1.1 	A bill for an act
1.2 	relating to energy; requiring electric utilities to meet resource needs using 
1.3 	carbon-free resources; requiring a study; requiring a cost of service evaluation; 
1.4 	amending Minnesota Statutes 2018, sections 216B.03; 216B.16, subdivisions 6, 
1.5 	13; 216B.1645, subdivisions 1, 2; 216B.1691, subdivision 9; 216B.2422, 
1.6 	subdivision 2, by adding subdivisions; 216B.243, subdivision 3b; Minnesota 
1.7 	Statutes 2019 Supplement, section 216B.2422, subdivision 1; proposing coding 
1.8 	for new law in Minnesota Statutes, chapters 216B; 216C; repealing Minnesota 
1.9 	Statutes 2018, section 216B.2422, subdivision 4.
1.10 	BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF MINNESOTA:

1.11 	Section 1. Minnesota Statutes 2018, section 216B.03, is amended to read:
1.12 	216B.03 REASONABLE RATE.
1.13 	Every rate made, demanded, or received by any public utility, or by any two or more 
1.14 	public utilities jointly, shall be just and reasonable. Rates shall not be unreasonably 
1.15 	preferential, unreasonably prejudicial, or discriminatory, but shall be sufficient, equitable, 
1.16 	and consistent in application to a class of consumers. To the maximum reasonable extent, 
1.17 	the commission shall set rates to encouragebased on cost of service, while considering 
1.18 	noncost factors such as economic growth, job retention, energy conservation, and renewable 
1.19 	energy use and to further the goals of sections 216B.164, 216B.1696, 216B.241, and 216C.05. 
1.20 	Any doubt as to reasonableness should be resolved in favor of the consumer. For rate-making 
1.21 	purposes a public utility may treat two or more municipalities served by it as a single class 
1.22 	wherever the populations are comparable in size or the conditions of service are similar.

2.1 	Sec. 2. Minnesota Statutes 2018, section 216B.16, subdivision 6, is amended to read:
2.2 		Subd. 6.Factors considered, generally. The commission, in the exercise of its powers 
2.3 	under this chapter to determine just and reasonable rates for public utilities, shall give due 
2.4 	consideration to the public need for adequate, efficient, and reasonable service and to the 
2.5 	need of the public utility for revenue sufficient to enable it to meet the cost of furnishing 
2.6 	the service, including adequate provision for depreciation of its utility property used and 
2.7 	useful in rendering service to the public, and to earn a fair and reasonable return upon the 
2.8 	investment in such property. In determining the rate base upon which the utility is to be 
2.9 	allowed to earn a fair rate of return, the commission shall give due consideration to evidence 
2.10 	of the cost of the property when first devoted to public use, to prudent acquisition cost to 
2.11 	the public utility less appropriate depreciation on each, to construction work in progress, to 
2.12 	offsets in the nature of capital provided by sources other than the investors, and to other 
2.13 	expenses of a capital nature. For purposes of determining rate base, the commission shall 
2.14 	consider the original cost of utility property included in the base and shall make no allowance 
2.15 	for its estimated current replacement value. If the commission orders a generating facility 
2.16 	to terminate its operations before the end of the facility's physical life in order to comply 
2.17 	with a specific state or federal energy statute or policy, or as part of a resource planning 
2.18 	order under section 216B.2422, the commission may allow the public utility to recover any 
2.19 	positive net book value of the facility as determined by the commission.

2.20 	Sec. 3. Minnesota Statutes 2018, section 216B.16, subdivision 13, is amended to read:
2.21 		Subd. 13.Economic and community development. The commission may allow a 
2.22 	public utility to recover from ratepayers the expenses incurred for: (1) economic and 
2.23 	community development; and (2) efforts to maximize employment of local workers to 
2.24 	construct and maintain generation facilities that supply power to the utility's customers.

2.25 	Sec. 4. [216B.1623] DEMAND-SIDE MANAGEMENT PROGRAM.
2.26 		Subdivision 1.Definitions.  (a) For the purposes of this section, the following terms have 
2.27 	the meanings given them.
2.28 	(b) "Demand" means the maximum integrated hourly sum of load, expressed in kilowatts, 
2.29 	imposed by an eligible customer on the system of an investor-owned electric utility, over 
2.30 	a specified period, such as a day, month, or year.
2.31 	(c) "Demand response customer facilities" is that portion of the load that eligible 
2.32 	customers commit to participation in a demand-side management program.
3.1 	(d) "Demand-side management program" is any program under which demand response 
3.2 	customer facilities are compensated for reducing demand or energy to a level specified in 
3.3 	a contract or tariff, during both emergency and normal economic conditions.
3.4 	(e) "Eligible customer" means those customers of an investor-owned electric utility that 
3.5 	are large industrial customers.
3.6 	(f) "Energy" means an amount of electricity that is consumed over a period of time and 
3.7 	measured in kilowatt-hours.
3.8 	(g) "Large industrial customer" means a customer that either (1) takes electric service 
3.9 	at a voltage of 69,000 voltage or greater; or (2) imposes a peak demand on an investor-owned 
3.10 	electric utility's system of not less than 10,000 kilowatts at a single site, based upon the sum 
3.11 	of measured demand of all meters for all buildings, structures, equipment, and installation 
3.12 	at that single site, and including demand offset by on-site generation facilities.
3.13 		Subd. 2.Demand-side management program. (a) No later than January 1, 2021, an 
3.14 	investor-owned electric utility shall petition the commission for approval of a new 
3.15 	demand-side management program, or seek modification of an existing demand-side 
3.16 	management program.
3.17 	(b) The commission may approve, disapprove, or modify a demand-side management 
3.18 	program. Any demand-side management program approved by the commission must:
3.19 	(1) be open to all eligible customers and designed in a manner that reasonably encourages 
3.20 	eligible customer participation in the demand-side management program;
3.21 	(2) fairly compensates the eligible customer, which shall include consideration for the 
3.22 	eligible customer's participation in the demand-side management program, any actual 
3.23 	reduction of demand or energy on the investor-owned electric utility's system, any reduced 
3.24 	need of the investor-owned electric utility for new capacity resources, and any reduction to 
3.25 	the environmental costs, established under section 216B.2422, subdivision 3, associated 
3.26 	with generating resources not utilized due to the demand response customer facilities;
3.27 	(3) allow the investor-owned electric utility to recover the actual cost of compensation 
3.28 	pursuant to a cost-recovery rider or other mechanism provided, however, that the utility 
3.29 	shall not recover any cost of compensation, or other cost associated with a demand-side 
3.30 	management program, from any demand response customer facility; and
3.31 	(4) be reasonably consistent with programs offered by the Midcontinent Independent 
3.32 	System Operator, or its successor.

4.1 	Sec. 5. Minnesota Statutes 2018, section 216B.1645, subdivision 1, is amended to read:
4.2 		Subdivision 1.Commission authority. Upon the petition of a public utility, the Public 
4.3 	Utilities Commission shall approve or disapprove power purchase contracts, investments, 
4.4 	or expenditures entered into or made by the utility to satisfy the wind and biomass mandates 
4.5 	contained in sections 216B.169, 216B.2423, and 216B.2424, and to satisfy the renewable 
4.6 	energy objectives and standards set forth in section 216B.1691, including reasonable 
4.7 	investments and expenditures made to:
4.8 	(1) transmit the electricity generated from sources developed under those sections that 
4.9 	is ultimately used to provide service to the utility's retail customers, including studies 
4.10 	necessary to identify new transmission facilities needed to transmit electricity to Minnesota 
4.11 	retail customers from generating facilities constructed to satisfy the renewable energy 
4.12 	objectives and standards, provided that the costs of the studies have not been recovered 
4.13 	previously under existing tariffs and the utility has filed an application for a certificate of 
4.14 	need or for certification as a priority project under section 216B.2425 for the new 
4.15 	transmission facilities identified in the studies;
4.16 	(2) provide storage facilities for renewable energy generation facilities that contribute 
4.17 	to the reliability, efficiency, or cost-effectiveness of the renewable facilities; or
4.18 	(3) develop renewable energy sources from the account required in section 116C.779.; 
4.19 	or
4.20 	(4) upgrade or modify existing transmission facilities primarily used to transmit electricity 
4.21 	generated by a carbon-free resource, as defined in section 216B.2422, subdivision 1, 
4.22 	paragraph (f), regardless of whether the public utility has satisfied the standards set forth 
4.23 	in section 216B.1691.

4.24 	Sec. 6. Minnesota Statutes 2018, section 216B.1645, subdivision 2, is amended to read:
4.25 		Subd. 2.Cost recovery. The expenses incurred by the utility over the duration of the 
4.26 	approved contract or useful life of the investment and, expenditures made pursuant to section 
4.27 	116C.779shall be, and efforts to maximize employment of local workers to construct and 
4.28 	maintain generation facilities that supply power to the utility's customers, are recoverable 
4.29 	from the ratepayers of the utility, to the extent they are not offset by utility revenues 
4.30 	attributable to the contracts, investments, or expenditures. Upon petition by a public utility, 
4.31 	the commission shall approve or approve as modified a rate schedule providing for the 
4.32 	automatic adjustment of charges to recover the expenses or costs approved by the commission 
4.33 	under subdivision 1, which, in the case of transmission expenditures, are limited to the 
5.1 	portion of actual transmission costs that are directly allocable to the need to transmit power 
5.2 	from the renewable sources of energy. The commission may not approve recovery of the 
5.3 	costs for that portion of the power generated from sources governed by this section that the 
5.4 	utility sells into the wholesale market.

5.5 	Sec. 7. Minnesota Statutes 2018, section 216B.1691, subdivision 9, is amended to read:
5.6 		Subd. 9.Local benefits. The commission shall take all reasonable actions within its 
5.7 	statutory authority to ensure this section is implemented to maximize benefits to Minnesota 
5.8 	citizens and local workers as defined in section 216B.2422, subdivision 1, balancing factors 
5.9 	such as local ownership of or participation in energy production, local job impacts as defined 
5.10 	in section 216B.2422, subdivision 1, development and ownership of eligible energy 
5.11 	technology facilities by independent power producers, Minnesota utility ownership of 
5.12 	eligible energy technology facilities, the costs of energy generation to satisfy the renewable 
5.13 	standard, and the reliability of electric service to Minnesotans.

5.14 	Sec. 8. Minnesota Statutes 2019 Supplement, section 216B.2422, subdivision 1, is amended 
5.15 	to read:
5.16 		Subdivision 1.Definitions. (a) For purposes of this section, the terms defined in this 
5.17 	subdivision have the meanings given them.
5.18 	(b) "Utility" means an entity with the capability of generating 100,000 kilowatts or more 
5.19 	of electric power and serving, either directly or indirectly, the needs of 10,000 retail 
5.20 	customers in Minnesota. Utility does not include federal power agencies.
5.21 	(c) "Renewable energy" means electricity generated through use of any of the following 
5.22 	resources:
5.23 	(1) wind;
5.24 	(2) solar;
5.25 	(3) geothermal;
5.26 	(4) hydro;
5.27 	(5) trees or other vegetation;
5.28 	(6) landfill gas, anaerobic digestion, and mixed municipal solid waste or refuse-derived 
5.29 	fuel from mixed municipal solid waste; or
6.1 	(7) predominantly organic components of wastewater effluent, sludge, or related 
6.2 	by-products from publicly owned treatment works, but not including incineration of 
6.3 	wastewater sludge.
6.4 	(d) "Resource plan" means a set of resource options that a utility could use to meet the 
6.5 	service needs of its customers over a forecast period, including an explanation of the supply 
6.6 	and demand circumstances under which, and the extent to which, each resource option 
6.7 	would be used to meet those service needs. These resource options include using, 
6.8 	refurbishing, and constructing utility plant and equipment, buying power generated by other 
6.9 	entities, controlling customer loads, and implementing customer energy conservation.
6.10 	(e) "Refurbish" means to rebuild or substantially modify an existing electricity generating 
6.11 	resource of 3040 megawatts or greater.
6.12 	(f) "Carbon-free resource" means a generation facility that, when operating, does not 
6.13 	contribute to statewide greenhouse gas emissions, as defined in section 216H.01, subdivision 
6.14 	2, or a program or practice that reduces the need for energy generation. Carbon-free resource 
6.15 	includes a generation facility, or a program or practice, that uses one or more of the following:
6.16 	(1) renewable energy;
6.17 	(2) energy storage;
6.18 	(3) conservation, energy efficiency, and load management as defined by section 216B.241, 
6.19 	subdivision 1;
6.20 	(4) nuclear energy;
6.21 	(5) hydrogen technologies; or
6.22 	(6) power generation utilizing carbon capture and storage technology, if that carbon 
6.23 	capture and storage facility captures, on an annual basis, at least 80 percent of the carbon 
6.24 	dioxide the facility produces from burning fuel to generate electricity; and
6.25 	(i) injects carbon dioxide captured into a geologic formation to prevent its release into 
6.26 	the atmosphere;
6.27 	(ii) makes commercial use of the carbon dioxide captured, including by transferring it 
6.28 	to a third party for commercial use; or
6.29 	(iii) employs a combination of items (i) and (ii).
6.30 	(g) "Energy storage system" means a commercially available technology that:
6.31 	(1) uses mechanical, chemical, or thermal processes to:
7.1 	(i) store energy, including energy generated from renewable resources and energy that 
7.2 	would otherwise be wasted, and deliver the stored energy for use at a later time; or
7.3 	(ii) store thermal energy for direct use for heating or cooling at a later time in a manner 
7.4 	that reduces the demand for electricity at the later time;
7.5 	(2) is composed of stationary equipment;
7.6 	(3) if being used for electric grid benefits, is operationally visible and capable of being 
7.7 	controlled by the distribution or transmission entity managing it, to enable and optimize the 
7.8 	safe and reliable operation of the electric system; and
7.9 	(4) facilitates the use of other carbon-free resources; and
7.10 	(5) achieves any of the following:
7.11 	(i) reduces peak or electrical demand;
7.12 	(ii) defers the need or substitutes for an investment in electric generation, transmission, 
7.13 	or distribution assets;
7.14 	(iii) improves the reliable operation of the electrical transmission or distribution systems, 
7.15 	while ensuring transmission or distribution needs are not created; or
7.16 	(iv) lowers customer costs by storing energy when the cost of generating or purchasing 
7.17 	it energy is low and delivering itenergy to customers when the costs are high.
7.18 	(h) "Carbon-emitting resource" means a generation facility that is not a carbon-free 
7.19 	resource.
7.20 	(i) "Local job impacts" means the impacts of an integrated resource plan, a power 
7.21 	purchase agreement, or a certificate of need for a new or refurbished energy facility on the 
7.22 	availability of high-quality construction and mining employment opportunities to local 
7.23 	workers.
7.24 	(j) "Local workers" means workers employed to construct or maintain energy 
7.25 	infrastructure that are Minnesota residents, residents of the utility's service territory, or who 
7.26 	permanently reside within 150 miles of a proposed new or refurbished energy facility.

7.27 	Sec. 9. Minnesota Statutes 2018, section 216B.2422, subdivision 2, is amended to read:
7.28 		Subd. 2.Resource plan filing and approval. (a) A utility shall file a resource plan with 
7.29 	the commission periodically in accordance with rules adopted by the commission. The 
7.30 	commission shall approve, reject, or modify the plan of a public utility, as defined in section 
7.31 	216B.02, subdivision 4, consistent with the public interest.
8.1 	(b) In the resource plan proceedings of all other utilities, the commission's order shall 
8.2 	be advisory and the order's findings and conclusions shall constitute prima facie evidence 
8.3 	which may be rebutted by substantial evidence in all other proceedings. With respect to 
8.4 	utilities other than those defined in section 216B.02, subdivision 4, the commission shall 
8.5 	consider the filing requirements and decisions in any comparable proceedings in another 
8.6 	jurisdiction.
8.7 	(c) As a part of its resource plan filing, a utility shall include the least cost plan for 
8.8 	meeting 50 and 75 percent of all new energy needs from both new and refurbished generating 
8.9 	facilities through a combination of conservation and renewable energycarbon-free resources.

8.10 	Sec. 10. Minnesota Statutes 2018, section 216B.2422, is amended by adding a subdivision 
8.11 	to read:
8.12 		Subd. 4a.Preference for carbon-free resources. (a) The commission shall not approve 
8.13 	a new or refurbished carbon-emitting resource in Minnesota in an integrated resource plan 
8.14 	or a certificate of need, pursuant to section 216B.243, nor shall the commission approve a 
8.15 	power purchase agreement for a new or refurbished carbon-emitting resource in Minnesota 
8.16 	or allow rate recovery pursuant to section 216B.16 for such a carbon-emitting resource, 
8.17 	unless the utility has demonstrated that a carbon-free resource, alone or in combination with 
8.18 	other carbon-free resources is not in the public interest.
8.19 	(b) When making the public interest determination under paragraph (a), the commission 
8.20 	must consider, based on projections in the integrated resource plan:
8.21 	(1) whether the resource need must be met by a carbon-emitting resource in Minnesota 
8.22 	to avoid an unreasonable increase in customer rates or a decrease in local or regional grid 
8.23 	reliability or energy adequacy;
8.24 	(2) whether the resource need could be met at lower cost by utilizing existing 
8.25 	infrastructure or site that has previously held electric generation;
8.26 	(3) whether the resource need could be met at a lower cost by refueling an existing 
8.27 	carbon-emitting resource with a less-carbon-intensive or noncarbon fuel supply including, 
8.28 	but not limited to, combinations of natural gas, bionatural gas, or hydrogen, whether the 
8.29 	proposed resource helps the utility facilitate the reduction of greenhouse gas emissions or 
8.30 	achieve the greenhouse gas reduction goals under section 216H.02, the renewable energy 
8.31 	standard under section 216B.1691, or the solar energy standard under section 216B.1691, 
8.32 	subdivision 2f;
9.1 	(4) utility and ratepayer impacts resulting from the intermittent nature of renewable 
9.2 	energy facilities, including, but not limited to, the costs of purchasing wholesale electricity 
9.3 	in the market and the costs of providing reliability and ancillary services;
9.4 	(5) utility and ratepayer impacts resulting from reduced exposure to fuel price volatility, 
9.5 	changes in transmission costs, portfolio diversification, and environmental compliance 
9.6 	costs, as well as utility and ratepayer impacts that might result from additional investment 
9.7 	in carbon-emitting resources;
9.8 	(6) ratepayer impacts of resource options on customer bills and utility rates; any doubt 
9.9 	regarding the various resource options before the commission must be resolved in favor of 
9.10 	supporting the economy, job growth, and job retention; and
9.11 	(7) the contribution of proposed resources to local and regional reliability considering 
9.12 	the ability of proposed resources to provide energy, capacity and essential reliability services 
9.13 	needed by the utility customers or the electric system, including to the extent feasible, 
9.14 	frequency response, balancing services, or voltage control.
9.15 	(c) If the commission finds the utility has demonstrated a carbon-free resource or 
9.16 	combination of carbon-free resources is not in the public interest under paragraph (a), the 
9.17 	commission may approve a utility's proposal for a new or refurbished carbon-emitting 
9.18 	resource.
9.19 	(d) This subdivision does not apply to energy facilities in a resource plan previously 
9.20 	approved by the commission, an energy facility approved by the legislature under Laws 
9.21 	2017, chapter 5, or to commission approval of an affiliated interest agreement for an energy 
9.22 	facility in docket number E015/AI-17-568.
9.23 	(e) The commission shall not approve a resource plan under this subdivision of a public 
9.24 	utility that has at least 100,000 customers, but no more than 200,000 customers in Minnesota, 
9.25 	if the resource plan includes the retirement of a generating facility that has a positive net 
9.26 	book value, unless the public utility has demonstrated that:
9.27 	(1) the retirement is consistent with the public interest;
9.28 	(2) the resource plan promotes the energy policy of the state to ensure competitive electric 
9.29 	rates for energy-intensive, trade-exposed customers, as required in section 216B.1696, 
9.30 	subdivision 2, paragraph (a); and
9.31 	(3) the costs of operating and maintaining the facility exceed the costs of retirement 
9.32 	based on the following factors:
9.33 	(i) all costs associated with decommissioning the generating resource;
10.1 	(ii) any stranded asset costs, including but not limited to, costs that have not been 
10.2 	depreciated and recovered by the utility having an ownership interest in the asset;
10.3 	(iii) any investments in replacement generation, including the utility's transmission and 
10.4 	distribution systems, to ensure all utility system reliability, energy, and capacity needs are 
10.5 	met once the generating resource is retired;
10.6 	(iv) any projected investments necessary to continue operating the generation facility; 
10.7 	and
10.8 	(v) any operation and maintenance saving from retiring the generation facility.
10.9 	(f) If the commission approves a resource plan that includes the retirement of a 
10.10 	carbon-emitting resource owned by a public utility, the public utility shall be entitled to 
10.11 	own the generation, transmission, and other facilities necessary to replace the accredited 
10.12 	capacity and energy of the retiring facility, provided:
10.13 	(1) the resource plan of the public utility with more than 200,000 retail electric customers 
10.14 	in Minnesota results in an 80 percent or greater reduction in carbon emissions from 2005 
10.15 	levels by the year 2030 and thereafter;
10.16 	(2) the resource plan of the public utility with between 50,000 and 200,000 retail electric 
10.17 	customers in Minnesota results in a 65 percent reduction in carbon emissions from 2005 
10.18 	levels by the year 2030 and thereafter; and
10.19 	(3) each public utility demonstrates its ownership of replacement resources is in the 
10.20 	public interest, considering customer impacts and benefits.
10.21 	(g) Nothing in this subdivision impacts a decision to continue operating a peaking 
10.22 	generation facility with no more than ten percent annual capacity factor that is generating 
10.23 	energy in Minnesota.
10.24 	(h) This subdivision does not apply to utility decisions to purchase capacity, energy, and 
10.25 	ancillary services for up to an annual period from any independent system operator market 
10.26 	or auction or to otherwise participate in a wholesale market administered by an independent 
10.27 	system operator.

10.28 	Sec. 11. Minnesota Statutes 2018, section 216B.2422, is amended by adding a subdivision 
10.29 	to read:
10.30 		Subd. 4b.Preference for local job creation. As a part of its resource plan filing, a utility 
10.31 	must report, to the extent known, on associated local job impacts and the steps the utility 
10.32 	and its energy suppliers and contractors are taking to maximize the availability of construction 
11.1 	employment opportunities for local workers. The commission must consider local job 
11.2 	impacts and give preference to proposals that maximize the creation of construction 
11.3 	employment opportunities for local workers, consistent with the public interest, when 
11.4 	evaluating any utility proposal that involves the selection or construction of facilities used 
11.5 	to generate or deliver energy to serve the utility's customers, including but not limited to an 
11.6 	integrated resource plan, a certificate of need, a power purchase agreement, or commission 
11.7 	approval of a new or refurbished electric generation facility.

11.8 	Sec. 12. Minnesota Statutes 2018, section 216B.2422, is amended by adding a subdivision 
11.9 	to read:
11.10 		Subd. 6a. Resource planning conference. The commissioner of commerce may, as 
11.11 	circumstances warrant, convene utilities subject to this section and stakeholders interested 
11.12 	in resource planning to: (1) facilitate the sharing of best practices and planning innovations 
11.13 	from one utility resource plan to the next; (2) help resolve issues that impact all utilities 
11.14 	during the resource plan development process; and (3) promote coordination across resource 
11.15 	plans. The commissioner must seek input from likely attendees regarding topics the resource 
11.16 	planning conference should cover. In addition, the agenda for the conference should review 
11.17 	key decisions by the Federal Energy Regulatory Commission and the North American 
11.18 	Electric Reliability Corporation that could impact resource planning, as well as recent and 
11.19 	ongoing transmission studies and market innovations from the Midcontinent Independent 
11.20 	System Operator.

11.21 	Sec. 13. Minnesota Statutes 2018, section 216B.243, subdivision 3b, is amended to read:
11.22 		Subd. 3b.Nuclear power plant; new construction prohibited; relicensing Additional 
11.23 	storage of spent nuclear fuel. (a) The commission may not issue a certificate of need for 
11.24 	the construction of a new nuclear-powered electric generating plant.
11.25 	(b) Any certificate of need for additional storage of spent nuclear fuel for a facility 
11.26 	seeking a license extension shall address the impacts of continued operations over the period 
11.27 	for which approval is sought.

11.28 	EFFECTIVE DATE. This section is effective the day following final enactment.

11.29 	Sec. 14. [216C.46] POWER PLANT HOST COMMUNITY TRANSITION 
11.30 	PLANNING.
11.31 	The commissioner of commerce must coordinate with the commissioner of labor and 
11.32 	industry and the commissioner of employment and economic development to develop plans, 
12.1 	programs, and other recommendations to mitigate the impacts on host communities in 
12.2 	Minnesota and workers resulting from the eventual retirement of large generation facilities. 
12.3 	The commissioners must coordinate this work with representatives of: (1) the local 
12.4 	government units that host large generation facilities; (2) the workers at large generation 
12.5 	facilities, including full-time employees and contractors; and (3) the utilities that own large 
12.6 	generation facilities.

12.7 	Sec. 15. COORDINATED ELECTRIC TRANSMISSION STUDY.
 12.8 	(a) The commissioner of commerce shall request the Midcontinent Independent System 
12.9 	Operator (MISO) to conduct an engineering study of the impacts on reliability and estimated 
12.10 	costs and benefits of operational changes and enhancements to the transmission system 
12.11 	necessary to support increased use of carbon-free electrical generation sources for Minnesota 
12.12 	and throughout the MISO footprint, along with the possible eventual retirement of existing 
12.13 	generation resources serving Minnesota customers.
12.14 	(b) If the request is accepted, MISO is responsible for completing the study work, with 
12.15 	the support of the electric utilities subject to transmission planning under Minnesota Rules, 
12.16 	chapter 7848. Prior to the start of the study, MISO shall appoint a technical review committee 
12.17 	with experience and expertise in electric transmission system engineering, power system 
12.18 	operation, and renewable and carbon-free energy technologies to review the study's proposed 
12.19 	methods, work plan, models, and preliminary and near final results. The technical review 
12.20 	committee shall be chaired by a representative from MISO and include representatives from 
12.21 	Minnesota electric utilities, including one representative from a utility that owns nuclear 
12.22 	generation, one from a generation and transmission cooperative, one from a transmission 
12.23 	company, one from a municipal utility, and one from a municipal power agency. In addition, 
12.24 	MISO will work with state utility regulators, as well as stakeholders from across the 
12.25 	electricity industry, nongovernmental organization, consumer advocates, and labor 
12.26 	representatives.
12.27 	(c) To the extent possible, the study shall integrate and optimize the study and resulting 
12.28 	potential transmission projects with previous and current study efforts, coordinate with 
12.29 	neighboring regions to the MISO footprint and adjacent regional transmission organizations, 
12.30 	and identify barriers, challenges, and opportunities.
12.31 	(d) The study shall include, but is not limited to:
12.32 	(1) establishing scenarios for study of increased carbon-free energy resources and energy 
12.33 	storage and retirement of existing generation;
13.1 	(2) identifying new power system operating challenges and possible mitigation strategies 
13.2 	and areas where new strategies will be required but are not yet discernible;
13.3 	(3) developing conceptual level plans of the required new and modified transmission, 
13.4 	including time frames and indicative cost;
13.5 	(4) identifying when ascertainable, likely new significant transmission projects or 
13.6 	modifications, including time frames and indicative cost; and
13.7 	(5) identifying functional requirements for and time frames when nontransmission 
13.8 	technology may be needed to augment the transmission in conceptual plan and the new 
13.9 	projects or modifications.
13.10 	(e) The first meeting of the technical review committee shall be held no later than June 
13.11 	15, 2020, and the study should be complete, with a comprehensive report submitted to the 
13.12 	Public Utilities Commission no later than December 1, 2021.

13.13 	Sec. 16. COST OF SERVICE ALLOCATION EVALUATION.
 13.14 	(a) The Public Utilities Commission, in consultation with the commissioner of commerce, 
13.15 	shall evaluate the current cost of service allocation for public utilities, as defined in Minnesota 
13.16 	Statutes, section 216B.02, providing electric service in this state. The commission shall 
13.17 	report for each utility: (1) the cost allocation between residential, commercial, industrial, 
13.18 	and energy-intensive trade exposed customers, as defined in Minnesota Statutes, section 
13.19 	216B.1696, subdivision 1, paragraph (c), relative to a single coincident peak cost allocation 
13.20 	methodology; and (2) whether rates for the utility's energy intensive trade exposed customers 
13.21 	comply with the state policy of ensuring competitive rates for those customers as established 
13.22 	in Minnesota Statutes, section 216B.1696.
13.23 	(b) The commission shall also include in the evaluation: (1) an analysis of historical 
13.24 	rates for each public utility for the previous ten years; and (2) any recommendations to help 
13.25 	ensure that future electric energy costs remain stable for energy intensive trade exposed 
13.26 	customers.
13.27 	(c) The commission shall submit the evaluation required under this section to the chairs 
13.28 	and ranking minority members of legislative committees with jurisdiction over energy policy 
13.29 	and finance by January 15, 2021.

13.30 	Sec. 17. REPEALER.
 13.31 	Minnesota Statutes 2018, section 216B.2422, subdivision 4, is repealed.

14.1 	Sec. 18. EFFECTIVE DATE.
 14.2 	Sections 1 to 12 and 14 to 17 are effective August 1, 2020, and apply only to dockets 
14.3 	initiated at the Public Utilities Commission on or after that date.

APPENDIX 

Repealed Minnesota Statutes: S1456-2 

216B.2422 RESOURCE PLANNING; RENEWABLE ENERGY.Subd. 4.Preference for renewable energy facility. 
The commission shall not approve a new or refurbished nonrenewable energy facility in an integrated resource plan or a certificate of need, pursuant to section 216B.243, nor shall the commission allow rate recovery pursuant to section 216B.16 for such a nonrenewable energy facility, unless the utility has demonstrated that a renewable energy facility is not in the public interest. When making the public interest determination, the commission must consider: 

(1) whether the resource plan helps the utility achieve the greenhouse gas reduction goals under section 216H.02, the renewable energy standard under section 216B.1691, or the solar energy standard under section 216B.1691, subdivision 2f; 

(2) impacts on local and regional grid reliability; 

(3) utility and ratepayer impacts resulting from the intermittent nature of renewable energy facilities, including but not limited to the costs of purchasing wholesale electricity in the market and the costs of providing ancillary services; and 

(4) utility and ratepayer impacts resulting from reduced exposure to fuel price volatility, changes in transmission costs, portfolio diversification, and environmental compliance costs.