81R9100 TRH-F

By: Keffer H.B. No. 2782

A BILL TO BE ENTITLED

AN ACT

relating to regulation of electric generation capacity ownership in the electric power market.

BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF TEXAS:

SECTION 1. Sections 39.152(a) and (d), Utilities Code, are amended to read as follows:

(a) The commission shall certify a power region if:

(1) a sufficient number of interconnected utilities in the power region fall under the operational control of an independent organization as described by Section 39.151;

(2) the power region has a generally applicable tariff that guarantees open and nondiscriminatory access for all users to transmission and distribution facilities in the power region as provided by Section 39.203; and

(3) no person owns, controls, or owns and controls in any combination more than 20 percent of the installed generation capacity located in or capable of delivering electricity to a power region, as determined according to Section 39.154.

(d) For a power region outside of ERCOT, a power generation company that is affiliated with an electric utility may elect to demonstrate that it meets the requirements of Subsection (a)(3) by showing that it does not own, control, or own and control in any combination more than 20 percent of the installed capacity in a geographic market that includes the power region, using the guidelines, standards, and methods adopted by the Federal Energy Regulatory Commission.

SECTION 2. Section 39.153, Utilities Code, is amended by adding Subsection (a-1) and amending Subsections (e) and (f) to read as follows:

(a-1) Not later than September 30, 2010, each electric utility subject to this section shall sell at auction or otherwise divest any additional entitlements to the utility's jurisdictional installed generation capacity necessary to ensure that the electric utility does not control more than 20 percent of the installed generation capacity:

(1) in ERCOT;

(2) in an ERCOT zonal boundary; or

(3) in a functional market recognized by the commission.

(e) The commission shall adopt rules by December 31, 2000, that define the initial scope of the capacity entitlements to be auctioned and not later than December 31, 2009, shall adopt additional rules that define the scope of the auctions necessary to comply with Subsection (a-1). Entitlements may be auctioned in blocks of less than 15 percent. The rules shall state the minimum amount of capacity that can be sold at auction as an entitlement. At a minimum, the rules shall provide that the entitlements:

(1) may be sold and purchased in periods of not less than one month nor more than four years;

(2) may be resold to any lawful purchaser, except for a retail electric provider affiliated with the electric utility that originally auctioned the entitlement;

(3) include no possessory interest in the unit from which the power is produced;

(4) include no obligations of a possessory owner of an interest in the unit from which the power is produced; and

(5) give the purchaser the right to designate the dispatch of the entitlement, subject to planned outages, outages beyond the control of the utility operating the unit, and other considerations subject to the oversight of the applicable independent organization.

(f) The commission shall adopt rules by December 31, 2000, that prescribe the procedure for the auction of the entitlements as required by Subsection (a). If necessary, the commission may adopt additional rules that prescribe the procedure for the auction of the entitlements as required by Subsection (a-1). The rules shall include:

(1) a process for conducting the auction or auctions, including who shall conduct it, how often it shall be conducted, and how winning bidders shall be determined;

(2) a process for the electric utility to designate which generation units or combination of units are offered for auction;

(3) a provision for the utility to establish an opening bid price based on the electric utility's expected cost, with the commission prescribing the means for determining the opening bid price, which may not include return on equity; and

(4) a provision that allows a bidder to specify the magnitude and term of the entitlement, subject to the conditions established in Subsection (e).

SECTION 3. Sections 39.154(a) and (c), Utilities Code, are amended to read as follows:

(a) Beginning on the date of introduction of customer choice, a power generation company may not own, [and] control, or own and control in any combination more than 20 percent of the installed generation capacity located in, or capable of delivering electricity to, a power region, zone, or functional market recognized by the commission in the power region.

(c) In determining the percentage shares of installed generation capacity under this section, the commission shall combine capacity owned or [and] controlled by a power generation company and any entity that is affiliated with that power generation company within the power region, zone, or functional market recognized by the commission in the power region, reduced by the installed generation capacity of those facilities that are made subject to capacity auctions under Sections 39.153(a) and (d).

SECTION 4. Section 39.155(a), Utilities Code, is amended to read as follows:

(a) Each person, municipally owned utility, electric cooperative, and river authority that owns or controls generation facilities and offers electricity for sale in this state shall report to the commission its installed generation capacity, the total amount of capacity available for sale to others, the total amount of capacity under contract to others, the total amount of capacity dedicated to its own use, its annual wholesale power sales in the state, its annual retail power sales in the state, and any other information necessary for the commission to assess market power or the development of a competitive retail market in the state. The commission shall by rule prescribe the nature and detail of the reporting requirements and shall administer those reporting requirements in a manner that ensures the confidentiality of competitively sensitive information.

SECTION 5. Sections 39.156(a), (b), and (g), Utilities Code, are amended to read as follows:

(a) In this section, "market power mitigation plan" or "plan" means a written proposal by an electric utility or a power generation company for reducing its ownership or [and] control of installed generation capacity as required by Section 39.154.

(b) An electric utility or power generation company owning, controlling, or owning and controlling in any combination more than 20 percent of the generation capacity located in, or capable of delivering electricity to, a power region, zone, or functional market recognized by the commission in the power region shall file a market power mitigation plan with the commission not later than the 90th day after the date the electric utility's or power generation company's generation capacity exceeds the 20 percent limitation under this subsection [December 1, 2000].

(g) In reaching its determination under Subsection (f), the commission shall consider:

(1) the degree to which the electric utility's or power generation company's stranded costs, if any, are minimized;

(2) whether on disposition of the generation assets the reasonable value is likely to be received;

(3) the effect of the plan on the electric utility's or power generation company's federal income taxes;

(4) the effect of the plan on current and potential competitors in the generation market; [and]

(5) whether the plan is consistent with the public interest;

(6) the ownership of generation resources in a zone;

(7) the control of generation through the use of contracts between affiliated retail electric providers and independent power producers; and

(8) the emissions credits owned or controlled by an electric utility or power generation company in a nonattainment area for national ambient air quality standards.

SECTION 6. Section 39.407(a), Utilities Code, is amended to read as follows:

(a) If an electric utility chooses on or after January 1, 2007, to participate in customer choice, the commission may not authorize customer choice until the applicable power region has been certified as a qualifying power region under Section 39.152(a). Except as otherwise provided by this subsection, the commission shall certify that the requirements of Section 39.152(a)(3) are met for electric utilities subject to this subchapter only upon a finding that the total capacity owned, controlled, or owned and controlled in any combination by each such electric utility and its affiliates does not exceed 20 percent of the total installed generation capacity within the constrained geographic region served by each such electric utility plus the total available transmission capacity capable of delivering firm power and energy to that constrained geographic region. Not later than May 1, 2002, each electric utility subject to this subchapter shall submit to the electric utility restructuring legislative oversight committee an analysis of the needed transmission facilities necessary to make the electric utility's service area transmission capability comparable to areas within the ERCOT power region. On or after September 1, 2003, each electric utility subject to this subchapter shall file the utility's plans to develop the utility's transmission interconnections with the utility's power region or other adjacent power regions. The commission shall review the plan and not later than the 180th day after the date the plan is filed, determine the additional transmission facilities necessary to provide access to power and energy that is comparable to the access provided in areas within the ERCOT power region; provided, however, that if a hearing is requested by any party to the proceeding, the 180-day deadline will be extended one day for each day of hearings. The commission shall, as a part of the commission's approval of the plan, approve a rate rider mechanism for the recovery of the incremental costs of those facilities after the facilities are completed and in-service. A finding of need under this subsection shall meet the requirements of Sections 37.056(c)(1), (2), and (4)(E). The commission may certify that the requirements of Section 39.152(a)(3) are met for electric utilities subject to this subchapter if the commission finds that:

(1) each such utility has sufficient transmission facilities to provide customers access to power and energy from capacity controlled by suppliers not affiliated with the incumbent utility that is comparable to the access to power and energy from capacity controlled by suppliers not affiliated with the incumbent utilities in areas of the ERCOT power region; and

(2) the total capacity owned, controlled, or owned and controlled in any combination by each such electric utility and its affiliates does not exceed 20 percent of the total installed generation capacity within the power region.

SECTION 7. Section 39.453(b), Utilities Code, is amended to read as follows:

(b) The commission shall certify that the requirement of Section 39.152(a)(3) is met for an electric utility subject to this subchapter only if the commission finds that the total capacity owned, controlled, or owned and controlled in any combination by the electric utility and the utility's affiliates does not exceed 20 percent of the total installed generation capacity within the power region of that utility.

SECTION 8. Sections 39.153(b) and 39.154(e), Utilities Code, are repealed.

SECTION 9. This Act takes effect immediately if it receives a vote of two-thirds of all the members elected to each house, as provided by Section 39, Article III, Texas Constitution. If this Act does not receive the vote necessary for immediate effect, this Act takes effect September 1, 2009.