50) feet above and fifty (50) feet below the base of the production casing. (4) Uncompleted wells. A cement plug of not less than one hundred (100) feet in length shall be placed fifty (50) feet above and fifty (50) feet below the base of the surf§ce casing. (5) All coalbed methane wells shall have a cement plug of at least twenty-five (25) feet in length placed near the surface of the ground in each hole plugged, and casing cut in such a manner so as not to interfere with soil cultivation and a steel plate affixed on top of the casing stub. (6) Other plugging methods may be required by the Supervisor. 400-4-3-.04. Drilling Fluid. The use of drilling fluids shall not be required in the drilling of coalbed methane gas wells when other appropriate methods are available to control any pressure which may be encountered. 400-4-3-.05. Cleaning Wells. Unless otherwise approved by the Supervisor, all wells shall be cleaned into a pit prior to production. The pit shall be of sufficient size to contain all fluids and shall be constructed in such a manner that no fluids shall be discharged except as allowed by the appropriate permit(s) and/or regulation(s). D-5 400-4-4. Producing 400-4-4-.01. Commingling. Each coalbed methane gas well shall be allowed to commingle production from distinct coalbed methane pools. 400-4-5. Safety and Environment 400-4-5-.01. Produced Water. No produced water shall be discharged to land surface, streams or rivers unless the appropriate approved permit(s) allowing such discharge is on file with the Board. The Supervisor and/or Board reserves the authority to prevent the discharge of any substances that may be harmful to the environment. 400-4-5-.02. Pits. All pits and holding ponds for produced water shall be constructed and maintained consistent with the appropriate permit(s) and/or regulation(s). The operator shall immediately notify the Supervisor of any modifications made to pits or holding ponds. (1) Reserve pits. (a) All pits utilized to contain fluids during the drilling and completion of a coalbed methane gas well shall be constructed and maintained to prevent the pollution of surface and ground water. Prior to utilizing such pit, the pit shall be inspected by a qualified engineer who shall make a determination that said pit is constructed in a manner that will prevent the pollution of surface and ground water. The operator shall keep a record of the determination and shall provide a copy of said determination to the Board, upon request by the Supervisor. If requested by an agent of the Board, an engineer may be required to be available at the well location for a review of the determination. (b) The fluid level in Such pits shall be kept at least two (2) feet below the top of the pit. (c) After a well is completed or is plugged and abandoned, all fluids and recoverable slurry that remain in such pits shall be disposed of in a manner acceptable to the Supervisor within ninety (90) days of the completion or the plugging and abandonment of the well, except as otherwise approved by the Supervisor. Pits shall be back, filled with earth and compacted to the satisfaction of the Supervisor within ninety' (90) days of the completion or the plugging and abandonment of the well, except as otherwise approved by the Supervisor. (d) Subsequent to the removal or elimination of debris and elimination of all conditions that may or will create a fire or pollution hazard, the Supervisor may, provided he has written approval from the appropriate surface owners, permit the operator to leave such pit open. 400-4-5-.03. Venting and/or Flaring of Coalbed Methane Gas. Upon approval of the Supervisor, venting and/or flaring of gas from a permitted coalbed methane gas well shall be allowed where necessary for safety reasons or for the efficient testing and operation of coalbed methane gas wells. With the exception of pressure relief valves, vents for the venting and/or flaring of coalbed methane gas shall be located at least twenty (20) feet above ground level, unless otherwise approved by the Supervisor. 400-4-6. Testing and Allowable 400-4-6-.01. Coalbed Methane Gas Production Test. All coalbed methane gas well production tests shall be made only after notification to and approval by the Supervisor. An operator completing a new gas well or recompleting an old well shall test the well to determine if the well is capable of producing and the amount it can produce. Before performing any coalbed methane gas well production tests, the water production in the well and the gas flow rate shall be stabilized for a period of not less than ten (10) days prior to measurement. The test shall be for a minimum of twenty- four (24) hours duration and tak,en in a manner prescribed by the Board in its rules and regulations. The results thereof shall be verbally reported to the Supervisor immediately and filed with the Board on Form OGB-9 within fifteen (15) days after such test is completed. When more than one test is made, the reverse side of Form OGB-9 may be used to give complete test data. The test shown on the front side shall be considered the official test results for such well. 400-4-6-.02. Coalbed Methane Gas Allowable. The gas allowable for coalbed methane gas wells shall be set at 100% of the well's capacity to produce, unless otherwise ordered by the Board. REPLACE WITH TAB INSERT OIL & GAS LAWS OF ALABAMA ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVEI~NO~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May ! 2, 1995 Mr. David Lappi, Prcsidcnt LAPP Resources 490¢) Sportsman Drive Anchorage, AK 995¢)2-4169 Dear Mr Lappi: After a rcvicxv of your application for pool mits, the AOGCC staff has advised thc Commission of tile folloxving specific information which was not included in your rcqucsl, and somc clarification's to slalclllClllS in your request which could be asked of you at the June 2 hearing. I) A legal description of your prcscntly proposcd dcvclopmcnt area. This should include a description of thc area within Section 2 I: you intend to dcvclop. 2) Thc ownership of thc subsurface cslalc of proposcd dcvclopmcnt area, brokcu down by fec parcel or s(alc oil and gas lease. This includes working interest and royalty owners. If you have been designated opcralor of land you do not own, or if you have acquired ownership of property from another operator, then a dcsig~mtion ofoperalor, or change of ownership form, as applicable (20 AAC 25.020 & 2(') AAC 25.022, page 3 of our regulations) should bc filed with us. The protection ofcorrclative rights within thc pool will be a central issue of the hearing (20 AAC 25.517 & 20 AAC 25.520, pp. 33 & 34 of the regs). 3) Even though there's bccu a filir amount of drilling adjacent to your project area, duc to the vintage of lhc dala. the control il rcprcsenls is poor. This impacts thrce factors: I) thc distribution of freshwatcr aquifers, an important consideration here due to proximity of private wells; 2) thc designation of a type log: aud 3) estimation of an appropriate well spacing for coal reservoirs. Thc protcctiou of aquifers can bc insnrcd if thc 3 1/2" or 4" production casing will be cemented 1o surface. Thc wording in your application does not specifically state this. Duc to the potential risk your prqject could pose to drinking water in the area, this procedure is, in our view, appropriate. David Lappi p. 2 The designation of the Rosetta 3 as the best available type log at this time is a good decision. We will nccd a copy of this dala. at a scale of 2" = 100', as an exhibit. The data you will obtain during your initial drilling will be much more meaningful and a lype log should be rcdesignated once this information becomes available. Several points relative to well spacing will be discussed at the hearing: I) The scicction of an appropriate spacing and standoff for these wells can at this time be estimated through comparison with other coalbed producing areas. The selcctiou of 40-acre spacing and a 330' standoff are typical sorts of values. 2) With thc acquisilion of engineering and performance data, these spacing criteria will be reexamined and may be subsequently modified. 3) lfgas is encountered in a sandstone reservoir, it will be developed under statewide regulations until a separate set of pool rules are written. The requirement for this project to produce and dispose of water and vent or flare gas for an as yet undetermined period prior to production ~vili be discussed. Your specific plans to vent or flare gas and dispose of water will be rcvie~vcd. If you would like clarification or assistance with any of these points, please contact either Jack Hartz, Blair Wondzell or Bob crandall of this office. Robert P. Crandali Sr Pctr Geologist Date: 10 May 1995 Memo: Lapp Resource lnc. Pool Development and ownership of Oil and Gas Leases To: Bob Crandall From: Steve McMains Bob requested me to find out ownership of the oil and gas leases in section 21, township 18n, range 3w, Seward Meridian. He needs to know the owners of the surface and minerals in the surrounding sections. A legal opinion also to define if mineral leases are equal to oil and gas leases. Steve Schmitz help me obtain the maps for 18n lease and minerals. We talked to Julie in lease sales about the best way to attain the requested information. With the data I gave her, Julie said it would be to time consuming to research with the staffing of her office. Both Steve and Julie suggest to put the work on the operator to furnish data when a permit is submitted to AOGCC. A LITIGATION REPORT WITH SUPPORTING DOCUMENTS tailored to the specific information requested for permitting (ownership, royalty interest) by independent operators. There is a fee required for this service. They also suggest liens against owners should be checked. After further research, I contacted DNR Land section and inquired about the ownership and royalty interest for oil and gas lease ADL-374135 and the following data was reported to me: Lapp Resource Owns 100% of the ADL 374135 since April 21, 1995 Lapp has royalty interest of 86.5%. The State of Alaska has 12.5% royalty interest. Marathon has 1% royalty interest. I called Dave Thomas of Mental Health Lands and informed him about the drilling and the hearing scheduled 2 June 95 at AOGCC office at 9 AM. ABE;TRACT F'AG.E: 00Oi NEXT ~ N M: S T: O'I:SN'R: 003W S: '.'--:AF;~.'rvc,.~.. OR L'-.:'~'?=''''anc'v ~.-.',--.~, ..... .',"-.?.,~ .... ,r_-c-c ..... N'" D N R A R lie A C M S C E:: C] !'iA T - S L! A R E A REC:E]F:D i NG D i ST. F..:31 .i. PALMER S E N A TfiE !:} ;[ S T ~ ~'~:i~ 4 D ! S T R ! C T N H 0 U E'.': E ID ! S'[', R E G :{: i'] N A i .... 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E T M ES N T A L H iS A i_"i' t-'i t--I Y P 0 T I-'-i i:Z C; A T E D i... A lq D (.)6-'-E~4 ..... :!.99'-'~. CHAh. tGE CASE: SUBTYF'E C A S E S U B T Y P E 67; O O K I tq L.. E T LANDS NO LC)NGER HYF"OTFt[]CATED UNDER THE NEW MENTAL. HEAL]"H .SE:.:]"TL..EME:NT 06-¢i~4- :[ 994. F;.:EF:'E:ALED MENTAl .... HEAL. TH HYPOTHEC','ATE']D L. ANI} ...... '()~f' ='OC4, ='".I:' ~9'~'~'' ~'': "":" ":"" "~'~:' ~'t~':' '!" 'C ~'T'";~f::~N'''' '"E?E'E~EE'"' "?C~"~iqt~t f3E'D~ ' ...... ~"'" ':" ..... :' ............. "" ....... i"..iEW htL. ( E'.O ) Ni:] T I F ill C A T I 0 ht i_ E S S E']E F:' R E S S E; ix!"l" E R '[' 0 *....." i E W FF::',, .... X, -r'. F:'A G E C) F;.: C L.. ,i:::' .... A R T...,r"~ "!" E F:;:. !"'! it: Ix!. A. 'I" E.':.: D i S P 1.... A Y I"..I LJ P A .-'..'!iii E: i5 [ii: F' F'E C T ! V 1.":.:.: D A'!" E C2 .L-'~ .::t :"" '-.t .... , ....... .... [...bl ,,i_l ,, I F: ~'"~ Dtii/: (::'., S Si: ! G N O R ' S C ! I} A:ii.:;;S I G NEE E ' S C i D W O F?. 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SE1/4NEi/4, ~ ACRES; ,=~p.'r I ON oo =', ~.m'~,'~"--'.=- m NE ~/"--'~ 160 ACRES ~ 'SECT!ON ?_9.~ SURVEYED, SE.t/4., W!/~.., 480 ACRES SECTION 30, SURVEYED, FRACTIONAL, LOTS &-] AND _ ' ¢ .... SECTION :3i.~ SURVEYED... FRACTIONAL:: I ..... )~.'::, 1 AND 31E:.68 ACRES; ........ · '% -'" ", '- ¢.'" c' ~::'1'7 ~:")"'~ ~.~ U R t::-. c..~ · .::, ..... I I 0 N ;:9 i:::, S U R V E Y E D, N I / ;a N E .t / 4, ..... SECTION 33, SURVEYED, E;1/i~NE]./4.~ 80 ACRES. ALL, 6~0.9-S: ACRES: Si/~,' ,..~I/i~NW]./4, NWI/4NWi/4,. 480 SEi/4, Si/RSWi/4, NEi/4SWI/4, 3~(::-' "FHtS "FRACT ,..,,]N,f..~IN...) Z~'765 ~:~'-':' ACF.'.ES M(:)I::~E OR .... EE ..... P/N 4 B m a F' Fi'. E S S E N T E R 'T' O V i E W hi E X 'T' F",...~" r:',..-~ E'" 0 Fi: C t.... E A R: T 0 T ii!: R f"i :l: N A'T' E D .'1: S F:' L.. A Y NUM J !i NIE X T: N C A S E ~ Y F' i::." Kg ~ ~. N A M E i A I;) D R E: S S ( Y / N ): N r--.o-~.,TATUS 54 APF'R ACF:;.:E!:S 640 CL..ASS ! F' iED ,~' 6"e' 0" ]-:'.'] T A L ,q-B ~ a , A NUN NL. M3,::)6,'.}P DEF'AR"I'f~ENT (:.DF NATURAL F.'E.C~,"]Ii-n'CF:::'] C.:,5tn,5/1 o,=' ~c~ ................. = L)ht CATEGOR"( --= - ........ C L ~ ..... I F I C A T '[ ' .I: N i 'F I A T E D A T E C, 9 --.- 2'7-' - I AC R E: S "4 T O F:'IL..E (:ii:)[... CASE TYF'E 501 'r'!MBE:R SAL. E F::'F:i .... HE.'LF:' PF8120 .... PRtEV f~ENU PF!2f24 - REE'I"URN q-B ~ a A NUM NL. M306':)F:' DEPARTMENT OF NATURAL RESOURCES 05/05/.t 995 .t 1 ~ .1.9 ." :3? ~: NE X ]': N CASE:. TYF'E = OR CA'i"EGOR'~: NAME/ADI}RE:SS (Y/N): N ..................... DATE I N i "i" T (::"'""" c- S'FATL~:E; DATE .i. 2-i0--1986 : CASE S-FA'FL}S 20 LEASE ISSLJED CAE':E SUB'I'YF:'E 5C, 04 :F';~'.,:~ USE ( A ) A c',:", ~.::' c.' ,'::. :::::,":: T 0 TAL. i:::' i L.. E L_ A S ~~3.-:c3 ) C A SE T Y F'E 5 V ~ !}L. WI"I P E R M, I T i N i 'T' ! :" "fl .... D A =" ~::: ~~~"q- - S T A T U S D.A T E ,06 - 2 ? - .I. 99'4 ,~ C A S E S'I," A "i" U S 4 D [3 L 0 S E D E: A S E S,U B T Y P E ? ?'.'} 2 i'! I ~ C L A N D U S E A C R E S 0 T O'F A L. :; .i,~.,i~.~ ~. ~-:,.,.:.-:.-..:.-:.,-:¥.-.,:. ~,.i.-.~--:.*.:..-x- ~--:,,:..,.-x-.~!. ~.-~ =~. :~- ~, MLiNI C i F:'AL _ N! M ::,') t--.. !:.. ;-; CASE' TYF'E:: OR CA r l Lb.. -,qDL C:-F ....... ~,ATE ,"~6,---'~('~- ';' 978 ArCRES 0 TO~ F5L. E ADL !NiTiATE DATE ~~ STA'TUS DATE 06-E6-i9,'7~ ACFCES '-'-- TO-rAL o ~ ' .... ACC,`. VE CASE .:.-T,-'-~ff .'..~:~ CASE TYPE 601 MUN!CIF"AL. EN'F!TLEMENT c- ,- US CASE .~T.~T 45 CLOSED **********************__ SUB-SURFACE-ACT I V i 'f'Y ***************'-'~'*****--~'****** ~-'; ~' ~""",: x, q374 i 34 ----...., ., ..... ,,c,- ~-:, ,-~ L_" .[,_c: ~--,~.. ~AS~. ] ~, E ,~.-~ ,.,I c.,: GAS LEASF' COMP iNiTIATE DATE STATL]S DATE 01-29-1991 CASE STATUS 82 CLOSE:D-NO BID RECD SALE AREA CI COOK INLET ACRES 6'"~ ::'; TOTAL F'!L.E ADL :]-)81i34 CASE TYF'E 784 OIL ::;. GAS i..EASE COMF' PF'i -'- HE'LF:' F'FS/2(]) .... F::REEV ME'NU 4B ~ a A NLiM P F' .i. 2 / 2 4 ..... R i.'.< T U iR N DI!.=.'F'A F:-',' T M.'E N T OF' N A T U F:i'.A L. i;.'E' S Q L !F:,'.."'] E S L. A N D F I !... E .c~ ~", c'.'"r' r:',,~, F"r' 0 5 / :"',.... ,.,'::': ,/ .,.' 9 9 5 i :L: ?.:.:.:...':'): .L P A G I:..:.:: -.'.::'., C,(.'.:' 6 NE X "I' :: · ,:-***.,.i, END F)F' i....AND ABSTRACT F:;:EPF.)RT F::F' .I. -- l."i!ii" L..P P F=' 8 / 20 .....P F;.: E.V M E. N U .:. 4 B ,: a ¢':"~ NUt'I NLM L ':::".--' C'.'-' · ._,::~..,I-- DEF'ARTMENT OF N~ TURAL RESOURCFS F i L E: A D L .... : .. ~]....:,~,,;,1,..~;.:.'::.~.. P A G E: CUSTOMER-.,."r D: ('.,.hr:, i. F_'6{)58 ,Lirn, u,_.,.~ir,,_,,,~i°Tn~''! , T¥ CASE '"'"'r' "" :'~,'E: 536 P 8; C USE SALE NON-COMF; ~i'LE, =~ OCATiON FROM: SCDOLD SCDO LAND SECT~'ON,. TO: SCDOLD SCDO~_.~ ,-~."'~.""~,,,,., SECTIqN ....,r'~:"~-c',,._.~_ STATUS: ii APPLICATION RECEIVED STATUS DATE: 0i ~5 TOTAL ACRES: ! "=~ F~,"~n DATE I N T 'f' I ATED: '"6 L:~4 ~ ¢';"P..'-" OFFICE OF PRIMARY F-.'ESF'ONSIBIL_ITY: ...... ,,.,. ...... ,: · ...t ~..,, &,.. ;._ Ir ! 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',,.o . ................ .:~.JE',J EL, I LANL..: HAY BE:.':' SUB3E:CT 'T'O l"::h,l T K NATI Vii!'.':b' '[ ~ I AGE .E;Et ...... CASF!'F:: t !....,;.ii: '::..' I '" .... . .. '" '''~ "' ~ I:.E.] _IR:NE..!.) FROM C¢.:.1[~TO SCD MGR F..UF.: RESO. L..UTIOht [)F' POINTS IhlVO. L. VE:D '~%"TF;.tANSAC:T."ION: C:F'CD C'ASEF'IL:E' CUSTOME!:~: Df.:)C,'(JMENTED ¢'". :'. ¢""'. 'T' R A N S A C 'T' I 0 hi D A 'T' E:: ('.,,. ,..,-°. 0 ,':'.:.: 19 E:,'- ,.'ST I M E;: 00 () .1. c',...: C'~... ,..,c::' ,...i I ~..,,..,P. '.::' v, ,..,c:: T ......... E Id -' i )::'..'-:: , *-.~ ,':~ · , ~ "i ~ ~ ...... . ............... . .......... :::. H., t ]: N A L: ,'. ....... ~,, v .[ 1~,, t'". .... D A'F E: C:,' 80 E"' i '7 86 I ;.S ;:' F:;': !::; ¢: 'T"'" ~-' ~'r; ....... , ~., ..... ,"-',.. ~,, C (:) N V E'.'. t:'7 S .~. ,.... N · '.~,-.. ,.', ~. ::::: ,:::, ..., r" D E!: F:'A ~::-: "," I", E:' N 'T' D F:' I'"-.i A T' ' ;"' "' ' u,',, ~...t L R E: S 0 U R C E S F:: 'r ~ t:::', A P'. [ '::'~ '~ =': ;:::" .... ...................... : ........... .'. :i. ,q. C A S iii';:. ;:' i i....E D E:. T' A i ~ P A Giii'.'.: ~'.' i ~'.~ r:, c' ~::, ,':"?, ,."'~ (') .1 P A ,'.'") 5 F.'::i"'i 0 U S ]" 0 hl. C T Y :, E:U S T 0 I'"t[E F;:. , .................. ,.. U N i 'i" C' O D E ;i70 C:: L. A N D M A N A G ii.:.': h'! ti!': N "[' F';::' L.. AT, ~... i t.] t q.::::, H .,. [" ,..,r" rvr'., t'::,_, ,...,, ...... 1. (':~ C) W N E']:'i'. TE"' X T' '.: THIS ]"F:--.:ANSACT ! C)N WAS (.:.")ENERATE:D BY TH[C CONVE]F,'.S i ,C!N TC) THE NEW C U S"i" 0 M E"'F:.'. S Y S T IEi:M "i." 0 D 0 C U ME:N T T H E UN i 'I" A N D R E L.A T i 0 N S H ]: F' C C) D E !ii!.: L. E A S F. A F' .::' L_ i C A"," i 0 N L I::. k:iA L D E S C R J: F' T i 0 N =~',k_ AS t...EASE APPL..ICATiON DESCRiF'TION. .i. i F'/:t. 4B ~ a FZLE: .ADL .i:'ARTt'dF:£NT OF': NATLJRA! .... Rr--.~nl ............ · -'; : .~ 65~7~ STATE n~- .,',i ,? ~'-'---- Df-G. ......... h .... ~ ,_, k. ,4 H A B Z 'F A'i' .... RASPBERRY RD A~Ronc.~,~ AK 995181 CASE TYPE: h_,~_iC .h_~- ..... DATE iNITIATED: 08-31-1970 CASE; STATUS: EASEMENT C'R:EATED TOTAL ACRES: ,~. I00 CASE SUBTYPE P TGHT OF F i L.~._ LOCAT I ON '. c-r. nrt._,,_.~. ~. L. AND SECT i ON OFF'iCE OF- PRIMARY RESPONSiBILiTY: SCDO MATSU AREA LAST ACTION: 0].-E:6-!993 FILE LOCATION LJF'DATE RECE!VED TO'FAL ACRES: 0 T.J Fr..iL. ACRES: C:-' TOTAl_ ACRES: O' TOTAL ACRIES: 0 TOTAL_ ACRES: ....,.,, :-, .-. ~.., . .. TOTAL AUI,,L_,.:. Tr)TAL ACRES: 0 '"' C" '"' - c'" 'F 0 T A L ~4 .,., F-, E::.._.~: F'/t',l 'AB ~ a . N L M :t E: 6, C, F::' F::!LE: ADL. F'r-,E:.~.:~,:::, EN'T'ER "t"0 t"IEW NE X"f' PAGE OR CL..EAF:;:. TO TERMINATE 'r'~.;.c:~.L..r...:',, N U I"t '" .. M: S "1" ,", C, .1. 9N R: OOE:'.W S: C, 9 TOTAl... ACRES: 0 !'~ I'!: S T: 019N R: O0;::]Wr S': .I. 0 'TOTA. 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'i.,. 9 ['!:; 9 ,_...-_, ,:'"' r'; '-'".'I..t:'!~,..., ,,.=:' ;". i T, c:.,..., ~ ,, 'r C i'"t ......... '"'" .... ~ ...... " q *' c:) ',",...~::' c. :::'.c: :,,:'c:.,",."r E ;(:) ............... ,,.., cf .,.W ~4 ',::::. .i. ¢.::, ;::, .,...; ,::. ! ........ , .... -' ;.:.!:!: 6-' '7 :I ........ ,, Et E:: .:... _ ,..,,, ,.... ,., ,..,, ," .L L.. E..'::¢ A F:;:. E N A TMI , ,:: ~'''' '""::..,- A D L. '....,(:~ ....'=; ,_:::::' ...., ':* 9. ,':'.,., ..... A T i-'4, R C)i...! G H 5 E:.: 3 '7 ":'+ '- %: ,, C; R T.,. ,...":':; .;"' .... N A i .... ,!:::' F: .... ,i::;:. t4, .,.'r T, I S i l':J. A D L. i::', I ! ..... ,i::' ..... 5 ;~ii'..':iii '7 ".'+- A NEW NAHE: S'i"ATE 0r.:' ALASKKA DFG. HAB]iTAT ....... f ') n~ r.... NAME: HAB i 'FAT , ..... I :.-..,--,~ .... ?-. ~:5 ~_ _ .-_', ..,:.._ c:.'~ ~-::.-....,b.~...* LEGAL DESCR :I PI' Z ON ...... ~ , , ~ A 50' TRAIL STARTING AT A POIN'T ON 'f'HE ANCHORAGE-FAiRBANKS HIGHWAY '"' - '~ ,., I ,-~,~ .T '-.[ N G ][ i",i APF~ROXi;r"!ATELY i/4 M.',.L~ SE OF HOUS'FON..,, AL_ASKA. SAzD TRAIL THE F;W1/",,. SECT'S'ON 2~ TOWNSHTP i8 NF~RTH R,r: R= ~ -- - . ..... , ..... , , .~-.,N,_,._3 WEST ~..~WF~RD MERIDIAN AND ENDING 'tN THE SWi/4 SECTTON ."c'-_".., ., , ..... TOWNSH'r p I o r.4.'Uh:: h F,'.ANGE 8 ........' P/N 4B~ a PRESS ENTER. TO V ]:,_W. NEXT, PAGE ORULc_~r,."-'"" '~'""~ ,...¢ -r.,.::.pM ]- ~, ,-,-r-~-, _,. , . ,q,._,, ,.. ...r', ~. c:rz,,.,. ~,, ,._.~..',v, NLM 1260F' FILE: Al}L_ DEPARTMENT OF NATURAL. RESOURCES 5~3'7¢:+-A CASE FIL. E ABSTRACT 5 / 95 14: 30: '42:: PAGE: '-'~, SEWAt.<i) MERIDiP, N .i._I ':::' MIL. ES LONG CON'f'AINz.'4u-_, ,.,v. i ACF..'.ES ME'.,'.REE OR SUBJECT "i'O ~ .,',,,tr~ T I ]'L.E c:-"r.,-.,"rl !o ,- '", t · ~-r 'zf-.~ 'r '- ml.._~'r_.r,l:_/..~x,.%; :[ · ~-~::::, ..... [ ..... [ ..... N R .i ................ .-.,,P E R' M "r U N D E F.',' ~... l"'i I '4 z.I ....I I I'"'~ I ,s..: .....,t .;. ' i ...... r- .... DL, LE ...... A, B AND C E N D 0 F' A B S T F,' A C T ,, F' R E S S ~:::',....,,, ~' m", ,...., .~:' q, T 0 B E:.' G i N ~-.',::~ ~-~ I N []F.: C L. E.: A F;'.' ~ U " .... "" "' ' ~ "' - :"" N U M '" DEPARTMENT OF NATURAL....R~BOURCES ~O~,:, 'C~E:;::.F...: IL, E:" .~IDG'T.':RACT... CUSTOMER- 'rD: i26573 MATANUSKA-SUS i TNA. BOR PO BOX !608 PALMER AK 996451608 CASE TYPE: MUNICIPAL ENTITLEMENT DATE INITIATED: 06-30-1978 CASE STATUS: ACTIVE TOTAL. ACRES: 0 FIL..E LOCATION: SCDO MLINICIPAL. SEL~='C OFFICE OF PRIMARY RESPONSIBILITY: SCDO HATSU AREA LAST ACTION: C',"~.-1D.-i995 CHANGE: LEGAL. ]"EXT M: S T: 01°~': M: S T: 018N R: O0 M: S T= C,!8N R: 00P..W S: 03 0,',"~ ,<:::; 04 Vt: S '!': O18t',t R M: S ]": C.;181'4 R: OC, E~W S: 0.5 M: S T: 018N R: 00~W S: 0.6 ," 0""~ S: 07 M: S 'T': 018N R: ,.).,r.=W I"I,:S 'l": 0 ! 8 N R: C:' C) E:'W S: 08 M" S "l": 018N R: (]:,06~.W S: ("~9 TOTAL. ACF'i'.ES: 0 · 'r F~'' ..... r Al_. ACF,'E]S: ]'O'I'A!_ ACRES: 'f' 0 T A L. A C R E.=.. S: C'- TOTAL_ ACRE;S: 0 TOTAL_ ACRES: 0 TO'l';"ll_ ACRES: C, -r' o T A L.. A C R E S: ,.".:.', 'I' 0 T A L. A C R E S: (7.) F'F:;.:E:.:SS ENTER TO VIEW NEXT PAGE OR [.';LEAF,,' TO TERM I,.4,...,t~:= D''c:''::' '"'"/ NLJM 'T' 0 T.A L_ A C R E S.." ,..,'"' ,'- -' '.i~ ::' C::' = 'i"O'T'AL. t...&..i: ,L.....,, 0 T 0 T ¢':~1 .... A C R E S: C:, :1:0'I::A[..ACRES: .... 0. . "" '~ ' = 006 J,,,i c: 0 '~ M: S "[" .'. ...... 8N R . ....,: .,. "~" ~. ~ - ...- ... ~ ~ ~ -"-'~ M: S i: -:.':::: '~ .-'::~N F.:: .,'"',o,.:.,· ,.i ::-3: ........ M: S "I": 0 .1. 9N R: (7.)03W SE;: ! 9 M: S T: 0 .1. 9 N F:;.: ~= C', C:--' :i:.{ W S: E:: () M',' S T: ().1.9N R: 003W S: ~i.---.:9 M: S T~..: 019N R=: 00 ::3W S: .".ii! M: S 'T': M: S T: M: S T: M: S T ~ M; S T: M: S T: M: S T: M: S M: S 0 ! 9N 0 .t 9 N 0 ! 9N C',. 19 N 019N 0i 9N "-' 19N 019N 0 i 9N 0! 9N 0t9N R: 003W S: 32 TOTAl .... Ar. iRES: 0 C '... :--. /'- '". *,, r" ~ ... F;.'.:O03W c, ,q.-~ TOTAL ~.~[...F;~c.~...'.: ~'~ R: 0 C) 3 W 34 '" '] 0 _ ,LTAL ACRES: R: O03W S: 35 TOTAL ACRES: C". R: 004W S: ,.")9 TOTAL ACRES: 0 ,,: -OC:A.W ,..,'=:: i "-',., -rf]TAL. ~._ACRES: R: 00,q.W S = .t i "FL]T£-'.:L Af..]R;,ZS: R: 004W S: i~ TO-[AL ACRES: O ,P:, OC,,~. W ...,°:i 4 Tr]'"'. _ ~--,,_;'~ ACRE'S: (]. R: OO4. W S: 2! TOTAL ACRES: 0 R: C) 04t,,,! S: 22 ..r {.q.. ,.,,i 0 : _..T~_ ACRES -' P/N q-B ~ a PRESS EN'T'.'ER TO VIEW NEXT F'AGE OR CLEEAR 'FO TERMINATE DISF'L. AY NLM i260F' DEF'ARTM, ENT OF' NATURAL ~' ~ ':", .,. ,_ ,::, L] { "":"-" '=_,r,L,E._, -'r .... r'ASE ~.-'r! ¢: ABSTRACT F .,. ,....L-.: ADL. ':~(')'" ~'- L/, Iq: '::'._, ]" : O 19N R: OC)4W c:,_,:WW' ........... ]'U'I ¢4L ACRE:S: C: M: c.: "i': () ! 9'lq ~:;' ;'2,.q- T ...... : 004t,4 S: ........... ; ............. : 0 Pi: .q T: 0i9N R: OC:~+W S: E:5 'tOTAL. ACRES: (} M: S "J": ('-.~ 19.1'4 R: OC, q.W S: :36 'T'OTAL_ ACRES: ,.":.', % % % .:,e % % .~ % .~ % % ..>:...~...x- ~. % ~,(. 4~- -'~. ~..;~. ~..~..~. % C A S E A C T I P "" ~,"'{ .... C) r.y (.'2, O 6-.."-],.. · I ...... I"IIJ 1'41 C I P A L N Old! t"4 A T I O N F';: E C E I V E"; D ..... ~"l' ~' 1'~{ j F' c::,l:::. L. ,' h.-.{.u,?. 0 N MSB NOHiNATES ;::-.'3, ~. 53 38 ¢.:~[.; TOWARDS ]'"t.' r'~..~{'~ F..ENT, .... "'" '""~ ,., / ..... ...~ cz, ..... ., ,:::, U N D E R A D L_ :::.~,"~ r', 6/", 6 P, r")"l'H ~.., b L.. S ! -..~ 0 Ix{ E:.' C A S E F: z L liE; C'7'"'0 I-:I. 978 TC.I]'Ai .... AC::RE]AE)E ENT ! TL..E;MENT FOR MUN ! [] I PAL. I"{"Y ?JUN ENTL. M'T' F:(]F~ THE'. MAT'Ai'..II. JSi<A-SUSI:'i"NA BOi:'~:C]UGH IS 355 ,, E"] :L () AC PUi:;'.St.h:::flxIT "['0 AS 0 :!:J ..... .1. 9'78 C 0 [:::' O R ]" ! C)t',.l S ]~.').]::z~' 2',' . ... ]. -:.': ..... %%',.;~ :'.~:.';;"y?.:'".~ '7:;] :'.'.3~.':' ..:..~]'~...~.~:..~`f~?'~.,`.:.U..~`~...~-..`.."`".`~.~`~.,~-.:.~.~-.~%~t:~.."~%.z~:~ .............. :'."':..:';',,'.:'"': 't.q..,z..,' ,' . ~'~':*.' '.-:[' ?..-(!.t.~:..?.~,].?: .. , .......... . .... ....'"" .,.'~ .... 3 .1.- :L' 9':::'r",.,. ...................... SEI..,.EC:T T ~'"'~".] APF"L. T ?"AT I ON REC]E".: I '"'-.,,' i"..:i: ;() .~.,,:i¢-., 0 :{,-;: 25-'; J; 98 ',.~¥ M S B R E:L.. :[ N(~U i SHii'.".: S APPI:r,:o'x .1. 5 AC ::,,."¢ :' C:,8":-, 80 .... .1. 986 R E L.. I N (::,'! LJ t S I"'i E D i", ..... ," ','"'~{ i .... M; S B ,",.t::.i ..... l ,i t.., ..... I S H E S A P P R'O X ,q. 8 (..:, A C .......... ()q ....... i 2-t.995 ,:' ACRE]A,.:..aE~'''E;TATd'S P/N :' 41. B m ,:?, P R E,..:c:' ,..,c::: E N 'T' E R "r', r't,._ ~,,.¢ T.. .... F:' l.,..{ l'..t E X T P A G E F"._...R C {.... E; A F;:. T, ....r') "{". [::'... ,r-:?.. {,.-'i, ...T IX{ A "{" E ,.,n T.,. S F:' L. A Y NUH P R E] P 0 S E D DEC A P P V,'.'..';,"-A C R E S 0 ,. 0 A P {:::'E' A L..[ii; D A C RE: S 0, C'. t::' ! NAL.. [)EEC; ACRES 0 ,, C:, S LJ R V E Y A C t:::..'. E:. S 0 ,, C, · !,4.'..;,.,..,. -.',. .,!. .i:,- % .,- ,-.:,:. .............. .~,~. % .*¢..'. 4::. ,- .,= .;,..,.,., ~x: -!,. ~:(.- ..~!- L E G A L D E S C R .:'r p '1' i 0 .r'J. EXHiB!T B T!SN. R3W~ SM SEC: i~_~: ALE ................................................... 640~00 AC T{9N, R4W~ SM SEC ~,: LOTS i THRU 4, NE~/4 Si ,o 608.98 AC :L q. ,: Z: 3: 09 6 E X H I B i 'T C T'~ Bt'J R3W~ SM S E C ! EJ.:: Al._ [ ......................................................... 6 q. C'- .. (.::' 0 A C 'r ~ 8 N R E?.W ,. c:: M P / N F' R' ':' c. c:. q- B m .:'.::',. E N"i" E R '[' O V .1'. E W N E:. X 'T' P A G E O R C L E A R T 0 '[' E R M i N A'T' E D i S F:' L. A Y D E P A R'I" M E N T 0 F::' N A 'i" U R A L. F:;,' E !ii';. 0 LJ R C E': S ('.'.', 5 / 05 / 95 ]. 4" ?.'iil :]ii: 0"i;:' P A (9 E :: "-* A ................................................................................ 8586,.96 AC T 18 N ,, SE-':C I: SE C, ;;i.:::: PAGE: 9 C:' i ..... 3 !.- i. 980 .~.~,.~.-~:.ADD LANDS .~.,!,:..~ ..... ~'-.X~'~ ~ "A~~': CLA .~ ~,.~c~ ..... SEC 2!.: N~i:~N2 ................................................... !60 AC AC 01 -.~5- i 983 **~REL '" ,NC4U Z SHED SELECT 1: ON~,.'--.~-~ P/N ~+B · a PRESS ENTER TO ViEW NEXT PAGE OR CLEAR TO "FERM][NATE D!SF'LAS' NUM NLM i E60P ~'iLE: ADL DEPARTHENT OF NATURAL.. RESOURCES E00664 CASE F~.t_E ABSTRACT TiSN, R3W. SM SE;[:].' ~1.: NW!/4NWI/4NW!/4, W!/E~NE!./;-'+NWI/4NW!/~'+. .................. 15.(77)(7) AC 08-E...':0 .... !. 986 .~'**REL.. 12 N!]!U ! SHED SELECT' I ON.~** T ! iii'].N, F..'7! W, S M SEC 16: N1./F?., SW1/~.+~ ......................................... q-SC".C:'O AC AC P / 1. lie N :-".') 0 F A B S T iR A C '!". F:' F,: E.":'.'3 S E N T E R T O B E: G :[: N A G A :[ lq 0 R C L E: A R 'T 0 DEPARTMENT OF NATURAL RESOURCF'S . ':'"374 I34' E:ASE F lEE ABSTRACT ::}5 / ,:.:,U / 95 ]. 3: ---:.,¢-4: ...... F'AGE;: i CUSTONER- I D: :i. 6042 SALE 67A DNR. DO;%G PO BOX ?034 ANCHORAGE AK 99501 CASE TYPE: OiL ~: GAS LEASE COMP ,'-'; .- · . ¢"4 ~ Z' -.~' ' '~ DATE I N I T i A'FED: C;9- I ,' - ! e,:4.'C) CASE S];'ATUS: ,..,: .O,_,E.D -,~E., B I D F,.:ECD TOTAL '"R ' ,=' . . . ,,q...,REo: 4 948 '730 SALE AREA COOK iNLET FiLE LOCATION: DIV OiL AND GAS OFFTCE OF F'RIMARY F::E~F.]1.-~....,IP,~.LITY: DIV OiL AND GAS LAST ACT!ON: 06-.~4-1994 ******************************* 09- i",;' .... 1990 TRACT DEFINED SALE D~..i'T ~: STATUS (:l.i) BID TYPE SAL..E NUMBER TRACT NLJbIBEF:,: FORM NUMBER C ON D I 'i' ! []N A L.. Y / N PRIMARY TERM F,'EPEAL_ED MEN'TAL HEAL'TH Fi'fPO'THE;CATE-ED L. AND C A S iF.: A C 'i- :[ 0 lq S ,.,., ..,,, ..,...,. -.'-4.., .~..:-~-. ,, -.,.,. 0 ].-;.3.9- ! 99 i 'f'RACT DEF'INEE) Fi XED ROYAL'TY F;.:A"FE 6'7A 1,34 D N R I (')- 403 ? 9 / 9 C:: N '7 P/N ¢.l. B q a F"IR E S S E N T E F-:.'. T 0 ~ ..... ~ :[ E:'. W hl E X T F:' A G E 0 R C t.. E A F: T 0 "F !iE.~';,' Fl 'r~NA,E, 'r - ?'-, 'r: ...... .5 ........ P L ¢.:! Y A NL!M F' ]: I.... E: A D L... 3'7 4 .I. 3 4 C A S E: F' I L. 140 F;,' K C 01''!M I'T "F lie I..';.:1''! ,:::,. 0 0 ]...... ~:iii'. 9 ..... :l. 9 91 NO B I D R E C E I VE!:) S "F A 'T U,S ( 8 ~:!~ ) C L. 0 S E D ...- 1''..t 0 B ! D F;.'. E C D .......... ,,i ['" I,, -- 0,':i ..... 06...'..1. 99;:Ji;: f-~,::.Ni~.-d .... HE. AL..TH I-..iYF'OTHEC]ATED L..AND :'"'~ '" H'4 F:' 0 T H [ii: C A T E D L.. i S"F: ,::::, ,, C 0 L.i ..... 0 F'-" L. A S T i-,. ~.'..::~ I'":"tJF,.. TM..::~U~''',,''~'''4'"I TO S ...... ='/..¢ ........ E:H 66., SLA 199 .1. , L..AND L.. t STE:D i N ' LANDS i '" '" r", "]" "i I '"' ~''''' "" "F r'" t'"t "r '] ~ .. - ....... t'", ;' ," t... I ,'". i::: .... ~-..'~, ,:::.,.. ~ L "I"H E': M [ii;N "t"A L.. H F:'A L.. ]"i"'l T F:;.'.U S "I" ,., M A Y .I. ? 9.1. A S F;.: E F; '~' N E il) 4 / 6 / 9;;;;.". 0 6- ¢JJJ'. z~ ..... .1. 9 9 4 R E: F::' E: A L. [ii: D M [ir N T A L.. I'-'I [ii: A L T H H Y !:::' 0 ]' H E C A'T' E !:) L A N D ,-, ....... ,~.-."~::~' -f',, , ~,., ",p"r'~ ['"~'",,". ""r.:,~ .~p,::.?.~ ~z~t',4'~." TO CH.'AF::tTE:!::;.: !:."5 ~ ...... ;...,..., .,. ~ ~ .... :, rt..E1.' r_:.~.-.L.E,.., F'ROM n ~ i:". .... "'t,.:: ..... ...~ t I ON. ,...,, ,,..,.....,,.,.,, ~:'c:~.c~.' o.: 'f ,::", c,,.:', "~: ~ 1: .......... .i.. 9 9/-'.I. DATED ,., L,.N.:. ~'iZ:."J, .............. · .-, ~.. · ,'",-r' I ,'7..'.,' N ., -;,;.- .!.,:-,..~,.'...., ..;~-, -:,.:-,,..~-...~- .~::.: .:,4....~.. O. q:". ..... .1, '7 .... ..I -':'~., c.,~ ¢-, ..... * .!.':~. S A L E N 0 T .T .... C E L. lie G A L D lie S C IR T p T i n ....... !', ~ .. 'T' F;.: A C: T 6'7 A .... ]. 34 "r' .1. 8N ,, F.: 3I,.4 , SEWARD MER T ?) T "-l,' ' ............. ~..~,'4, ALASKA F i i._ E!:: A D i .... ,.,.~...,:'",c'r::'AR'T'MENT r';~:'..,, NAT'LiF;.:AL. RE:SOURCE:S %-'- ..'- &'-. ¢-"'. ,..,'° '7 4 .1. :3 4 C A S E F:.,.T ,....: ~::~ .... A B :'."'.3 ,."~ ~..~, .... · ::,o 56 .I. 3: ........ : ,':3 TH i~-u:~. TRACT CONTAINS 4948 , '-"-',, o ,,~-",CRC"F,.',,., ,._,... ,MOF,.'~z. , ,,_ OF: LESS. P/N ~+B~ a N I... f"l 1260F' ........ : ADL.. PRESS ENTER TO ~."IEW NEXT PAGE OR CL. EAR ]-n ]'ERM:ENATE Di..-:FLAT A NUM DE:FA.. t, .E,,,, OF NA'!'UF:;,'AL r, I:- .:::, L, :J F'.. ..., ~.'_ ,:, ~.,~]~_~.- - ~ ~-~ ,-.--. . 374134 CASE' F' i L_E'; ~-~ ......[ R~-t.,]' ............. ......... ......... ........ .. . ....... · ' · ' "· 4 ' ': .... : "" · ' ":: ...... "" '":' : ' '" ' ...... "'."' ' ' : .... ~:u ,~.=,~.-~., I ~60F' F!LE~ ADL DEF'ARTMF'NT DF ~.,..---,T,~ .... ~ · e,,.~c.'r: r: '~ LE ABSTRACT P_ 152 t ;~ ...,: ...... 05 / 05/' 95 t. ].: 36: 59 PAGE: ~ SR BOX 272'7 HOLjSTON WAS!LLA AK 9968? CASE TYPE: c, & C USE SALE NON-COMP "~: T~-~TU~.,: .............. DAT~ INITIATED: 06-24-!982 C~,~,- S * ~ q APF'LICAT!qf'~ ~;'~:'['EIVED ................ ~B~ Vf E. IC b: CHARI]" USE TO'I-AL ACRES= 15,000 CAE~ ~, cT'':,' F'UBL. " · ~, i ~ F l L.E LOCAT I ON: SCDO LmND SECT' I~,,n~'"~ , ,. r-,'-,*-,r- c,T ~ SC] OFFICE OF PRIMARY r, EoFONo.~B.~LtTY: DO MA'FSLt AREA LAST ACTION: r~m-'-13-'"¢'Rz ...... ,.-;,.~o F'LAG ERF:OR TRANSACT ION FOF;'. NON D iSF'LAY .~ ............... pz.,. os,. i mc, c, APF'L. ]; CAT I ON REECE T VED L. SE AF'LN FC)R REECLAMATIn*''~,, OF U.¢~,i..."P'" S"i'RiF' i'4]:NE AS A SANITARY L. ANDF'T~..~.' ' .... , -~r,~ .... '-k' ' .5 ¢-,,',-RU.. :1.5 AC LOC AF'PRC]X MI NE OF CiTY C]F I"~(]LIS]'ON. 08-E~'?-]. 982 bL~M,'E::.NT ~:, ..... ,~ "' " ~. Lc. ADL.. L~L..N,'~ HEN[] TO C ZTY OF HOLtSTON REGARDING DL. OSUE OF DdFLiCATE F'T' ~'- .......... .,..:: cz ~_, 0 P E N E D A C C i D E N T A L L Y B Y S E R i A L.. ! Z i N 8 A P L N T N i C E, 0].'25-].983 CHANGE CASE TYPE: FOR AN EXIS'T'tNG CASE ' OL.D CASE TYPE P 8: C USE L=r..~c:,E. N(]N .... NE W C,m c:~E T Y F'E P 8: C U S E ,..,A ~...[... N C)N- C P/N kKE:.,::~:.'::, b.,',,t TO ViEW NEXT F:'ACgE OR CLEAF;: TC) 'T'~:zF'M'rNA]"E r~ISF::'L..AY A NUM .. ' ....... · B Ii! F.~. ............. . ........... :::.- ..: .- ..... : ........ :: .... . .:..:: -- ..- . '-:-:.: ~'~,*'~:,'7~. ........ "'"- '"%" ...... ~ ............. :"::""' ':% ' ........ ' ....... "': ': .................. ':"~ :'"'" ........... N~-.~ ~t.u,h:,~.,d t;4:[~.4:r, UUI-(UES ,,.,, ....., I .1.: .M 126':".q::' D t::: l::' r.': c:' "r' ~'," l::: ': ~ ":", ...-,.: ..., , ~,....,..,, C]F' '"' '~'' ' '"""' '", '"'c' ', '"', ..... -'"': ........ '('"'='/9'5 3/".. ......: ,,..'~ c? ' ~,.. ~ "~ ~"'~~ ~, ~"5 ' ~"° F~ ~'" : ADL . 2 .I. 5;::: ]. 4 CASE F' ILE P,B.::r, [ R,.-~L,q' F'~.~:~E: c::: C]LD CASE STAT'US NEW C;ASE STA'r'us r3 L.. DOF F' i C E ,"" r ....... ~" ". "" NE W Ur" i:...~. [... E::. r3i f'] ,-..-. --. r.-. F' ~.", I' ,:: ..... F: r'l)[') [::' "~ '"' ["' T ."', i¢ ...... ¥ Nt::I'1,.,_ ,-~ ..,,c:'tF E..u, .~.:i,,:~,_ F:'~.'.,:C USE ( A ) ...L::~[:. I::'L.IBI..:. I C ~.,: C;HAF.'. I'T I ~ L. A I'.",1D L. E A S F.:.: ..... , c', ~::.. -'; c:. ,", l T 0 B E: ~'" ''"' '"" """"' c. ,"' ,'"' ,"., A S M U N I C i PA L.. .::~ .:::. L.. ,.:: .., 1 i 0 N, t}' .1. -25'-' i. 9';.3:3 CC]MMENTS ......... I',I,,,:F. '~ ~=fl~...,t'..:. OF' '~ F'~t..:. -['r'~ C .i: T ¥ OF' .L,'-.',i ~C.'T'r',i-...i I:- F','-,. d v i::.,d 0 N () '~ .... '::::":~ i ? ~::~::'::~ I::: 0 R r::: .r.:),, ' -'"",, ,i ...... "-": ....... UNDEF:. AS :.'!'~8.0~.5,3:!.5(A)- MAT-SU BORO F:IEI .... F:C)F;.' L.A. NDS I::;:EC:D 0:i.-2.5 .... .i. 9S3,' }i'27 .... :~983 COMMENTS F ! hi A L F:' i hiF;' I big AF'P R 0 V E D B Y Si;C D MG F;,' C)hl ,2: .t. ..... ;'2 ? .... :i. 983 T C) C Eii'"..iV E Y ~. 5 A C F:'::.E S (... :.;) .. .... i..),J,~,, J,4 L.jNf3EF¢ .... ,:,c9 ;:¢.I ...... A "F 0 Ci "t:' Y P F' i-. i'" ~ ' c~"r f'" h h,'" '=: (' )B-"' ~. E.: ..... i '983 C::OMMEN"t"S MEMC) F'ROM CALJ TO DL. NM F,:E]"AIi",.iF'i) L_ANDS UN]:T STATES THAT TF':.'.ANSF'ER E.'F' SUBJEC;'T' i....AND NEE:DS AF:'PF:;:C')."~,"AL C)F:: COMM!SSIOr,.!EF:':,' DUE: TO MH L_ANDS. :'.~2-E!:q. ..... :t. 983 E;OMMENTS · -:::'l ~ -~:..' '",' .'-::' r" "r' L.A N D S M A Y 'P'"'"" ..... ~:~ ~ ~:'''' 'i ..... r" :. i ,", -," ',' ......... .--.r.:'l. ¢::: '"'::'r-:'~::' 'r L E ?_:,c..-.;~c,.;,.:. .... r,.¢ i':::~'~TK,,, :. U~,'-.~ ~"2E V.~.LL_AGE .:::,.':: ..... C"; .,. I""~ ...... Y' ] [, · ...... ,,.,,~ ~ ..... '¢% ~ ..o~ ..,.,. r.,..[-.~,...~i::;'NF'¥'~ i::'F.'f'.')?'! f']~-.',cJ TO ct¢"'f"~ ~"'i{}~i::~'. i::'OR F,.r.::,:,L:h._d] Z:3r, (DF' POINTS INVOL. VE:'D., · ;'/N PRES',"::; EN,,L"..t":. TO ~"'r[::N i"..i~:'XT PAGE.:: F""' i'"'i FAR T[')"['~.RMTNATE D'rSF:'L-AY ),. a A NUM "~ tc .... ;] · --' · I :" ~:~':' "' HF)iJS"r'ON ,.. P]"Y ....... · :.'.~ .... Mb.F,. i'4...d 1 ..... :...F: ............ ............ L.: d ~.,E. ,¢I~' L A NIL} -.,[ ,'. ,., "r',~::'.,-:'~:::' . ........... F~"'-~ ..4' -. "-'Or, E ,..,t.,-.-,: .... F,.. 1-",;E:.L F.'~ T ! L; ,,.-,t', .[ t- L ..... ~ T'i",'~ -r'~:,.,",~,~r,.c'-~'Tnh', t,.~i¢C'5 GEhiEF;,'A'f'ED BY TF!E c--.--,:---,,,:,='~,c TO "~"~_m:' NEW CLJSTOh!ER SYSTEM TO '.,-,r~,-'Hr,~'-~,r~' THE'_' UNIT AND LEASE AF'F'i.. I CAT l,.Ob;,, LEGAL_ DF'SPR_ _, .,.'r PT I ON t I-]C:.-"~TCl-) WiTH~.N TOWNSHIP !8 NOFTH RANGE 3 WEST', ......... , ........... " , . , . SE;WARD MER"-' n ~' ,~.~ : = /-' ~..t .I~ r ..... r .... r~r--:~:¢]¥ SECTION ;~i: NW1/4NWi'-,/q-NW!/4, {,Ji/;~NEi /,",~,-'W~, ~+,,W.~/4, L].ON]A'rN.,,NL-~ ; ...... .,,. 15 ACRES. -'F..'" ~.,.'EL, I I F.,,E.~_!MINARY '" "' S ON LEGAl._ DES._,RIF'TION SAME AS LEASE AF'F'L!CA]'iON DESCR!F'TION. 01 --P_5-19~3 P / N ,q.B, a F,p~'-'Rc:: E:N'['ER 'TO ",'"' ......... ,. F' W N E X 'I" F' A G E 0 R C L E A R 'T' 0 'T' E; R M I N A'T' E D ! S F' L. A v A NUM NA ~,.Jh:r-lL. REESOURCES DE:F:'ARTMENT OF ' .... : '"'"" ~!.~ :L ~'."'~.!.~ t ,~+CASE t:' i i....E ABSTF;:f'tCT F ! N A [... D E C.'. ! S I 0 hi L E: G A ! .... D E E; C.'. R ! F' T I 0 N S A M E A S L. ii!"' A S E A P P L. I C A T i 0 N D E S C 1::;: ! P"t" i 0 N. 0 5 / 0 5 / 9 5 :i. ].: :B 6: 5 9 F'AGE: 4 () J...... ~i.:.'~'7 -' J. 9 8 3 N L hi 3 0 4 ¢:, F' M: S "F: 018h.i R: O03W S: ;::_'! ACRES: 640.('.~(".',0 CASE TYF'E: OR CATEGORY: DNR AREA SCDO MAT-SU AREA n.~-. yURL, i NG D i ST. PALMER ..... · ,.,-- ,-.!s'r'. D ....TRICT N HOLiSE r, ~ ...... ~ DISTRICT REGiONAi .... Cb~.~- ,. COOK INLET ,~,,...G I ON q~ z',. T C T .......... NFO D I ST .,.,,",'rc.,~ BO~:-'O "~'HE'SE L. ANr:S P '" ' " " '""'"' ©URT EF'FF'CTI Vi.:.' 'rl .~':.tE:' .~:....:::,. ...,. 4 L. OC A T I r'~N BY T H E AL. A S K A S U PF_.'R I ,._,t:.,, C ..... ' ~" -' P A R C Ii:' LI. D E N T I F i. F R ........................ L A N D T Y P E ............................... S .... ":.~,". 6 t'I- MFiT ,. M c:.. +, ..... = OR i G I NAL. TRUST L. AND F'iI"-I T S i"'!- E: 4 4 ()-- C" .I. 0 R I G I N At .... T R U :S T L A N D F'! LE 'TYPE 8~: NUMBER · .............................C,~-~,.:,E': 'f'YPE: ......................... S"f'A'['LE'.:; I N I T I A"f'E DATE ..............C: 'r D .............. · .:,,:..:,4.... % .?.,~....,4--.,......,..-!,-'!.....i-*.'.... 'T' i "t' L. E ..,~.i ,..,r' p.:,: ,..,~ ~ .,.'r ....,c:: i -r'. I ,':.] N +-'.. * -~:...!..,.'...,., .. *....i--.:...,, -.:.*.:..~,~..:/..- +..,: ...-,... . GS I. 2.64 ":':F.~'':::'~:'?': =(" ..... . .. :I. 244:3 .I. ................... - ...... GF.'.Ai',tT ,j .., (..:,~.::: ! (":, .t. ! .t. 96:.:.-]: Ni...t":i 3(} 4 0 P .. M: :ii.-'; T: 018N R: .00::3W S: ;::'?. :i. ACRtL':.S: 640,000 ........ C,A S.E "i'; Y F' r::::: 0 F;:. C A T E .G O.R.Y .:... F:' I i.... E: T Y P [::: ~,: lq U MB IFZ R r"" ~: .... ,., ................................. .., ~.../,.::, E "f' Y P E ................................ S T A'T' U S i N ! T I A T E D A T liE: ............... C ]: r'., ............... F:! F" .i. i---i E L_ F' .... , r c,, ~.: .... '- i::'REV HENLJ 4 B :, a N U .r,t ADL ADL LAS LAS LAS LAS LAS ,'::::' ....... ~ 01 O',o,,.., WATER RI GHTS , ~:~ =,.J [4 ATE :: iS H 'i- S · ...'-,..'Jo WATER R l' UH '.. =, !0054 WATEF-.: RIGHTS 1C, 594 WATER RIGHTS il, ;; WATER ~'TGHTS ************************* M i SCELL_ANEOUS LAS i6560 OiL AND GAS WELl_ SITE ,'-mS i7380 OIL AND G;~, WELL S~'-FE LAS i ??84 01L~,'~'~,~- GAS WELL ~ I ~r., ~. **'*ce* END ,t]F LAND iNDEX REr£_~-<[ -.',:.-:.',:.**~* F:F.i. - FiEL. P PF8/i~O- F'REV !flENU 4B ~ a NUM 15 10/!~/!993 ~1486 1 = r:, I ooo o 1465 .~ I I~/I , ,.= PF' .I. ~::2_ / E:4 '- RETURN _ i'~P-P,C'.,RTi'-4.c't-..!T OF NATL!RAL .;-,c'~r-¢t~,r-r=o LAND FILE ABSTRACT' F'Au,_ ."-"= C-E:, C~ ! ~,r-- ¥ -r .4c:,., : N :'.iM -.. : ACRES; TY='E (Y/N): ,,, , , : : NAME/ADDRESS ~'~ DNR AREA CM SCDO MAT-SLJ AREA RECORDING DIST. R31i F'ALMER SENATE DIST. 28A DiSTRiCT N HOUSE D I ST. ;?.RS D I STR i CT .... ' ~"~ 94 ..... REG l U1..:HL.. COF-iP. COOl'::: INLET t:;.'E..-R I ON ,...,C:'TAT,'E i NF=O F',_...T ST.. ,, qo.'=,,_ ,_.:.. MATSU BORO. PLO NONE FICHE DATA NONE -.'~:~'~-~-~'~-~'-'~'-~-~'~,':~'~:~'~'~':'~='~"~-~.- MENTAL. HEAl_TH ,..~-,r.,L.'.:, ~'~.~'~-a-x'~-'~'%~"~"i~'%~:(-~'~':'~'*'~'>'''~'=''-~''''-'''~' ........ :'~' T H E S E LA i"..iD S A R E AF= F E C' T E D BY A T E M P 0 R Ai:R Y C i_ F.]S UR E T 0 M i NE I=,'.AI .... I....O C A T i Otil B Y "1- l'"tE A L A SI< A S LJ PER P A R C E t_ i D E N T I I=' I E R. .................... L A N D T Y P E".'; ............................... M H'T' S 5056 ("?- M PI T Fi'. LJ ~'~ T t_ A Iii D M H'T' "" '='') "'"' '~ ...... c.~._:,...=~ o .,. M H T R U 5 I L. A N D P F:' 1 ....I'"! E L.. F::' F::' I:= 8 / ~':~ 0 ..... F:' R E V M E. N U 4. B ,~ a N U M F' F' .i. E'. / ;":!~ 4 ...... F'i' E T U F'i' t''4 NL. M3()60F::' LE.,'" Ai"~ ~, I[.-,,, 1 C)F= him I .Jt-',,~.-.d_ · ....... : :~ L:AND FI'I...E ABSTRACT F:'AGE: 000E: N E X "i' :', N '~ M: S T: 0.1.8N R: O():BW S: 15 ACRES: 64.0,,000 C A S E T Y P E: 0 R C(4 T E G C) F,'. Y: iq A M E / A D'i.;) R E S S ( Y / N ): N :'"'?:%..~..~..~..~,:- :!~-:.-x...~,.~..~4;.:4..~, :~,.~.~...~..~.'.~..~..~r,..~,.'...~s.x...~..~.~.~. T ITLl..Z AC DU IS I'T '"','"'.k F ii: 1... E,.::.,r:'" ,..:c" 'E'. C A S E T Y P E 10 i b E l N I 'I" :I: A T E: D A"r'E 0 6 .... :f. 8-... '.I. 9 5 9 c:; T i':'::i"i" LJ S D f..".'f T liE: .I. ;::'. ....- ~::: b .... .1. ': .? r.::. /x .... ::;., ::.-,::::- r.'.l.O() ...... ,"., · / 4 'r ),":"".~, ,"-~ ,...d..,I .l ........ I A t .... ,.....~...d,ID ..' h .... ..tt::.t".¢. ,J .... i::: i i.... E G.S ::::iF::A I N ! T ]: A T iii:_' D A T E 1 1- ,.. ,?- .,. ';,") .... ~ ":" ':";,,='"' STATUS DATE: .I. ;:i~:--'f.~!:E:~ .... I '":?9E': A C F:~ E :::.:; :iii) 0 P A T"'" i.... A N D / M i N E R A I .... F i I_ E L..S H 3 ! N i T i A T ii:.':: D A T ii':". () .1.- 0 f~.:~ ..... :i. 96 · '.:.ii; T A T U S D A T E C, .1. -0 E: ..... i 96 F..:!: ¢"'""'~::" ="S T 0 T A! .... --, ..... '.t ..... ('.':: I:::' iii L. E,~'"'~,,r'::' .... 3 ! N i T ]: {-ti T E D A T E C, &:' ..... i 8- .1. 9 6 .,:.::."r ,",.";"t t,'::. ," ,', "t",'"' ("-" i::::' ..... .t 8 ..... .t. 9 6 3 ""., t:.. ¢". I ......... .., ~-..,,:::~,:::. S'T' A"I" t.J S 5,:..~ A C T i V E: 4.0 ,:.'.; 'T' C] T'AI_ CASE 'T' i'F:'E :i. 0 i GENERA L.. GRAIq T C A S E .'.:.ii TA. T U S.,.1 ,..;*::' U N V E 1::;.: I F' I E: ii) c::, A ,r .,...i S:, ........ V E F'F:::[ ..... FiiELF' i::'F'S/i~O - F::'REV !'IENU ~:1: .P..' -"* ..-'~. N I,! M F' F i ~ / ?2 ,:'+ ..... F,' E 'T' U R I'..i N i.... M 3 (7.:, 6 C, F' N i T i ATE DATE c',~-C:, .I.-' I o.'", o *-"v" '? i '"' '-',e 976 .... -~.~o DATE ~.., .... 0i--~ ACRE']~, 48¢.~. RESERVED USE N i T i AT~c. DATE i 1 -. ""~-._. ._.. i 989 S"r,","r~ ~ DATE i ~ -0:3- I ACRES 3PC'._ ,Re'mn, ,~:,nc.~.~,~,,~.~... P, AN~oE4E~4T C A S E ..., ~ ~..-~ T L, ~'+ 8 ':"." , 07 CASE TYPE ;F.::01 ................. ~-.i...-., b .,.. F 'r nAT l :J,'.-, CASE STATUSw~=" APPROVED 3Re) TOTAL .. '~- ,. .'"- ~'-'~ I F% - ' CASE 'TYPE a2"~3 L..EA~EH~J~...~.., L. OCA] iON ORi)ER PFi -- HEL. F' A.B .,~ a PF'8/F20 - PREV MENU PF:t ~/[.::4 - RETURN N L.. M 3 C, 60 F' DEPARTMENT OF NATUF;:'.AL RE:?.~OL!RCES LAND FiL.E AB:L-;TRACT A C R E S: 6/-+ 0.00 C) C.', L A S S I F I C A T I 0 N 05 ./08 / .1. ";' q'~"'; :I. '~.: .i. F::: ....... PA(SEE: NEXT: N NAME/r.-,L][ ............. , (Y/N): N M= L "i": C_:,!SN R: 003W S: .I. 5 CASE TYF'E: OR CATEGOF:.'./: i N I '1" I A"!' E D A'r E .1. ].-' ! ',3 .... ! 989 c.- ",-.,", "r'i ~ c:. D A T tie 't 1 - 13-1 '::' 8'::;' A C R E S :]..) Fi.."O RE' S T R i C T E D F' i L E M,'::] 0 i:.~ 50 ]' b ..... .,. ~ '~ ! T I A T E D A T E 03 .... .1. 3- ! 98 E~. ::::) ~ Al'ILS DA, ,: ....... -.,. ~ .... ,,:... ACREi:S 3D'.0 CL_OSF.'.D i::: I L. tii:' M 00 58q- CF.'" /", T CASF{ .~ F~-~,~ t.j~ 54 APF:'ROVED 320 TOTAL ..... ( ..... "...'1 .., [...u:: [.". ]"YPE E]O,:. M I NEF:;'.Ai .... CLC]S i NG C:)F..'.DEF.: S T A T U S D A T E .1. 1 ....0 :ii)-'- .I. 9 ii!) 9 C A S E S T A T U S 54 A F' F::' R 0 V E D ~'"'~'"" ACRES 3~0 FOTAL: · .>:..:,,~..!,.~..:,:i..~ ..:'~..~..~..:'4.'. -.'~...:,.'...¥;..:~..:,:. -~...~. ~.~. * .:,..,:. ->~..t4..!,:.'....x- e -~. S U R F A C E A C T I V ! 't" Y F'I L.E ADI .... 5fft. 374-A i Ix} I ]" I A TIE D A'i" El C:, 8 ..-3 .1. -.. 19";;' 0 ....... STATLiS DATE C,E'-F26 ..... 1.97t .CASE STATUS £:':0 EASENE:NT C.:RE:ATED I',,ii ',,.' ::;) F"t ':'. "1:5 ........ 11 ....... c.,t,! H: S -l" :: 0 .i. 8 N R: (':,0:3 W S: .1. 5 A C R E.':_:.'2;: 640 ,, 000 C A S E T Y F' E ,". 0 R C A'T' E G r] R Y: ~..~...~....~'....~...?-:. ~..~..~..~...~,:..~ ~..~ e .~...,,.':- .~....¥ -'.~ -:~ .~ -.¥ .?-.., 4,., S U R F' A C El. A C 'T l V i 'T' Y C A S E f::]!; U B'[' Y F'['.':'J 80 C-' 5 F;..' ! G H"[' C) F' b,l A Y ACRES 0 TOTA! .... ~:-':, !'~... ~:::.'"' A D i .... ;-'.!?. 6 .1. (.'.:, '7 · r r...i 17' t ""-"'"'" DATE:.,"-, :::, ..... r'; .'::~. "9,.,'-.,.'::; ..... ?"t i [Z. .. ....... -_...... ..... ~ ......... S..,- ,-, ..,-,,,... ~ ~-..~, ,...,.::': DATF' 09-09 .... .I. 97,':~. A C R E S ,.".:, 'I" 0 T F-:fi .... F' i' :"" Ar",i ......... L.. r.:: ............ ~::: C'.'. C:': ~'., ,:5 "-4- i N ! T i A T E E, A "[' E 0,.':.5 - :.:30 - .i. 9 '7.';3 S T A T U S L') A T E ,:.~::6-.-.- 30 .... .1. 9'7 ?.'.-) A C':: R E S ,.--.,.... "-..'": ,...,r'; "F A. L F'. .,.'r L.. E A D L. :::._:: () ]. S 93 i..~".i., .,.'r T, .,.'r ATE DA''re': , ....... ':"::5'"-0::~ ..... .i. 97©, ~. -r' ."... T:: '::: D A T E 09- Ei: 8 .... :i. c.'- c:: :'? A C F:;.'. E :ii.:; 0 'T' 0'i" A i .... C:, 5 / ('.~ 8 ,/:l. 9 9 5 ]. 4 :: 18: PAG[ii:: C)::")c:, NE X'T': hi LAND F iL..E ABSTRACT' O(".~3W S; i5 ACRES: 640,000 [JR FiLE ADL 374!33 i N i T I ATE DATE 09- 17-- 199(":. STATUS DATE 01-29-199! SALE AREA C'i ACRES 640 TOTAL. FiL. E ADL 38]. 13:13 .[ N I ]" I ATE u~.:, ~ E I. ,t:,-627- i ~. c. STA]'.,',US DATE 01--.E'.6 .... .1.993 SA. LE AREA Ci .,-,. r. c, r:',=. 6q.r~ TOTAL. 05 / '-.".:.'-' 8 / J. 995 PAGE NAME/ADDRESS (Y/N?: N MtJN I C ! PAL ***********-~-*********%****** ~,=,..._,°'":°--'°"-_,,-,,~='=~?='--~"r'T,, ~=.=. ~,.., I V i TY CASE TYPE 784 OiL. g: GAS LEASE' COMP CASE STATUS 82 CLOSED-'NO BiD RE]CD COOK INLET CASE TYPE 784 OiL &: GAS LEASE COMP CASE STATUS 8E-': CLOSED-NO BiD RECD C 00 K I N L. E; T * ** * * * E N D E) F i..., A N D A B S T R A C T' t:;.', E P 0 R '[ * * * * ** PF':i. -"- HELP PF'8/8() - PREV MEhiU 4 B ,, a N U M F' F :i, ;'.:i.::. / E': 4 -- R E.'T' L.J R N DEF'ARTMENT F~F_. !4,~-i -~ ;'"';~ LH-~,htL ...... RESQURCEE:- LAND ~i ABSTRACT T. O,:[8N,,,R,:,, ¢O~W S,. i&, ACRES: CASE TY'"'- OR ,;"--'-',TFR..,'],q:-Y: I- ~'.. -" ............ DNR AF:,:EA,..,'-'M ,S'-'DO,-, , MAT-SU AREA RECORDibiG DIST, R311 PALMER SENATE~,,_,r; ? ~, T,, B84 ,...:"'" i STF:-.: .-,T CT N HOUSE DIST, ~i2S DISTRICT RS REGiONAL COG:F'. 9/-+ COOl'.'.': !biL_ET REG iON STATE iNF:O DIST, '.'t83 MATSU BORO PL.O NONE; F I C !'"iED A T A h.tO N E F i L.E S Ci"4 q. 4 i N i T i A T F..'E D.A T E' 04- 2'. 7 - 1960 640, C:' O'.'Z:: F::'A G E': 000 i NEX-': :.-"~ NAME/ADDRESS (Y/N): N P F 1 -' HE L.. F' PF 8 / ~.':~ C:, ..... F'R E V M E:hiU 4 I3 ;~ a N U M · S'TATL]S DATE!: 05-E!9 .....:L9?:B .................. :.,' ..:..', .,.. :.-- ;L 'P ['...~'~. h"'"' r" C,C'C:.,._,, ,,,_...., ,..,'::"'"'~,... i'",'E.*..::;'I::: R %J I::. D USE F Z L..E:' C'i .... :L 000 I N i "F I A'T' E D A'I' E: 09'.... 0 :L - :t. 9'76 S 'T' A'T' U S D A'T [ii; 0 9-C', .t. ..... :L 9'76 A C R F:i: S 6 :L 0,c', ,.......,,_.,~:: ,::: c:: ~::',,, ,....,:c',._ ,..,'n U :!ii; l.Z F i L..F.'.{ Ci .... :LSN3WSG i N I T I A T E n,","r ~:.- ,h/...-. ':] r',- i ,':.:,"::,,::.~ S T A T U S D A T E c:, 6- 3 C) -...I '--':', TM, '::', ACF:;:ES i C:.' F::'UBi.... iC i::;:ECF'iE:A,] .... i t..,-'"',, F:IL.E Ci .... SC-E:0-(')3'7 7:i'."4 Z "i" ! ATE DATE 08-2.9' i 980 ,"; 'r' ?'.. "~" l ; ;'", · :~; ,~.~; ... ,:'~ DA'T'E: 08'"',29- :L 980 A C iR E :{El 640 C L.. A S S ! F' I E D F' !' L... ECi .... S C - 8- 2:.- () 18 ,i::' F 'i.,. .... H, F:' i.... ,.... ,i:::, P F S , .... f::..L."' "" '- F:' R E V M E N U 4 B ,, a N LJ M F' F::' ]. 2 / ~!!Z 4 ...... F';'. lei: T LJ R N N L. {""i :}] 0 60 P '....;,._,; :_.-' o / .,. ;, .~ .... PA G[ii:: NEXT:: 'F'8, TI~C.'. ::::'0~ [.::'E',c.'-:r.::'bi.~;ii~.~.!T ¢".r-~r" r, -r'r'-".,-:. S-F ~.-~ i L} t':.~ .,...:,,-4 ~ ~:' 0 7 - E':': 9- I ": ~_, ~:_, ..... E S ~ ,. ............................ ...................... ,,, ~ ;r... X C LU S Z VE' R 0 W ACRE:E; 4 TOT'~L c'T ~ p- ADL '-:':' ~ 6330 C. ASE ,.._ .". ! N i T ! A T E D A T E 08 - i 9 - ! 9 ,cB 3 RT.,":~'-, :c:. T')ATF .~.~ -t oR-=. ............................................... . .... -. ;,...... ..... I--E:--'~. ,.--_,,., F'.'AR-~' ST~'!"LJS- ';:":"'-' CASE SUB-r'YPE ,;;.:,212 CQHH COHF' SALE ACRES ?9 TOTAL. .'---.~.o,~, CASE 'f'Y'F'E 5C'::: TiNBER SAL. E P' i L..E ADL c:.~ F'F:L - HELF: PF8/~O - F'REV MENU 4B · a NUN ' "='*.' RETURN F'F' z ,..'~ ,' ,_ .-~ .... N L H 3 C"- 6 C: P DEF'ARTM -":' OF ., ,EN~ NATLJRAL._ RESOURCES LAND .F" i LE ~4~:.c.-," ,-.c.',; .......... F,'.r::~U ~ 05/,:::,:~,," i 995 i4: E:O: 54 r-, r, --. r- {"~ ["~ (5 r- ?.-t L5 ~:: = ...... NEXT: N H: S T: 018N R: OC::3W S: 16 ACR!i..'-.S: ~)4,'.}.c:,00 ..... F"/% ']" rT.' ~] I-"~ r-, \; CASE -t-YF'E: LJh: .... r. ..... ".. ~ : *-.** .**, *., .,, * .r**..*****.,.,.**** SI. jF:.:.I::rACE ,..,C, ,. :[ V ! ]"Y i N I T I A T E "'" "' '~ r 0 o_ I c,. ~.,,,, ,: ....... ',-'- 1983 S T A 'f' U S D A T E i ;.-7--' i 6-' i 983 C A S E FS 1' A TLt S ;{i-30 C 0 N'f' F,'. A C T' I S S U E )7.) C A S ii:."; """ ":' ..... ' '" - .., U, h't ........... S A L E .:'.'~ d B t 'r F" E (':, i i ~!:3~ F' "*,' ~' r', p~.4 A C R E' S 80 ]" 0 T A I .... F:' I I.... E A D L. c::...'.::, r,"-::: .'.::, ,, ~. .............. *.,- C A S E T Y P E 556,r'::' Z,: C t_,~.,,":::' t:::' .... L. E A S E hi 0 N'"" C C-' M, F' T., 1'"..! I T .~T A T iii"' D A T E -'.".~.. 9 ' ,.* ':;~, - 1 c;,, ,..,.c:~ 4 T CDC;'[ S'T'ATL.iS DATfE i i':'.:-. 10 .... 1986 CASE S't'A'i"LiS 8,.']:, L...E:'.AE;E ........ : .......... ,, ¢'**'f ~]'~"f"\! '"~ ......... * '"' '* ~ .... A C R E S 4 8 0 'T' tS)]"A L... r.::' I I_ E L... A S i F::' s" ':::, ,':~ I"'/' c.. ........... ',.',, ~, ~:.':, r.:' q, ~..4 I ................ 4.=, E T"/F:' F'. 5 / 1 .~., t.... W,'I ........ T '~'=~;u~;' ?'.~.':'~/.J" ~: "~ .,.'~ A' ~ w"'*" ', E:..'. "'"~ ,~'%~., ~ ''~ ~' :' ,~''' '~ "i"~.. '"~:¢"'?.,- '' .1.": ,::, ''''~ '?~.'~'°", ,. "~:,4. .... ': '"": ......... :~: '"' ~ '?" ?'"' ~."r'/%.T~ c:. 'r'.,A"r,:' C',,". .... :':.""::" .... .!c,',c;,¢.': CASE:' c,"r',","r' 'c, /~.:' ::,, ~.-.~, U,.::, .,.t.,J C L C) S E; D ....,~ t i'"t/ ~.,.~..~ /...-' '1 i i.~ .. ,.,,~ i.- ,~ .~ ,~ ~ *~ C A S Ii!!; c: I * B"t' Y P E ,",,",,"- "r, ~,,' 'rcl r- / /,.¢,.::.. ,.~ .......... L. AND USE A C: R E S C, ""1 U ~''' T, ,...,_,', ~ % ':.'& * ":'4' * '!:':.:'-~* '!~' %, ~.'." '~.~' * '.::'.:!. % *K- .~. % ¢'.'.'. * .':.~' '~ * * * % MLJ hi I C I PA! .... P I::'- .I. · .... I"'I liE: L...I:::' P F 8 / c. ':'~ 0.., .... t:::' F;.: IE V Pt E N U 4 B ~ a Bt LJ M NL.M::iiiO6OF:' DiEF:'AF:-','T'HEI',i"i" C]F I'.4A'T'Ut::-".:Ai .... F';::ESOUF;'.CES ,.';:::5 / 08 / :L 995 ;J. 4: E: I: :L 4 L. AND F:' ! L...E ABSTF;:.AC:;T PAGE: c:,0(;.:,5 NEXT: N M: S "i" ',', 0 t 8 N i::..:: 00 :B W S: :i. 6 A C;' l:,:.iii[ S:64 C:,. ;.. 000 CASE 'f'YF::E: OF:;; CATEGORY: NAME/ADDF;,'ESS (Y/hi): hi · :.--¢.-. 4::..:.$ .;-,:. ;v.. .:,.:. ..:, .:v.. ,,;., .K.. % % .!~..!:.':..~F * * .iR...~? '~-'.!. * * .iR- ~"';;: """ ':' F'" ;[. I::~','5 t * * * * % .*.¢..X- ..:'4. * -:-"- .:¢.. .ir.~-.,. ¢:..,...:'4..~:. -:-s -"':. % .:'*- .?'*- -:":..:~:. -" '" -~ '"~ '"~ .'" · "" :~ .'" l'i&,,,~J'"l ,J. ,,,,r s = ~,., - .... '"' ...... "": ' ": :: ": '' F ][ J....E A~)L.. ~'.'i~C)O,.z.;.:*6Li· (.".:A~E ]"YPE 6C.'.' .i. ?JUN i C~ I PAL.. ENT I TLEI'IENT "'.,". c..:' i i 5 (7.) .... ..~ ,_, t:.. S'T' A T ,.., S A C 'F ]: V E ..,/, cz... :: ........ ~,: b ¢~'; :::.~ L. Er. A S E .F': Fi N F::' .... ...;...., L. T Y P ES '784 -""; ! ~ ....... . ....... C A'"'.2!;E S T A T lJ S 8 2 C L..F] S E D-' N O B ! D RE!i: C';D C 00 K :[ N L.. E"F F' F' i E: / E'. 4 ...... R E T LJ R N NL.H:F.:",OaOF:' DEPARTt"iEN"I' OF NA'!'URAL RESOLJRCES 05/08/.I. 995 1,g- 2.t.: 30 '" L.. A N D F I L.. E A B ~-J" R A C T ~ F:' A G E: 0 C:: O,:is M: S i-: 018N R: 003W S: 16 ACRES: 64,},-0C, 0 CASE TYPE: OR CATEGORY: NAME/ADDRESS ~+ .~ ~'~* ~ .~ .~ ~..~-.'~:' .~ ~.~ ~ .~ ~-.~** ~- .~ -~ .~ .~ SUB-SURFACE-ACT ! V I TY ~- .~ '-~.:~ .~.~ '.'~ ~ .~ .~. ~ :~ ~ ~-.~.~ ~ ~- .~. ~-~-.'~. ~ ~-~ ..~- ~-.~ iNiTiATE DATE STATUS DATE 03-~5-1993 CASE STATUS R1 p~TI., SALE AREA CI COOK INLET ACRES 640 TOTAL ,:~'~-'!~."~"~'-."~' END OF LAND ABS]"RACT F~EPOF:?.T ~.~*~.'~-~- ,P I='..I. - I'-f E=_ L P ,~::','r:' ~..,'"::' ," F.~ C.'. - I:::" R E V M E}: .... N I J :,'.'+ B · a NUM P F' .!. ;.'E'. / f.-? q. ..... R E 't" LJ 1::,.' N ,540.0 ('.~ 0 .,. ~= IS T ~' T,... ~::. A C QU i T I ON .. I", .L.., t'% IT... -~ ~ u TYPE: ;t""~:t::"'~GDF.'.Y: NR AREA CM SCDO MAT-SU AREA ECORDING DIST. R31i PAL. MER ~ENATE D!ST. ~_84 DiSTRiCT N It3USE DIST. ~R8 DISTRICT ~8 :EGIONAL CQRF', 94 COOl-.':] INLET REGI ON ~TATE INFO DIST, .0~3 MATSU P, ORO :'LO NONE :ICHE DATA NONE I L E" --~¢::' ._.,c' 2 iNITIATE DATE 06-18-1959 STA'TLJS DATE 18-E~8 t99E'~ ACRES 160 PAT-L. AND/MI NERAL. t L.E L. SH ;:.'.!9 ]'. hi ! T i ATE DATE 09- ;i. ? .... ! 96 ;I. STATUS DATE 09 ..... :t'7 ..... :1.96.1. ,:}5/08/1995 PAGE: C-'O0 .'-'..lC' vT: N NAME/ADDRESS <Y/N): N CASE TYPE: i C.'! GE:.'NE::RAL GRANT' CASE S'T'ATUS' 50 ACTIVE :!. 60 T [] T Al .... ('" ^ ~"i'" .., ~-.~ .::-.. ,::: TYF'E .1. 15 t_ i M!'T'ED STATE HOi....D i NG r- A S E S'T' A T U S ~ 5 U N V E F,.'. I F 'r ~:n .~B m a F'F8/~O .... F ~.E.V MENU N U M ] ~ (::,~ /" '-' .'.", ':7 (:"' . ' ~1 .......T: 0:1. 8 N R ." 00::9 W S :." .I. '7 ,~t., t,.1:.....) ,, 6 ~+ o. 000 C A c::. ':':' . ........ .... t.:. 'T' t; F:'E: 0 R [."; AT E::' Giq RY: :1: ]: :;FLE ,, A Ct.;.)U ]: S,i T A C F,: Iii!:,..,"::: ¢:,.. -r, 0 T. A L.. ~::' ~' ~ ::::' ; c:'~...~ :~5 t .~, t,...i .... f.,..,....~i i ....... ]: N ]: T ]: A'T'E DA'Tiiii: 0 .I. '"-'30 .... i o,. ,.6;F-' ...... E'~'T' A"[' !...j S D A T E 0 .I. '"" 3 ('~::-'; % 9 6 ~ A C i:;.: i::.: S ,..,'"" T 0 T A i .... F i i.... E M E 3 ]: '"'!. ..... ""'" ''~ ........... .~ ' ...... , ,, t .~. r.-~, i::. 1) A. T lie -':..'.-"d. ..... i 8 .... '; V e, 3 S T~.-~"': '""~ .u,': c:~ ?' D A T E: ,..,'"" ..... ''':~ - :i. E.-' .... :i. 96 ;:iii ........ ,'-,'"' ri 'r ~ r::.' (,. ~:~ ,'..*' ~ .......... 400 F' A T-.-.. Cl. 0 A I F: ! i...E 0 SI .... ]. 01 i N I T i A T E r) A T F q""::,' ........ ;' ~ '.I c,, ,~ · -, , , ...... , .L t- ,. ;~' ('.D ST'ATU.E; DATIE 05-08- :1. 9'79 A C R E S 0 T E)"i' A! .... F i L E 0 S! .... :I. =' 't ]: N T T T A TiiE: D A Tiii!: .:;-:, .i .... ,::.,,(', .... ~ c:, .,,...:::, -~- -~ ., .~, ~. ..... ; .~. ,,' ~,.$ i .... CASE; T 'f ~:' E:, .. I :I.. =5,.. L. i M T,. 'T'E:D S'T'ATE t.. "F" 't ',. . L.'~J'- .... .1: N G r'. s.. ~ ...... S "' ..... · . ,:,1:.:. STA]"U :I. 5 LiNVEF;.: .i. F i EiD CASE: STATUS 50 ACTIVE: 4 0,:) ]" 0 T A L ~"' '": '"" i:"' ,. ' ....... ""' "~ ...... i A I',.1 ¥'~ · '-.... ~...~ c::, ,:' '!"Y P E: 'J. '~ 4 o"r' H E R b i ~..~, ~: ............... F'F:i - H E L.. P F'F'!.:.'il ,/E" 0 ..... P R E V ME N L] '4 B · a N U Pi ' ~ ':-' ...... ::' L.' E:. r i..:t r~ M r_::' ~d"r -' , ....... NATURAl._ F,,l::' c.*. ,'"¢.........,.._.,_.,,~r..~,r' ~:' c:.. ,..., ,... ,., r,,:::: / () 8 /;.., ,._, .~ ...... :i. ,g-: £':'Y,5: 49 LAND F i i....E ABS"FRAC'F i::'AGE:'. i" iI:::' v "I" ..... ..-, ," N M ,", .!i.:; "r:0 :i. "'"" '--.'.".:: 03 ' /,,,'.., ::, c..,-., or, i R i,, W :ii..:; ',' :i.'7 ,. ..... i ..... :..:::,: 640,00(':., ,.r;/... r-- '- i f .r- r.::. ~ L.J i'~: ::'"'/''' T r': ~.'....-.;. ~.;:,-,,.- "' ~'~ "::" ['::' '"" '" ' ""' ~"' ' ...... ~" '" ' ~:- ~-:~ '"' "'. ~: ~"~ ,4 ;-.., ' ,.::.'"' ~"' ~"' ,,' A .... i.) D R ..... =' E;,.,'.::' ",. '¥'/' N' ) ~ N * .?,+ * .x-..........~.-.'. s~ ~,.: ....x- ,,..... "i" i "r'i ..... ,~::' .... ,..~,'"-- ....,,'"' ::,:,"'.' i...,~ "i E; i ..... i i ';.] N ...,..............!+.........!,..~..... .,,"..ii; "i" A"I" L.i S D A T E (", 5-... r. o .I.c.-...--., ,:::, ............... - C A E; E ~: -r .,"-....?i ~ '" ' ' ,' ...... ..,; ...,.'.::, 4 .i. C L. 0 S. E D ;?.;: C H A hi G r..ii: D- A C R E S .':.'.:, T 0 T A I .... -':.":' * * .':.+ * * * * * -~.+ * * * * -:,-.:-...~:+ ~:. ~.s..... C L. A S S i F:' ]'. C A T I 0 N ......~...-.......!+....~. ,.:...:.............. .... , .. · .. "m'""~'¢',',:~-~',:.r-..,,,-.-,~*--.,..,~-,~t.~,.. ,,-,.~t,,.,,-.".m,-~. --.-¢, ...................... .................................. . .............. ..:~,,.,:..: ;:...,::,~.-% ? .... ,, ....... %: ......... ~,.¥?.....-..:.~!b::..,:,::i..:..~:~.:~.~;~::..¢.,~.:~::~:4 ..................................................... ............... i N !'!" !l ATE T.)ATE 10.--06-. :L 96-:'+ s'r'A T US ":",ATE,_, .,.~ E:,-06-~. cT.,,. AF':F;:E F',: 80 ~ i"r' ~', i T Y ! p' i'-,~ I NTT' !e;-F-~- ,~.'AT E r:'m- .I ..: ;4 ~ Jo.,. DATE 08- :L .z._ I q,"71 ACRES 80 i. iTiLiTY · :::) ,_, ~ ~..~ ~",J ,.: L, ,.-, ('-.] .. 'T,, q L.E MR ,-'-e,. -~ o.. ,'- .-,-=. ~. N £ T I ATE~. ~-.~'f] "' T~', ,-- 06--~0--. _ 1989 STFqTUS [)ATE 04-06-!989 80 'FO-i"AL F-'AS~': 'I-YF'E 20,'~ SLJRi::ACE r"i ac:c:: T ~:- i ;-','--'"T i ~.,;'~'~,, CASE STATUS 5."~ AF'PROVED 80 TOTAL_ SL!RVEY-MAF'-F'LAT-D I AG -~*~.~ .* .~'~ .~ -~ .~ -~ ~'~-~ ~-~: -~ ~*: ~-~ CASE TYF'E 317 ,tw,~,,I~ ............... CASE STATUS 5,:) AC'FiVE F'F.i. .- HEI....F' PFS/k~C, - PREV MENU 4B · a NUM F'FIF-"/B4 - RETURN I"4 L M :3060 F:' 05 / 0 ~!.-"] / :[ 995 ]. '"J- = 26: -":7.:, 6 F' A G E: ';'.',0 (].', q. N Ii.-': X 'F: !"..t j-.q: c~ "i- = -t:) '~ ~JN F..'. ,,."-..,"-- ...... : C:'.O3W S: 1 '7 ..-., ......... : ~":+':':' OC:O CASL< 'FvPE: OR r- ,..'.,~ ~- -,;- :~. ~--~ -:~ -.'4- ~ .:~.-~. ~.- ¢~- -~..4s ~. ~,~..x- ..~..~ ~. ¢.- ..~..~ S L.! A C R [:i!: S C, TOT A i .... ~.'~..K-. % .4.,:. % ~. % ':;4...% % :¥ % % .~. ~..~..~-.~. % % ~..~..~..~. F I L. E: A Df .... :i. ""? '"",: o, ...,': I N .... T "i" ]: A 'r' ,..r.:' D A T E-'.; I ,':::' .... - :L ~::.', ..... 't,. :-;..' 6 ....,q TA T LJ S r,:.: ,-.,."'~ T, i:.::', .... ,...,'~. E:~ ...... '"' ;i:~ "':', .... 19 '? 4 ,...,"" f:"~" .'.::~"'"' ~:::'-- S "l" A "I' U .'.'!'."; 91 'T', ,'-.'"'.,.. ~.~,/' t',, ,,; -'::::'....,,r-: ,....c' ,~::'".. ,t::', ,....t::: ;'",,.~. r"., ~ ","" CASE c, uB t YF'E B,:)0.1 ,'..,L,,.., ~ .,. t..,,.J x'..r~ ................... A C R E: S 8' 0 T 0 T Al .... F' ! L.E AE:,t .... ~..-.: I a,;::~:~ I CASE : t F' I::. D~.:-' i T It I ........ r,.. ~5,'..:~L..k. iNITTATE '""* .... ~:" ...... ),.at,.:. 08 .... i 9 .... 1983 m~,~m~: .?,,,'.~,',,x,,.,',.~:x;w:~ f'TN'! ! 't~2, ....... ,~;,_~,.f~", %',%;:.";'~. ';x,' ,, m~' 4 ~"", -t .."' '1 ,'..":.) ~.":., q:) ,'"" .":-'"'?"' -"""~'/". "~"; I'---' ?,", c-. c'] ?..i"'.,-~, ,"-. F".-F 1' CDC:'! !~:::' '.t-'-, ,,...~ t r'-i i ,,..., ,,..., ,~,,.' ,-i ~ ~ ..... L f:::. ..... .i. C::, ..... ..'. ,' ;....-' ......' ."..... i'.ff .',::) D:. C::.' ; ,..q : -"...; -::7., ;% "...." '-..., ',...: i ,i , : , :'"i .'..., i .i.....,, ....,, ............ 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R311 PALMER SENATE DIST. 884 DISTRICT N HOUSE D!ST. 888 DISTRICT ~8 REG'rp~''''~...~,.~_ CORP. 94 COOK INLET REGION, STATE t,,~n DIST r~R:~ MATSU BOR.~ "PLO NONE 'FICHE DATA NONE THESE LANDS ARE AFFECTED BY A TEMPORARY CLOSURE TO MINERAL L. OCATION['Y::, THE ALASKA SUF'ERIOR'.. COURT EFFECTIVE JUNE 23. 1994. I::'ARCEL iDEN]'IFIER .......................... LAND TYF'E ............................... F i LE GS 2 T I T' L ti'.-'. A ,'.':.i Q U I S I T I .ri N , ~ ,. ,,....,, ,, ..',,4- ,., ,..,....~:i.-:,4. [:;AS[.'.-; TYF'E 10 :L GENEF,:AL GRANT P F:' ~ .... i'~i lie 1.... I::' P I:: 8 /2 0 - P R iEV i'!I:: ~. ,, l.j ...... 4 :E: ~, a l'..l U I'.i F' F= :L F_' / ;i:ii: 4 .... R E 'T' U F...: !',i . NL.M:.:.iiO6.'.":,F:' ,,,I....F ¢.1., FI'I[.:,41 ...CF i",IA'I"ijF:;,'At r,J:.:::~.]L~F.:L,i::..:= ".")5/ ...... J. -,-.',' ,..¢ :i. 4: i.::"..8: L. AND F'..LT' .... [:' ABS'T'!::;,'AC'T' PAGE-::: 0¢..'.)02 c., F'. ¢.}¢.'):E:tW S: ;:...'~¢."~ 640,,.000 s T., ..,. nCR. ES: ....... 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V M E i'4 LJ ,:+ B · a N U M F:' F ! 2 / 8 4 ..... F,.'. E T U R Ix! hl L... I'"'[ :B C) 6 (':: P ¢.Jt:.P i-f!'".. ~ I,:!'~ OF NA'r'UF;..'Ai .... RESOL!F:?.CES t... A N D F i L E A B S T F'?. A C"[' ¢.}. 5 / 08 / i 995 :L 4.: ;::'~': 8: ! PAGE{: ............. hiE: X T = N ¢ C;~SE STA'Fi}S 5q- AF'F:F.'.E P"' "'" TOTAL_ C-,',c"- -'--'-,'F,C: ~.~'~I c~!!R~:'Ar'F..' CL.ASSZ~:'TfZ:AT]'r]~.~ CASE STATUS 54 '":?'"'"TOTAL .-~ %.., CASE f Yr-'E 21,:'_:'. i ...... F ................. i F i L.;.F~ i i UN PFI -- HELP · "~- B ,,,a PFS/20 -- PREV MENU NUM PF1~/24--RETURN N i.._ H 3 o 6 0 P DEPARTMENT OF NATURAL RESOURCES L_AND FILE ABSTRACT A C i:-,: E S: 640.0 C: 0 Ct....A S S I F I (]At'.,.T r", ~u...,, .., M: S T: C:,!8N R: 003W S: 20 CASE TYF'E: OR CATEGORY: I N I T' I "'~ .... ~ ~" ............. ~.~, E L, ~.~ t E (_:, ~¢-- (3'7-' 1 9 8 3 S T A T U S D A 'I' E 03- ~,r,c,c~* 64¢) CL_ASSI FiED F:: I L. E M C 0 455 iNIT!ATE DATE 08-.07-1985 S T A T U S D A T E: 08..... 0 ? ..... i 985 (.r., :..:.q .............. · 4,..,~,.[ ...... 640 F I I_ E A D i ................... ~ .... iNITiATE DA]"E 01 .... :30-1980 0!5 / ()8 / t 9 9 5 i ¢:+: ..... ., ,".. _ PAG-E: 0004 N Ii:..: X T: , ,, .......... / ....... -' PF;.:EV ME NL.! 4. B m a lql. jl": A C F:;':. r.-'.': s = 6 4 0.0 0 0 M tj N I C: I P A I .... t"': A F:: [::' S"t' A TLt S ':'": '"' A C T i V !El C A S E T Y F::' E: ? ~::~,":.,. C] 'r i... ;% G A S ,....L,: ':"'/''':::., .... r.: C 0 M F:' ......... - ,' ,',..,.::. v M [iil hi U F':' F 1 ~ii!: / E:: ,q ...... .:.::;: lie T U R N L. AND FiL. E ABSTRACT SUB-SURFACE--ACT i V i TY ¢-' F",. ,';'"'~ b" t': t i r_- T M= S T: O.tShi R: OC, 3W S CASE TYF'E: OR CATEGORY SALE AREA '."C I ACRES F'iLE ADL P00547 iNiTiATE DATE C,?- ! 3-- 1981~. PAGE: ,'.}0C.~6 NE X ]" :. N WATER ****************************** CASE TYPE 80t WATER RIGHTS STATUS DATE 03-!3-199t CASE STATUS 44. CLOSED SOURCE CATEGORY SUB SUBSURFACE ACRES F' 'r ........ L.E L..AS i i. 97? CASE Tvr.::,C' 801 W~-~' '""~ ..... ,'-::.h: R ]: GHTS INiTiATE DATE 07-:14-!988 STATLIS DATE 07-14'" i 988 CASE STATUS ].0 AF'P ACCF'TD · '~,_~UI .... L.. CATEGORY F.b_._~ ~NS]"REAM R.E~:,E~ ¥~ ~ iON ACRES 0 TOTAL · ************************ M I SCEI_i_ANEOL~S *****************:x-********** FII_E LAS ! 5?36 CASE 'rYPE 95i OIL AND GAS WELl_ SiTE F'F']. - HELF' PF"'8/2('.~ .... F:'REV MENU 4 ti:.': ~ a i'"..i U 1"t F' F' 1 E: / ~: 4 .... Fi E 'l' i..i F,' N I' ................ ::, ... r" I} E F:' A F;.: T M E N "1' 0 F' N A'i" LI Fi A L.. F;,' E ": ..... I · ,::, L.,I .J r", ,..., E ,:::, "";~'::; / ""~:::~ / ]. 995 .i. A-: i'::': V: ....... L. A N D F' ! L. 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T,,-,":-i :':::' DA T'E ,: ,' ..... , ....... ~ ..... ,"',- ,'"'",",', -r, ,,"', .: ,-'-" , ,.,, ,' ..... , .... .u .,-'"'" ~. :::"':' 19"/,'3 :... :,,t.~ :::; c~.:. :-:, :..~: .~ ,J ul',v EK I F I.,::;r'":'":.; "'"' '""" ........ . ....... L, ~-..t .::."., i":. SI 19"t' YPF' 95 ! 4- ,.... , ,i ._, ri O l: ~. ..... i,...i",IF ,',,I. BLL¢~..,I::.r,, , ~., A C F:;.: iii[ S I T O'T' A L. FiL..E L..AS 16:f46 CASE: 'T'YF'Ei[ 951 OIL. AND tSAS WEL. L SiTE , I N.;i; 'Ti ATE. DA"r:.EF . :f, 0-. :t. S ]" A T U S '.f.;) A ]" Iii..'. i () .... I ~!:..'( .... i 99 3 C A iii:; E E; T A"I" U S 15 U N V E 1::;.: I F I iii[ D CASE; ,:::" ~ :::'T'".: ::'- '::;"=:~ 14 t']t"..JSHC]F:.::.fE l.,t,Jl,~l I ..... t ..... ., ...... :::.I. · ...~,..., L, . f I I::: ..... ' ''''~ * ~ ::"' ::' "'"' ''''~ t ~;"' r'" ::i' .................. '.. "',-r' ," 1 4 L; h". E.'::::; ., 1 [..¢, i..."f ri ..... c. :LAS l??Si :[ N i T I ATE: [)ATE :i. O- .1. i!'~ ..... .1. 99:B S T A T tJ S D A T' E '~ C-' .... .i E: .... i. 9"":"'":' """ '"" .................. . .......... ........ C A S E S L.t B T Y P E'] q:' F':~ :t. 4 C! N S I.--t r..'] R E; N i;"i N P F;:. 0 D U C E F:i'. · "~. t'", t'"~ r-' t": ~-~ ~..,r':. c:..::~ .I. "1" 0 T A.I .... F T L. E:' I. A S ! 8 .1. 8 ......... ,...l I L A N D G A S W E L. I .... .'.".ii; ! T !E l::' r.:' .1. E: / E'. ii ..... t::;.: !ii'.'. 'i" U F.'. hl N L. I't 3060 F::' L A N D F' 1: L. E A B S'T'I:;,'A C'T' ~-~-~--~--~- EE~4,..~ n~.-':LAND ABSTRACT :..'4'.EF'ORT ~-.~-.~-~-.~- ~'r-:--L - H~'i P F'F8/8,:::, - F-,r4,~",..,, h.-~.rut~ 4B~ a NUM DEr-'AE'T''4p'i'-~T .,"]P- NATURAL ~;,-qn~ %--._.-:.-_- ................ b_._ .,_~..j r-~ u F .-.. LAND FTLE ABSTRACT 'FITL..E ACQUISiTiON M: ~ T: O18N R:. O03W S: .'e~ " CASE T't. E: OR CATEGORY: DNR ~.'::--A CM SCDO M ...... u AREA F.'.:EC.'.ORDING DIST, R311 PALMER SENATE DIST. P_84 DISTRICT N HOUc'.~ D i ST ':'"~ ........ REG i ONAL_ , . CORP . o-4.,. ,~"~nP~-'",.~.~,., t NLET RFG .i ON ~:]~-,:E INFO DiST Pt..O NONE F I C Fi E '") ""~'" ~-. ~ ~w NONE ~:: T, ~:' ~": c- ~ ~264. I hl i ]" .~. ,...t ~ ~::. DATE C',?-2-C:, :i. - .1. 963 S T A T U S D A T E 01 - C:, i - 19 C.) 0 ACRES 5 " ........' ......... R E J t::.,.., ~ [:. ~:, ............ R E L I N Q U I S H E D F' ]:~ *:::' F'r' .1. 5"" ~''' ......... 2,] ~:::,' .., / "? I N I ] ..... l ~..,;' TM* ..... ~::. D A ]"E,.; .... ,::.);'* ...... i ""'., '"- .,.'~ ""-,, ¢.-., .... ,." CASTE TYPE :[0i GENERAL. GRANT CASE STA'I-US 50 ACTIVE 80 F' A T-'-' L. A N D / Pt t N E R A !._ E:,', 0TOTAL CASE '"'"'"'~"' I ,".'.'ir-:'?,L=~;,~::...~ · . ! '~ .~'- ,_'::. 0 ] ........................ G F;.'.A N T 'PF'I -HE;L.F' F'FS/EZC, ..... PREV MENU' 4 B ¢ a N U M F:'F' I ~:'.':'./E?. ,':.i .... RETURN iq L.. M :B C:, 6 C, F:' DEi:F'AF,:TM[EN'T' OF NA'T'LJFb:~t .... RESC)URCE;S 05/'08/1. 995 l,'q- = :B:I. = 3'/ LAND F:I.LE: ABS]::RAC']" PAGE: 000E-t NEXT.". ht .... M: S 'T': 0:1.8N R: C.'03W S: ;'.:~? ACRES: 6q:O..C'.OC, CASEi: 'f'YF:'E: C)R CATEGOF;.'.Y: NAME/ADDi:'?iF:SS (Y/N) = hl S"f' A ]" U S D A ]" E C) 8 ..... .1. ? ..... 196 ? C A S E E:;-"[' A T U S 50 A C T I V E A C R E S 5 S fi; I .... ....:,.,'"' ........ ,'"l i-.,,, '"': ......... n 'r,. ,: .... S. U' ....... A :::?, :i. 5.'.':5 S E L "'" L A N D / M i *' iF' ~::' ~, t C A S [.!!: T Y F: E:: ! 06 M E N'f' A L H E A L. T F! C A S E :::]"f' A"[' U S '::,', -..,-/: C C)M F: L. E -f' E PF: .i. - t-iEL. F' !::::i::8/2C.~ .... F'f::,'.EV MiENU Z.t. B m ~.-'~. ...... 05 / 08 / .I. 995 14 = 3 :i. ,".. 54. PAG[ii:-- 000:B NEXT.. i',,i A C R E S. C:: T G' T A L , ¢$ .~.. ~!..!~....!~ ~ .~ x. ~.~..~ :.~..~., ~:..~...~. ~...~. ~ .!~..:~.. ,~ ~._.r"~_ ~.,;'., ~ c::...., ,~ I F I u, ~''' ~-~'" 'r', i ON .:.~-: ..... .... !~- -~ -!~!. * ~- .!~- * -!~. ¢(- .!~ ~ .~ -::~- * :.~.. * ~--~. ~:- * ~- ~. ;.~- s-':. i N ! T i ATE DATL:: o6-09- :i. 98;.-.3 '='"~'"'""*-'US....-: ,.~, DATE ,:'; /-. - C:, 9_. ._. _ .... i°c'°, ,..,,_, CASE STATU'::'..., PT-":;,_..., Ei-':c:r--c'r '" VE_ ~ _.. ~ .~. CASE .C:UBTYF'E ........ ;=' 8 (' :, -~: RECREAT '~' ON f-;.~. T t,...,~-,'-~.,._,. ~ CF,.:ES 5 TOTAL F i -* ~ "-"~ ~,:].,2 CASE TYPE R,.'::,'t SURFACE C' "" ~'-' ~. CAT '" ON INITIATE DATE 08-!9-!966 o-f'A"r'~ i~: DATE C)R-'~ '9-:L 966 CASE STATUS ..... . ,--: .: ......... 5-i F" r' r"., *.~.- ,/~ ACF.:rEs 8C:, RESERVED USE 80 "'"'-'""", _~ ,, ,~L_ PF1 - HELP PFS/F.:y.') - F'REV MENU 4B' ~ a NUM .N}, ..... MRC.'.AC:,F',., .... , .. DEF'AF?TMENT OF' NATURAl,_. F;.:E:SO LJF;..'CES ,....-"'.,,::.;,., ,,' r',r:::~/... ,.., 19q"5, ,_ ]. 4: 3E:: ...'i r:,... LAND F i L.E ABSTF..'.ACT F'AGE: ,:".',O0/-~- NEXT: N M: S ..... T: r, .1. 8 N R: 00:3 W ~:-' : ¢:_2':': AE RES: b 40 ,, C.:,O,:::, C ,-,,. l-.; ,- ¢.4 ,::-, E T Y F' E: 0 R C A T E: G 0 t:.:.'. Y: N A i"iE /_¢::,, 'i)....,',,", ..... [.:;., i::' .~.,'::::' !::::.., ( Y / N ): N F' i L E: L.. L. C) 5 l N i T I ATE [)ATE.--.. 04-05 .... 1989 STA]"US DATE 04-::}5-- I. ,789 ACtRIES i 0 F,;ESTFR I CTED F'IL.E MCI] 605 Ihl I T I A]"E DATE C..~6-~i~8 ..... ! '::?cF' :!. S"!" A T U S D A T E 06'".. 28- .I. 99 ! AC;RES 3 CL. OSED []' L.. A SS ! F ! [:'.;' A T ); ON ******..*-. **-.,4.: ***. ,. ***..*. ****..,4-., ..,...!.,..'-,-.,..- CASE TYPE E::03 LEASEHC) L.D L. OCATiON ORDER ,::.'r,".'," ,.:': 54 C A S E: ..... ~.'~ ~ U,.:, A P F' R 0 V E D i 0 "i"0 T AL_ C A S E T YF::' E E~ 04 M i r',tE F,:A L.. C L.O S ! N G 0 F:;.:D E F;.: C A S E S"!" A'T' L! S 5 4 A F::' F:' R 0 V E D 3 TOTAL F:: ! L E i''!R .:::~ .,..L .-.::, N,..) ~.....:., W .I. :31 .... C A S E T Y P E :3 :L '7 M 0 N U M E N T R E"' []: 0 R D e,,¥,~.. I ht IT I AT'[::': DATE .... 06"'",3fY'". 1.987 ST'A'T'US' DATE 04-..~.:~7'- 1989 A C F::,.'. E {-.'ii; () 'r' c) T A I .... .......... · c:~ t'., I f"'~ r'.~,:.:, h.! '1 ~::; F I i i:::' M R S 0 .i ................................ 'r ,~ '~' .... ,','.~"r "" . ......... .,. N .,. I .[ ,..... E D A T E ('~ 6- 30.x ]: 989 .... ;..:t...:, E ......... A I U ..........A F' T T C A S E T Y F' E" 31 ? M 0 N U M E N"I" F:;.' F::' r' C) R D ./.+ B :, a i",I U M NLP!3060F' DEF'ARTMENT OF NATLJRAL. RESOL!Fi'.C;:ES 05108/! 995 :L 4: :.'.:.!~:,",. 26 LA 1''..! D F: ! L.EA BS T R A C'T' P A G E: 0,.':) C:5 NE X T ~. h.i ':::'"" A C F:;.: E S" 64 ~.:::: c:,,."~,"; M: S T: ,'"', .I 8N F:,': "'"'~':' ~'~ S: ..... c. E: A S E T Y !:::' E:: 0 R C A T [.'ii: G 0 F:;.: Y: N A M E / A D D F:;.: E S S ( Y / N ) :: N · ::, ~ ,-..~, ,....'..::::, D A 7' E ..... ~ ...... c. / .... 198'9 A C R E S 0. T 0 TA L F::' i L. E M F:,: ...-.:,,,., .i. ;::¢ N ,:..:~ 0 :.'::~ M i 51 .... iNiT'r" .....,- . ............. · .......... ,_ ,-..~. I c. DATE ."",A-'::x":,- .I. "¢U'/ S ]" A T LJ S D A"}" E 0 ,q ..... E:: 7 ..... !. 9 :.-'..'.', 9 ACRES C, TOTAL. F' i ~ i::.' r.::,,'.::. .,;..~ · --,,- .,~ =:' r..' .,, 11'.4 ~:) ""' "...: -',..) "-r -....~ -" .:"' h4 T ~"- ~ '[ T i "'" T I::' T".: A "r ~.':.: r'., %-. ,":,. ..... 'i 986 ,,.~ ,. , ?'°t t .:.. .--.. , , ,.-...-.-- -. ,L ,:.::.--r ,",-r'i ~,: ::. D A"i" E: C:, ;::' .... i r',. -. ~ ? E3 7 A C F::.: E: S ,"... "...'" ,'"', "r ,", ' %/ ; ~..,; t i-iL. F' ! L. E F::-.: S E') 6- ':":: 05 E:.-'"-F'A L.. i'i I i"-,i i T I A T E D A T E 0 D'"'-B ?- 1986 S T AT U S [) A T E () 2 ..... ]. 0 .... i. 9 E:..' ? A C F:;.'.E S r,. T ;q T ""' F' !'~.... ~:::.""' F:'::'. :!S :!ii) 6 - C: 06 '-::::, "'- F::' A L M :-".".:; A S t!:.'E'. "r'.: v, ":::', "::'*... 313 R E: C 0 R D ri,.. F S U R V E Y MENU~' ' ': F:'F::' :i. ;:!!::. / -::'fii:,q ...... RE'T'LiF:..:N NUM ..._, :....'...~ .-' ~ f--., j:L. .h',j /"' ' ' ~ ' p /\' '::' ."." C:;' FI ~ ~ ' .''; C:.' / ..'",. ,::::, ~' 0 C': ~ Z.F :'", '~' ~.." 'J ." '.." "...." : :' '.J ~ ',:] ~.7] ~ t'" I Lc. ¢4~':,.-_'~ i r'u.4L, ~ ,. PAGE ~ 0006 L. AhlD r.- ~- ,- -r,c'.-:-:-, ,- ,---,' NE v T ., .... ~ S T: ,:-:,i~N R: C, 03W S: ~;-2 ACRES: 6 40.0C-:C-: CASE TYPE: OR rv'"'r=Rq~"v t,~/',M~.: ,',',r',nc,=,::'c.' "/N ): N ****. ********************* I N i T i ATE DATE 05--~9- ! 988 qT~i-n ~ DATE O~- ACRES 0 TOTAL FILE ADL 5~374--A iNiTiATE DATE 08-3i-i970 STATUS DATE SURVEY-FIAF'-PLAT-D I AG *******,**************%****** CASE STATUS 50 ACT:[VE CASE TYPE 58.i. F,..JB .... C EA,oEME,qT CASE STATUS ~0 EEASEMENT CREATED CASE'] Cl ." vF..- ,:,UB r,, E AC;RES 0 TOTAL F ! L. E A D ~ .... '3/~ n=8~ .... I N I T I ATE: DATE: 1 t-, i 0-1966 STA'I'US DATE 03-....E'3--i97:3 '". F' c,::' o ('.~ 'i' 0 TA L 8~"(]={ R'rf'-'LJT OF WAY MUN i [31 PAL. **************************** CASE TYPE] 601,~'.'~,,_,,,, z,.., ~'~ "' ""' :[ PAL. ~:~,n-,_,,,, I ]'L...~::~'~r-:'~'~'r...., ,,_,,, , c--, "I c, 90 CASE o FA I _J:_'., _ CONVEYED P F .1. - 1.4.c'~ p 1:::' F 8 / ':: '~ ......... ,::.{.., --- F'REV MENU ~,- .~ ,.+B ~ a NUN NLM3060P DEF:'AR'T'HE. NT OF' NA'I'UF?AL. I":,'ESOL!F;'.CEES 05/08/!995 14: .3E': 5'7 LAND F'IL.E': ABSTRACT PAGE:: 000'7 N E X "!': N r.:'.', A S E: T Y P E ,- C) R [] A T E G 0 F,: Y., N A t',tE / A D D R E S S ( Y / N ): N ., .....~...,x-....,..?............. ~ .:..4- S U B- S t.J F..' F'A C E:-- {",, C "i" I '--...; .~. 'T'Y * *** *:*' .*.:~ * ** * ~* ** *:'.~ * ~ ¢.- ~ ~ * ~ * * L... F'iL.E: ADL.. : 3.5'4:1.36 PAc?'- TYF:'E'. ?84 OIL. ,.s: [:]AS LE:Ac'~r':: r"n~.~r.::, I N I T ! A T liE: D AT E:". 09' .I. ? E!; T A 'T: U S D A T E () 3- E?. '7 ..... 1991 C A S E S 'T' A"I" U :Ei:; E: ! A C T i V E'.'.': C i L,L)OK. .INLET' ~::~..~ ...... :::. (..~i"k["_' A C R Ei: S 4 Ei: 0 "~," 0 ~i" A ~ .... ..".. "" ~"" F I L E A D i .... E_' (} (} 5/.+ :7 C A S E 'T' Y P E. 80 .I. l/~ A T E R R I G H T S i N I T ! A T E: D A T Iii!: C.:,'7 - ~ 3 - 198 S T A T U S D A, T E ,:') :q- ! 3 - . ............... :, ~ ~-~,.,.'_'.~ 44 (:]L_OSED S ii:) U R C E: C:: AT E G 0 RY S U B ' S U B S L) R F A C E .¢-_..: r-. J::, r::,:::. .r) T ri T,5 ! F t L E: L...AE: ! 09 E: E') C A S E T Y F:'E: 80 ! W A T EiR R I G H T S :[ N :[ T i A T E ):.i:: A T ii.:.' :L E:' :3 :L ' :i 985 c ..... '" 'r'~ i'"' D A. T ~:::' C~:3- ~.") :! .... .:: 1~..~ ..... ..o ............. '- ( ....... .-r SSD S 0 LJ R C E: C A T E. G 0 F'",' Y S LJ B S U E: S U F.: F A C fi". P F' ! - H EE:' L.. P P F' 8 / E!::':") - F' R E: V M E:N U 4 B · a N U M F:' F ! E' / ~:'. ,q ..... F.: !iii: T U R N N L.. M 30 60 F' DE:]::'AF;'.'FME:t',i',r OF:' NA'T',LJF;,'AL_ RESC]LIF;.:CES LAND,c"rl.,. _;.._r: ABSTRACT 0 5 / C',8 / ! 995 ! 4: 33 :.I 4 PA G lie - (':, C:-'.".', 8 NEiXT: iq N I "1' ! A T Ii!".' D A T E! S'I-ATUB DATE :[ ..?.-'_' ..... SOURC;'E CA"rECgORY ~('¢ SUBSUF.'.FAC'E: ACRES 0 TO"f'A! .... FIL. E L. AS !!97'7 CASE TYPE 8C,! WATER RIGHTS N i T i ATE DATE 0'7- .i. ,~+- .t 988 STATLiS DATE 07- !'4- 19S8 CASE S-A'JTM i¢..:: -i, r'~ AF'P ACCPT;:) F:""'~ -' HELP P'~'c~iRO F:REV MENU ~-B~ a NUM PF:t.E:/-~q- - RETURN N L M 3 ('.~ 6 () F' DEPARTMENT OF NATURAL RESOURCES LAND FILE ABSTRACT 640.000 M: S T: O!SN R: O03W S: ~.'.78 ACRES: · '-' .~, (.e~..,E TYF'E: OR CATEGORY: .**.~. ~....~ ~. %.~e.~:... ~ ~..~:- ~ .. ~. ~.. ~...~..-.'~. WATER ACRES 0 T 05/08/!995 !q-: 33: 33 PAGE- 0()09 NE:X-[: ]. ':~i,~..~.~,.i-,.?..~:: END OF' LAN!') ABSTRACT RE]F'OF:;.:i" .~.~.~.~..~s-:~. F:'F'! - i--iE:LP F-"F:'8/2;~O. ....F:REV Ml::.,qt..¢ PF~'c::t./F.F.:'-q ...... RE]"URN .;':. q r~ . ...... .,,k.~,: a "'" DEPARTMENT OF NAT~iRAi LAND FIL. E ABSTRACT 6,"~ 0.000 ]' ! TLE ACr':,!LJ t S I ]' I ON i~',fft:: ACRES: ¢: DNR AR~ZA '-'h'~ SCDO MAT-SLJ ,~-R RECORDING DIST. R3!I PALMER SENATE DIST. ~84 DiSTRiCT N HOUSE DIST. 888 DISTRICT F28 REGiON~:~L C(]RP, 94 COOK INLET REGION STATE !NFO DIST. 0~;~3 MATSU BORO F'L_O NONE FICHE DATA NONE F I LE GS INITiAl"E: DA]"E; 06 .... 18 .... 1959 S T A T U S D A T E 1 ~ - R 8 - :[ r,~vczo ,n ACRES 80 PAl' .... L..AND/MINERAL. F I L.E ME 3 i N I "f' I A T E D ATE 0 ~- 18 ....1963 S T A T U S D A T E 0 E~- 18-1963 05/(:).cZ,.'/i 995 14: 3~'+: 3;:3 PAGE = OOC-~i N = ..-', 'f': N CASE TYF:E .1. 0.1. LE.,qEt:'~:-,L GF,'.ANT F'F1 .'"h:::.L.F PF'8/E::O- PREV MENU 61' B · a ~ ,: :..a ~ ~ F' F:' 1 ',.:.'.]' / E:,':'4- - R E T U R N N L M 3 0 6 0 P I;) E: F: A R T M E N T 0 F' N A T LJ R A L.. R E S 0 U R C E S 0 5 / (') 8 / :t. 9 9 5 1. 4: 3 5 ,~ 15 , ~ "'~ ?' T t "'" "" ~C':' ..... : ."'"'""' M ,', S T: 018N R ,', 003W S: ;:~? ACRE:'.S: 640,000 C A S E T Y P E;: 0 R C A T [ii: G 0 F:-.: Y: A C F?. E S ! 6 0 P A T-'"' C O A 1 .... .I. 6 0 T 0 T A L ,.~-.74..~...¥.~,~..~-.~,~...~...~..,,~-.~...~..74-.:-~..-74--~...~.,~.~,'!. %.i.,':..i~.~. ~..~.+ CLASS i F I CAT ! ON NEXT: hi F'i L..E: AS 4 .i.. ~E:3,500 ( ii. ) CASE TYPEE }!i}X":,Et !'iLJL. T I PL..E[ USE L. EG i S i N i T I A T E D A "1" E.7. ,..,'"' ,...,'-'- ..~. '":,., o, .... .i. 9 8 8 S"f'ATLJS DA"f'E 06-('::9 .... ].988 CASE STA"[US 55 EFF'ECTiVE CASE; SLJBTYF:E ?}]80;:~ REC','F;':EA]" i (;)iq R I VE~I:'-;.' FiLE C! .... '765 1 i".4.,.'r "r, .,.'r A T E DA T' EE ,..,'"' :-", "* .1; 3 .... 19 ? ?;. S'T'ATUS DATE 07 .... 13-i971 ACF.:E:S E]C;... U'f":':.,., .... I'T'Y F I L:E L.L. 0 5 ! N I T i A T ii.:.' D A T E 0 4- 0 5 - .1. 9 8 9 STATUS "" '"'""'"' ............. :.-~ :.., :'-',,:::.,:~ 4 0 F.: iii'.] S r !",: 'r C T E D ,':+ C.:: TC]TAL P F' I E:: / ~:e,':'+ - R EE'i' U F,: N F .'[ LZ F;:S E.:~ 6. - C:, ('.~ 45- F' A L_ i':! .T. N I T :[ A't-E D ATE 0 D- 0 ! - i c;.::,~,'~ .... c-'-r'-'?' T U S DATE C.,'~- ACRES (') TOTAL F .T. i ~.- "F' i c:, z.. i ~']"7..' ~.. ,..,'- .:_ .,. ,_. IN!TiATE DATE 02-03-i965 STAT'US DATE C)9-C'-.9-!974 AC:RES ,.':) TOTAL CARE TYPE 6c:,i ~'~UN*C; F-'A.L ENT'r TL_EMEN-..r C;ASE STATUS 90 CONVEYED SUB-SURF'ACE-ACT ~Z V I TY **-:~. **** ***** ***-:~-************ F'FI .- HE!_F' F'F8/20 - PREV MENU 4B ~ a NLJM PF!2/E~4 - RE-f-URN NL. M3060F' DEPAF'-.:TMfF_N'I' OF' NATLJF.'.AI .... RESOURCES 05/08/1995 :L4: 35 · "- : ~" ~"'~ ~ r"'r . ._, _. LAND F I L..E RB._.,.T~-~ ..... PAGE: N E X'!": N ?i: :i:.:; T: ,:';:, ! 8N R: c:,(":,3W S: E"7 AC;REES: 640, C, 00 C' / ..... :' .,A~F:. TY'F'E: OR C~TIEGORY: NAME/Z'.,,r,p~.:;,F.:c.c. f Y/N) - FI I_..E ADL. 3?4 !. 36 Z hl i. 'T' .T.A "t' lie D A T E09- i ? - :i. 99 () S'T'ATUS DA]"E ('~3-.87 .... !99:1. CASE S'T'ATL]S 2]:t. ACTIVE S A I... E A R E.'. A C I C'; 00 I< ! r,.l L. E T A C R E; S 80 T 0 T A L "~' * * * * % 'K- * * * * .'?4.' * * * *,~- '>¥ % ':'4'. * % '~: * % !:::' ]: L. E A D ! .... 209542". I N i T i A T E: D A TEi: 0'7- ,t. 3 .... .1. 982 S ,C) U R C r.::: C A"I" E: G 0 F;.'. Y S U B S U B S U R F A C E:' .... f.-, ...,I,t ........ , 0 'f'O TAt .... F' I L.E LAS .~ .~ c~'":.,,"':., C.'.ASE TYF'E!: E3r', :L ........................... ',, R I G H T S ! It! ! T ! A T ti".'.': D A T E:'. 0'7-! 4- ! 9 E~, 8 S T A T L]S D A T Ii!!: 0";; ...... ! ,q ...... .t. 988 C A F!:; E: S T A T U S :L () A P P A C C F:' T D "='.i;ro U F: C E: cAT!EGC) RY i:':" i::: C'3 ................ '-- .......... L ¢"1".::~ t ,""- l=:. A M R E: S ii.": I::": V A T i C)N S U B --S U F': I= A C E '"" A C T ! V ! T' Y * * * * * * * * * * * .~.- * * .~'... * * * ..* * * * * * * * .~,.'. * C A S E: 'r' Y F' E ';;' 84 0 ! L_ ;E G A S L. [ii: A S E C.,".':) M F' C.,' A SE T Y F::'E 8 0 i W A"I"E R R i (3t"'I T S P F' :i.- H E,.... P F::' F' 8 / 2 () ..... PR E V M E:t',iU 4 B ~. a N U !'"'! i:::' F:' i E!: /;:i'.':'q ...... !:::E'i" LJR N D E !:::' A R T iq E N T 0 F ' ~ "'" J 'r; .... ¢..,?..,, ~ ,.~,,~.--, t .... R E S [:JU RC E S ,,.... /"' ,. ! -; I ~.-...,1,~ D F Ii_ ii'.-'.: A B S T F?. A C "F 6 4 C:. 0 0 0 M: S 'T'= (.)!EiN R: ,:) ,:.'.:: :3 W S: 2'7 ACRES: C A S [.:.:: ]" Y P E: 0 R C A T E G 0 R Y ,", ,,. -~.. +4..~:~- -:~- ='~...~.. -,:- ..~. ,..~.,...~.. ** .~.~., .. WA"!'E F:-?. A C R [ii: S C, "F C)T A L.. C.'5 / C-'Ei/'~ c, ,..., ,.::. .... .,. ? "? ....,, .~. 4 = 3 6 = .;. C:.' PAGE: 0005 i'.-.iE: X'f': :L L_AND F:'!LE ABSTRACT M": 'S T: OiSN R.: "OO,~W S: 'RS ACRES: :5~'+C.~.00C~ CASE TYPE: OR CATEGORY: NAME/ADDRESS (Y/N)~ N DNR AREA CM SCDO MAT-SU AREA RECORDING D!ST~ R31i PALMER SENATE DIST. ~84 DISTRICT N HOUSE DIST. ~8 DiSTRiCT D:8 REGZONAL CORP. 94 COOK INLET' REGION STATE INFO DIST. 0R3 MATSU BORO r L,..] N 0 N E FICHE DATA NONE ~'~'~'~'%:~'~'~'~*%%%~**~'~:~'~'~' ...... MENTAL. HEALTH [_.~..~.,~"~"~h~"o :~"~'%~':~%:~'%'~'~'%~":~-~":~':~"~:~":~:"~'~'%';~':':'::~'-~' ............................................ THESE L. ANDS ARE AF:'FE]CTED BY A ]'EMF'OF~ARY CL. OSL~RE -t'0 HINEF;:AI .... L. OCATtON BY THE ALASKA SUPERIOR COUR"F EF:'F'ECTIVE JUNE ~:3. :!.994~ PARCEL. IDENTIFIER ......................... L. AND TYF'E .................................. MHT SM--~]z+~3 ORI G INAL TRLIS"r LAND MHT SM-E~G~:~'~+ C]R IG I NAL. TRUST L. AND MHT SM-'R445-"'A OR IGI NAL TRLIST L. AND MHT SM'"-6'.,q.,~5-'"'B OR i G I NAt .... 'I'RUS]" L..AND F' F Z .... l'-'l E L.. F:' F:' F:' 8 / ~:.:.' 0 .... F' R E V M E N U ':" :'z+ B .',. a lq U M LAND F I i...If.:..'~...i~::.,..::, I f'.~..,' .... 1 F:'AGE: OC:,C:,~i:.?. M: S T,, C' .1. 8 N I::;'. ',:' (:) 03 W S: Fi! 8 A" r..., ..... 1-,. l:::...c'":~ ,, 6,% C, ,, 0 C::, 0 ',:Ii / ;., ,]...~ .:-, r::~ c:. c: N CAF:;[: TYF:'E: OFt CATEGORY: hiAME:, ~..-~L L. i: '.. L ,.., ...., ( Y / N ) ~ ~ % %.i.,,...~:. % % % %.~.,~:..:,,:..~.-%.~. % %.i~-% %.~-% %-i~:..~: % ' ME N TA L.. i-.IE:A L T t'..i L A N DS % % % % % % %.?.!-.i~- %.~..!.~. ~,~. %.!~'.- %.!~..~r,. % %.~.,....~. %.~ %.~,.~ % % ..... ~', ,", ~",'~":. ",.r'i:::.' ~ r:' R .......................... i:" ~-,",. .'.... k:. .'.... I DENT~., .,.~:. L.i'::~ND '9'Y'F~[::' - ................................. F I L E FI[ii: 3 ! N i T i A'T'E DATE: OE:; ..... .i. 8 ..... ! 96:'.!!) '.:::' T z::-~"r~ ~ ¢:. ~"'~ ~:"' ..... 'i 8-.I. c:, ~. ,::, ,.., .... : ..... , DPi]'E: ......... :: ...,,.., (..iff": i::,' [:' S ].6C) t::' */::c'r' '-- r" fi "'" ~ ............ ! :r-. ~ :~.., F i L [.,iil M H 16 :I. l N i T i A T E-] D A T E C:, f.::~- i 0 ..... .1. 966 S T A T U S D A T E.,.'~ ,'::.:'- ..... -. C;.....,":~ ~.. ~" ..... c.;, 7 F";, A C F:;.: E ~i:::; 48 (} F:" A T-----~ "" ~" ~ ' ~'" ,_,,--,, ,, D,' .:'~ i N iii': R A i .... F': i L E A !ii!; ,':+ :i.. L:?.:.'iil, 500 ( 4 ) i N :[ "i" i A ]' E: D ~'"~"i" E: C, 6- C-' 9- i 988 : ~ ~...,, f ,...~;..~ DATE: 06-09- .i: ,::-, c).::::, CASI:.:i: "t"YPE i 04 "!'"'f I t",tEF;.:At .... ESTATE: C A S E.. c:..., T A 'T' U !:i) 5 () A C:: "[' .,. ~' V E: .t. 60 TO TAi .... C A SEi' T Y'F:'[::.: .I. 06 I'"! E N T'A L H.[.iiiA L T H ,:+ B · a N U i'"I, L.. A N D J:::' i L_E A B S T'R A C:: T 0 5 / 08 / ]. 9 95 ]. 4 .-'. 3 '7: 5 ;.E i'", ~'"',, ~'"',. "" F:: A il}!) E: ........... :.::~ N E X T '.-.' ,.., S"FATUS DATE O.t-13 .... 197 A(]RES 16-:.'i) UT i L i ]'Y F' I LE '""' ~ o. "'.' .,-=. ~,,,,~, T N 'r T i A T ir D A T E '"; '~' - o o C'T?,TI ~c? DATE 06-"'E'9'" .i. ACRES .t'-,,F2.'.]:: RESERVED USE ~ ~,,._E CL 18NSWSF ~-,'r T IATE ~4 i ~_ O~-uo-~v/9 STATUS DATE 06-30- ~. 9'/9 ACRES I P(') :." ~ ......... u HAB/PUB REC F~LE CL 18NBWSG CASE .............. -,- ," n.u ,,- ED I~C) TOTAL CASE TYPE PO! c-::=,'=',",-'~=' r'.: .,-,~c.'~ ....... CASE S'FATUS 54 AF'PROVED .~. ,=,_~ "[ O T A L _,m~E TYPE ~ i SURFACE CL. ASSIFiCAT~'ON F'F! -HELF' F'FS/F2'_O- F'REV MENU ':+ E.'- ,~ ,'..-.-.,. NUM DEF'ARTMEh. tT OF NATURAL RIESOURCES LAND FIL. E ABS'f'RP~CT F'AGE: 0004 l" ~I::: '( "r lr,'t: ~:~ T: Oi8N R: 003W c'-, ,"..m.,:=o. '- ..... : ~:2 ¢..3 ~-, ~., R E,.,: ~'~ 4 .'J. ',".~ C?. t-.~ ~-.. ¢.-. ....... .... ~..~:'.~E. FYF'E: OR CATIEGORY: *-.~..~ ¢--**":~. '.~ :~"~--:~. ***'.~-.~****.~.~(-*.~.~ C!._.ASS I F I CA"t" I ON i N I ]" i A ]" E,.,,r' ~_~,-,-,'-~ .r.:. '- 06-30-19 ? 9 STATLiS DATE 06""3C)-:i. 979 t..~ ..., ~', E,.::, ...... F' U B L I C R E C R E A T I O N ~ ....... F ii; .... i::. C i... S C-80-015 I I",i T .... T l A 'T' E D A T E=. o, o..., _ ~...::~ '~. - .i. o, ,.,.~:,' C',.. .::~ ~ ~--~, ,..., .... D AT'E .. ,:~'"-¢=/~, I ...... "... r', t::(, r':' c'¢ '", c', ~::' c: i:=' ~;(,~ .~ I ¢''' .... .., ...... ~:..,.:, -+-'.., ,', ............... v E D ..., ::.E. t:::' '.ii L. E C l .... S C-,'"'30- 03 ~? I I".i :Il T l A'T E': D A T E 08- ~}~ 9 ..... :t 98 (.) ~'~:?~'='~T~ Ff...L.~'" ""' ' ~:~"::~'"~f~i~TE"' " ~'~:'"' ~?"",'.': ;:.'~' (f~ ..,. ~i~a.: .... ~,.~ .."~i. ~ %'"~' ;:: '?"" ":" ~" ' '"' ~ A!.:~ ''~' '"'~:~'"'~;~".'.:~Tt-~,l...,,.~'"' "~ 't~'~'Z""'~'~;:;~'~'.~-F i.-,l'?" PD!O v [:.~~ ~'~ r~'" ."~'.?"' '""'?" · .... A C::F;.: E':::; 64 (':, C L A.q S ]; F:' ! I::' t".) 6 A 0 ]" C) T A t .... "'" ,,:- .... , , . ,,,:;- ?~'" .. F I L!ii'" M C 0 ' '= =' , ..... ,p I ........... "+,.:~,; C A S E T Y I=' E 804 I'd I 1 ,i t= I'", -~ ..... P l r") S I ix! G 0 R D E F.: 1 t"'41 'T' T. ATE:' DA'T'E 08-0'7'"" ! 985 "7 ': ,'": T/.% "r ~ ~c:' ~'"~ ~ ..... r~-7 .... .I. 9 "::'"/'' TI ~ c' ~.~4 / r',~ ~ -:'" fi .'-':, ,..., ...... :., DA"FEE ........ 85 CASE: .:.~ I~.-~ ..... ~ .... ,.+ A F' I:-'" ,":. ,..¢ ,,' :.= .... A C'. R I=; S 6. '::'+ () C L... 0 iii E D 6 ~+ 0 T 0 T A L. NLM306C:,P ~'"':AR'r'MENT OF N,q ~, ,.Jr,.>fl r,,b..:=L.,,.JFf "- ,"'""'~ /08/:i. 99'5 :L 4 · 38:44 , ,_b_ f--.~E .:7, h:RU i -- %,.. PAGE: ._ ,...F-'~N~.., r.:: I f"~=,,= X T: N M: S T: C)!SN R: 003W -~ "'~ .... : : .... ACRES ' 64C',. (':,C',0 CASE TYF'E: OR CATEGORY: NAME/ ..... ,---,-c-.:q ...,~ :-,~,p (V/N): N ........... _ ...... f-iL, ! ', .,.. - .......................... FiLE ADL 80i648 CASE TYF'E 581 F'UBLtC EASEMENT' INITIATE DATE 0D_-~8-1979 STATUS DATE C.,9-19-1984 CASE STATUS ~0 EASEMENT CREATED CASE SUBTYPE 8005 RIGHT OF WAY ACRES R TOTAL ***************************** F!LE ADL 658!E~ I NIT I ATE DATE 09-R6- ! 9?4 STATUS DATE 01- ! 0--1995 SALE AREA C I ACREZS ]. 60 TOTAL FiLE ADL. 374i35 !NIT!A'TEE DATE 09 .... 17-i99C, STATLJS DATE C, 3-"-~7- ]. 991 SAL. E AREA CI SL. B-.....,URF ,qC,....-AL: F T v ........................... '~84 CASE TYPE ,' OIL GAS LEASE COMP CASE STATUS 8]. CLOSEi}-HIGH BID REJ COOK !NL. ET CASE: TYF'E 784 O]:L e:.: GAS LEASE COMF' CA SE q-- A C T ... I A'F U S :F:' ]. I V E C 00 K I NI..~E T F'F' ! - H E L.. P t:::'F::' 8 / F2 (') - F' R E V M E N U 4 B ,, a N U I"t P i:::' ! ~2 / F_'" z--I ..... F;.: Ei; T LJ R N :: N L. M 3 () 60 F' DE:F:'AR'TME:NT OF NATL.!RAL.,PE'":301 ~PF'F'c'', _,', ..,,',.....,,::.,.:, L.. A Ni;) F i L. E A B S T' F;,'A C'T C, 5 / 08 / ]. 9 9 5 ]. 4: 39: 0 F:'A G ii!!:: 0,::'.', 0 :','-:' N E'X T: i I.... fie I.... A S 8061 C'; A S E T' Y F' E '"',:::~ ,'"'..., .,." W A '""; E F;:. R i G l..t '!' S i N.i.T.IATE. DA;:f'.E ...... STATUS DATE:_ 08-(':,7 ..... 1987 CASE'.'; S'I"A'I'LJS 44 C]L.C]SED SOUF:;CE: CATEGOF;,'Y SUB SUBSL,tF;.:FACE ;% t"*" I.,,~ .~,,.. ,.~ ..., r', t:.~::~ 6 4 0 "F O'T'A L. F:iL.E: L:AS 1:,]:977 CASE: 'T:YF:'E: 8().1.' WATEF;: F;.'.!GH,"FS i hl ! "!" ! ATE DA.T'E ,:]:,'7 ..... .1. 4 ..... i ......... ~ ....... ",""~ l,'"' :I. 0 ~!::; F f.:'~ T U S D A ]" E.'". 0'7 .... :f. q ...... .t. 9 E'). 8 C A S E ,::) I ~..-~ t ,.,.:::) A P P A [] E: P T D L".:: E) U F:;,' C E: CATEGORY F;..'ES I NS'T'F-:.'.EAM F;,:tESEF";:.VAT' i ON A C I::;: E S 0 T O'T' A L ~'~"' ~ T: 01'.8N R:' O03:W S:. 29 ,.-,mpa=c=. ..- CASE TYPE: OR CATEGORY: NA?(EiADDRESS (YIN): N DNR AREA CM SCDO MAT.-SU AREA RECORDING DIST. R311 PALMER SENATE DIST. ~8,~+ DISTRICT N HOUSE DIST. ~8 DISTRICT REGIONAL CORP. 94 COOK INLET REGION STATE iNFO DIS'T. 0~3 MATSU BORO F'LO NONE F'I C:HE DA-FA NONE ~e*'~'~*;~-'~'***~.~.*-~e*~.~.*~.***~e~.~- MENTAL HEALTH L. ANDS THESE LANDS ARE AF:FECTED BY A TEEMF'ORARY CLOSURE TO M iNEFRAL. LOCATION BY THE AL..ASKA SUPER!OR COUR]" EFFECTIVE JLJNE ~3. PARCE~ .... iDENTIF'!ER ....................... LAND TYPE ............................ MHT SM-..~E:4,q. 5-A ORi G i NAL. TRUST L. AND C A S E 'F Y F::' E t. 0 '! G E N [::;F:;,'A) .... G RA N"F' F'F i · .... i'") E'7. L. P P F 8 / E":::..," ..... F:' F', f::... ",;' ~'"I ........ F: N l ..i 4 B ~ a N U M NL.M:BO6,.OF' DEF:'AF:~TMENT OF:: NA'!"LJF:;.:Ai .... F:;,'ESC)URC:ES 05 / OS / :L 995 :L ,':'+ ,".. 40 :: 04 L. AND F:ILE ABS'T'RACT F'AGE:: ).~ ~ .... %... .... M :: S 't": 0 i 8N iR: C.~():BW S: Et9 ACt::;:ES: 6;:+C., ,, C:,00 '~',:"..?:' CASE -TY'F'E: OR' C'A]?EGORY: NAME/ADDRESS (Y/N) :' N ,'." '..~...~..~. ~..~. ¢,'....~..~- ..~. ,~ ..,'4. ,..x., '.4. ~. -.'4, .~..~. ~. -.', ..:.4...~.~ .!~..~ .~ T I "I" L. E A C f2 U I S I T ICi I"..I .~..~,~..~.,...~...~ .~..:,~...,,t..~:...:,4...i,~..~,.,...~..~..~,.,...~.-~,~..~..~..~¢.....~,~- ...',~..~..~...,'4....~ ...',4. -."4.. ....... IN!'T'IA'T'E DATE 06 ...... 18 .... 1959 c:."', ..... ~:* '~ ":'- ::'~ P .... 199 E:.'. ..., 1 ~:.-~ i U....~ D A"I"E .~. ~::. - ~ ..... .~ ........ A C f";.'. EE S ;:.i:E':') 0 ' PA T'=" L. A ND/M I NE R'A L F= :[ L E Pil'"i i 61 .,", '.':.:, _. ("'~ .... C:) f~ Z. I N :[ T I A T E D A T [ii: .... r:..' .I .... .t. , ~ ...... STA]'LE:3 DA]"E] .t. E:-03- .t. 9'75 ,~:','-'~':;~::'¢'?' ! 60 F'AT""'L. AND/M i NEi:RAL. 1"". L.,, /~, ~,,, ,,~ ,.~.~.'f-~ F'~. ' T c'~. T ~' CAS1E TYPt!F !06 MIEN'T'AL. H!EAL. TH 1:"' "" '""' , ~Ji:3 =:' ('.,(-.~ ~' ,.:: ) c::, ("~ c:', ......... F'. I L;,':. ~..~.:=, q- :l. ,, ,..¢.. ... , ~ CASE TYPE: ........ , i""ILIL..'.r' I I:::'L..E.': LlE.}ii!i: L. Eb'., :l: ::ii I N I T i A'l" E D A 'l" E 06- 09--. 1988 S 'l" A'F U S D A T E C:, 6-C, 9 ..... 1988 C A S ii:.:: S 'i" A'!" tJ S 55 liE: (:::' F' EEl C "f' ]: V lie C A S Ii.'-" c'i t'":'"r' v F:' F '::*'":') C"-:" ............... ...... : ,:.:.., ,'= R E C t:-;: E A T '~',. ...,n ,~"',,~ ,:::', T.,. ~..: ,=,.. ,~:;', ACF:..:ES .I. 60 TO")"AL_ F' ! L E C I .... 18 N 3 H S F' .r.:; A S E T Y P E E:' 01 !:!:;. L) R F: A C E] C L. A Si.; S i F' ]: C A")" ]: 0 N ]: h..l 'r T ~'/,.'-re' DATF"_' :"~F ...... ':]0 ..... .I 9'79 q. B ~ .a N U M C:: A S E: S ]" A T LJ S 5,q. A P F' R 0 V E .i. 6 C:, 'i" 0"i" A! .... . C A S E: ")" Y P iii:' E' C: :)..'.:':' t:, ..... ,t::",. ,~:=' A C E C L. A S :E; .i: i:::' I ,...,; ..... F.:'~ T I f";._,, ~'',,i c,,-"¢,--,--.-_, UT T, .............. C. I T Y F'FI - HE;L.F' F'F8/20 - F'REV MENU F'F 1 8/c.~+"-' ....RETURN N L... PI 3,:-:, 60 F: DEPARTMENT OF N~-,'i~._t-...~-~L RESOURCES LAND F!LE ABSTRACT ,-', ,--, "'414 M= S T= OiSN R: ........ S= 29 ACRES: .. --,-.-:,r.- OR CATEGORY: .,,-~ .~ ,::. ")" Y F' E: . ********************************************** SUF-i'FACE ACT :[ V I 'i'V A C F.: E ::S C:, T 0 T A L · F I L_E': ADL E::O38:B8 i N I T I A '1' E D A T F=' 01 - ,?'30 - S "[' A T U S D A '1" E: C, .i. -- 3 (':' .... 1 c:,, ,..,c.', ('.,.. CASE SUBT'YF'E 9(':,0'2". IL_MA A C R E: S 0 T 6..)T A L F: i i... E A Dt ':::'F. :t. (.':.""'7 '::): i i"',l.I 'T I ATE DA'f'E '0~-'0:]i,~- 1' 965 "" · S'F A T U S D A TIE ,:.) 9..-0'="" .!. 9'74 A C R [ii: S ,", "r' ,'"'~'r/', ~ ,--,~:=' .,' r.,c::, / c;, =:''~. C.) ...... .~ ........... :j., 9 ._..:~. ,~+: : "t 3 F'A G E: ::} 004 N E: X'T: N CASE 'FYF'E" 59]. ft,.,1,,Ru.,L,t,...N] ...-~t.:.~F..E:.[::.ld'.'::.~,~, C A S E T Y P E 60 i M U lq :[ C :i: P A t .... E N'F :[ "t" t_ tie M E N T '"~, .,% ?'". ¢'''~ '" ,, I. I .... t.,H.:.~E:' S.1"A"r'us 9C, ,..,Llt'4,,E.'¢ED F' I LE ADi .... ::.3'TZt '.I. 35 CASE TYF:'E:. '78q 011 .... S: GAS L. EASE ~??';'"' t:N'I 'F']iATE' DATE :: '-(:')'9=:I?-::t.'~90: S'TA'T'US DATE: 03'8? .... .1.99:! CASE ST'ATtJS ;:!.::1 AC, T'IVE .....P ....... ' ...... . ....... R ['Z 'T' U R N P F :i. i'...,:::. L I:..F:' F 8/' ;:':.'.:' (') P R [:"_' V M E' lq L.I P F::' :i. E.". / E: ,q. T"*q: B ~' a NU t'! N L. M 30 6 0 F:' DEP,.~F,. l t't[:.N~ OF' ,4,-/~ .....",,~...[ .... ,,L..:U..,i...{ ........... L A N D F ! 1... E A B S"t'I:;,' A C'T A C F.: E: S: 6 4 C,. 0 0 C:, ..' ¢'H'J . .:... M: S "t':: (")Ic:,,',~ R: .0C:,3W S, 2'.9 CASIE TYPE:: OR CA'!'EGOF;.:Y: SAi....[ii: A R[ii: A C I A C F;,' E :.:.'3 <-'+ 80 T O'T' A I .... · '.,...,..>.'.-..,!..,..,.'..*: ..,'4....,.'- -.,..!,....!,~...,...*......,..'.,4...~ % -:'.4..*:...,:..~..~..-,.. F: I !._ E:: !., AS ! :[ 560 i N I ]" ! ATE DATE: -0 E:; -- ,:':' ¢+ - ~':787 "f' .1" ',. / SUB-SLJF(FAC2, E:-'AC: T i M *. ',' C[)OK ]: NLE:T NAME:/ADDRFJ::SS (Y/N): N % .x-.~:. % .~-.>~.-.,. % .~e-~ % % % % % % % .~..~, .~. % .~,~. % .,-.,..x...,:. % CA S E: .1' Y P Er ii:_;.":.:." 1 W A'T' liE: F:;'. R i G H "I" S · ,::..x-.,..i, .x- % E N D 0 F: L. A N D A B :ii';.' 'T R A C T' R Ii!'.: t:::' C) R'F ~-'x- % %-~ % ~-', .I:::' .,'~ ........... ..... i-.. 1::: L ~ .... P F: Fq / F:' ,'.":, ..... P F:. E: V :!'4:,_~:' lq L! q- B .~. a N U t"! Frontiersman/Valley Sun Newspapers Alaska's Best Small Town Newspaper 1261 Seward Meridian Road (907) 376-5225 (907) 694-6318 Wasilla, AK 99654 (907) 352-2277 Fax AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF ALASKA THIRD DIVISION. BEFORE ME, THE UNDERSIGNED. A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED SUSAN LINDSEY WHO, BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT SHE IS THE BUSINESS MANAGER OF FRONTIERSMAN NEWSPAPER PUBLISHED AT WASILLA IN SAID DIVISION THREE AND STATE OF ALASKA AND THAT THE ADVERTISEMENT, OF WHICH THE ANNEXED IS A TRUE COPY, WAS PUBLISHED ON THE 5TIt DAY OF MAY 1995, AND THERE AFTER FOR -0- ADDITIONAL ISSUES, THE LAST PUBLICATION APPEARING ON THE ~ DAY OF 19 , AND THAT THE RATE CHARGED THERE ON IS NOT IN EXCESS OF THE RATE CHAlk?ED PRIVATE,INDIVIDUALS. .... SUBSCRIBED AN; ~WORN T0 (~EQRE ME THIS 5'TH DAY OF MAY 1995. // NOTARY PUB~-~FOR STATE OF ALASKA /'/' MY COMMISSION EXPIRES OCTOBER 20, 1998.L~'/ FR6040 AO-02-5-1454 Notice' of Public Hearing STATE OF ALASKAr , Alask, a,,Oil a'nd Gas i,,,,, .:' ',' C~h'Sk'.rv~lon '. .,:. ;,..,:;,....:.....,,i:~O,'Mmi~lOn, "R'~:' '~'E/~Pilb~t~°h of I~pp : :':,':,,.~ ,%. '~, ,,,., .: '." qsour.cesv.J,nc; .for, a ..,....Pub.!ic, he~.qg, t0. present . .:.: tesumony/or'~lassifloa- ... : ~d.. prescribil~g ~.rules . i..i:i' .,fg~ jt~>deVelOp, ment 'in ' ".". s~i~n ~2~ ;~Ti~: RaW '.'.' seward'Me,drab: ', ',,,:,,',!~!T'.,:,,%~2,,,,!,,,,,,,,, ?:,, ,, ,,,., N~i~!:'is?hereby. giveh' that undeJ?.:20 :AAc 25.520 to hold a 'public hearing to present teStimOny for. classification and pr~sctibingpool rules for develop~Jent of a series of coal-.se,~s as=natural gas' reservoir~' in the vicinity of Hou.e~LAlaska ..The pro- posed development area is . Icicatad'iff~e Matanuska val- ley0fthe C0ok.lnlet Basin in Southcentral Alaska. ithe Alaska,~Oil a'nd :.~' Coh'Ser- ration Ooh'i~ission: 3001:'pOr. cupine :Drive; Ani=hora~ge, .Nas~a ,, 9950~..~. at cie0 AM-on ,:jUne!2i.~99S.iri .w~ 20:.aAC.2s,S40::aii.in~. eSted ~,;Ipers0nS '.an~d parties .. .'are inVited, tO preSent..te~ti. 'mony.. ""':.' '." If yOUr. ~re. 'a person 'with' a disability who may nee.d'~.a special` modification in:order to' eom meht(°r to. attefi~J;.the PubliC!.: heati'hg tact.Dia~a Fleck.. ~t 279Z.1..433 no laler:than May 31, .11995. , .'.' ~ . ..commis,~oner A0:02,5.14.54. :.:. . '. Publish: MaY 5 .1995' .' FR6040' '. · , , , F F:: III I','1 g 0 [5'C C ~upi~m Dr.i ye ~1 ^nchorage,'Al( 99501 I',aU i !1..,~ i U I-'UPH...I~_~I'iL, I I [ ...... INVOICE MUST BE IN TRIPLICA'I'E SHOWING ADVERTISING I-A0 ORDER NO,, CERTIFIED AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COPY OF ADVERTISE.. MENT MUST BE 'SUBMITTED WITH INVOICE. 1AGENCY CONT'AOT Dian. a Fleck ~HONE_ ...... (.on !3'14 No.042 P.OI (.)2- 5-] 4-54 DATE OF A,O, ' .......... 05/01/95 , . Il.. IT o tTypeof Advertla'ment: Front ier .91u a n Attn: L~ 1 o 1261 Seward Meridian Pkwy Wasil~a, AK 99654 t 05/05/95 THE MAT[iR!Ak ~TW~EN THE DOUBLE LINES MUST BE PRINTED ~N ITB ENTIRE~ Y ON'THE DATES BHOWN. I~[egal [] Dtspley LO Classified Other (Specify): See attached pub,l~c h~aring no,ice NUMBER _ AMOUNT PGM DATE .:~ ~'AO£'~j ALL_ PAGES COMMENTS i'3 ACC? · 540 o2-~'01 (Rev. §-85) ._ PUBLISHER Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re~ The application of Lapp Resources Inc. for a public hearing to present testimony for classification of a new gas pool and prescribing pool rules for its development in Section 21, T18N R3W Seward Meridian. Notice is hereby given that Lapp Resources Inc. has petitioned the Alaska Oil and Gas Conservation Commission under 20 AAC 25.520 to hold a public hearing to present testimony for classification and prescribing pool rules for development of a series of coal seams as natural gas reservoirs in the vicinity of Houston, Alaska. The proposed development area is located in the Matanuska Valley of the Cook Inlet Basin in Southcentral Alaska. A hearing will be held at the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, at 9:00 AM on June 2, 1995 in conformance with 20 AAC 25.540. All interested persons and parties are invited to present testimony. If you are a person with a disability who may need a special modification in order to comment or to attend the public hearing, please contact Diana Fleck at 279-1433 no later than May 31, 1995. Russell A. Douglass Commissioner Published May 2, 1995 ', HALLIBURTON I .. I III -- - ~_11111 Lapp Resources, Inc. Houston Area Alaska Cementing PTA Recommendation Prepared for: Dave Lappi 49(}0 Sportsman DrK'e Anchorage, Alaska 99502 Fax: (907) 248-7278 4/28/95 Prepared by: Mark Wedman Halliburton Energy Ser¥1ces 6900 Arctic Blvd. Anchorage, AK 99518 907-344-2929 Hal~,'hurton Wants a Safer World RECEIVE Alaska OJJ & Gas Cons. Corn~ 'tlnChora.q, .~ ~ission . III I III _. I ...... II I II- ~ I II Ir- _ Plug to Abandon Foreword__ Dave, Halliburton Energy Services appreciates this opportunity to be af service to you. The enclosed cost estimate is based on Halliburton Energy Sexwices mobilizir~g out of our Kenai/Nikiski.loeation. Cemem is to be pumped via tl-,e 1-i/2" CT arid circulated to surface. Lapp Resources to provide the mixing water required and sufficient mixing water to clean the cement pumping equipment. Lapp Resources to provide a means to store excess cement slurry and water used to clean up the cementing unit and ro dispose of said material. I apologize for nm ~, ,' o . ~etan~ this information t.o you sooner', bur i was o'ur of town an[ii this week. If you have any questions or need any additional in[ormation, please feel free to comact me anytime. Sincerely,. _ Mark Wedman, PE Technical Specialist i'~LI~IBu RTON II I _ II IIII IIII IIIII I- Plug to Abandon Well Information Existing Surface Cashxg' Existing Production Casing: Tubing PTA Cement Interval Calculations 300 ft- 6" Casing 2100 ft - 4" Casing 1-1/2" Coiled Tubing - Open-ended at 2100 ft 0-2100 R Inside i-1/2" CT and 1-1/2" CT x 4" '~ I C.as.ng Annulus PREMIUM CEMENT: (2100 ft fill) 2100 ft * 0.0545 i¥/ft * 0 % TOTAL PREMIUM CEMENT Job Recommendation = 114,54 fi* = 114,54 ft~ = 20.40 bbls FLUID 1' FRESH WATER Fresh Water FLUID 2: PREMIUM CEMENT PTA Cement $1un'y 2% Calcium Chloride- Anhy (Accelerator) Mixed With Fresh Water Top of Fluid' Fluid Volume: Fluid Weight: Fluid Yield: Fluid Water Ratio: Total Mixing Fluid: Top of Fluid: Calculated Fill: Fluid Volume: Calculated Volume: Proposed Volume: Circulated out 5 bbls 15.8 lb/gal 1.15 fla/sk 5,0 gal/sk 11.7 bbls Oft 2100 ft 20.40 bbls 100.0 sks 100 sks Plug to Abandon Cost Estimate Description MILEAGE CEMENTING ROUND TRIP MILEAGE FOR CREW MILEAGE CMTG MAT DEL OR RETURN OPERATOR TIME - CEMENTING EQUIPMENT OPERATOR- PER HOUR FOOD AND LODGING AND TRAVEL EXPENSES PLUGGING BK SPOT CEMENT OR MUD CEMENT - PREMIUM ANHYDROUS CALCIUM CHLORIDE BULK SERVICE CHARGE BULK BLENDING CHARGE Q_~ U/M Unit Price Total 560 MI S 4.'?0 $ "'"40 00 I UNT 560 Nil 3.00 1,680.00 1 UNT 1350 TMI .[. 15 1,552.50 "~,: MAN '75.00 1,500.00 10 HR 1 MAN 7"3.00 700.00 10 HR ~ DA'z' 230,00 t ,380.00 g, . 3 MAN l FT 2,090,00 ;!,090.00 1 UNT 100 SK 22.00 2,200.00 3 SK 64,05 192.15 106 CFT t .55 164.30 106 EFT 1.00 106,00 TOTAL COST Es'rIMATE DISCOUNTED TOTAL COST ESTIMATE NOTE: SeDric. e LocatJo.n ~ Kenai Conditions $ 13,804.95 $ 10,000.00 The cost in this analysis is good for the materials and/or services outlined v,.'ithi, n, These prices are based on Halliburton Services being awarded the work on a first call basis. Prices will be reviewed for adjustments J.f awarded on 2nd or .>rd. cali ba:ds and/or after .30 days of this written analysis. This is in an effort te schedule our work and maintain a high quality of performance for our customers. The unit prices stated in the proposal are based o.n our current published prices. The projected equipment, persmmel, and material needs are only estimates based on mfom~ation about the work presently available to us. At the time the work is actually performed, conditions then existing may require an increase or decrease in ti:e. equipment, personnel, and/c,r material needs. Charges will be based upon unit prices in effect at the time the work is performed and the amount of equipmem, persom~el, and/or material actually utilized in the work. Taxes, if an)', are not inclucled. Applicable taxes, if any, wilt be added to the acmaI invoice. It is understood and agreed between lhe parties that with exception of the subject discounts, all said serviee, s and materials will be fiu',,fished in accordance with the tenr~s and conditions of Halliburton Services' regular work orders applicable to the particular item. In connection, it is also understood and agreed, that Customer will continue to execute Halliburton Services usual field work orders and/or tickets customarily required by Halliburton Services in connection with the furnishing of said services and. materials. TEL NO:1 90? 248 ?2?8 LAPP Resources Inc. 4,900 SDortsrnan Drive Anchorage, Alaska U,S.A. (~.-fiL,.." 99 S02-4169 Telephone + 1 (907)248-7155 i ii rI , i llll .. Fecsimile + 1 (907)24~-727~ FAX TRANSMISSION ~I~EET I;tAT~ ~ ff ~" TOTAL # O1~ PAGF.,S CALL OR FAX IF YOU HAVE QUESTIONS ON THIS FAX. APR 28 41aSka Oil & Gas Cons. C'ornmissio~ '4'~Chorage APR-~B-' 95 FRI 09:28 I D: LAPP RESOURCES I NC TEL NO:i 90? Lapp Resources, Inc. Houston Area Alaska Cementing PTA Recommendation 4900 ~portsman ])rive Fax; (9o7) ~8-?~78 4/28/9~ Prepared Mark Wedman Balliburton glx~rg~' ~900 A~ Blvd, ~7 344-2929 ,~PR-28-' 95 FRI 09:29 I D: LAPP RESOURCES I NC " O,~,.~.~,~.~RTON TEL NO: 1 :_:Jla? 248 ?27[3 i' ~36@ P03 Hall[bttrtoll Bne~ s~vice$ appreciates ~is oppor~nit>, to ~ et' s~i~e to y~. ml~ ~ ~tm is b~ on ~alli~on ~e~y Sezwi~$ mobitiaing out of K~tlNAis~ loct~on. C~t is to ~ pun~c~ via ~ 1-t/Z" CT a~ ctr~ula~ ~~ ~in~ cquipm~m, ~p R~sources t~ provt~ ~ means to stere ~ass ~ment ll~ a~ w~r ~ to ~le~ ~p ~c ;cmenti~ u~t au~ to di~esc of ~dd ~teriii. I apoto~ for not s~ttint~ this information to you sooner, but I w~ts out of town ~B~I ~is Mark Wedsnan, PE Techn~ttl Specialist APR 2 alas~!.,.Oil .a Gas Cons. _O..PR-28-' 95 FR I 09:29 I D: LAPP RESOURCES I NC . "' O~.A.~LT~-O-RTO N Iii ...... II .... _ _.. II I IlIII ....I _ . TEL NO:i 987 ~48 7278 ~68 P04 lill III Plug Casing: ~bini PTA C~m lut~zval B00 fi- 6" CaSitlg 2100 it- 4" Casing 1-1/2" Coiled Tubin~ - Open-ended at 2100 t 0.2100 t~ inside 1-1/2" CT and 1-112" CT x 4" Casiug Annulus CBMENT: (ZI00 It fill) 2100 ft * 0.0545 fl'Irt * TOTAL PREMIUM CEMI~NT --. 114,54 It~ - 20.40 bbls Job Renommemfe~an ___, ....... I~LUID 1: PR.l:.~It WATER PLUID 2: ~UM CEMENT PTA C. emem $11a'I/ 2% Cald~ Chloride- ~hy (Accelerator) Mb~d With I~r;sh WetTer Too of Fluid: Circulated ouL Fluid Volt, AC; $ bbl$ Fluid Weight; Fluid Fluid Water Ratio: Total Mi~ir,41 Fluid: Top of Fluid; FlUid Volvme: Propos~ Vol~e: 15.8 lb/gal Ii,0 gal/fl( 11.7 bbls 019 2100 ft ;10.40 bbls 100.0 100 ski RECEIVED APR 2 8 c~{a~a.,0il .& Gas Cons. Anchora!t~ .......... ~.PR-28-' 95 FRI 09:30 I D: LAPP RESOURCES I NC ~ -1~ I ..... IIIII - ' '11__11 I .... TEL NO:i 98? 248 ?2?8 .... I IIIlll ..... Plut~ to Abandon l/Il I I UNT MI~~ C~ ~AT D~L OR RETURN t~0 O~A~R ~M~ - ~~TINO '2 MAN 75.00 10 HR ~~T OP~TOR- P~R HOUR 1 MAN 70,~ ~D AND ~J. NO AND TRAVEL ~X~ENSSS g DAY ~ MAN PLU~O BK ~T CEMENT OR MUD t t UNT C~ENT. P~IUM 100 ANHYDROUS CA~IUM CRLO~{D~ ,~ g~ ~4.0~ ~UL~ SERVICE CHARGE ~0~ C~ [,55 BULK ~LBNDINO CHbRO~ 106 c.~r Unl_t Pric,;, z~O.OO $ 2, ~-40,00 L ,680.00 1,5~2.S0 1,$00,00 ?o0.oo 1,$80,00 LOg0,00 102.15 t~4 lo6 TOTAL COST £$TIMA'[I/ $ I3,804 ,M DI,~ICOUNTBD TOTAL COST ESTllViATI;, 5 TM cost in this aaaiysi.~ ;s good .%r ~¢ ' ' mat¢.oals and/or ~;ervicee outlined v,,itb~n. ~ese pri~s a~ ba~ on Hattibu~oa Se;vlc~$ bein~ awaked thc work on a first call bas~, Prices will 1~ mviaw~ for adj~ uts if awar~d on 2nd or 3rd, call basis and/or aRgr 50 days of this wrtumu a~lysis. ~h i~ in au effori to schedule our wm'k and maintain a high qumiity of The u~ pri~s sta~ed in the proposal a~e basuO on our cum:ne publl~hgd pri~a, Th~ p~j~ ~uipment, ~rso~cl, a~d material needs a~ o~ly e~timate~ based o~ i~onuatton about ~e work p~dy available to us, At d~e time the work is auh~ally performed, conditio~ ~en ~xi~ may r~ an i~gr~a~¢ or d~creaee in a~ ~4ui.pment, psrgon,~el, and/~ material n~$. C~Ses war ~ based upon u~tc prices ia ~ffc;~ at. th~ tim~ ~e work is p,rf,,~td aaa the ~~, ofe~lp~nt, ~raom~el, and/or ma~ria~ actually utilized in thc wu~k. Tax, s, if aw, ~ not t~lu~. Appl~ble ~xes, if any, w/Ii Dc added to ac acmat invui~e, It is urtd~rstood and a~reed betw~n the parties that with exception of the subj0ct d~~, aU ~d se~ig, s ~d materials will l)c ~ul~shc~ in a~cordanc~ with the te~s tnd co~iom o{ ~ibv. on S~rviccs' r%mlar work orders apUlicaDl~ to th~ paak~la~ imm, la co~tlon, it ia al~ amtooa agreed mat Customer will ~outinu~ to ~x~;u~ HalliUu~un gowns usu~ ~ld work orde~ and/or ti~ts a~atomariiy requir~ Dy Halli~non ~tvi:es in R E C ElY E P Alaska ,Oil & Gas Cons. Com~sstc>~ 'Anchorag~ LAPP Resources In( . Telephone + 1 (907)248-7188 4900 Sportsman Drive Anchorage, Alaska U.S.A. 99502-41 69 Facsimile +1 (907) 248-7278 April 25, 1995 The Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: 20 AAC 25.520 - Request for Public Hearing tO Establish a New Gas Pool Dear Sirs: PLAN FOR POOL DEVELOPMENT AND OPERATIONS Drilling LAPP Resources Inc. is the sole oil and gas owner in the development area and is proposing a coalbed methane production program at Houston, Alaska to develop and produce gas known to exist in coal seams in the area (see Rosetta 1-4A well files and LIS Bureau of Mines R.I. 5350). We are seeking permits for six well locations and plan to drill three wells this year to 2100 feet on 40 acre spacings. Initially, a local water well contractor will drill an eight-inch diameter hole to a depth of 300 feet and at least 75 feet into bedrock using downhole hammer rig. A six-inch steel casing (possibly ERW line pipe) will be cemented in place. We are planning to use Dowell Schlumberger's coiled tubing unit with two inch coiled tubing to drill about five inch diameter open hole for the next 1800 feet to TI). Dowell's BOP system will be bolted in place for all drilling below the surface casing. The wells will be logged by Schlum- berger using standard oilfield logging tools. A 3 1/2 inch or possibly four inch jointed (flush jointed if 4 inch) tubing will be cemented in place as production casing from surface to TI) using a jacking stand. Completion Depending on the results of drilling and wireline log interpretations, we will complete the wells for production at the appropriate intervals. We expect for coalbed methane production, that the producing intervals will be between 1000 and 2000 feet deep. Perforation of selected coal seams or sandstones will be carried out by standard oilfield methods. A suffactant de- signed to stimulate coalbed water production and reduce coal frees may be pumped into the coal seams at matrix (non-fraccing) rates. A downhole pump will usually be required to dewater and depressurize the coalbed and allow the gas to desorb and be produced. Progress- ing cavity pumps or jet pumps are our preferred options for these wells. Both pumps would require two additional jointed strings installed in the well. In both cases, water would be produced up the larger production tubing, and gas would be produced up the annulus. Production The wells.will be tested on tong-term production test until a commercial flow rate is achieved (projected to be about 200 MCFD), or until sub-economic flow rates have stabilized. If the rate is sub-economic, further operations in the well will be contemplated which may include pulse-fraccing, cavity completions, or sand-propped hydraulic fracturing. If commercial production rates are established, the testing will be completed and a gas-gathering, compres- sion, dehydration and odorizing system will be installed at a central point. [~ E ~ E IV E D APR 2 6 1995 Alaska Oil & Gas Cons. Commission 'Anehnr~n~ Produced Water Disposal Produced water will be disposed of downhole in an interval approved for disposal. One of the three wells may be used as a disposal well, or alternatively the wells may be designed to simul- taneously dispose of water and produce gas from different horizons. One of the existing deep petroleum wells in the area may also serve as a disposal well. Beaver Lakes State 1 (TD 8474') is within this lease. If fresh water is produced, permission may be sought for domestic use or surface disposal. Gas Distribution Gas distribution lines will be installed to serve residents and businesses within the Houston City Limits. A 60 psi gas transmission line will also be installed if sufficient production is established, to connect the facility with Enstar's existing low-pressure (60 psi) plastic distribu- tion system at the Houston Jr/Sr High School four miles to the south. This will allow LRI to sell gas not consumed in Houston to its major customer who has already agreed to purchase a minimum of one million cubic feet of gas per day at a specified price. This customer also has an option to accept the remainder of LRI's production from this lease at the same price. REQUEST FOR POOL ORDER We hereby request a notice of public hearing be issued, to assist in establishing the pool, clas- sifted as a gas.field, which will be operated under the following rules: Pool Rules The area of the "pool" is the developed area of the lease, the coalbeds being stacked in the subsurface in discontinuous lenses from the surface to 2,100 feet depth, but are likely to be spatially present in the entire area of the lease. The section which will be drilled in our, wells will be best typified by the section encountered in Rosetta 3. An AOGCC bonding requirement of $10,000 per well or $50,000 more than five wells will apply. This lower bonding requirement reflects the reduced cost of plugging and abandoning the wells in a road-accessible location. A quotation of $8,365.75 for P&A costs from'Dowell Schlumberger is attached herewith. A quote from Halliburton will be supplied in the near future. These service companies are required to have their own cement mixing equipment and pumps onsite. An Operator could cement the wells, top to bottom, for about $2,000 using construction cement supplied by local ready-mix companies from Wasilla. We suggest however that most operators acquiring the lease in future would rather have the wells suspended, rather than permanently abandoned. Even if non-productive, they are still assets and could serve as disposal wells. Drilling unit spacing for this pool shall be 40 acres and shall be subject to modification depending on the Operator's engineering, production and economic experience. Appendix A, attached, shows our proposed well spacing pattern and examples of well spacings used in other states for methane drainage projects. Wells drilled closer than 330 feet from a' change in ownership require a letter of non- objection or a hearing where no objection from the adjacent owner is sustained. The'requirement for diverters on the eight inch surface hole shall be waived, as it will be drilled with standard water well drilling equipment and techniques. Venting or flaring of gas will be allowed during the dewatering phase, up to the amount required to establish the commercial long-term production rate from the reservoir. RECEIVED APR 2 6 1995 0il & Gas Cons. Commission Water disposal shall be in accordance with AOGCC regulations and disposal/injection orders. The available groundwater information is summarized in Appendix B. A list showing the names of all the owners of the oil and gas rights in the 40 acre parcels di- rectly and diagonally offsetting our proposed 40 acre drilling units will be supplied soon. Sincerely, David W. Lappi President · RECEIYED APR 2 6 1995 Oil & Gas Cons, Commission Anchorage Oo~ell Schlumberger, Inc. 'Pa~'e 1 'of .1. I To: Lapp Resources Inc. From: Cliff VViebe Date: April 12, 1995 Regarding: area. Quote to Plug and Abandon proposed Coal Bed Wells in the Hous[on As per our conversation to provide a service to plug and abandon proposed ,,','ells in the Houston AK area, Dowell is pleased to provide the following quote. This quote is based on filling the 2100 foot wellbore to surface wi~h cement without ex',racting the production string. Kee~ in mind that if the casing needs to be cut off below surface, then those digging and cutting cosis are not included. Dowell Cost Estimates Item Unit # of Units S per Unit Discount Cost . PACR ea I S555.00 15% 5,471.75 Personnel ( per man per day) ea 3 $750.00 0% S2,250.00 Fluid Pump, ea 1 S1,480.00 15% $I,258.00 Batch Mixer ea 1 S3.000.00. !5% ~.u..v~ :'~'" 00 Cement Silo ea 1 S445 00 15% S3'78 25 Air Compressor ea 1 S225.00 15% S191.25 D907 Class G Cement cuft 100 $.14.90 15% $ ~.,..~6 50 Total Cost estimate $8,365.75 RECEIVED APR 2 6 1995 Alaska 0il & Gas Cons. Commission Anchorage legend Diamond drill hole .o -% ,.,. 400 ~oo fFoo i/soo ~--]----]------ I Figure 2. - Plan, Houston coal-drilling project. F ECEIVED APR 2 6 1995 A~sk~ 0il & Gas Cons. Commission Anchome · IO 3O0 200 I00 0 - I00 -200 -300 -~,00 -500 -600 -700 -800 Collar El. 249 Collar El. 330 Collar El 303 2900' 'Gas & water 16 60' Strong gas flow brackish water. SECTION A-/~ o_ _ 590 Ia,aa ~5,oo, Hocizontal Scale i~ Feet with o o. 0 2000 .... ' i .' .,J~ .: · ii..id[I, il I . . · ..... 'q'i'l, .'--' '"' ' "L ...... ~ ', .... J-f-rd ' ' "', ..... : '--,' .... 0 0 0 0 0 0 0 0 ..... ".': '"'.:1:'"' "" ~' r~': ......... .:: ,'. ~. ~-:::::::-:-,- '~ ":~:::::.:: ... ~:~'~:~.:..~'~ ..... ~t~'.. ~..:,:.. ,1~'- ' ~:':':~-'~::::;:~:~1 0 _~ ~ ~ 0 ~ 0~ ~ 0 ~ 0 ~ 0 ~ 0 ~ 0 ~ ~ ~ - 0 .:.:';:.' .... :~'..':: ::: ...... ,.t~.-: :::: "c 0 0 0 0 0 0 0 0 0 0 ~ o ~ o ~ ~ ~ o ~ Figure 3. - Section A-A' and gm,lc logs, Houston coal-drilling proje~. Appendix A Spacing Justification Our map shows the proposed 40 acre drilling units. These closer spacings are desirable for coalbed methane production since dewatering of the seams is required to reduce in-seam pres- sures and allow the gas to desorb from the coal and flow to the wellbore. The interference of the pressure drawdown between wells is desirable and speeds the onset of initial gas produc- tion. Closer spacings also allow more complete recovery of the gas resource (coal is relatively impermeable) over the life of the field. Previous drilling in the area also shows poor correla- tion of geology between similarly-spaced wells (three USBM coal coreholes and five oil explo- ration wells), caused partly by faulting and partly by the high-energy fluvial environment of deposition of the Chickaloon formation. We expect.that the effective gas drainage area of our wells will be approximately 40 acres. The effective drainage area is a function of the stratigraphy, structural geology (faulting), depth (pressure differential), coal composition and rank, water content, natural coalseam permeability and artificial stimulation treatments undertaken. Since our wells are shallow and are each projected to cost less than $200,000 completed for production, we are willing to drill more wells and spend relatively little (or less than normal) on artificial stimulation. Also enclosed are spacing examples from the Black Warrior Basin in Alabama where the Oak Grove methane drainage site wells (figure 1) are drilled on 20 acre spacings, the Rock Creek Site (also figure 1), where the wells are drilled in an irregular pattern 100 to 300 feet apart, and the Cedar Grove Field (figure 3) where the wells are drilled on 80 acre spacings. RECEIVED APR 2 6 lgg5 Alaska Oil & Gas Cons. Commission Anchorage ., · STATE Township 18N Range 3W Seward Meridian IC, RECEIVED LAPP R~ources Inc. 4900 Sportsman Drive Anchorage, AK U.S.A. 99502-4169 Ph: 907-248-7188 Fax: 907-248-7278 APR 2 6 1995 Alaska Oil & Gas Cons. Commission Anchorage for eight of the wells; well P8 had not been brought on pro- duction prior to the end of the simulated historical period (March 31, 1992). In addition to the producing wells, gas content and pressure data from several coreholes and monitor wells are being used to validate the modeling results. All the producing wells except P1B and P1C are multiple- seam completions in the Mary Lee and Black Creek groups. The reservoir model thus was designed with two layers (Figure 2) corresponding to the Mary Lee coal group (Mary Lee and Blue Creek seam.~) and to the Black Creek coal group (A through H seams). : The 19 x 25 x 2 simulation grid was designed to include the effects of the Oak Grove Mine and the Oak Grove degasi- fication field located south of the Rock Creek site (Figure 1), resulting in the addition of ten degasification wells, three monitor wells/coreholes, and fourteen mine blocks within the simulation grid. The principal grid axis was aligned parallel to the average face cleat direction for the Mary Lee and Black Creek groups (N56°E). The second axis was aligned parallel to the butt cleat direction, which for modeling requirements was assumed to be normal to the face cleat direction. The model area measunm 2.2 miles in the face cleat direction by 2.7 miles m the butt cleat direction, representing an a_r,~ of about 3,800 ac'ms or nearly six times the area of the Rock Creek site. ROCK CREEK SITE T 18 S MODEL AREA Oak Grove Field o Origi~-q i~ltem · Wells a~gl~l 1982.85 · Corehole t, Monilor well [~ Extent of mining C~ CX,EAT i i i R6W PlC'~-...._, · / I o. OAK GROyr: I 23-WELL P^'Ci'ERN E O O I o · · · o · Figure 1. Control well locations and simulation grid orientation for the Mary Lee-Black Creek coal reservoirs at the Rod[ Creel[ project site. 22 MErHAHE FROM COAL SEAMS TECHlqOLOGY / OCTOBER 1992 RECEIYED APR 2 6 199§ Alaska 0il & (]as Cons. Commission PIP WELL SOTERRA 9-7 #1 Background Mefidian's Soterra 9-7 #1 has been producing since March 1990 and currently averages about 100 MCFD and 34 B WPD. The well appears to be producing below its potential as production-trend mapping demonstrates that offset wells in the area produce between 200 and 225 MCFD, as shown in Figure 3. In the Soterra well a thick sequence of coals totaling 35 ft is distributed among five coal groups over the interval from .- Figure 3. Production trend analysis of the Soterra 9-7 #1 well area, Cedar Cove field. Contour interval 25 MCFD. PRODUCTION LOGGING ANALYSIS Depth Total to Top CoaJ Cont.,ibul~<~ Specific Results (11) .Co~ Sequence (fi) by Interval Ten~o. Row Noise Comments GWlN g.5 No~e Nora, Very NA Equipment No~e No~e Very NA Equtpme~ 8.5 Ma~odty High High High - 11.4 Low Very NA Low Iow 6.3 Low Very NA Ve~'y Scale Low Iow Total 35.7 Laiestg~mte =110MCFD I.amst water rate = 34BPD F'~,ure 4. Production log analysis of the SOterra 9-7 #1 well, Cedm' Cove field. 52 METtVa~ FROM COAL SEAMS TECt~OLOGY / APRIL 1994 1,040 to 3,413 fi (generalized section in Figure 4). The Mary Lee, Pratt, Cobb, and Gwinn seam~ were fracture stimulated primarily with 40-lb linear gel and 20/40,mesh sand. The Black Creek group was stimulated-with a large-volume acid treatment and no sand. Gas and water rates have been essen- tially fiat over the life of the well. In general, the well appears to have been completed similar to other wells in the area, indicating that more thorough diagnosis is required to identify the subtle completion problems experienced in this well. Prediagnostic Analyses To date, three sets of prediagnostics analyses have been conducted on the Soterra well--(l) production logging, (2) zone-isolation packer (ZIP) production testing tool, and (3) downhole camera survey. The results of these prediagnos- tie analyses are discussed below. Production Logging A production log, consisting of a slim-hole temperature, flow, and noise log, was mn to establish the incremental gas and water contribution from each coal interval that was per- forated. Although the presence of scale hampered use of the spinner survey in the Mary Lee and Black Creek intervals and equipment problems precluded use of the noise log uphole in the Cobb and Gwinn, the production log nevertheless pro- vided useful information. As summarized qualitatively in Figure 4, the log showed that (1) most of the flow into the wellbore originated from the Pratt group seams; (2) gas flow from the Mary Lee interval was found to be unexpectedly low, given that it probably is the major contributor to production in this area; (3) gas flow from the Black Creek, another con- sistent group of target seams in the basin, also was found to be low; and (4) the Gwinn and Cobb seams were found to be contributing little or no gas to the wellbore. ZIP Tool To provide a more quantitative measure of gas and water production from each coal interval in the well, the GRI- sponsored ZIP tool was placed downhole for approximately 20 days. The tool's three packer elements can be inflated to isolate and measure the production contribution from individ- ual coal zones (Spafford and Schraufnagel, 1992). As shown in Figure 5, the findings confirm the inferred results of the pro- duction log mn. Most of the gas being produced originates from the Pratt seams, and a low measured gas rate comes from the combined Gwinn and Cobb seams. As similarly inferred from the production log, the Mary Lee and Black Creek seams produce relatively small volumes of gas. Camera Survey The final prediagnostic test conducted on the Soterra well was a downhole camera survey. This relatively low-cost tool provided the most valuable and enlightening information about the condition and problems with the we[~ E C E i V ED [Iii ~ Rne ~nno f~,,,-,--~--,-,- to Top ZIP ANALYSIS Productio~ Comments by Interval (Test duration 11/3-22/93) 12 MC, FO Most accurate water production data; negL water combined Gwinn/~ test 64 MCFD Primary gas zone; Iow liquid inflow dudng 1-2 BWPO 4+ hour test 24 MCFD Some difficulties wi~ mido~e pac~ec Iow 21 BWPD con6dence in water measureme~ 14 MCFD -'~ 8WPD We/I gas rate = 104 MCFD Well water rate = 52 BPD Difficulties with lower packer, Iow co,ff~mo in water measurement Figure 5. Results of ZIP tool analysis of the Soterra 9-7 #1 well, Cedar Cove field. 1. Many perforations appear unabraded, evidence that they had taken little or no sand during the hydraulic fracture treat- ment. The camera showed that these unabraded perforations contribute little or no gas or water flow into the we[It)om. 2. Several abraded perforations appear to contain coal fines, particularly in the Gwinn and Pratt coal seams, thus ef- fectively prohibiting flow into the wellbore. 3. Only one set of perforations (at 2,808 fi) in the target Mary Lee interVal appears to be well abraded and flowing gas and water. The main coal section of the Mary Lee, containing approximately 5 ft of clean coal (2,650 to 2,656 ft), shows no indication of gas or water flow. CAMERA SURVEY to Top Status of Status of (ft) Coal Sequence Perfo('ations G/W Flow GWIN Unabraded: No flow Wetl abraded: Possible 1065'; 1075'; 1086'; flow 1104'; 1143': 1355' at 1104' Unabraded: 1856'; 2035'; 214,9'; 2180' Well alxaded: 1853; 1855'; 1898'; 1910;, 1927; 1972' G/W flow No flow No flow Plugged pelfs al 1853'-1855' Per, lie Cam~m n~t run Figure 6. Flu/d-flow observations from the downhole camera APR 2 6 1995 ~aska 0ii & (las Cons' Oommir~i0n [[ , a_ _1 __ As shown in Figure 6, thc downhole camera survey identi- fied a series of problems with this well, including plugged perforations, unabraded perforations that took no frac sand, and little or no connection of the wellbore with the major coal zones, such as the Mary Lee. Upon closer examination of the survey results for the Mary Lee coal interval, as defined by bulk density (Figure 7), one sees that the upper and middle seams accepted little or no fi.ac sand and thus are currently nonproductive. Review and Diagnostics As the next step in the project, the operator (Meridian Oil) and the GRI Cona'actor Team met in December 1993 to dis- cuss the observations and findings fi.om the prediagnostics and to plan the next steps. Based on a review of the produc- tion logging, ZIP tool analysis, and camera survey (as well as a review of well records and geologic information), the group set forth several preliminary observations on the con- dition of the Soterra'well: 1. The Mary Lee, typically the principal target coalbed in this area, contributes only 24 MCFD; five sets of perforations, between 2,651 ft and 2,770 ft, appear to have accepted little or no frac fluid. However, the Mary Lee is confirmed to be gas productive in this area, producing 170 to 210 MCFD, as measured by PIP-sponsored production logging in two offset wells. 2. Black Creek group coals (acid stimulated) contribute little to gas production. Because these coals are distributed over a large interval, a separate R&D effort is recommended to address this coal sequence. The volumes of Black Creek gas produced from several offset wells were found to be Iow (<20 MCFD); however, one offset well recorded a flow rate of approximately 75 MCFD fi.om Black Creek coals. CAMERA SURVEY ANALYSIS Depth Thickness Number of Perforation Observed (fi) (fi) Perforations Coodttion Flow Density Log 2 · 3 i 1.0) £ 2650 2700 2750 28O0 10 Not abraded No flow 0 ~ - 4 Mod. at:N'aded No flow 4 Mod. abraded Noflow 6 Mod. abraded No flow 4 Not ab~alded NO fR~v 11.4 35 Figure 7. Perforation analysis results of the camera survey of the Mary Lee interval in the Soterra 9-7 #1 well, Cedar Cove field. FROM COAL SEAMS TECHNOLOGY I APRIL 1994 53 Appendix B Groundwater Quality The DGGS Report of Investigations 87-17 titled "Water-Well Data from the Houstofi Area, Matanuska-Susitna Borough, Alaska" summarizes groundwater characteristics in the Houston region as follows: Total Dissolved Solids < 1,000 mg/1 (conductivities <350its) pH Slightly above 7.0 Hardness Above 60 mg/1 (Ca, Mg and bicarbonate ions) Fresh water is f6und in most glacial sediments and in some bedrock areas down to depths of approximately 300 feet. Fresh water zones will be protected by continuous casing in the eight inch surface hole and in the five inch hole drilled to 2100 feet. The water is generally of good quality and is free of objectionable taste or odor except in TI 8N R3W Section 21 where bedrock ground water may be contaminated by adjacent septic systems, exhibiting high levels of sodium and orthophosphate, low levels of calcium and sul- fate, a pH of up to 9.4, a conductivity of 660 to 1190/.ts, and occasional rotten egg odors. The following table summarizes the existing drilling information available in the Houston region. Table 2 is from RI 87-17 and details water analyses carried out on drinking water sources in the area. · Orig O~ner Drifter Oate Depth Water Yietd Area ge[t Ntm~er ROGERS, MEL UNKNOUN 7/ 1/77 50 17 HOUSTON INN AREA SBO18-OO3-17CBBCl-1 ROGERS, HEL GIELAROUSKI dOE OR 5/ 9/85 58 36 15 SEC 17 LOT C4 SBO18-OO3-1?CHCA1-4 HILLTOP ABMHY OF GOO UNKNOUN 135 82 HOUSTON AREA SBO18-OO3-1?CCAB1-2 HILLTOP ASHBY OF GOO UNIOIOq~N 1/ 1/68 130 HOUSTON AREA SBO18-OO3-17COBC1-3 OVERBAY, ED MOON DRILLING 7/26/76 82 15 CHAPEL ON THE HILL SHO18-OO3-1?CDBC2-3 HILLTP ASHBLY OF GOO MOON DRILLING 82 SEC L-C1/PORTION OF SBO18-OO3-17COBC2-3 RICHHOND UNKNOUN 1/ 1/50 140 HOUSTON AREA SBO18-OO3-18BBCA1-4 gALLACE, WALLY PENN JERSEY DRILLI 2/ 1/77 213 HOUSTON LOOGE S8018-003-18BBCCl-5 HOUSTON INN UNKNOUN 1/ 1/6~ 150 HOUSTON AREA SBO18-OO3-180ACA1-Z ~ANION, RUBY G & G DRILLING 118 96 10 HOUSTON AREA SBO18-OO3-18DBAA1-3 US BUR MINES US BM 8/18/52 ~86 HOUSTON AREA SH018-O03-18DOABl-1 ANCH GAS & OIL ANCHOR G & 0 4260 ROSETTA 1 SB018-003-20 ANCH GAS & OIL ANCHOR G & 0 1100 ROSETTA 2 SB018-003-20 HOUSTON CITY OF DERALI DRILLING 8/ 3/8~ 35 12 HOU LANOFILL ~ELL1 SH018-O03-20AACB1-3 HOUSTON CITY OF OENALI DRILLING 8/ 3/8~ 30 HOU LANDFILL ta~LL2 SBO18-OO3-20AACB2-3 US BUR MINES US BM 1/ 1/51 /~82 471 RAT COALFIELD CH 1 S8018-O03-20ACBA1-1 US BUR MINES US BM 1/ 1/52 1142 555 RAT COALFIELD CH 2 SBO18-OO3-20BADB1-Z CAPERS, HILLY dOE GIELAROU~SI DR 10/31/8/, 40 BRYANT Lll B2 SH018-003-21 ANCH GAS & OIL ANCHOR G & 0 6109 ROSETTA 3 SB018-003-21 HOUSTON CITY OF DEHALI DRILLING 8/ ?/8~ 28 7 HOU LANDFILL HELL3 SHO18-OO3-21BBBBl-12 ANCH GAS & OIL ANCItoR G & 0 10/ 9/61 1627 ROSETTA 4 SBO18-OO3-21BCCA1-11 ANCH GAS & OIL ANCIKN~ G & o 9/24/62 2607 ROSETTA 4A SBO18-OO3-21BCCA2-11 DEHART, CALVIN ACHE DRILLING 11/20/69 85 12 HOUSTON AREA SBO18-OO3-21CACB1-3 CHURCH OF CHRIST G & G DRILLING 1965 100 18 3 HEATH HEIGHTS TR-D SBO18-OO3-21CAOC1-2 FAR N MINISTRIES INC MCr, AY UELL DRILLIN 3/18/81 137 6 HEATH HEIGHTS TR-A SBO18-OO3-21CAOD1-15 FAR N MINISTRIES INC MC~AY WELL DRILLIN 7/ 2/85 160 32 HEATH HEIGHTS TR A SBO18-OO3-21CAD02-15 CHURCH OF CHRIST . G & G ORILLING 27 11 8 HOUSTON AREA S8018-003-21C~001-1 GRAHAM, FRED FRONTIER DRILLING 12/ 8/69 141 18 3 BRYANT 1 L13 S8018-003-2100AA1-9 BRYANT SUB VLY SERV MESHEW TOHMY & SON 43 50 BRYANT L8 BZ SBO18-OO3-Z1DDAB1-14 PERKINS, RALPH HOFFITT DRILLING 1/ 1/70 30 11 BRYANT L8 SBO18-OO3-21DOAC1-8 YENTA, SHARVA GRATIOT, RICHARD 12/ 1/76 32 BRYANT 1 L1 SBO18-OO3-21DOBB1-15 GRAHAHS OUNER 1/ 1/77 28 BRYANT 1 SBO18-OO3-Z1DOBC1-6 LYONS, R 0 CLEMENTS 1/ 1/72 26 10 BRYANT 1L~ Sl1018-003-2100BC2-6 HILL/FLANNIGAN BLUE BEAR DRILLING 11/16/78 280 4.8 2 BRYANT 1 1.3 SBO18-OO3-21DDBC3-6 NELSON, RUTH CLEMENTS 1/1/74 33 12 BRYANT 1 L6 SHO18-OO3-ZIDDBD1-7 EILERTSON UNIO~ 7/ 1/7'Z 2:3 12 BRYANT 1 SBO18-OO3-ZIDDBO2-7 GLASS, PENELOPE UNKNOUN 1/ 1/69 50 20 BRYANT 1 L4 SH018-O03-21DDB03-7 BRUCE, OOg UNKNOUN 30 7 BRYANT 2 S8018-003-210DC01-10 STRASSBERG CLEHENTS 1/ 1/73 27 BRYANT Z L9 SBO18-OO3-21DDDA1-4 STRASSBERG CLEMENTS 1/ 1/73 25 4 BRYANT Z L8 SH018-O03-21DDDB1-5 NAIL, JAMES MESHEW TOMMY & SON 6/15/78 55 BRYANT 2 L8 SHO18-OO3-21DDDCl-13 PITT/BARR JR. GIELAROUSKI 6/24/8~ 8S SEC L-C11 Sa018-003-22 HOUSTON CITY OF GIELAROUSICI JOE OR 5/ 1/86 203 HOUSTON CITY HALL SBO18-OO3-Z2BCB81-10 AK OOH UNIOK~N 11/ 1/63 22 HOUSTON AREA SBO18-OO3-22CCAA1-2 WILSON, RORIND UHIOIOI~ 1/ 1/76 50 14 BRYANT AREA SB018-003-ZZCCAB1-3 MITE OWL ELEC SUPPLY UNIO4OUN 25 7 BRYANT 2 S8018-003-7~.CCCA1-6 MESHL:g, TOHI~ OUNER 175 BRYANT 2 SBO18-OO3-22CCCB1-? BRYANT, BASIL OUNER 1/ 1/58 35 7 HOUSTON LOOGE SBO18-OO3-77CCDB1-1 HOUSTON CITY HALL UNIO~ 51 ~8 HOUSTON SBO18-OO3-22CDACl-5 HOUSTON, CITY OF BLUE BEAR DRILLING 6/Z~/82 75 26 65 HOUSTON FIRE HALL S8018-003-22OOBB1-8 HOUSTON CITY OF BLUE BEAR DRILLING 5/29/81 100 25 LITTLE SU PARK SHO18-OO3-Z2.OOOB1-9 ARHSTRONG, I~ITH OUNER 1/ 1/59 28 20 HOUSTON AREA SBO18-OO~-22DDOB1-4 DOORES, LOUIS HESHEU TOI~Y 4/ 1/77 130 8 SUSITNA HEIGHTS LS g5 SH018-O03-Z~DBA01-5 SIK~TS, MICHAEL G OUNER 1/ 1/74 30 20 SUSITHA HEIGHTS L& B5 SBO18-OO3-23DBJU)2-5 DOORES, LOUIS E DAVIS I~LL DRILLIN 3/ 4/83 ]8 9 4 SUSITNA HEIGHTS L5 85 SBO18-OO3-Z~OBAD3o5 SHORTS/CHURCH FRIESEN DRILLING 10/24/8~ 100 5 16 SUSITHA HEIGHTS L4 B5 S8018-003-250BA04-5 HAYS, MICHAEL F MESHEq~ TOMMY 6/28/77 125 SUSITHA HEIGHTS L5 B6 SBO18-OO3-Z3DBOA1-2 STAN~RY, FREELON F D & E ORILLING 1/ 1/75 33 21 SUSITNA HEIGHTS LS B8 SIi018-O0~-Z~OCAC1-1 BAKER, CHUC~ O & E DRILLING 1/ 1/76 33 21 SUSITHA HEIGHTS L4 B8 TORNB~RG AR#STRONG, iCEITH 32 27 SUSITNA HEIGHTS SBO18-OO3-Z~OCJU)l-4 TORIffiERG, BRUC~ GIELAROUSKI JOE DR 8/21/85 ~8 13 20 SUSITNA HEIGHTS L6 B8 S~O18-OO3-2~OCAD2-4 Table 2. Laboratory analyses of ground water in the Houston, ^laska area. Measurements other than gross alpha are in mg/L, Gross alpha is measured in ptcocurtes perltter, Samples are Identified by section number followed by map number.. 2-3 Constituent 09-20-85 San~le locations and date 2-3a 8-2 13-18 17-3 21-2 * 21-2a 21-12a 22-1b 22-8a 22-9 25-7 26-2 EPA/c 03-19-84 09-20-85 09-26-85 09-11-85 09-11-85 06-11-85 10-06-83 08-22-69 05-21-84 09-20-85 09-26-85 09-26-85 DEC Sodium 2.07 Potassium 0.53 Hagne~tum 1.10 Calcium 4.01 Strontium 0.05 Barium < O.O01 Sulfate 1.28 Nitrate < 0.01 Phosphate < 0.01 Fluoride < O.O1 Chlortde 1.24 Bromide < 0.01 Silica 4.33 Boron 0.039 Arsenic < 0.002 Aluminum 0.034 Copper O.O21 Iron O.158 Hanganese O.O10 Lead < 0.03 Zinc 0.048 Chromium < 0.002 Selenium < 0.02 Gross Alpha < I aOEC records. bUSGS records. 260] -- 4,69 5.22 8.54 i~32 27 -- 1.12 0.68 0.87 1.28 ...... 0.59 3.1 -- 6.67 5.00 5,30 -tr 0,57-'~. -- -- 0.10 0.14 0.10 ....... -- -- < 0.05 0.01 < 0.001 0.036 < 0.001 0.010 -- -- 2.80 3.87 0.05 0.16 -- ~_14.0 \ < 0.10 < 0.01 < 0.01 < 0,01 < 0.01 < 0.5 'OT2'O" -- < 0.01 4.80 < 0.01 8.23 .... < 0.10 < 0.01 0.05 < 0,01 0.69 0.5 -- -- ,1.20 1,00 1.05 0.46 -- < 1.0 . -- < 0.01 < O,O1 < O.O1 < 0.O1 .... -- 3.47 3.89 5.63 2.00 .... -- 0,044 0.055 0.040 0.377 .... 0,002 0.012 O.O21 < 0.002 < 0.002 O.O15 -- -- 0,037 0.066 0,008 0.036 < 0.040 -- -- < O.O1 < 0.O1 < 0.01 < O.O1 0.044 -- -- O.195 0.443 -- 0.066 0.037 -- -- 0.051 - 0.096 -- < 0.005 < 0.005 < 0.05 < 0.01 < 0.03 < 0.03 < 0.03 < 0.03 < 0.005 -- -- 0.008 0.005 0.120 0.028 0.020 -- < 0.O1 < 0.002 < 0.002 < 0.002 < 0.002 < 0.005 < 0.001 < 0.02 < 0.02 < 0.02 < 0.02 < 0.002 -- -- <1 <1 <1 <1 <1 -- CDEC/EPA Public Drinking Wate~ recommended limits. -- = not determined. q.6 0.6 3.1 0.1 0.0 1.7 0.0 5.3 .. 20 -- __ 0.2q 0.02 0.00 0.03 0.24 0.02 0.01 -- 6.3 34 .q -- 1.61 -- 2.51 -- 5.61 -- 0.31 0.029 0.042 -- tr < 0.5 < 0.01 -- < 0.01 -- 0.83 -- 2.63 -- < 0.O1 -- 2.71 -- 0.075 < 0.005 < 0.002 -- 0.039 -- < 0.01 0.045 0.660 < 0.005 0.013 < 0.005 < 0.03 -- 0.272 0.008 < 0.002 < 0.002 < 0.02 <1 <1 3.58 0.86 2.01 7.89 0.12 < 0.001 1 69 <001 <001 0 04 1 20 <001 4 90 0 041 < O. 002 0.037 0,016 0.056 O. 005 < 0,03 0.943 < 0.002 < 0.02 < 1 3,16 250 0.70 -- 1.36 -- 6.87 -- 0.08 -- < 0.001 1 2.01 250 < 0.01 10 < 0.01 -- < 0.01 2.4 1.78 250 < O.01 -- 4.16 -- 0.040 -- < 0.002 0.05 0.048 -- 0.050 1 0.061 0.3 o. 007 O, 05 < 0.03 0.05 1.384 5 < 0.002 0.05 < 0.02 0.01 < 1 -- RECEIVED APR 2 6 1995 .Oil & Gas Cons. Commls.~.'- Anchoraue ,- ?,' · . REEE' '"' I -~-,-~ .....~-, ~, ~:' ~' '~ ', i ' APR 2 6 ~995 . . . ~ ~ %' ,~, . . . ~ ~ '~' ~,~' Oil & Gas Co~. ~mmission ~c~ :e '~'~'=~ : .... .': ' ~..~ :-','-... 3. = '~.",. ',, ~". ~. '0 ' ~"'i ~i', ~'~ '"" .... :'""~'.!-~ I'1~,. i l i. ......... ,~,, :' . ~ O.~, ~'-..~......] ........ '",,' .,i~ ~, .-i ,, ,, \, ,, .. · .. .. / NO~l~flOtt iLAPP Resources Inc. 4900 Sportsman Drive Anchorage, Alaska U.S.A. 99502-4169 Telephone + 1 (907) 248-7188 Facsimile + 1 (907) 248-7278 April 25, 1995 The Commissioners Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: 20 AAC 25.520 - Request for Public Hearing to Establish a New Gas Pool Dear Sirs: PLAN FOR POOL DEVELOPMENT AND OPERATIONS Drilling LAPP Resources Inc. is the sole oil and gas owner in the development area and is proposing a coalbed methane production program at Houston, Alaska to develop and produce gas known to exist in coal seams in the area (see Rosetta 1-4A well files and US Bureau of Mines R.I. 5350). We are seeking permits for six well locations and plan to drill three wells this year to 2100 feet on 40 acre spacings. Initially, a local water well contractor will drill an eight-inch diameter hole to a depth of 300 feet and at least 75 feet into bedrock using downhole hammer rig. A six-inch steel casing (possibly ERW line pipe) will be cemented in place. We are planning to use Dowell Schlumberger's coiled tubing unit with two inch coiled tubing to drill about five inch diameter open hole for the next 1800 feet to TD. Dowell's BOP system will be bolted in place for all drilling below the surface casing. The wells will be logged by Schlum- berger using standard oilfield logging tools. A 3 1/2 inch or possibly four inch jointed (flush jointed if 4 inch) tubing will be cemented in place as production casing from surface to TD using a jacking stand. Completion Depending on the results of drilling and wireline log interpretations, we will complete the wells for production at the appropriate intervals. We expect for coalbed methane production, that the producing intervals will be between 1000 and 2000 feet deep. Perforation of selected coal seams or sandstones will be carried out by standard oilfield methods. A surfactant de- signed to stimulate coalbed water production and reduce coal fines may be pumped into the coal seams at matrix (non-fraccing) rates. A downhole pump will usually be required to dewater and depressurize the coalbed and allow the gas to desorb and be produced. Progress- ing cavity pumps or jet pumps are our preferred options for these wells. Both pumps would require two additional jointed strings installed in the well. In both cases, water would be produced up the larger production tubing, and gas would be produced up the annulus. Production The wells will be tested on long-term production test until a commercial flow rate is achieved (projected to be about 200 MCFD), or until sub-economic flow rates have stabilized. If the rate is sub-economic, further operations in the well will be contemplated which may include pulse-fraccing, cavity completions, or sand-propped hydraulic fracturing. If commercial production rates are established, the testing will be completed and a gas-gathering, compres- sion, dehydration and odorizing system will be installed at a central point. [~ E ~ E IV [ D APP, 2 6 1995 Alaska 0il & Gas Cons. Commission Anchorage Produced Water Disposal Produced water will be disposed of downhole in an interval approved for disposal. One of the three wells may be used as a disposal well, or alternatively the wells may be designed to simul- taneously dispose of water and produce gas from different horizons. One of the existing deep petroleum wells in the area may also serve as a disposal well. Beaver Lakes State 1 (TD 8474') is within this lease. If fresh water is produced, permission may be sought for domestic use or surface disposal. Gas Distribution Gas distribution lines will be installed to serve residents and businesses within the Houston City Limits. A 60 psi gas transmission line will also be installed if sufficient production is established, to connect the facility with Enstar's existing low-pressure (60 psi) plastic distribu- tion system at the Houston Jr/Sr High School four miles to the south. This will allow LRI to sell gas not consumed in Houston to its major customer who has already agreed to purchase a minimum of one million cubic feet of gas per day at a specified price. This customer also has an option to accept the remainder of LRI's production from this lease at the same price. REQUEST FOR POOL ORDER We hereby request a notice of public hearing be issued, to assist in establishing the pool, clas- sified as a gasfield, which will be operated under the following rules: Pool Rules The area of the "pool" is the developed area of the lease, the coalbeds being stacked in the subsurface in discontinuous lenses from the surface to 2,100 feet depth, but are likely to be spatially present in the entire area of the lease. The section which will be drilled in our wells will be best typified by the section encountered in Rosetta 3. An AOGCC bonding requirement of $10,000 per well or $50,000 more than five wells will apply. This lower bonding requirement reflects the reduced cost of plugging and abandoning the wells in a road-accessible location. A quotation of $8,365.75 for P&A costs from Dowell Schlumberger is attached herewith. A quote from Halliburton will be supplied in the near future. These service companies are required to have their own cement mixing equipment and pumps onsite. An Operator could cement the wells, top to bottom, for about $2,000 using construction cement supplied by local ready-mix companies from Wasill. a. We suggest however that most operators acquiring the lease in future would rather have the wells suspended, rather than permanently abandoned. Even if non-productive, they are still assets and could serve as disposal wells. Drilling unit spacing for this pool shall be 40 acres and shall be subject to modification depending on the Operator's engineering, production and economic experience. Appendix A, attached, shows our proposed well spacing pattern and examples of well spacings used in other states for methane drainage projects. Wells drilled closer than 330 feet from a change in ownership require a letter of non- objection or a hearing where no objection from the adjacent owner is sustained. The requirement for diverters on the eight inch surface hole shall be waived, as it will be drilled with standard water well drilling equipment and techniques. Venting or flaring of gas will be allowed during the dewatering phase, up to the amount required to establish the commercial long-term production rate from the reservoir. RECEIVED APR 2. ro 1995 AlaSka Oil & Gas Cons. Commission l~nrhnr~n Water disposal shall be in accordance with AOGCC regulations and disposal/injection orders. The available groundwater information is summarized in Appendix B. A list showing the names of all the owners of the oil and gas rights in the 40 acre parcels di- rectly and diagonally offsetting our proposed 40 acre drilling units will be supplied soon. Sincerely, David W. Lappi President RECEIVED APR 2 6 199,5 Alaska. Oil & Gas Cons. Commission Anchorage "Wedr~'esday, April 12, 1995 05:34:I ~M Page 1 of 1 To; Lapp Resources lr~c. From' Ciiff Wiebe Date: April 12, 1995 Regarding: area. Quote to Plug and Abandon proposed Coal Bed Weiis in the Houslon As per our conversation to provide a service to plug and abandon proposed wells in the Houston AK area, Dowell is pleased to provide the following quote. This quote is based on fi!lin9 the 2100 foot wellbore to surface wi~h ceme. nt without ex*,racting the production string. Keea in mind that if the casing needs to be cut off below surface, then those digging and cutting costs are not included. Dowell Cost Estimates Item Unit # of Units S per Unit Discount Cost PACR ea I S555.00 15% S'471.75 Rersonnel ( per man per day) ea 3 $750.00 0% S2.250 00 Fluid Pump. ea 1 S1,480.00 15% $1 Batch Mixer ea 1 $3.000.00 15% $2.550 00 Cement Silo ea 1 $445 O0 15% S378 25 Air Compressor ea 1 $225.00 15% S191.25 D907 Class G Cement cuft 100 $14.90 15% $i .266 50 Total Cost estimate $8,365.75 RECEIVED APR 2 6 1995 Alaska 0ii & Gas Cons. Commission Anchorage · Legend Diomond drill hole -% o. , ~,oo ~ IFoo ~oo Figure :2. - Plan, Houston coal-drilling project. RECEIVED APR 2 6 199§ Alaska Oil & Gas Cons. Commission Anchora¢ie '10 $00 2OO IO0 - I00 -200 -500 -~,00 -500 -600 -700 -800 Collar El. 249 Collar El. 330 Collar EL 503 r ~'""~"Pit" Bed Strong ~a$ f lo~ ~ith brackish water, o O. SECTION A-/~ 2900' 'Gas 5 water 16 60' 0 5 lO0 I0,00 1500 Horizontal Scale in Feet 20CC I I ~1::::::.:::.~:~,,,,,,,:,,,',,~1~.,~-%~,.-'1~),','.',~.'~T}:':::: ::':-~::::::':: E~'~,:,.'_~ ~.'.+~;,,,?,~::~.k,',,,~,,~,~,~:~.:~:'~F~i,!,i ~::~:{::~t~+;~;~t;~-:~,:',:,~:~ ~:~:~:~:::~:~:{:~q,t,',,',','F~~{~~':L:~ o' o' o' o-' - o6 ~ 6 o-6 .~ o '6 6 6 6 ~ a 6 ~ o .-~ o ~ o ~ ~ o ~ o ~ o ~ o . . ~ .. . , ~ ~ .... ~ .. ,. .....I ~:~:;~;'i~'*;~:: .~ ~-~:f~-:~: ::.-::-,'.-. -':J:l-:-:-: ':. ,:- :~:.:-~-.,.-::~:-~::,.~[::g:~:: ~:~::~m~-~.:-:-::j.:~'~.~:,-:-~ .... ~":1 ~ 0 ~ 0 ~ 0 ~ 0 ~ Figure 3. - Section A.A' and graphic logs, Houston coal-drilling project. Appendix A Spacing Justification Our map shows the proposed 40 acre drilling units. These closer spacings are desirable for coalbed methane production since dewatering of the seams is required to reduce in-seam pres- sures and allow the gas to desorb from the coal and flow to the wellbore. The interference of the pressure drawdown between wells is desirable and speeds the onset of initial gas produc- tion. Closer spacings also allow more complete recovery of the gas resource (coal is relatively impermeable) over the life of the field. Previous drilling in the area also shows poor correla- tion of geology between similarly-spaced wells (three USBM coal coreholes and five oil explo- ration wells), caused partly by faulting and partly by the high-energy fluvial environment of deposition of the Chickaloon formation. We expect that the effective gas drainage area of our wells will be approximately 40 acres. The effective drainage area is a function of the stratigraphy, structural geology (faulting), depth (pressure differential), coal composition and rank, water content, natural coalseam permeability and artificial stimulation treatments undertaken. Since our wells are shallow and are each projected to cost less than $200,000 completed for production, we are willing to drill more wells and spend relatively little (or less than normal) on artificial stimulation. Also enclosed are spacing examples from the Black Warrior Basin in Alabama where the Oak Grove methane drainage site wells (figure 1) are drilled on 20 acre spacings, the Rock Creek Site (also figure 1), where the wells are drilled in an irregular pattern 100 to 300 feet apart, and the Cedar Grove Field (figure 3) where the wells are drilled on 80 acre spacings. RECEIVED APR 2 6 1995 Alaska Oil & Gas Cons. Commission Anchorage ,, / mc ~1 ~I(;II'I'~ - TRACT A pARKS HIGHWAY !7 {32 Tc~nship 18N Range 3W Seward Meridian Tc4 RECEIVED APR 2 6 1995 Alaska Oil & Gas Cons. Commission Anchorage LAPP Resources Inc. 4900 Sportsman Drive Anchorage, AK U.S.A. 99502-4169 Ph: 907-248-7188 Fax: 907-248-7278 for eight of the wells; well P8 had not been brought on pro- duction prior to the end of the simulated historical period (March 3 I, 1992). In addition to the producing wells, gas content and pressure data from several coreholes and monitor wells are being used to validate the modeling results. All the producing wells except P1B and P1C are multiple- seam completions in the Mary Lee and Black Creek groups. The reservoir model thus was designed with two layers (Figure 2) corresponding to the Mary Lee coal group (Mary Lee and Blue Creek seams) and to the Black Creek coal group (A through H seams). . The 19 x 25 × 2 simulation grid was designed to include the effects of the Oak Grove Mine and the Oak Grove degasi- fication field located south of the Rock Creek site (Figure 1), resulting in the addition of ten degasification wells, three monitor wells/coreholes, and fourteen mine blocks within the simulation grid. The principal grid axis was aligned parallel to the average face cleat direction for the Mary Lee and Black Creek groups (N56°E). The second axis was aligned parallel to the butt cleat direction, which for modeling requirements was assumed to be normal to the face cleat direction. The model area measures 2.2 miles in the face cleat direction by 2.7 miles in the butt cleat direction, representing an area of about 3,800 acres or nearly six times the area of the Rock Creek site. ROCK CREEK SITE T 18 S MODEL AREA Oak Grove Field o Original pattern · Wells added 1982-85 · Corehole Monitor well ~.~ Extent of mining ~ N H3~N ~ Face N56E COAt. Ct. EAT SCALE 2000 400~ F~t R6W R5W ',~ , · / I t I I o 0 I · OAK GROVE ! 23-WELL PATTERN I 0 0 0 ~0 · I · · · · · · · Figure 1. Control well locations and simulation grid orientation for the Mary Lee-Black Creek coal reservoirs at the Rock Creek project site. 22 METHANE FROM COAL SEAMS TECHNOLOGY / OCTOBER 1992 RECEIVED APR 2 6 1995 Alaska 0il & Gas Cons. Commission Anchorage PIP WELL SOTERRA 9-7 #1 Background Meridian's Soterra 9-7 #1 has been producing since March 1990 and currently averages about 100 MCFD and 34 BWPD. The well appears to be producing below its potential as production-trend mapping demonstrates that offset wells in the area produce between 200 and 225 MCFD, as shown in Figure 3. In the Soterra well a thick sequence of coals totaling 35 fi is distributed among five coal groups over the interval from _ Figure 3. Production trend analysis of the Soterra 9-7 #1 well area, Cedar Cove field. Contour interval 25 MCFD. PRODUCTION LOGGING ANALYSIS Depth Total to Top Coal Co~tdbution Specific Results (ft) Coal Sequence (fi) by Interval Temp. Flow Noise Comments GWIN 9.5 N(me None Very NA Equipment Iow problems None None Ve~ NA Equipment lew problems 8.5 Majority High High High - 11.4 Low Very NA Low Scale Iow 6.3 Low Very NA Very Scale Low Iow Total 35.7 Latest gas rate =110MCFD L~_!e~_ water rate = 34 BPD Figure 4. Production log analysis of the Soterra 9-7 #1 well, Cedar Cove field. 52 METHANE FROM COAL SEAMS TECHNOLOGY / APRIL 1994 1,040 to 3,413 ft (generalized section in Figure 4). The Mary Lee, Pratt, Cobb, and Gwinn seams were fracture stimulated primarily with 40-lb linear gel and 20/40-mesh sand. The Black Creek group was stimulated with a large-volume acid treatment and no sand. Gas and water rates have been essen- tially flat over the life of the well. In general, the well appears to have been completed similar to other wells in the area, indicating that more thorough diagnosis is required to identify the subtle completion problems experienced in this well. Prediagnostic Analyses To date, three sets of prediagnostics analyses have been conducted on the Soterra well--(l) production logging, (2) zone-isolation packer (ZIP) production testing tool, and (3) downhole camera survey. The results of these prediagnos- tic analyses are discussed below. Production Logging A production log, consisting of a slim-hole temperature, flow, and noise log, was mn to establish the incremental gas and water contribution from each coal interval that was per- forated. Although the presence of scale hampered use of the spinner survey in the Mary Lee and Black Creek intervals and equipment problems precluded use of the noise log uphole in the Cobb and Gwinn, the production log nevertheless pro- vided useful information. As summarized qualitatively in Figure 4, the log showed that (1) most of the flow into the wellbore originated from the Pratt group seams; (2) gas flow from the Mary Lee interval was found to be unexpectedly low, given that it probably is the major contributor to production in this area; (3) gas flow from the Black Creek, another con- sistent group of target seams in the basin, also was found to be low; and (4) the Gwinn and Cobb seams were found to be contributing little or no gas to the wellbore. ZIP Tool To provide a more quantitative measure of gas and water production from each coal interval in the well, the GRI- sponsored ZIP tool was placed downhole for approximately 20 days. The tool's three packer elements can be inflated to isolate and measure the production contribution from individ- ual coal zones (Spafford and Schraufnagel, 1992). As shown in Figure 5, the findings confirm the inferred results of the pro- duction log run. Most of the gas being produced originates from the Pratt seams, and a low measured gas rate comes from the combined Gwinn and Cobb seams. As similarly inferred from the production log, the Mary Lee and Black Creek seams produce relatively small volumes of gas. Camera Survey The final prediagnostic test conducted on the Soterra well was a downhole camera survey. This relatively low-cost tool provided the most valuable and enlightening information about the condition and problems with the we~ E C E ! V E D APR 2 6 1995 A~aska Oil & Gas Cons. Commission to Top (It) ZIP ANALYSIS P roductioct Comments by Interval (Test duration 11/3-22/93) 12 MCFD Most accurate water production data: negt. water combined Gwinn/Cobb test 64 MCFD Pdmary gas zone; Iow liquid inflow dudng 1-2 BWPD 4+ ho~r lest 24 MCFD Some diffmulties with middle packec, Iow 21 BWPD confidence in water measurement 14 MCFD 29 BWPD Well gas rate = 104 MCFD Well water rate = 52 BPD Difficulties with lower packer; Iow confa:leflce in water measurement Figure 5. Results of ZIP tool analysis of the Soterra 9-7 #1 well, Cedar Cove field. 1. Many perforations appear unabraded, evidence that they had taken little or no sand during the hydraulic fracture treat- ment. The camera showed that these unabraded perforations contribute little or no gas or water flow into the wellbore. 2. Several abraded perforations appear to contain coal fines, particularly in the Gwinn and Pratt coal seams, thus ef- fectively prohibiting flow into the wellbore. 3. Only one set of perforations (at 2,808 ft) in the target Mary Lee interval appears to be well abraded and flowing gas and water. The main coal section of the Mary Lee, containing approximately 5 ft of clean coal (2,650 to 2,656 ft), shows no indication of gas or water flow. CAMERA SURVEY Depth to Top Status of Status of (ft) Coal Sequence Perforations GAN Flow GWIN Unabraded: No flow 1041'; 1064' Well abraded: Possible 1065'; 1075'; 1086'; flow 1104'; 1143'; 1355' at 1104' Unabraded: 1856'; 2036'; 2149'; 2180' Well abraded: 1853'; 1855'; 1898'; 1910'; 192'P; 1972' G/W flow Plugged perfs No flow at 1853'-1855' No flow Unabraded: No flow Main May Lee 2651'; 2768' coal not pecxJucing Moderately abraded: No flow 2711'; 2715'; 2734' Well abraded: 2808' Possible P,:.s_-_~=":le (me pod gas bubbles due to cloudy water ocxtd~ons Figure 6. Fluid-flow observations from the downhole camera APR 2 6 1995 ~,laska 0il & Gas Cons. Commission As shown in Figure 6, the downhole camera survey identi- fied a series of problems with this well, including plugged perforations, unabraded perforations that took no frac sand, and little or no connection of the wellbore with the major coal zones, such as the Mary Lee. Upon closer examination of the survey results for the Mary Lee coal interval, as defined by bulk density (Figure 7), one sees that the upper and middle seams accepted little or no frac sand and thus are currently nonproductive. Review and Diagnostics As the next step in the project, the operator (Meridian Oil) and the GRI Contractor Team met in December 1993 to dis- cuss the observations and findings from the prediagnostics and to plan the next steps. Based on a review of the produc- tion logging, ZIP tool analysis, and camera survey (as well as a review of well records and geologic information), the group set forth several preliminary observations on the con- dition of the Soterra well: 1. The Mary Lee, typically the principal target coalbed in this area, contributes only 24 MCFD; five sets of perforations, between 2,651 ft and 2,770 ft, appear to have accepted little or no frac fluid. However, the Mary Lee is confirmed to be gas productive in this area, producing 170 to 210 MCFD, as measured by PIP-sponsored production logging in two offset 'wells. 2. Black Creek group coals (acid stimulated) conWibute little to gas production. Because these coals are distributed over a large interval, a separate R&D effort is recommended to address this coal sequence. The volumes of Black Creek gas produced from several offset wells were found to be low (<20 MCFD); however, one offset well recorded a flow rate of approximately 75 MCFD from Black Creek coals. SURVEY ANALYSIS CAMERA Depth Density Log Thickness Number of Perforation Observed (fi) 1 (~/F) 3 (fi) Perforations Condition Flow ~: 3.4 10 Not abraded No flow / I "} I ,14 4 uo~i~-~d~ .o.ow I '--==~=====~' I 2.5 7 Welleb~aded O~eperf To~l 11.4 35 Figure 7. Perforation analysis results of the camera survey of the Mary Lee interval in the Soterra 9-7 #I well, Cedar Cove field. METHANE FROM COAL SEAMS TECHNOLOGY / APRIL 1994 53 Appendix B Groundwater Quality The DGGS Report of Investigations 87-17 titled "Water-Well Data from the Houston Area, Matanuska-Susitna Borough, Alaska" summarizes groundwater characteristics in the Houston region as follows: Total Dissolved Solids < 1,000 mg/1 (conductivities <350frs) pH Slightly above 7.0 Hardness Above 60 mg/1 (Ca, Mg and bicarbonate ions) Fresh water is found in most glacial sediments and in some bedrock areas down to depths of approximately 300 feet. Fresh water zones will be protected by continuous casing in the eight inch surface hole and in the five inch hole drilled to 2100 feet. The water is generally of good quality and is free of objectionable taste or odor except in T18N R3W Section 21 where bedrock ground water may be contaminated by adjacent septic systems, exhibiting high levels of sodium and orthophosphate, low levels of calcium and sul- fate, a pH of up to 9.4, a conductivity of 660 to 1190frs, and occasional rotten egg odors. The following table summarizes the existing drilling information available in the Houston region. Table 2 is from RI 87-17 and details water analyses carded out on drinking water sources in the area. RE££1V[r Gas ,Cons. 'Ancli0ra.t.'~0 Orig O~ner Driller Date Depth Water Yield Area ~ett Nt~lber ROGERS, MEL UNKNOWN 7/ 1/77 50 17 HOUSTON INH AREA SBO18-OOS-17CBBCl-1 ROGERS, HEL GIELAROWSKI JOE DR 5/ 9/85 58 36 15 SEC 17 LOT C4 SBO18-OO3-17CBCA1-4 HILLTOP ASHBY OF GOO UNKNOUfl 135 82 HOUSTON AREA SBO18-OO3-1?CCAB1-Z HILLTOP ASHBY OF GOO UNKNOWN 1/ 1/68 130 HOUSTON AREA SBO18-OO3-17CDBC1-3 OVERBAY, ED NOON DRILLING 7/26/76 82 15 CHAPEL ON THE HILL SBO18-OO3-17CDBC2-3 HILLTP ASHBLY OF GOO MOON DRILLING 82 SEC L-C1/PORTION OF SBO18-OO3-17CDBC2-3 RICHHOND UNKNOWN 1/ 1/50 140 HOUSTON AREA SBO18-OOS-18BBCA1-4 WALLACE, WALLY PENN JERSEY DRILLI 2/ 1/77 213 HOUSTON LOOGE SBO18-OOS-18BBCC1-5 HOUSTON INN UNKNOWN 1/ 1/64 150 HOUSTON AREA SBO18-OOS-18DACAl-2 HANION, RUBY G & G DRILLING 118 96 10 HOUSTON AREA SBO18-OO3-18OBAA1-3 US BUR MINES US BM 8/18/52 386 HOUSTON AREA SBO18-OO3-18DDAB1-1 ANCH GAS & OIL ANCHOR G & 0 4260 ROSETTA 1 SB018-003-20 ANCH GAS & OIL ANCHOR G & 0 1100 ROSETTA 2 SB018-003-20 HOUSTON CITY OF DENALI DRILLING 8/ 3/84 35 12 HOU LANDFILL WELL1 SBO18-OO3-20AACB1-3 HOUSTON CITY OF DENAL! DRILLING 8/ 3/84 30 HOU LANDFILL WELL2 SBO18-OO3-20AACB2-3 US BUR MINES US BM 1/ 1/51 482 471 HAT COALFIELD CH 1 SBO18-OO3-20ACBA1-1 US BUR MINES US BM 1/ 1/52 1142 555 MAT COALFIELD CH 2 SBO18-OOS-20BADB1-2 CAPERS, BILLY JOE GIELAROWKSI DR 10/31/84 40 BRYANT Lll B2 SB018-003-21 ANCH GAS & OIL ANCHOR G & 0 6109 ROSETTA 3 SB018-003-21 HOUSTON CITY OF DENALI DRILLING 8/ 7/86 28 7 HOU LANDFILL WELL3 SBO18-OO3-21BBBB1-12 ANCH GAS & OIL ANCHOR G & 0 10/ 9/61 1627 ROSETTA 4 SBO18-OO3-Z1BCCAl-11 ANCH GAS & OIL ANCHOR G & 0 9/24/62 2407 ROSETTA 4A SBO18-OO3-21BCCA2-11 DEHART, CALVIN ACME ORILLING 11/20/69 85 12 HOUSTON AREA SBO18-OOS-21CACB1-3 CHURCH OF CHRIST G & G DRILLING 1965 100 18 3 HEATH HEIGHTS TR-O SBO18-OO3-21CADC1-2 FAR N MINISTRIES INC MCKAY U~LL DRILL[N 3/18/81 137 6 HEATH HEIGHTS TR-A SBO18-OO3-ZICADD1-15 FAR N MINISTRIES INC MCICAY ~ELL DRILLIN 7/ 2/85 160 32 HEATH HEIGHTS TR A SBO18-OO3-21CADD2-15 CHURCH OF CHRIST G & G DRILLING 27 11 8 HOUSTON AREA SBO18-OO3-21CBDDl-1 GRAHAM, FRED FRONTIER DRILLING 12/ 8/69 141 18 3 BRYANT 1 L13 SBO18-OO3-21DDAA1-9 BRYANT SUB VLY SERV HESHEW TCI~Y & SON 43 50 BRYANT L8 B2 SBO18-OO3-21DDAB1-14 PERKINS, RALPH HOFFITT DRILLING 1/ 1/70 30 11 BRYANT L8 SBO18-OO3-21DDAC1-8 VENTA, SHARVA GRATIOT, RICHARD 12/ 1/76 32 BRYANT 1 L1 SBO18-OOS-21DOBBl-15 GRAHAMS OUNER 1/ 1/77 28 BRYANT 1 SBO18-OOS-21DOBCl-6 LYONS, R 0 CLEHENTS 1/ 1/72 26 10 BRYANT 1 L3 SBO18-OOS-21DDBC2-6 HILL/FLANNIGAN BLUE BEAR ORILLING 11/16/78 280 48 2 BRYANT 1 L3 SBO18-OOS-21DDBCS-6 NELSON, RUTH CLEMENTS 1/ 1/74 33 12 BRYANT 1 L6 SBO18-OOS-21DOBD1-7 EILERTSON UNKNO~ 7/ 1/72 23 12 BRYANT 1 SBO18-OO3-21DDB02~7 GLASS, PENELOPE UNKNOUN 1/ 1/69 50 20 BRYANT 1 L4 SBO18-OO3-210DBD3-7 BRUCE, DON UNKNObli 30 7 BRYANT 2 SBO18-OOS-210DCD1-lO STRASSBERG CLEMENTS 1/ 1/73 27 BRYANT 2 L9 SBO18-OO3-21DDDAl-4 STRASSBERG CLEMENTS 1/ 1/73 25 4 BRYANT 2 L8 SBO1B-OO3-21DODB1-5 NAIL, JAMES MESHEW TOMMY & SON 6/15/78 55 BRYANT 2 L8 SBO18-OO3-21DDDCl-13 PITT/BARR JR. G[ELAROUSK[ 6/24/84 85 SEC L-C11 5B018-003-22 HOUSTON CITY OF GIELAR(]~/SKI JOE DR 5/ 1/86 203 HOUSTON CITY HALL SBO18-OO3-22BCBB1-lO AK DON UNKNO~ 11/ 1/63 22 HOUSTON AREA SBO18-OO3-22CCAA1-2 WILSON, ROBIND UNKNOUN 1/ 1/76 50 14 BRYANT AREA SBO18-OO3-22CCAB1-3 MITE OUL ELEC SUPPLY UNKNO~ 25 ? BRYANT 2 SBO18-OO3-ZZCCCA1-6 MESHEU, TOI~MY CRalER 175 BRYANT 2 SBO18-OO3-22CCCB1-7 BRYANT, BASIL OUNER 1/ 1/58 35 7 HOUSTON LOOGE SBO18-OOS-22CCDBl-1 HOUSTON CITY HALL UNKNOUN 51 48 HOUSTON SBO18-OOS-22OOAC1-5 HOUSTON, CITY OF BLUE BEAR DRILLING 6/23/82 75 26 65 HOUSTON FIRE HALL SBO18-OOS-22CDBB1-8 HOUSTON CITY OF BLUE BEAR DRILLING 5/29/81 100 25 LITTLE SU PARK SBO18-OOS-22CDDB1-9 ARMSTRONG, KEITH OUNER 1/ 1/59 28 20 HOUSTON AREA SBO18-OOS-22DDDB1-4 DOORES, LOUIS MESHEW TOMMY &/ 1/77 130 8 SUSITNA HEIGHTS L5 B5 SBO18-OOS-23DBA01-5 SHORTS, MICHAEL G CR4NER 1/ 1/74 30 20 SUSITNA HEIGHTS L4 B5 SBO18-OOS-23DBAD2-5 DOORES, LOUIS E DAVIS WELL DRILLIN 3/ 4/83 38 9 4 SUSITNA HEIGHTS L5 B5 SBO18-OO3-230BA03-5 SHORTS/CHURCH FRIESEN DRILLING 10/24/8:3 100 5 16 SUSlTNA HEIGHTS L4 B5 SBO18-OO3-23DBAD4-5 HAYS, MICHAEL F HESHEW T(]I4MY 6/28/77 125 SUSITNA HEIGHTS L5 B6 SBO18-OO3-230BOA1-2 SIANBERRY, FREELON F 0 & E DRILLING 1/ 1/75 33 21 SUSITNA HEIGHTS L5 B8 SBO18-OO3-Z3DCAC1-1 BAKER, CHUCK 0 & E ORILLING 1/ 1/76 33 21 SUSITNA HEIGHTS L& 118 SBO18-OO3-ZSDCAC2-1 TOR#BERG ARMSTRONG, KEITH 32 27 SUSITNA HEIGHTS SBO18-OO3-23DCAD1-& TORHBERG, BRUCE GIELARO~SKI JOE OR 8/21/85 48 13 20 SUSITNA HEIGHTS L6 B8 SBO18-OO3-231)CAD2-4 Table 2. Laboratory analyses of ground water in the Houston, Alaska area. Measurements other than gross alpha are in mg/L. Gross alpha is measured in ptcocuries perliter, Samples are identified by section number followed by map number. Sample locations and date 2-3 2-3a 8-2 13-18 17-3 21-2 21-2a Constituent 09-20-85 03-19-84 09-20-85 09-26-85 09-11-85 09-11-85 06-11-85 a 1b 21-12 22- 22-8a 22-9 25-7 26-2 EPA/c 10-06-83 08-22-69 05-21-84 09-20-85 09-26-85 09-26-85 DEC I I Sodium 2.07 -- 4.69 5.22 8.54 ~ 260'[ 27 4.6 6.3 34.4 3.58 3.16 250 Potassium 0.53 -- 1.12 0.68 0.87 1.~8 ....... 0;5~~ 3.1 0.6 -- 1.61 0.86 0.70 -- -. Magnesium 1 .lC -- 1.47 1.68 1.47 0.69 0.30 ~'~5'~'' 3.1 -- 2.51 2.01 1 .36 - -0.'57-', -- {~3 -- 5.61 7.89 6.87 -- Calcium 4,01 -- 6,67 5,00 5,30 ~,~tr ~-- . Strontium 0,05 -- 0,10 0,14 0,10 0,01 ........ __.L--' .-- 0'1 '' 0,31 0,12 0,08 --' '-- 0.1 0.029 0.042 < 0.001 < 0,001 1 Barium < 0,001 < 0,05 0,01 < 0,001 0,036 < 0,001 0,010 ~'1' '~ tr 1,69 2,01 250 Sulfate 1.28 -- 2.80 3.87 0.05 0.16 -- 41~ 0.0 -- Nitrate < 0.01 < O.lO < O.O1 < 0.01 < 0.01 < 0.01 < 0.5 '"'O~2(F' 1.7 < 0.5 < O.O1 < 0.01 < 0.01 l0 Phosphate < O.O1 -- < O.O1 4.80 < 0.01 8.23 ........ < 0.01 < O.O1 < O.O1 -- Fluoride < O.O1 < O.lO < 0.01 0.05 < 0.01 0.69 0.5 -- 0.0 -- 0.83 0.04 < O.O1 2.4 Chloride 1.24 -- 1.20 1.00 1.05 0.46 -- < 1.O 5.3 -- 2.63 1.20 1.78 250 Bromide < 0.01 -- < 0.01 < 0.01 < O.O1 < 0.01 ........ < 0.01 < O,O1 < O.O1 -- 5il ica 4.33 -- 3.47 3.89 5.63 2.00 .... 20 -- 2.71 4,90 4.16 -- Boron 0.039 -- 0.044 0.055 0.040 0.377 ........ 0.075 0.041 0.040 - - Arsenic < 0.002 0.002 0.012 0.021 < 0.002 < 0.002 0.015 .... < 0.005 < 0.002 < 0.002 < 0.002 0.05 Aluminum 0.034 -- 0.037 0.066 0.008 0.036 < 0.040 ...... 0.039 0.037 0.048 -- Copper 0.021 -- < O.O1 < 0.01 < O.O1 < O.O1 0.044 -- 0.24 -- < O.O1 0.016 0.050 1 Iron 0.158 -- 0.195 0.443 -- 0.066 0.037 -- 0.02 0.045 0.660 0.056 0.061 0.3 Manganese 0.010 -- 0.051 0.096 -- < 0.005 < 0.005 < 0.05 0.00 < 0.005 0.013 0.005 0.007 0.05 Lead < 0.03 < O.O1 < 0.03 < 0.05 < 0.03 < 0.05 < 0.005 -- 0.03 < 0.005 < 0.03 < 0.03 < 0.03 0.05 Zinc 0.048 -- 0.008 0.005 0.120 0.028 0.020 -- 0.24 -- 0.272 0.943 1,384 5 Chromium < 0,002 < 0,01 < 0,002 < 0,002 < 0,002 < 0,002 < 0,005 -- 0.02 0,008 < 0.002 < 0,002 < 0.002 0.05 Selenium < 0,02 < 0,001 < 0,02 < 0,02 < 0.02 < 0,02 < 0.002 -- 0,01 < 0,002 < 0.02 < 0,02 < 0.02 0,01 Gross Alpha < I -- < 1 < 1 < I < 1 < I .... < 1 < 1 < 1 < 1 -- aDEC records. busGs records. CDEC/EPA Public Drinking Wate~ recommended limits. -- = not determined. RECEIVED APR 2 6 1995 Oil & Gas Cons. Anchora~j'a co 0 . ' 'X Oil & Gas ConLs. Commission ~ni!ho;ra! e NOJ,SflOH ........... .. MAR-21-'gS TUE 12:37 ID:LAPP RESOURCES INC TEL NO:i 987 24@ 7~?@ ~ 20° l~ff Alaska Oil and Oas Conservation Commission 3~01 Pareupinm Drive AnOh0rlt~, AK ~.~01 Atta: The Commisdoners 1~: Cl~ll~t~tion of Coalbed Methane Wells for DBC Purth~ to my oonvor~ation with Russell Douglas la.q F~d~y, l ~e4n~t t~at the A~CC w~e a l~r ~ sawn of my ~gfion ~at L~I's pro,sM ~dlli~g program in the Housm~ ~as d~opm~t ..... ~d pr~uc~on program, not ~ explora~.d~llin~ p~o?am~ ?d taererore would Rot ~ut~ ~ Off Spill PrevenUon ~d ~on~geaC. y ~1~ ~ no~ ~e ~it~j~t ~ a .. $1,~,~ D~C bond. Mr. K~ Rogows~ ~l~ ~.D~C.~out~e~tral ~g~s~ omce ms~ . cus~ ~ Wi~ m~ on Friday, 3/17/95, and lnd~C~t~ tna~ ms omce woul0 m)y to rome on ~e o!assifl~tion that AO~CC gave the well, exth~ exploration or pr~uction. C~k Inlet ~ ~s is g~n~ly not found in producible quan6ties at depths above 3~ ~~h &o Nik0'~ Cr~k fioldpmdu~ for a shot: time at 1035 f~t ~om the.~og~ forma- lin. Oil pr~uc~on in C~k lnlgt has historically ~so b~n from d?~r th~,}~ f~!~ a~ ~ 8w~son ~v~ field produ~ from the S~rhng ~rmau0n' as snmiow as 2s'/v ~eet. Oil ~ C~k Inlet is u~u~ly found bgtw~n depths of 4~ W 120~ Our pro~s~ w~lls, dfill~ to only 2100 f~t, follow thc AK-94CBM-1 w~l drill~ ~y a~ ~s~[a last spring, wh~c ~ ~mplcs wcrc r~ove~ ~d dcgass~ ov~ a ~n~ ot- mon~s, yi~din~ a~u~'a~ iai ~ntepts of thc ~oE s~s for th~ first tlme. Tho S~to's well about ~ ~t depth, to 24~ cubi~ f~t pc~' ton at about 1240 f~t (s~ onclo~ ~ loi). Our ~r~-wal drillin~ pro,ram will bc col~duc~ in ~ ar~ w~h has.~5 fiv~ ].eum ~vl0~fion wells, ~d thru.U. ~, Bureau of Min~s corehol~s dnll~ duBn~ th~ mxddlc to la~ 19~s. De~i~ aC ~pl~aflon wells' obj~tivi ur fmdbit ~omm=rci~ oil p~ucfl0n ~hich ~d bo ~s~ by ral to.m~ke~, none was ~?ozer~.' Oas.shows w=~ dufin{ ~ dflHing, ~d one dnll stem lest su~ossluiiy liow~ ~as .om a m~l ,~s~oir, uu~ the ~ was not ~nomic ~d ~here was no pip~ine sys~m in pla~ t~ u~s~rt tho ~as m~ts, T~ risk of finding oil du~ng our s~allow dfillint protram m U~c ~ous~n ~'~ ~s vcxy 10w. ~ in}~pd to test-produce coalb~ methane from ~he gassy coal s~ms d~vur~ during pr~ious drilling to deiermine the ~onomics of ~a~ methane production.' ~ ~e ~dressint ~e incr~s~ ~sts associa~ with co~b~ methan~ p~uc~on (s~mulatlon, pumping, wa~r dis~) by designin~ our w~lls to bu drill~, ~mpW~, stimulate, ~uipp~ ~d p~u~ at low cost. Our drill ates are n~r ~ds, a~trical power lines, ~n~i~ cus- ~m~s ~d tho gas pi~line network. An AOOCC classificagon of "pr~uction well" would h~lp r~uce our D~C regulaW~ costs. David W. l..~ppi President "' Exploration and Development 6 ?. 8 9/10 11 12 Legend L_~ Coal ~ Silts~one and mudst~ne ~ Sandstone ~ Conglomerate t..33,..=~'.~..~1 Glacial deposits Gas (DAF) Iridium Ash Volatile Matter crn'!gram scl/ton % % RfC IV D Alaska 0jJ & Gas Cons. Anchorage 1.96 $3 9.02 8.47 33 4.14 132 7.13 19_60 32.78 4.99 160 7.43 11 .BI] :34.3~ 5.31 17(~ 7.96 8.26 34.55 5.1 $ 165 5.06 49.80 21.93 F'~ed Carbon Ro % % 48.71 40.49 0.48 5.54 177 6.02 14.30 33.84 4.42 141 6.15 26.64 29.47 5.94 190 7.17 5.57 37.51) 5.10 163 6.25 14.E2 35.11} 5.73 183 5.5~ 40.18 23.42 5.7~ t83 5.23 44.74 22.85 13 7.66 245 4.82 42.00 30.15 49.23 0.47 2321 -493 37.54 -~7.0 49.76 O.52 43.95 30.87' 27.18 0,58 -43.3 23.03 O~ -44.0 F '-o -o ITl ~] ITl U-J I-ri F- ]~ig~rc 9. Coal ana]yscs for AK-94CBM- 1.