2nd Engrossment - 83rd Legislature (2003 - 2004) Posted on 12/15/2009 12:00am
1.1 A bill for an act 1.2 relating to energy; modifying provisions relating to 1.3 radioactive waste management and renewable energy; 1.4 amending Minnesota Statutes 2002, sections 116C.71, 1.5 subdivision 7; 116C.779; 216B.1645, subdivision 2; 1.6 216B.2424, subdivisions 5, 6, 8, by adding a 1.7 subdivision; 216C.052, subdivision 1; proposing coding 1.8 for new law in Minnesota Statutes, chapters 116C; 1.9 216B; repealing Minnesota Statutes 2002, section 1.10 216B.2411. 1.11 BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF MINNESOTA: 1.12 Section 1. Minnesota Statutes 2002, section 116C.71, 1.13 subdivision 7, is amended to read: 1.14 Subd. 7. [RADIOACTIVE WASTE MANAGEMENT FACILITY.] 1.15 "Radioactive waste management facility" means a geographic site, 1.16 including buildings, structures, and equipment in or upon which 1.17 radioactive waste is retrievably or irretrievably disposed by 1.18 burial in soil or permanently stored. An independent spent fuel 1.19 storage installation located on the site of a Minnesota nuclear 1.20 generation facility for dry cask storage of spent nuclear fuel 1.21 generated solely by that facility is not a radioactive waste 1.22 management facility. 1.23 Sec. 2. Minnesota Statutes 2002, section 116C.779, is 1.24 amended to read: 1.25 116C.779 [FUNDING FOR RENEWABLE DEVELOPMENT.] 1.26 Subdivision 1. [APPLICABILITY.] This section applies only 1.27 to any 17 casks filled and placed at the Prairie Island 1.28 independent spent fuel storage installation. 2.1 Subd. 2. [RENEWABLE DEVELOPMENT FUND.] (a) The public 2.2 utility that
operatesowns the Prairie Island nuclear generating 2.3 plant must transfer to a renewable development account $500,000 2.4 each year for each dry cask containing spent fuel that is 2.5 located at the independent spent fuel storage installation at 2.6 Prairie Island after January 1, 1999. The fund transfer must be 2.7 made if waste is stored in a cask for any part of a year. 2.8 (b) Funds in the account may be expended only 2.9 for development of renewable energy sources.: 2.10 (1) payments, not to exceed $2,500,000 annually, by the 2.11 public utility under a settlement agreement with the Mdewakanton 2.12 Dakota Tribal Council at Prairie Island, a federally recognized 2.13 Indian tribe, for resolving outstanding disputes and to be used 2.14 for, among other purposes, acquiring land in the state of 2.15 Minnesota for placement in trust; and 2.16 (2) Preference must be given todevelopment of renewable 2.17 energy source projects located within the state. 2.18 Payments from the fund in any year shall first be made to 2.19 satisfy the terms of the settlement agreement described in 2.20 clause (1). No more than a total of $25,000,000 may be spent 2.21 from this account for payments by the public utility to the 2.22 Mdewakanton Dakota Tribal Council. Only those projects that 2.23 have a direct benefit to Minnesota citizens may be funded under 2.24 this section. 2.25 (b)(c) Expenditures from the account for the purposes of 2.26 paragraph (b), clause (2), may only be made after approval by 2.27 order of the public utilities commission upon a petition by the 2.28 public utility. 2.29 (d) Of the amount required to be spent annually from this 2.30 account: 2.31 (1) up to 25 percent each year must be spent for production 2.32 incentives for small wind energy facilities, and production 2.33 incentives under this section must not exceed 1.5 cents per 2.34 kilowatt-hour for a period not greater than ten years; and 2.35 (2) up to 25 percent a year may be used to provide low- or 2.36 no-interest loans, grants, or other financial means to reduce 3.1 the capital costs for the construction of small wind energy 3.2 facilities. Capital assistance awards under this clause may be 3.3 coordinated through nonprofit entities that provide financial 3.4 assistance to rural areas, such as designated federal economic 3.5 development districts. 3.6 (e) For the purposes of this section, "small wind energy 3.7 facility" means a wind energy facility, or group of facilities, 3.8 with a nameplate capacity of two megawatts or less that: 3.9 (1) is owned by one or more natural persons who are 3.10 residents of Minnesota and who own or rent the land where the 3.11 facility is sited or is owned by a Minnesota school district; 3.12 (2) is not enrolled in the renewable energy production 3.13 incentive program under section 216C.41; and 3.14 (3) begins generating electricity after June 30, 2003. 3.15 Sec. 3. [116C.83] [AUTHORIZATION FOR ADDITIONAL DRY CASK 3.16 STORAGE.] 3.17 Subdivision 1. [AUTHORIZATION.] (a) Subject to the cask 3.18 storage limits of the federal license for the independent spent 3.19 fuel storage installation at Prairie Island, the public utility 3.20 that owns the Prairie Island nuclear generation plant has 3.21 authorization without additional administrative review for 3.22 sufficient dry cask storage capacity at that installation to 3.23 allow: 3.24 (1) the unit 1 reactor at Prairie Island to operate until 3.25 the end of its current license in 2013; and 3.26 (2) the unit 2 reactor at Prairie Island to operate until 3.27 the end of its current license in 2014. 3.28 (b) Notwithstanding any law to the contrary: 3.29 (1) except as provided in subdivision 2, authorization of 3.30 any future nuclear storage facility or dry casks at either 3.31 nuclear generation facility in this state beyond the capacity 3.32 authorized in paragraph (a) and the facility and capacity 3.33 authorized in Laws 1994, chapter 641, is limited to approval by 3.34 the public utilities commission pursuant to section 216B.243 and 3.35 the commission's certificate of need rules; 3.36 (2) in any proceeding pursuant to clause (1), the 4.1 commission may make a decision that could result in a shut-down 4.2 of a nuclear generation facility; and 4.3 (3) the storage of spent nuclear fuel in the pool and in 4.4 dry casks at the Prairie Island nuclear generating plant must be 4.5 managed to facilitate the shipment of waste out of state to a 4.6 permanent or interim storage facility as soon as feasible in a 4.7 manner that allows the continued operation of the plant 4.8 consistent with sections 116C.71 to 116C.83 and 216B.1645, 4.9 subdivision 2. 4.10 (c) The authorization for storage capacity pursuant to 4.11 paragraphs (a) and (b) is limited to the storage of spent 4.12 nuclear fuel generated by a Minnesota nuclear generation 4.13 facility and stored on the site of that facility. 4.14 (d) The authority granted to the public utility in 4.15 paragraphs (a) and (b) is contingent on the public utility 4.16 maintaining the headquarters for the corporation in Minnesota. 4.17 If the corporation moves its headquarters outside the state, the 4.18 public utility must seek and receive express legislative 4.19 authorization for any additional storage of spent nuclear fuel. 4.20 Subd. 2. [ENVIRONMENTAL REVIEW AND PROTECTION.] (a) The 4.21 siting, construction, and operation of an independent spent fuel 4.22 storage installation located on the site of a Minnesota 4.23 generation facility for dry cask storage of spent nuclear fuel 4.24 generated solely by that facility is subject to all 4.25 environmental review and protection provisions of chapters 115, 4.26 115B, 116, 116B, 116C, 116D, and 216B and rules associated with 4.27 those chapters, except those statutes and rules that apply 4.28 specifically to a radioactive waste management facility as 4.29 defined in section 116C.71, subdivision 7. 4.30 (b) An environmental impact statement is required under 4.31 chapter 116D for a proposal to construct and operate a new or 4.32 expanded independent spent fuel storage installation. The 4.33 environmental quality board shall be the responsible 4.34 governmental unit for the environmental impact statement. Prior 4.35 to finding the statement adequate, the board must find that the 4.36 applicant has demonstrated that the facility is designed to 5.1 provide a reasonable expectation that the operation of the 5.2 facility will not result in groundwater contamination in excess 5.3 of the standards established in section 116C.76, subdivision 1, 5.4 clauses (1) to (3). 5.5 Sec. 4. Minnesota Statutes 2002, section 216B.1645, 5.6 subdivision 2, is amended to read: 5.7 Subd. 2. [COST RECOVERY.] The expenses incurred by the 5.8 utility over the duration of the approved contract or useful 5.9 life of the investment and expenditures made pursuant to section 5.10 116C.779 and expenditures under an agreement with the 5.11 Mdewakanton Dakota Tribal Council at Prairie Island regarding 5.12 the provisions of Laws 1994, chapter 641, article 1, section 4, 5.13 to the extent that funds collected pursuant to section 116C.779 5.14 in any given year are insufficient to cover these settlement 5.15 costs, shall be recoverable from the ratepayers of the utility, 5.16 to the extent they are not offset by utility revenues 5.17 attributable to the contracts, investments, or expenditures. 5.18 Upon petition by a public utility, the commission shall approve 5.19 or approve as modified a rate schedule providing for the 5.20 automatic adjustment of charges to recover the expenses or costs 5.21 approved by the commission, which, in the case of transmission 5.22 expenditures, are limited to the portion of actual transmission 5.23 costs that are directly allocable to the need to transmit power 5.24 from the renewable sources of energy. The commission may not 5.25 approve recovery of the costs for that portion of the power 5.26 generated from sources governed by this section that the utility 5.27 sells into the wholesale market. 5.28 Sec. 5. [216B.2412] [SUSTAINABLE ENERGY PROJECTS.] 5.29 Subdivision 1. [DEFINITIONS.] (a) For the purposes of this 5.30 section, the terms defined in this subdivision and section 5.31 216B.241, subdivision 1, have the meanings given them. 5.32 (b) "Energy utility" means any public utility, cooperative 5.33 electric association, or municipality subject to section 5.34 216B.241. 5.35 (c) "Sustainable energy sources" means fuels and 5.36 technologies to generate electricity through the use of any of 6.1 the following resources: 6.2 (1) wind; 6.3 (2) hydrogen, provided that after January 1, 2010, the 6.4 hydrogen must be generated from the resources listed in this 6.5 paragraph; 6.6 (3) solar; 6.7 (4) geothermal; 6.8 (5) hydroelectric with a capacity of less than 60 6.9 megawatts; 6.10 (6) biomass; 6.11 (7) landfill gas; and 6.12 (8) refuse derived fuel and solid waste. 6.13 (d) "Biomass" includes: 6.14 (1) methane or other combustible gases derived from the 6.15 processing of plant or animal material; 6.16 (2) alternative fuels derived from soybean and other 6.17 agricultural plant oils or animal fats; 6.18 (3) combustion of barley hulls, corn, soy-based products, 6.19 or other agricultural products; and 6.20 (4) wood residue from the wood products industry in 6.21 Minnesota, or other wood products, such as short-rotation woody 6.22 or fibrous agricultural crops. 6.23 (e) "Sustainable energy project" is a project to either 6.24 conduct research into the development of sustainable energy 6.25 sources and technologies or to deploy technologies in Minnesota 6.26 that utilize sustainable energy sources in: (1) a distributed 6.27 generation facility with an interconnected capacity of ten 6.28 megawatts or less; (2) a combined heat and power generation 6.29 facility; (3) a district energy system; or (4) other facility or 6.30 application consistent with the commissioner's order under 6.31 subdivision 6. 6.32 Subd. 2. [SUSTAINABLE ENERGY RESEARCH.] (a) An energy 6.33 utility shall spend five percent of the total amount that 6.34 utility is required to spend under section 216B.241 to support 6.35 basic and applied research at the University of Minnesota for 6.36 the development of the sustainable energy sources and 7.1 technologies listed in subdivision 1, paragraph (c), clauses 7.2 (2), (3), and (6). The University of Minnesota shall ensure 7.3 that at least 25 percent of funds spent under this section are 7.4 available for basic and applied research at least one rural 7.5 campus or experiment station. 7.6 (b) Research funded under this subdivision must have a 7.7 direct benefit to Minnesota. Research funded under paragraph 7.8 (a) may focus on hydrogen, solar, and biomass and: 7.9 (1) conversion of state wind resources to hydrogen for 7.10 energy storage and transportation to areas of energy demand; 7.11 (2) improvement of scalable hydrogen fuel cells for 7.12 stationary combined electricity generation and heating/cooling 7.13 function for residential and commercial use; and 7.14 (3) processing of agricultural and forestry products for 7.15 production of hydrogen and other fuels and sequestration of 7.16 carbon using a variety of means, including biocatalysis and 7.17 fermentation. 7.18 (c) An energy utility may spend up to an additional five 7.19 percent of the total amount that utility is required to spend 7.20 under section 216B.241 on research for the development of the 7.21 sustainable energy sources and technologies listed in 7.22 subdivision 1, paragraph (c), clauses (2), (3), and (6), in a 7.23 research project consistent with determinations made by the 7.24 commissioner pursuant to subdivision 6. 7.25 Subd. 3. [DEPLOYMENT OF SUSTAINABLE ENERGY SOURCES.] (a) 7.26 An energy utility shall spend ten percent, and may spend up to 7.27 25 percent, of the total amount that utility is required to 7.28 spend under section 216B.241 for the deployment of technologies 7.29 that use sustainable energy sources. Funds under this section 7.30 may also be used for incentives to convert existing Minnesota 7.31 generation facilities to use sustainable energy sources, either 7.32 exclusively or in conjunction with other fuels. Expenditures 7.33 under this subdivision must be consistent with the determination 7.34 of the commissioner pursuant to subdivision 6. 7.35 (b) Electricity generated using a renewable energy resource 7.36 may be counted toward the renewable energy objectives in section 8.1 216B.1691. For a generation facility that utilizes a 8.2 sustainable energy source based on the combustion of fuel, 8.3 electricity produced by the facility may only count toward an 8.4 electric utility's renewable energy objectives if the facility: 8.5 (1) was constructed in compliance with new source 8.6 performance standards promulgated under the federal Clean Air 8.7 Act for a generation facility of that type; or 8.8 (2) employs the maximum achievable or best available 8.9 control technology available for a generation facility of that 8.10 type identified by the federal Environmental Protection Agency 8.11 pursuant to the federal Clean Air Act. 8.12 (c) A sustainable energy source listed in subdivision 1 may 8.13 be blended or co-fired with other fuels in the generation 8.14 facility, but only the percentage of electricity that is 8.15 attributable to the sustainable energy source can be counted 8.16 towards an electric utility's renewable energy objectives. This 8.17 percentage shall be calculated as the thermal content of the 8.18 sustainable energy source as a percentage of the overall thermal 8.19 content of the blended fuel used to generate electricity. 8.20 Subd. 4. [POOLING OF RESOURCES OF MULTIPLE UTILITIES.] Two 8.21 or more energy utilities may pool resources under this section 8.22 to provide assistance jointly to proposed sustainable energy 8.23 projects. The utilities shall negotiate and agree among 8.24 themselves for allocation of benefits associated with a project, 8.25 such as the ability to count energy generated by a project 8.26 toward a utility's renewable energy objectives under section 8.27 216B.1691. The utilities shall provide a summary of the 8.28 allocation of benefits to the commissioner. 8.29 Subd. 5. [CREDIT FOR PROJECTS OUTSIDE OF SERVICE 8.30 TERRITORY.] An energy utility may spend funds under this section 8.31 for sustainable energy projects in Minnesota that are outside 8.32 the service territory of the utility. Upon application by an 8.33 energy utility, the commission shall authorize a credit of three 8.34 percent of the amount the energy utility contributed toward a 8.35 sustainable energy project that is outside the energy utility's 8.36 service territory. This credit shall be deducted from the 9.1 utility's overall required spending under section 216B.241. The 9.2 commissioner may extend that credit to up to ten percent of the 9.3 amount the utility contributes to a project outside of its 9.4 service territory, if the commissioner determines that a 9.5 proposed project is important to the advancement of state policy 9.6 goals under subdivision 6 and would not occur without the 9.7 additional credit. This section does not apply to contributions 9.8 toward research under subdivision 2, paragraph (a). 9.9 Subd. 6. [ELIGIBLE RESEARCH AND TECHNOLOGIES; 9.10 DETERMINATION BY COMMISSIONER.] At least annually, and upon 9.11 consultation by an energy utility, the commissioner of commerce 9.12 shall, by order, identify research, technologies, and projects 9.13 that are eligible for expenditures under this section. In 9.14 identifying eligible technologies and projects, the commissioner 9.15 shall consider the extent to which the technology or project 9.16 advances state policy goals, such as: ensuring affordable, 9.17 reliable energy for Minnesota consumers; use of Minnesota energy 9.18 resources; and promoting local economic development and 9.19 protecting Minnesota's environment. By January 15 of each year, 9.20 the commissioner shall issue a report to the legislature 9.21 detailing and evaluating expenditures under this section, as 9.22 well as the process and criteria used by the commissioner to 9.23 make decisions under this subdivision. 9.24 Sec. 6. Minnesota Statutes 2002, section 216B.2424, 9.25 subdivision 5, is amended to read: 9.26 Subd. 5. [MANDATE.] (a) A public utility, as defined in 9.27 section 216B.02, subdivision 4, that operates a nuclear-powered 9.28 electric generating plant within this state must construct and 9.29 operate, purchase, or contract to construct and operate (1) by 9.30 December 31, 1998, 50 megawatts of electric energy installed 9.31 capacity generated by farm-grown closed-loop biomass scheduled 9.32 to be operational by December 31, 2001; and (2) by December 31, 9.33 1998, an additional 75 megawatts of installed capacity so 9.34 generated scheduled to be operational by December 31, 2002. 9.35 (b) Of the 125 megawatts of biomass electricity installed 9.36 capacity required under this subdivision, no more than 50 10.1 megawatts of this capacity may be provided by a facility that 10.2 uses poultry litter as its primary fuel source and any such 10.3 facility: 10.4 (1) need not use biomass that complies with the definition 10.5 in subdivision 1; 10.6 (2) must enter into a contract with the public utility for 10.7 such capacity, that has an average purchase price per megawatt 10.8 hour over the life of the contract that is equal to or less than 10.9 the average purchase price per megawatt hour over the life of 10.10 the contract in contracts approved by the public utilities 10.11 commission before April 1, 2000, to satisfy the mandate of this 10.12 section, and file that contract with the public utilities 10.13 commission prior to September 1, 2000; and 10.14 (3) must schedule such capacity to be operational by 10.15 December 31, 2002. 10.16 (c) Of the total 125 megawatts of biomass electric energy 10.17 installed capacity required under this section, no more than 75 10.18 megawatts may be provided by a single project. 10.19 (d) Of the 75 megawatts of biomass electric energy 10.20 installed capacity required under paragraph (a), clause (2), no 10.21 more than 2535 megawatts of this capacity may be provided by a 10.22 St. Paul district heating and cooling system cogeneration 10.23 facility utilizing waste wood as a primary fuel source. The St. 10.24 Paul district heating and cooling system cogeneration facility 10.25 need not use biomass that complies with the definition in 10.26 subdivision 1. 10.27 (e) The public utility must accept and consider on an equal 10.28 basis with other biomass proposals: 10.29 (1) a proposal to satisfy the requirements of this section 10.30 that includes a project that exceeds the megawatt capacity 10.31 requirements of either paragraph (a), clause (1) or (2), and 10.32 that proposes to sell the excess capacity to the public utility 10.33 or to other purchasers; and 10.34 (2) a proposal for a new facility to satisfy more than ten 10.35 but not more than 20 megawatts of the electrical generation 10.36 requirements by a small business-sponsored independent power 11.1 producer facility to be located within the northern quarter of 11.2 the state, which means the area located north of Constitutional 11.3 Route No. 8 as described in section 161.114, subdivision 2, and 11.4 that utilizes biomass residue wood, sawdust, bark, chipped wood, 11.5 or brush to generate electricity. A facility described in this 11.6 clause is not required to utilize biomass complying with the 11.7 definition in subdivision 1, but must have the capacity required 11.8 by this clause operational by December 31, 2002. 11.9 (f) If a public utility files a contract with the 11.10 commission for electric energy installed capacity that uses 11.11 poultry litter as its primary fuel source, the commission must 11.12 do a preliminary review of the contract to determine if it meets 11.13 the purchase price criteria provided in paragraph (b), clause 11.14 (2), of this subdivision. The commission shall perform its 11.15 review and advise the parties of its determination within 30 11.16 days of filing of such a contract by a public utility. A public 11.17 utility may submit by September 1, 2000, a revised contract to 11.18 address the commission's preliminary determination. 11.19 (g) The commission shall finally approve, modify, or 11.20 disapprove no later than July 1, 2001, all contracts submitted 11.21 by a public utility as of September 1, 2000, to meet the mandate 11.22 set forth in this subdivision. 11.23 (h) If a public utility subject to this section exercises 11.24 an option to increase the generating capacity of a project in a 11.25 contract approved by the commission prior to April 25, 2000, to 11.26 satisfy the mandate in this subdivision, the public utility must 11.27 notify the commission by September 1, 2000, that it has 11.28 exercised the option and include in the notice the amount of 11.29 additional megawatts to be generated under the option 11.30 exercised. Any review by the commission of the project after 11.31 exercise of such an option shall be based on the same criteria 11.32 used to review the existing contract. 11.33 (i) A facility specified in this subdivision qualifies for 11.34 exemption from property taxation under section 272.02, 11.35 subdivision 43. 11.36 Sec. 7. Minnesota Statutes 2002, section 216B.2424, 12.1 subdivision 6, is amended to read: 12.2 Subd. 6. [REMAINING MEGAWATT COMPLIANCE PROCESS.] (a) If 12.3 there remain megawatts of biomass power generating capacity to 12.4 fulfill the mandate in subdivision 5 after the commission has 12.5 taken final action on all contracts filed by September 1, 2000,12.6 by a public utilityunder subdivision 9, this subdivision 12.7 governs final compliance with the biomass energy mandate in 12.8 subdivision 5 subject to the requirements of subdivisions 7 and 12.9 8. 12.10 (b) To the extent not inconsistent with this subdivision, 12.11 the provisions of subdivisions 2, 3, 4, and 5 apply to proposals 12.12 subject to this subdivision. 12.13 (c) A public utility must submit proposals to the 12.14 commission to complete the biomass mandate. The commission 12.15 shall require a public utility subject to this section to issue 12.16 a request for competitive proposals for projects for electric 12.17 generation utilizing biomass as defined in paragraph (f) of this 12.18 subdivision to provide the remaining megawatts of the mandate. 12.19 The commission shall set an expedited schedule for submission of 12.20 proposals to the utility, selection by the utility of proposals 12.21 or projects, negotiation of contracts, and review by the 12.22 commission of the contracts or projects submitted by the utility 12.23 to the commission. 12.24 (d) Notwithstanding the provisions of subdivisions 1 to 5 12.25 but subject to the provisions of subdivisions 7 and 8, a new or 12.26 existing facility proposed under this subdivision that is fueled 12.27 either by biomass or by co-firing biomass with nonbiomass may 12.28 satisfy the mandate in this section. Such a facility need not 12.29 use biomass that complies with the definition in subdivision 1 12.30 if it uses biomass as defined in paragraph (f) of this 12.31 subdivision. Generating capacity produced by co-firing of 12.32 biomass that is operational as of April 25, 2000, does not meet12.33 the requirements of the mandate, except that additional12.34 co-firing capacityadded at an existing facility after April 25,12.35 2000,may be used to satisfy this mandate. Only the number of 12.36 megawatts of capacity at a facility which co-fires biomass that 13.1 are directly attributable to the biomass and that become 13.2 operational after April 25, 2000,final commission action under 13.3 subdivision 9 count toward meeting the biomass mandate in this 13.4 section. 13.5 (e) Nothing in this subdivision precludes a facility 13.6 proposed and approved under this subdivision from using fuel 13.7 sources that are not biomass in compliance with subdivision 3. 13.8 (f) Notwithstanding the provisions of subdivision 1, for 13.9 proposals subject to this subdivision, "biomass" includes: 13.10 (1) farm-grown closed-loop biomass; agricultural wastes,13.11 including animal, poultry, and plant wastes13.12 (2) methane or other combustible gases derived from the 13.13 processing of plant or animal material; 13.14 (3) alternative fuels derived from soybean and other 13.15 agricultural plant oils or animal fats; 13.16 (4) combustion of barley hulls, corn, soy-based products or 13.17 other agricultural products or wastes; and 13.18 (5) waste wood, including chipped wood, bark, brush, 13.19 residue wood, and sawdust. 13.20 (g) Nothing in this subdivision affects in any way 13.21 contracts entered into as of April 25, 2000, to satisfy the 13.22 mandate in subdivision 5. 13.23 (h) Nothing in this subdivision requires a public utility 13.24 to retrofit its own power plants for the purpose of co-firing 13.25 biomass fuel, nor is a utility prohibited from retrofitting its 13.26 own power plants for the purpose of co-firing biomass fuel to 13.27 meet the requirements of this subdivision. 13.28 Sec. 8. Minnesota Statutes 2002, section 216B.2424, 13.29 subdivision 8, is amended to read: 13.30 Subd. 8. [AGRICULTURAL BIOMASS REQUIREMENT.] Of the 125 13.31 megawatts mandated in subdivision 5, at least 75 megawatts of 13.32 the generating capacity must be generated by facilities that use 13.33 agricultural biomass as the principal fuel source. For purposes 13.34 of this subdivision, agricultural biomass includes only 13.35 farm-grown closed-loop biomass and agricultural waste, including13.36 animal, poultry, and plant wastesthose biomass fuel sources 14.1 listed in subdivision 6, paragraph (f), clauses (1) to (4). For 14.2 purposes of this subdivision, "principal fuel source" means a 14.3 fuel source that satisfies at least 75 percent of the fuel 14.4 requirements of an electric power generating facility. Nothing 14.5 in this subdivision is intended to expand the fuel source 14.6 requirements of subdivision 5. 14.7 Sec. 9. Minnesota Statutes 2002, section 216B.2424, is 14.8 amended by adding a subdivision to read: 14.9 Subd. 9. [STATUS REVIEW.] In January of 2004, the public 14.10 utilities commission shall conduct an initial review of all 14.11 projects selected to satisfy a portion of the biomass mandate 14.12 pursuant to this section, to make a preliminary determination of 14.13 each project's status and viability. The commission shall 14.14 conduct follow-up reviews in June of 2004, and December of 2004. 14.15 By December 31, 2004, the commission shall: 14.16 (1) make a final determination as to each project's 14.17 viability; 14.18 (2) cancel the contract for any project that is not yet 14.19 producing electricity and that the commission determines is not 14.20 viable; and 14.21 (3) direct the public utility subject to the biomass 14.22 mandate to request competitive proposals under subdivision 6 for 14.23 the biomass capacity in the amount of the canceled contracts. 14.24 Sec. 10. Minnesota Statutes 2002, section 216C.052, 14.25 subdivision 1, is amended to read: 14.26 Subdivision 1. [RESPONSIBILITIES.] (a) There is 14.27 established the position of reliability administrator in the 14.28 department of commerce. The administrator shall act as a source 14.29 of independent expertise and a technical advisor to the 14.30 commissioner, the commission, the public, and the legislative 14.31 electric energy task force on issues related to the reliability 14.32 of the electric system. In conducting its work, the 14.33 administrator shall: 14.34 (1) model and monitor the use and operation of the energy 14.35 infrastructure in the state, including generation facilities, 14.36 transmission lines, natural gas pipelines, and other energy 15.1 infrastructure; 15.2 (2) develop and present to the commission and parties 15.3 technical analyses of proposed infrastructure projects, and 15.4 provide technical advice to the commission; 15.5 (3) present independent, factual, expert, and technical 15.6 information on infrastructure proposals and reliability issues 15.7 at public meetings hosted by the task force, the environmental 15.8 quality board, the department, or the commission; and 15.9 (4) in consultation and collaboration with experts within 15.10 the industry, state government, and the University of Minnesota 15.11 system, research and identify present and emerging energy 15.12 issues, including adequacy of energy supply to consumers in the 15.13 state, energy infrastructure issues, demand and delivery 15.14 concerns, environmental constraints, regulatory structures and 15.15 procedures, emerging energy-related technologies fuels and 15.16 applications, and reliability matters that affect energy prices 15.17 paid by Minnesota consumers. In so doing, the administrator 15.18 shall serve as an information resource to state agencies and 15.19 legislators on energy issues affecting Minnesota consumers. 15.20 (b) Upon request and subject to resource constraints, the 15.21 administrator shall provide technical assistance regarding 15.22 matters unrelated to applications for infrastructure 15.23 improvements to the task force, the department, or the 15.24 commission. 15.25 (c) The administrator may not advocate for any particular 15.26 outcome in a commission proceeding, but may give technical 15.27 advice to the commission as to the impact on the reliability of 15.28 the energy system of a particular project or projects. The 15.29 administrator must not be considered a party or a participant in 15.30 any proceeding before the commission. 15.31 Sec. 11. [REPEALER.] 15.32 Minnesota Statutes 2002, section 216B.2411, is repealed. 15.33 Sec. 12. [EFFECTIVE DATE.] 15.34 Sections 1 to 5 and 7 to 11 are effective the day following 15.35 final enactment.