By:  Sibley, et al.                                      S.B. No. 7
         99S0120/1                           
                                A BILL TO BE ENTITLED
                                       AN ACT
 1-1     relating to electric utility restructuring and to the powers and
 1-2     duties of the Public Utility Commission of Texas.
 1-3           BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF TEXAS:
 1-4           SECTION 1.  Subdivisions (1) and (16), Section 11.003,
 1-5     Utilities Code, are amended to read as follows:
 1-6                 (1)  "Affected person" means:
 1-7                       (A)  a public utility or electric cooperative
 1-8     affected by an action of a regulatory authority;
 1-9                       (B)  a person whose utility service or rates are
1-10     affected by a proceeding before a regulatory authority; or
1-11                       (C)  a person who:
1-12                             (i)  is a competitor of a public utility
1-13     with respect to a service performed by the utility; or
1-14                             (ii)  wants to enter into competition with
1-15     a public utility.
1-16                 (16)  "Ratemaking proceeding" means[:]
1-17                       [(A)]  a proceeding in which a rate is changed[;
1-18     and]
1-19                       [(B)  a proceeding initiated under Chapter 34].
1-20           SECTION 2.  Section 12.005, Utilities Code, is amended to
1-21     read as follows:
1-22           Sec. 12.005.  APPLICATION OF SUNSET ACT.  The Public Utility
1-23     Commission of Texas is subject to Chapter 325, Government Code
1-24     (Texas Sunset Act).  Unless continued in existence as provided by
 2-1     that chapter, the commission is abolished and this title expires
 2-2     September 1, 2005 [2001].
 2-3           SECTION 3.  Section 31.002, Utilities Code, is amended to
 2-4     read as follows:
 2-5           Sec. 31.002.  DEFINITIONS.  In this subtitle:
 2-6                 (1)  "Affiliated power generation company" means the
 2-7     power generation company that is affiliated with or the successor
 2-8     in interest of an electric utility certificated to serve an area
 2-9     when customer choice is introduced.
2-10                 (2)  "Affiliated retail electric provider" means the
2-11     retail electric provider that is affiliated with or the successor
2-12     in interest of an electric utility certificated to serve an area
2-13     when customer choice is introduced.
2-14                 (3)  "Customer choice" means the unrestricted freedom
2-15     of a retail customer to purchase electric services, either
2-16     individually or on an aggregated basis with other retail customers,
2-17     from the provider or providers of the customer's choice and to
2-18     choose among various fuel types, energy efficiency programs, and
2-19     renewable power suppliers.
2-20                 (4)  "Electric Reliability Council of Texas" or "ERCOT"
2-21     means the area in Texas served by electric utilities, municipally
2-22     owned utilities, and electric cooperatives that is not
2-23     synchronously interconnected with electric utilities outside the
2-24     state.
2-25                 (5)  "Electric utility" means a person or river
2-26     authority that owns or operates for compensation in this state
 3-1     equipment or facilities to produce, generate, transmit, distribute,
 3-2     sell, or furnish electricity in this state.  The term includes a
 3-3     lessee, trustee, or receiver of an electric utility and a
 3-4     recreational vehicle park owner who does not comply with Subchapter
 3-5     C, Chapter 184, with regard to the metered sale of electricity at
 3-6     the recreational vehicle park.  The term does not include:
 3-7                       (A)  a municipal corporation;
 3-8                       (B)  a qualifying facility;
 3-9                       (C)  a power generation company;
3-10                       (D)  an exempt wholesale generator;
3-11                       (E) [(D)]  a power marketer;
3-12                       (F) [(E)]  a corporation described by Section
3-13     32.053 to the extent the corporation sells electricity exclusively
3-14     at wholesale and not to the ultimate consumer; or
3-15                       (G)  a cooperative corporation;
3-16                       (H)  a retail electric provider;
3-17                       (I) [(F)]  a person not otherwise an electric
3-18     utility who:
3-19                             (i)  furnishes an electric service or
3-20     commodity only to itself, its employees, or its tenants as an
3-21     incident of employment or tenancy, if that service or commodity is
3-22     not resold to or used by others;
3-23                             (ii)  owns or operates in this state
3-24     equipment or facilities to produce, generate, transmit, distribute,
3-25     sell, or furnish electric energy to an electric utility, if the
3-26     equipment or facilities are used primarily to produce and generate
 4-1     electric energy for consumption by that person; or
 4-2                             (iii)  owns or operates in this state a
 4-3     recreational vehicle park that provides metered electric service in
 4-4     accordance with Subchapter C, Chapter 184.
 4-5                 (6) [(2)]  "Exempt wholesale generator" means a person
 4-6     who is engaged directly or indirectly through one or more
 4-7     affiliates exclusively in the business of owning or operating all
 4-8     or part of a facility for generating electric energy and selling
 4-9     electric energy at wholesale and who:
4-10                       (A)  does not own a facility for the transmission
4-11     of electricity, other than an essential interconnecting
4-12     transmission facility necessary to effect a sale of electric energy
4-13     at wholesale; and
4-14                       (B)  has:
4-15                             (i)  applied to the Federal Energy
4-16     Regulatory Commission for a determination under 15 U.S.C. Section
4-17     79z-5a; or
4-18                             (ii)  registered as an exempt wholesale
4-19     generator as required by Section 35.032.
4-20                 (7)  "Freeze period" means the period beginning on
4-21     January 1, 1999, and ending on December 31, 2001.
4-22                 (8)  "Independent system operator" means an entity
4-23     supervising the collective transmission facilities of a power
4-24     region that is charged with nondiscriminatory coordination of
4-25     market transactions, systemwide transmission planning, and network
4-26     reliability.
 5-1                 (9)  "Power generation company" means a person who:
 5-2                       (A)  generates electricity that is intended to be
 5-3     resold;
 5-4                       (B)  does not own a transmission or distribution
 5-5     facility in this state other than an essential interconnecting
 5-6     facility, a facility not dedicated to public use, or a facility
 5-7     otherwise excluded from the definition of "electric utility" under
 5-8     Subdivision (5); and
 5-9                       (C)  does not have a certificated service area,
5-10     although its affiliated electric utility or transmission and
5-11     distribution utility may have a certificated service area.
5-12                 (10) [(3)]  "Power marketer" means a person who:
5-13                       (A)  becomes an owner of electric energy in this
5-14     state for the purpose of selling the electric energy at wholesale;
5-15                       (B)  does not own generation, transmission, or
5-16     distribution facilities in this state;
5-17                       (C)  does not have a certificated service area;
5-18     and
5-19                       (D)  has:
5-20                             (i)  been granted authority by the Federal
5-21     Energy Regulatory Commission to sell electric energy at
5-22     market-based rates; or
5-23                             (ii)  registered as a power marketer under
5-24     Section 35.032.
5-25                 (11)  "Power region" means a contiguous geographical
5-26     area within the state which is in a distinct region of the North
 6-1     American Electric Reliability Council.
 6-2                 (12) [(4)]  "Qualifying cogenerator" and "qualifying
 6-3     small power producer" have the meanings assigned those terms by 16
 6-4     U.S.C. Sections 796(18)(C) and 796(17)(D).
 6-5                 (13) [(5)]  "Qualifying facility" means a qualifying
 6-6     cogenerator or qualifying small power producer.
 6-7                 (14) [(6)]  "Rate" includes a compensation, tariff,
 6-8     charge, fare, toll, rental, or classification that is directly or
 6-9     indirectly demanded, observed, charged, or collected by an electric
6-10     utility for a service, product, or commodity described in the
6-11     definition of electric utility in this section and a rule,
6-12     practice, or contract affecting the compensation, tariff, charge,
6-13     fare, toll, rental, or classification that must be approved by a
6-14     regulatory authority.
6-15                 (15)  "Retail customer" means the end-use customer who
6-16     purchases and ultimately consumes electricity.
6-17                 (16)  "Retail electric provider" means a person that
6-18     sells electric service to retail customers in this state.
6-19                 (17)  "Transmission and distribution utility" means a
6-20     person or river authority that owns or operates for compensation in
6-21     this state equipment or facilities to transmit or distribute
6-22     electricity in a qualifying power region certified pursuant to
6-23     Section 39.152.
6-24                 (18) [(7)]  "Transmission service" includes
6-25     construction or enlargement of facilities, transmission over
6-26     distribution facilities, control area services, scheduling
 7-1     resources, regulation services, reactive power support, voltage
 7-2     control, provision of operating reserves, and any other associated
 7-3     electrical service the commission determines appropriate.
 7-4           SECTION 4.  Sections 32.051 and 32.052, Utilities Code, are
 7-5     amended to read as follows:
 7-6           Sec. 32.051.  Exemption of River Authority From Wholesale
 7-7     Rate Regulation.  Notwithstanding any other provision of this
 7-8     title, the commission may not directly or indirectly regulate
 7-9     revenue requirements, rates, fuel costs, fuel charges, or fuel
7-10     acquisitions that are related to the generation and sale of
7-11     electricity at wholesale, and not to ultimate consumers, by a river
7-12     authority operating a steam generating plant on or before
7-13     January 1, 1999.
7-14           Sec. 32.052.  Ability of Certain River Authorities to
7-15     Construct Improvements.  A river authority operating a steam
7-16     generating plant on or before January 1, 1999, may acquire,
7-17     finance, construct, rebuild, repower, and use new or existing power
7-18     plants, equipment, transmission lines, or other assets to sell
7-19     electricity exclusively at wholesale to:
7-20                 (1)  a purchaser in San Saba, Llano, Burnet, Travis,
7-21     Bastrop, Blanco, Colorado, or Fayette County; or
7-22                 (2)  a purchaser in an area served by the river
7-23     authority on January 1, 1975.
7-24           SECTION 5.  Section 32.053, Utilities Code, is amended by
7-25     amending Subsections (b) and (f) and adding Subsection (g) to read
7-26     as follows:
 8-1           (b)  Notwithstanding a river authority's enabling legislation
 8-2     or Chapter 245, Acts of the 67th Legislature, Regular Session, 1981
 8-3     (Article 717p, Vernon's Texas Civil Statutes), a corporation may:
 8-4                 (1)  acquire, finance, construct, rebuild, repower,
 8-5     operate, or sell a facility directly related to the generation of
 8-6     electricity; [and]
 8-7                 (2)  sell, at wholesale only, the output of the
 8-8     facility to a purchaser, other than an ultimate consumer, at any
 8-9     location in this state; and
8-10                 (3)  purchase and sell electricity, at wholesale only,
8-11     to a purchaser, other than an ultimate consumer, at any location in
8-12     this state.
8-13           (f)  The proceeds from the sale of bonds or other obligations
8-14     the interest on which is exempt from taxation and that are issued
8-15     by a corporation or river authority subject to this section, other
8-16     than a bond or obligation available to an investor-owned utility or
8-17     exempt wholesale generator, may not be used by the corporation[,
8-18     and may not have been used,] to finance the construction or
8-19     acquisition of or the rebuilding or repowering of a facility for
8-20     the generation of electricity by the corporation.
8-21           (g)  Notwithstanding any other law, the board of directors of
8-22     a river authority may sell, lease, loan, or otherwise transfer
8-23     some, all, or substantially all of the electric generation property
8-24     of the river authority to a nonprofit corporation authorized under
8-25     this section.  The property transfer shall be made pursuant to
8-26     terms and conditions approved by the board of directors of the
 9-1     river authority.
 9-2           SECTION 6.  Section 35.001, Utilities Code, is amended to
 9-3     read as follows:
 9-4           Sec. 35.001.  Definition.  In this subchapter, "electric
 9-5     utility" includes a municipally owned utility and an electric
 9-6     cooperative.
 9-7           SECTION 7.  Section 35.004, Utilities Code, is amended to
 9-8     read as follows:
 9-9           Sec. 35.004.  PROVISION OF TRANSMISSION SERVICE.  (a)  An
9-10     electric utility or transmission and distribution utility that owns
9-11     or operates transmission facilities shall provide wholesale
9-12     transmission service at rates and terms, including terms of access,
9-13     that are comparable to the rates and terms of the utility's own use
9-14     of its system.
9-15           (b)  The commission shall ensure that an electric utility or
9-16     transmission and distribution utility provides nondiscriminatory
9-17     access to wholesale transmission service for qualifying facilities,
9-18     exempt wholesale generators, power marketers, power generation
9-19     companies, retail electric providers, and other electric utilities
9-20     or transmission and distribution utilities.
9-21           (c)  When an electric utility or transmission and
9-22     distribution utility provides wholesale transmission service at the
9-23     request of a third party, the commission shall ensure that the
9-24     utility recovers the utility's reasonable costs in providing
9-25     wholesale transmission services necessary for the transaction from
9-26     the entity for which the transmission is provided so that the
 10-1    utility's other customers do not bear the costs of the service.
 10-2          (d)  The commission may price wholesale transmission services
 10-3    based in whole or in part on the postage stamp method of pricing
 10-4    under which a transmission-owning utility's rate is based on the
 10-5    utility's annual costs of transmission divided by the total demand
 10-6    placed on the combined transmission systems of all such
 10-7    transmission-owning utilities within a power region.
 10-8          (e)  The commission shall ensure that ancillary services
 10-9    necessary to facilitate the transmission of electric energy are
10-10    available at reasonable prices with terms and conditions that are
10-11    not unreasonably preferential, prejudicial, discriminatory,
10-12    predatory, or anticompetitive.  In this subsection, "ancillary
10-13    services" means services necessary to facilitate the transmission
10-14    of electric energy including but not limited to load following,
10-15    standby power, backup power, reactive power, and such other
10-16    services as the commission may determine by rule.
10-17          SECTION 8.  Subsection (b), Section 35.005, Utilities Code,
10-18    is amended to read as follows:
10-19          (b)  The commission may require transmission service at
10-20    wholesale, including the construction or enlargement of a
10-21    facility[, in a proceeding not related to approval of an integrated
10-22    resource plan].
10-23          SECTION 9.  Section 35.033, Utilities Code, is amended to
10-24    read as follows:
10-25          Sec. 35.033.  Affiliate Wholesale Provider.  An affiliate of
10-26    an electric utility may be an exempt wholesale generator or power
 11-1    marketer and may sell electric energy to its affiliated electric
 11-2    utility in accordance with [Chapter 34 and other] laws governing
 11-3    wholesale sales of electric energy.
 11-4          SECTION 10.  Section 35.034, Utilities Code, is amended by
 11-5    adding Subsection (c) to read as follows:
 11-6          (c)  For purposes of this section, "electric utility" does
 11-7    not include a river authority.
 11-8          SECTION 11.  Section 35.035, Utilities Code, is amended by
 11-9    adding Subsection (d) to read as follows:
11-10          (d)  For purposes of this section, "electric utility" does
11-11    not include a river authority.
11-12          SECTION 12.  Section 36.008, Utilities Code, is amended to
11-13    read as follows:
11-14          Sec. 36.008.  STATE TRANSMISSION SYSTEM. In establishing
11-15    rates for an electric utility [not required to file an integrated
11-16    resource plan], the commission may review the state's transmission
11-17    system and make recommendations to the utility on the need to build
11-18    new power lines, upgrade power lines, and make other necessary
11-19    improvements and additions.
11-20          SECTION 13.  Section 36.052, Utilities Code, is amended to
11-21    read as follows:
11-22          Sec. 36.052.  ESTABLISHING REASONABLE RETURN.  In
11-23    establishing a reasonable return on invested capital, the
11-24    regulatory authority shall consider applicable factors, including:
11-25                (1)  [the efforts of the electric utility to comply
11-26    with its most recently approved integrated resource plan;]
 12-1                [(2)]  the efforts and achievements of the utility in
 12-2    conserving resources;
 12-3                (2) [(3)]  the quality of the utility's services;
 12-4                (3) [(4)]  the efficiency of the utility's operations;
 12-5    and
 12-6                (4) [(5)]  the quality of the utility's management.
 12-7          SECTION 14.  Subsection (d), Section 36.058, is amended to
 12-8    read as follows:
 12-9          (d)  In making a finding regarding an affiliate transaction[,
12-10    including an affiliate transaction subject to Chapter 34,] the
12-11    regulatory authority shall:
12-12                (1)  determine the extent to which the conditions and
12-13    circumstances of that transaction are reasonably comparable
12-14    relative to quantity, terms, date of contract, and place of
12-15    delivery; and
12-16                (2)  allow for appropriate differences based on that
12-17    determination.
12-18          SECTION 15.  Section 36.201, Utilities Code, is amended to
12-19    read as follows:
12-20          Sec. 36.201.  AUTOMATIC ADJUSTMENT FOR CHANGES IN COSTS.
12-21    Except as permitted by [Chapter 34 or] Section 36.204, the
12-22    commission may not establish a rate or tariff that authorizes an
12-23    electric utility to automatically adjust and pass through to the
12-24    utility's customers a change in the utility's fuel or other costs.
12-25          SECTION 16.  Section 36.204, Utilities Code, is amended to
12-26    read as follows:
 13-1          Sec. 36.204.  COST RECOVERY AND INCENTIVES.  In establishing
 13-2    rates for an electric utility [not required to file an integrated
 13-3    resource plan], the commission may:
 13-4                (1)  allow timely recovery of the reasonable costs of
 13-5    conservation, load management, and purchased power, notwithstanding
 13-6    Section 36.201; and
 13-7                (2)  authorize additional incentives for conservation,
 13-8    load management, purchased power, and renewable resources.
 13-9          SECTION 17.  Section 36.207, Utilities Code, is amended to
13-10    read as follows:
13-11          Sec. 36.207.  USE OF MARK-UPS.  Any mark-ups approved under
13-12    [Chapter 34 or] Section 36.206 are an exceptional form of rate
13-13    relief that the electric utility may recover from ratepayers only
13-14    on a finding by the commission that the relief is necessary to
13-15    maintain the utility's financial integrity.
13-16          SECTION 18.  Section 37.001, Utilities Code, is amended to
13-17    read as follows:
13-18          Sec. 37.001.  DEFINITIONS.  In this chapter:
13-19                (1)  "Certificate" means a certificate of convenience
13-20    and necessity.
13-21                (2)  "Electric utility" includes an electric
13-22    cooperative.
13-23                (3)  "Retail electric utility" means a person,
13-24    political subdivision, or agency that operates, maintains, or
13-25    controls in this state a facility to provide retail electric
13-26    utility service.  The term does not include a corporation described
 14-1    by Section 32.053 to the extent that the corporation sells
 14-2    electricity exclusively at wholesale and not to the ultimate
 14-3    consumer.  A qualifying cogenerator that sells electric energy at
 14-4    retail to the sole purchaser of the cogenerator's thermal output
 14-5    under Sections 35.061 and 36.007 is not for that reason considered
 14-6    to be a retail electric utility.
 14-7          SECTION 19.  Subchapter B, Chapter 37, is amended by adding
 14-8    Section 37.060 to read as follows:
 14-9          Sec. 37.060.  DIVISION OF MULTIPLY CERTIFICATED SERVICE
14-10    AREAS.  (a)  If requested by a retail electric utility that is
14-11    providing customer choice to all of its retail customers, the
14-12    commission shall examine all areas within the retail electric
14-13    utility's service area that are also certificated to one or more
14-14    other retail electric utilities and, after notice and hearing,
14-15    shall amend the electric utilities' certificates so that only one
14-16    retail electric utility is certificated to provide distribution
14-17    services in any area.  Only retail electric utilities certificated
14-18    to serve an area on June 1, 1999, may continue to serve the area or
14-19    portion of the area under an amended certificate of convenience and
14-20    necessity.
14-21          (b)  This section shall not apply in any area in which a
14-22    municipally owned utility is certificated to provide retail
14-23    electric utility service if the municipally owned utility serving
14-24    the area files with the commission by February 1, 2000, a request
14-25    that areas within the certificated service area of the municipally
14-26    owned utility remain as presently certificated.
 15-1          (c)  The commission shall enter its order dividing multiply
 15-2    certificated areas within one year of the date a request is
 15-3    received.
 15-4          (d)  In amending certificates under this section, the
 15-5    commission shall take into consideration the factors set out in
 15-6    Section 37.056.
 15-7          (e)  Notwithstanding Section 37.059, the commission shall
 15-8    revoke certificates to the extent necessary to achieve the division
 15-9    of retail electric service areas as provided by this section.
15-10          (f)  Unless otherwise agreed by the affected retail electric
15-11    utilities, each retail electric utility shall be allowed to
15-12    continue to provide service to the location of
15-13    electricity-consuming facilities it is serving on the date an
15-14    application for division of the affected multiply certificated
15-15    service areas is filed.  No customer shall be permitted to switch
15-16    from one retail electric utility to another while an application
15-17    for division of the affected multiply certificated service areas is
15-18    pending.
15-19          (g)  If on June 1, 1999, retail service is being provided in
15-20    an area by another retail electric utility with the written consent
15-21    of the retail electric utility certificated to serve the area, such
15-22    consent shall be filed with the commission.  Upon notification of
15-23    such consent and a request by the affected retail electric
15-24    utilities to amend the relevant certificates, the commission may
15-25    grant an exception or amend a retail electric utility's
15-26    certificate.
 16-1          (h)  The commission shall not grant a retail electric utility
 16-2    certificate to serve an area if the effect of the grant would cause
 16-3    the area to be multiply certificated.
 16-4          SECTION 20.  Section 38.001, Utilities Code, is amended to
 16-5    read as follows:
 16-6          Sec. 38.001.  GENERAL STANDARD.  An electric utility and an
 16-7    electric cooperative shall furnish service, instrumentalities, and
 16-8    facilities that are safe, adequate, efficient, and reasonable.
 16-9          SECTION 21.  Section 38.004, Utilities Code, is amended to
16-10    read as follows:
16-11          Sec. 38.004.  MINIMUM CLEARANCE STANDARD.  Notwithstanding
16-12    any other law, a transmission or distribution line owned by an
16-13    electric utility or an electric cooperative must be constructed,
16-14    operated, and maintained, as to clearances, in the manner described
16-15    by the National Electrical Safety Code Standard ANSI (c)(2), as
16-16    adopted by the American National Safety Institute and in effect at
16-17    the time of construction.
16-18          SECTION 22.  Subchapter A, Chapter 38,  Utilities Code, is
16-19    amended by adding Section 38.005 to read as follows:
16-20          Sec. 38.005.  ELECTRIC SERVICE RELIABILITY MEASURES.
16-21    (a)  The commission shall implement service quality and reliability
16-22    standards relating to the delivery of electricity to retail
16-23    customers by electric utilities and transmission and distribution
16-24    utilities.  The commission by rule shall develop reliability
16-25    standards including but not limited to the following:
16-26                (1)  the system-average interruption frequency index;
 17-1                (2)  the system-average interruption duration index;
 17-2                (3)  achievement of average response time for customer
 17-3    service requests or inquiries; or
 17-4                (4)  other standards that the commission finds
 17-5    reasonable and appropriate.
 17-6          (b)  The standards implemented under Subsection (a) shall
 17-7    require each electric utility and transmission and distribution
 17-8    utility subject to this section to maintain adequately trained and
 17-9    experienced personnel throughout the utility's service area so that
17-10    the utility is able to fully and adequately comply with the
17-11    appropriate service quality and reliability standards.
17-12          (c)  The standards shall ensure that electric utilities do
17-13    not neglect any geographic area, including communities of less than
17-14    1,000 persons and low-income areas, with regard to system
17-15    reliability.
17-16          (d)  The commission may require each electric utility and
17-17    transmission and distribution utility to supply data to assist the
17-18    commission in developing the reliability standards.
17-19          (e)  All generation providers shall be obligated to comply
17-20    with any operational criteria duly established by the independent
17-21    system operator or adopted by the commission.
17-22          SECTION 23.  Section 38.071, Utilities Code, is amended to
17-23    read as follows:
17-24          Sec. 38.071.  Improvements in Service; Interconnecting
17-25    Service.  The commission, after notice and hearing, may:
17-26                (1)  order an electric utility to provide specified
 18-1    improvements in its service in a specified area if:
 18-2                      (A)  service in the area is inadequate or
 18-3    substantially inferior to service in a comparable area; and
 18-4                      (B)  requiring the company to provide the
 18-5    improved service is reasonable; or
 18-6                (2)  order two or more electric utilities or electric
 18-7    cooperatives to establish specified facilities for interconnecting
 18-8    service.
 18-9          SECTION 24.  Subtitle B, Title 2, Utilities Code, is amended
18-10    by adding Chapters 39, 40, and 41 to read as follows:
18-11          CHAPTER 39.  RESTRUCTURING OF ELECTRIC UTILITY INDUSTRY
18-12                     SUBCHAPTER A.  GENERAL PROVISIONS
18-13          Sec. 39.001.  LEGISLATIVE POLICY AND PURPOSE.  (a)  This
18-14    chapter is enacted to protect the public interest during the
18-15    transition to and in the establishment of a fully competitive
18-16    electric power industry.
18-17          (b)  The legislature finds that it is in the public interest
18-18    to:
18-19                (1)  implement on January 1, 2002, a competitive retail
18-20    electric market that allows each retail customer to choose the
18-21    customer's provider of electricity and that encourages full and
18-22    fair competition among all providers of electricity;
18-23                (2)  allow utilities with uneconomic generation-related
18-24    assets and purchased power contracts to recover the reasonable
18-25    excess costs over market of such assets and purchased power
18-26    contracts; and
 19-1                (3)  educate utility customers about anticipated
 19-2    changes in the provision of retail electric service to ensure that
 19-3    the benefits of the competitive market reach all customers.
 19-4          Sec. 39.002.  APPLICABILITY.  This chapter, other than
 19-5    Sections 39.155, 39.157(d), and 39.203, does not apply to a
 19-6    municipally owned utility or an electric cooperative corporation.
 19-7    If there is a conflict between the specific provisions of this
 19-8    chapter and any other provisions of this title, except for Chapters
 19-9    40 and 41, the provisions of this chapter control.
19-10              SUBCHAPTER B.  TRANSITION TO COMPETITIVE RETAIL
19-11                              ELECTRIC MARKET
19-12          Sec. 39.051.  UNBUNDLING.  (a)  On or before September 1,
19-13    2000, each electric utility shall unbundle its costs and rates into
19-14    generation, transmission, distribution, and retail energy services
19-15    and a system benefit fund charge and expected competition
19-16    transition charge.
19-17          (b)  Not later than January 1, 2002, each electric utility
19-18    shall separate its business activities from one another into the
19-19    following units:
19-20                (1)  a power generation company;
19-21                (2)  a retail electric provider; and
19-22                (3)  a transmission and distribution utility.
19-23          (c)  An electric utility may accomplish the separation
19-24    required by Subsection (b) either through the creation of separate
19-25    nonaffiliated companies or separate affiliated companies owned by a
19-26    common holding company or through the sale of assets to a third
 20-1    party.
 20-2          (d)  Each electric utility shall unbundle under this section
 20-3    in a manner that provides for a separation of personnel,
 20-4    information flow, functions, and operations.
 20-5          (e)  If the commission determines that a power region will
 20-6    not qualify for customer choice under Section 39.152 by January 1,
 20-7    2002, it may adjust the filing and implementation dates in this
 20-8    section for utilities in that region.
 20-9          Sec. 39.052.  FREEZE ON EXISTING RETAIL BASE RATE TARIFFS.
20-10    (a)  Until January 1, 2002, an electric utility shall provide
20-11    retail electric service within its certificated service area in
20-12    accordance with the electric utility's retail base rate tariffs in
20-13    effect on September 1, 1999, including its purchased power cost
20-14    recovery factor.
20-15          (b)  During the freeze period an electric utility may not
20-16    increase its retail base rates above the rates provided by this
20-17    section except for losses caused by force majeure as provided by
20-18    Section 39.055.
20-19          (c)  Notwithstanding any other provision of this title,
20-20    during the freeze period the regulatory authority may not reduce
20-21    the retail base rates of an electric utility.
20-22          (d)  During the freeze period the retail base rates, overall
20-23    revenues, return on invested capital, and net income of an electric
20-24    utility are not subject to complaint, hearing, or determination as
20-25    to reasonableness.
20-26          (e)  An electric utility that has a rate proceeding pending
 21-1    before the commission as of January 2, 1999, shall provide service
 21-2    in accordance with the tariffs approved in that proceeding from the
 21-3    date of approval until the end of the freeze period.
 21-4          (f)  Nothing in this section affects the authority of the
 21-5    commission to fulfill its obligations under Section 39.262.
 21-6          Sec. 39.053.  COST RECOVERY ADJUSTMENTS.  This subchapter
 21-7    does not limit or alter the ability of an electric utility during
 21-8    the freeze period to revise its fuel factor or to reconcile fuel
 21-9    expenses and to either refund fuel overcollections or surcharge
21-10    fuel undercollections to customers, as authorized by its tariffs
21-11    and Sections 36.203 and 36.205.
21-12          Sec. 39.054.  RETAIL ELECTRIC SERVICE DURING THE FREEZE
21-13    PERIOD.  (a)  An electric utility shall provide retail electric
21-14    service during the freeze period in accordance with any contract
21-15    terms applicable to a particular retail customer approved by the
21-16    regulatory authority and in effect on December 31, 1998.
21-17          (b)  Nothing in Sections 39.052(c) and (d) shall be construed
21-18    to restrict any customer's right to complain during the freeze
21-19    period to the regulatory authority regarding the quality of retail
21-20    electric service provided by the electric utility or the
21-21    applicability of an electric utility's particular tariff to the
21-22    customer.
21-23          (c)  Nothing in this title shall be construed to restrict an
21-24    electric utility, voluntarily and at its sole discretion, from
21-25    offering new services or new tariff options to its customers during
21-26    the freeze period.
 22-1          (d)  Any offering of new services or tariff options under
 22-2    this section shall be equal to or greater than an electric
 22-3    utility's long-run marginal cost and not be unreasonably
 22-4    preferential, prejudicial, discriminatory, predatory, or
 22-5    anticompetitive.
 22-6          (e)  Revenue from any new offering under this section shall
 22-7    be accounted for in a manner consistent with Section 36.007.
 22-8          Sec. 39.055.  FORCE MAJEURE.  (a)  An electric utility may
 22-9    recover losses resulting from force majeure through an increase in
22-10    its retail base rates during the freeze period.
22-11          (b)  Notwithstanding Subchapter C, Chapter 36, the regulatory
22-12    authority, after a hearing to determine the electric utility's
22-13    losses from force majeure, shall permit the utility to fully
22-14    collect any approved force majeure increase through an appropriate
22-15    customer surcharge mechanism.
22-16          (c)  For purposes of this section, "force majeure" means a
22-17    major event or combination of major events, including new or
22-18    expanded state or federal statutory or regulatory requirements;
22-19    hurricanes, tornadoes, ice storms, or other natural disasters; or
22-20    acts of war, terrorism, or civil disturbance, beyond the control of
22-21    an electric utility that the regulatory authority finds increases
22-22    the utility's total nonfuel costs or decreases the utility's total
22-23    nonfuel revenues related to the generation and delivery of
22-24    electricity by more than 10 percent for any calendar year during
22-25    the freeze period.  The term does not include any changes in
22-26    general economic conditions such as inflation, interest rates, or
 23-1    other factors of general application.
 23-2                     SUBCHAPTER C. RETAIL COMPETITION
 23-3          Sec. 39.101.  CUSTOMER SAFEGUARDS. (a)  Before retail
 23-4    competition begins on January 1, 2002, the commission shall ensure
 23-5    that retail customer protections are established that entitle a
 23-6    customer:
 23-7                (1)  to safe, reliable, and reasonably priced
 23-8    electricity, including protection against service disconnections in
 23-9    extreme weather or in cases of medical emergency or nonpayment for
23-10    unrelated services;
23-11                (2)  to privacy of customer consumption and credit
23-12    information;
23-13                (3)  to bills presented in a clear format and in
23-14    language readily understandable by customers;
23-15                (4)  to the option to have all electric services on a
23-16    single bill, except in those instances where multiple bills are
23-17    allowed under Chapters 40 and 41;
23-18                (5)  to protection from discrimination on the basis of
23-19    race, color, sex, nationality, religion, or marital status;
23-20                (6)  to accuracy of metering and billing;
23-21                (7)  to information in English and Spanish and any
23-22    other language as necessary concerning rates, key terms and
23-23    conditions, and the environmental impact of certain production
23-24    facilities;
23-25                (8)  to information in English and Spanish and any
23-26    other language as necessary concerning low-income assistance
 24-1    programs and deferred payment plans; and
 24-2                (9)  to other information or protections necessary to
 24-3    ensure high-quality service to customers.
 24-4          (b)  A customer is entitled:
 24-5                (1)  to be informed about rights and opportunities in
 24-6    the transition to a competitive electric industry;
 24-7                (2)  to choose the customer's retail electric provider
 24-8    consistent with this chapter, to have that choice honored, and to
 24-9    assume that the customer's chosen provider will not be changed
24-10    without the customer's informed consent;
24-11                (3)  to have access to providers of energy efficiency
24-12    services and to providers of energy generated by renewable energy
24-13    resources;
24-14                (4)  to be served by a provider of last resort that
24-15    offers a commission-approved standard service package;
24-16                (5)  to receive sufficient information to make an
24-17    informed choice of service provider;
24-18                (6)  to be protected from unfair, misleading, or
24-19    deceptive practices, including protection from being billed for
24-20    services that were not authorized or provided; and
24-21                (7)  to have an impartial and prompt resolution of
24-22    disputes with its chosen retail electric provider and transmission
24-23    and distribution utility.
24-24          (c)  The commission shall adopt and enforce such rules as may
24-25    be necessary or appropriate to carry out Subsections (a) and (b),
24-26    including but not limited to rules for minimum service standards
 25-1    for a retail electric provider relating to customer deposits and
 25-2    the extension of credit, switching fees, levelized billing
 25-3    programs, termination of service, and quality of service.  The
 25-4    commission has jurisdiction over all providers of electric service
 25-5    in enforcing Subsections (a) and (b) and may assess civil and
 25-6    administrative penalties under Section 15.023 and seek civil
 25-7    penalties under Section 15.028.
 25-8          (d)  On or before December 31, 2001, the commission shall
 25-9    modify its current rules regarding customer protections to ensure
25-10    that at least the same level of customer protection against
25-11    potential abuses and the same quality of service that exists on
25-12    December 31, 1999, is maintained in a restructured electric
25-13    industry.
25-14          Sec. 39.102.  RETAIL CUSTOMER CHOICE.  (a)  Each retail
25-15    customer in the state, except retail customers in power regions
25-16    that are not certified as qualifying for competition by the
25-17    commission and retail customers of electric cooperative
25-18    corporations and municipally owned utilities that have not opted
25-19    for customer choice, shall have customer choice on and after
25-20    January 1, 2002.
25-21          (b)  The affiliated retail electric provider of the electric
25-22    utility serving a retail customer on December 31, 2001, may
25-23    continue to serve that customer until the customer chooses service
25-24    from a different retail electric provider.
25-25          (c)  An electric utility that has in effect on January 1,
25-26    1999, and extending beyond January 1, 2002, a systemwide rate
 26-1    freeze for residential and commercial retail customers in this
 26-2    state that has been found by the regulatory authority to be in the
 26-3    public interest is exempt from the provisions of Sections 39.153,
 26-4    39.154, 39.156, and 39.157 and Subchapters E and F unless
 26-5    application of the provisions is permitted by a federal court
 26-6    having jurisdiction and by the regulatory authority.  If such
 26-7    provisions are not permitted to be applied to such a utility by a
 26-8    federal court having jurisdiction or by the regulatory authority,
 26-9    the utility shall offer retail customer choice at the later of
26-10    either the end of its prior-approved rate freeze period or when the
26-11    region in which the utility serves is determined to be a qualifying
26-12    power region under Section 39.152 and shall have no claim for
26-13    stranded cost recovery under this chapter.
26-14          (d)  A request for a determination under Subsection (c) as to
26-15    whether an electric utility should be exempt may be made by any
26-16    ratepayer of the utility.  In making its determination under
26-17    Subsection (c), the regulatory authority shall consider:
26-18                (1)  the total economic cost to customers as compared
26-19    to the systemwide rate freeze referenced in Subsection (c);
26-20                (2)  the impact on the utility's financial integrity;
26-21    and
26-22                (3)  whether the exemption is in the public interest.
26-23          Sec. 39.103.  COMMISSION AUTHORITY TO DELAY COMPETITION AND
26-24    SET NEW RATES.  If the commission determines under Section 39.104
26-25    that a power region is unable to offer fair competition and
26-26    reliable service to all retail customer classes on January 1, 2002,
 27-1    or that the power region fails to meet the requirements of Section
 27-2    39.152, the commission shall delay customer choice for the power
 27-3    region and may on or after January 1, 2002, establish new rates for
 27-4    all electric utilities in the power region as provided by Chapter
 27-5    36.
 27-6          Sec. 39.104.  CUSTOMER CHOICE PILOT PROJECTS.  (a)  Customer
 27-7    choice pilot projects may be used to allow the commission to
 27-8    evaluate the ability of each power region and electric utility to
 27-9    implement customer choice.
27-10          (b)  The commission shall require each electric utility
27-11    operating in ERCOT to offer customer choice in its service area
27-12    amounting to five percent of the utility's combined load of all
27-13    customer classes beginning on January 1, 2001.
27-14          (c)  The commission may require an electric utility operating
27-15    outside of ERCOT to offer customer choice in its service area
27-16    amounting to five percent of the utility's combined load of all
27-17    customer classes beginning on January 1, 2001.
27-18          (d)  The load designated for customer choice under this
27-19    section shall be distributed among all customer classes of a
27-20    utility consistent with the purpose of this section and subject to
27-21    commission approval.
27-22          (e)  Each utility operating a pilot project under this
27-23    section shall charge residential and small commercial customers in
27-24    accordance with Section 39.052.
27-25          (f)  The commission may prescribe reporting requirements it
27-26    considers necessary to evaluate a pilot project consistent with the
 28-1    purpose of this section.
 28-2          (g)  Customers having customer choice under this section
 28-3    shall be billed as provided by Section 39.107.
 28-4          (h)  The commission may prescribe terms and conditions it
 28-5    considers necessary to prohibit anticompetitive practices and to
 28-6    encourage customer choice offered under this section.
 28-7          Sec. 39.105.  LIMITATION ON SALE OF ELECTRICITY.  After
 28-8    January 1, 2002, in areas in which customer choice has been
 28-9    introduced, a transmission and distribution utility may not sell
28-10    electricity or otherwise participate in the market for electricity.
28-11          Sec. 39.106.  PROVIDER OF LAST RESORT.  (a)  The commission
28-12    shall designate retail electric providers in areas of the state in
28-13    which customer choice is in effect to serve as providers of last
28-14    resort.
28-15          (b)  A provider of last resort shall offer a standard retail
28-16    service package for each class of customers designated by the
28-17    commission at a fixed, nondiscountable rate approved by the
28-18    commission.
28-19          (c)  A provider of last resort shall provide the standard
28-20    retail service package to any requesting customer in the territory
28-21    for which it is the provider of last resort.
28-22          (d)  For all areas of the state for which the commission has
28-23    determined that customer choice is to be introduced on January 1,
28-24    2002, the commission shall designate the provider or providers of
28-25    last resort no later than June 1, 2001.  For areas of the state for
28-26    which customer choice is not to be introduced on January 1, 2002,
 29-1    the commission shall designate the provider or providers of last
 29-2    resort at the earliest feasible date after determining that
 29-3    conditions for permitting customer choice in that area have been
 29-4    met but no later than 180 days before customer choice is to begin.
 29-5          (e)  The commission shall determine the procedures and
 29-6    criteria, which may include the solicitation of bids, for
 29-7    designating a provider or providers of last resort.  The commission
 29-8    may redesignate the provider of last resort according to a schedule
 29-9    it considers appropriate.
29-10          (f)  In the event that no retail electric provider applies to
29-11    be the provider of last resort for a given area of the state on
29-12    reasonable terms and conditions, the commission may require a
29-13    retail electric provider to become the provider of last resort as a
29-14    condition of receiving or maintaining a certificate pursuant to
29-15    Section 39.352.
29-16          (g)  In the event that a retail electric provider fails to
29-17    serve any or all of its customers, the provider of last resort
29-18    shall offer each such customer the standard retail service package
29-19    for that customer class with no interruption of service to any
29-20    customer.
29-21          Sec. 39.107.  METERING AND BILLING SERVICES.  (a)  On
29-22    introduction of customer choice in a service area, metering
29-23    services for the area shall continue to be provided by the
29-24    transmission and distribution utility of the unbundled electric
29-25    utility that was serving the area prior to the introduction of
29-26    customer choice.  Metering services shall be provided on a
 30-1    competitive basis beginning:
 30-2                (1)  January 1, 2004, in areas in which customer choice
 30-3    is introduced January 1, 2002; and
 30-4                (2)  in areas in which customer choice begins at a
 30-5    later date, two years after the date that customer choice is
 30-6    introduced in the area.
 30-7          (b)  On introduction of customer choice in a service area,
 30-8    tenants of leased or rented property that is separately metered
 30-9    shall have the right to choose a retail electric provider, and the
30-10    owner of the property must grant access to transmission and
30-11    distribution utilities or retail electric providers for metering
30-12    purposes.
30-13          (c)  Beginning on the date of introduction of customer choice
30-14    in a service area, a transmission and distribution utility shall
30-15    bill a customer's retail electric provider for transmission and
30-16    distribution services.
30-17          (d)  A transmission and distribution utility may bill retail
30-18    customers at the request of a retail electric provider.  A
30-19    transmission and distribution utility that provides billing service
30-20    at the request of an affiliated retail electric provider shall
30-21    offer billing service on comparable terms and conditions to any
30-22    other requesting retail electric provider of a customer served by
30-23    the transmission and distribution utility.
30-24          (e)  Beginning on the date of introduction of customer choice
30-25    in a service area, any charges for metering and billing services
30-26    shall comply with rules adopted by the commission relating to
 31-1    nondiscriminatory rates of service.
 31-2          Sec. 39.108.  CONTRACTUAL OBLIGATIONS.  This chapter shall
 31-3    not:
 31-4                (1)  interfere with or abrogate the rights or
 31-5    obligations of any party, including a retail or wholesale customer,
 31-6    to a contract with an investor-owned electric utility, river
 31-7    authority, municipally owned utility, or electric cooperative
 31-8    corporation; or
 31-9                (2)  interfere with or abrogate the rights or
31-10    obligations of a party under a contract or agreement concerning
31-11    certificated utility service areas.
31-12                      SUBCHAPTER D.  MARKET STRUCTURE
31-13          Sec. 39.151.  ESSENTIAL ORGANIZATIONS.  (a)  Before obtaining
31-14    commission certification as a qualifying power region, a power
31-15    region must establish one or more independent organizations to
31-16    perform the following functions:
31-17                (1)  ensure access to the transmission and distribution
31-18    systems for all buyers and sellers of electricity on
31-19    nondiscriminatory terms;
31-20                (2)  ensure the reliability of the regional electrical
31-21    network;
31-22                (3)  ensure that information relating to a customer's
31-23    choice of retail electric provider is conveyed in a timely manner
31-24    to the persons who need such information; and
31-25                (4)  ensure that electricity production and delivery
31-26    are accurately accounted for among the generators and wholesale
 32-1    buyers and sellers in the region.
 32-2          (b)  For the purpose of this chapter, "independent
 32-3    organization" means an independent system operator or other person
 32-4    that is sufficiently independent of any producer or seller of
 32-5    electricity that its decisions will not be unduly influenced by any
 32-6    producer or seller.  An entity will be deemed to be independent if
 32-7    it is governed by a board that has equal representation of all
 32-8    segments of the electric market, including at least one
 32-9    residential, one commercial, and one industrial retail customer.
32-10          (c)  The commission shall certify an independent organization
32-11    or organizations to perform the functions set out in this section.
32-12          (d)  An independent organization certified by the commission
32-13    for a power region shall establish and enforce procedures,
32-14    consistent with this title and the commission's rules, relating to
32-15    the reliability of the regional electrical network and accounting
32-16    for the production and delivery of electricity among generators and
32-17    all other market participants.  The procedures shall be subject to
32-18    commission oversight and review.
32-19          (e)  The commission may authorize an independent organization
32-20    that is certified under this section to charge a reasonable rate to
32-21    wholesale buyers and sellers to cover the independent
32-22    organization's costs.
32-23          (f)  In implementing this section, the commission may
32-24    cooperate with the utility regulatory commission of another state
32-25    or the federal government and may hold a joint hearing or make a
32-26    joint investigation with that commission.
 33-1          (g)  If it amends its governance rules to allow
 33-2    representation reflecting the makeup of the retail market on its
 33-3    governing board in accordance with Subsection (b), the existing
 33-4    independent system operator in ERCOT will meet the criteria
 33-5    provided by Subsection (a) with respect to access to the
 33-6    transmission systems for all buyers and sellers of electricity in
 33-7    the ERCOT region and ensuring the reliability of the regional
 33-8    electrical network.  The ERCOT independent system operator may meet
 33-9    the criteria relating to the other functions of an independent
33-10    organization provided by Subsection (a) by adopting procedures and
33-11    acquiring the resources needed to carry out those functions.  The
33-12    commission shall determine whether the ERCOT independent system
33-13    operator may be certified as meeting the criteria relating to
33-14    Subsections (a) and (b).
33-15          (h)  The commission may delegate authority to the existing
33-16    independent system operator in ERCOT to enforce operating standards
33-17    within the regional electrical network and to establish and oversee
33-18    transaction settlement procedures.  After the introduction of
33-19    customer choice in ERCOT, the commission may establish the terms
33-20    and conditions for the ERCOT independent system operator's
33-21    authority to oversee utility dispatch functions.
33-22          (i)  A retail electric provider, transmission and
33-23    distribution utility, or power generation company shall observe all
33-24    scheduling, operating, and settlement protocols established by the
33-25    independent system operator in ERCOT.  Failure to comply with this
33-26    subsection may result in the revocation, suspension, or amendment
 34-1    of a certificate as provided by Section 39.356 or in the imposition
 34-2    of an administrative penalty as provided by Section 39.357.
 34-3          (j)  To the extent the commission has authority over an
 34-4    independent organization outside of ERCOT, the commission may
 34-5    delegate authority to the independent organization consistent with
 34-6    Subsection (h).
 34-7          Sec. 39.152.  QUALIFYING POWER REGIONS.  The commission shall
 34-8    certify a power region as qualifying for customer choice if:
 34-9                (1)  a sufficient number of interconnected utilities in
34-10    the power region fall under the operational control of an
34-11    independent organization as described by Section 39.151;
34-12                (2)  the power region has a generally applicable tariff
34-13    that guarantees open and nondiscriminatory access for all users as
34-14    provided by Section 39.203; and
34-15                (3)  no person owns, operates, or controls more than 20
34-16    percent of the installed generation capacity located in or capable
34-17    of delivering electricity to a power region.  In determining
34-18    whether a power region meets the requirements of this section, the
34-19    commission shall consider the extent to which the available
34-20    transmission facilities limit the delivery of electricity from
34-21    generators located outside of the power region.
34-22          Sec. 39.153.  CAPACITY AUCTION.  (a) Each electric utility
34-23    subject to this section shall sell at auction, conducted at least
34-24    60 days before the date set for customer choice to begin in the
34-25    power region in which the utility serves, entitlements to at least
34-26    15 percent of the electric utility's installed generation capacity.
 35-1    For the purposes of this section, the term "electric utility"
 35-2    includes the power generation company that is unbundled from the
 35-3    electric utility in accordance with Section 39.051.
 35-4          (b)  The obligation to auction the entitlements shall
 35-5    continue until the earlier of 60 months after the date customer
 35-6    choice is introduced in the power region or the date the commission
 35-7    determines that 40 percent or more of the electric power consumed
 35-8    by residential and small commercial customers within the affiliated
 35-9    transmission and distribution utility's certificated service area
35-10    before the onset of customer choice is provided by nonaffiliated
35-11    retail electric providers.
35-12          (c)  A retail electric provider affiliated with an electric
35-13    utility selling entitlements in the auction shall not be allowed to
35-14    purchase entitlements from the affiliated electric utility at the
35-15    auction required by this section.
35-16          (d)  The commission shall adopt rules by December 31, 2000,
35-17    that define the scope of the capacity entitlements to be auctioned.
35-18    Entitlements may be auctioned in blocks of less than 15 percent.
35-19    The rules shall state the minimum amount of capacity that can be
35-20    sold at auction as an entitlement.  At a minimum, the rules shall
35-21    provide that the entitlements:
35-22                (1)  may be sold and purchased in periods of no less
35-23    than one month nor longer than four years;
35-24                (2)  may be resold to any lawful purchaser, except for
35-25    a retail electric provider affiliated with the electric utility
35-26    that originally auctioned the entitlement;
 36-1                (3)  include no possessory interest in the unit from
 36-2    which the power is produced;
 36-3                (4)  include no obligations of a possessory owner of an
 36-4    interest in the unit from which the power is produced; and
 36-5                (5)  give the purchaser the right to designate the
 36-6    dispatch of the entitlement, subject to planned outages, outages
 36-7    beyond the control of the utility operating the unit, and other
 36-8    considerations subject to the oversight of the applicable
 36-9    independent organization.
36-10          (e)  The commission shall adopt rules by December 31, 2000,
36-11    that prescribe the procedure for the auction of the entitlement.
36-12    Such rules shall include:
36-13                (1)  a process for conducting the auction or auctions,
36-14    including who shall conduct it, how often it shall be conducted,
36-15    and how winning bidders shall be determined;
36-16                (2)  a process for the electric utility to designate
36-17    which generation units or combination of units are offered for
36-18    auction;
36-19                (3)  a provision for the utility to establish an
36-20    opening bid price based upon the electric utility's expected cost,
36-21    with the commission prescribing the means for determining the
36-22    opening bid price, which shall not include return on equity; and
36-23                (4)  a provision that allows a bidder to specify the
36-24    magnitude and term of the entitlement, subject to the conditions
36-25    established in Subsection (d).
36-26          (f)  In adopting the process under Subsection (e)(2), the
 37-1    commission shall consider the furtherance of the development of the
 37-2    competitive market, the cost of transmission, physical constraints
 37-3    of the transmission system, the proximity of the generation to
 37-4    load, economic efficiency, and such other factors that the
 37-5    commission finds relevant.  The process may provide for commission
 37-6    approval of the designation prior to auction.  The commission may
 37-7    consult with the applicable independent organization to develop the
 37-8    process.
 37-9          Sec. 39.154.  LIMITATION OF OWNERSHIP OF INSTALLED CAPACITY.
37-10    (a)  Beginning on the date of introduction of customer choice, no
37-11    power generation company may own and operate more than 20 percent
37-12    of the installed generation capacity located in, or capable of
37-13    delivering electricity to, a qualifying power region, which
37-14    capacity is available for sale to others.
37-15          (b)  In a power region not entirely within the state, the
37-16    commission may waive or modify the requirement in Subsection (a)
37-17    upon a finding of good cause.
37-18          (c)  In determining the percentage shares of installed
37-19    generation capacity under this section, the commission shall
37-20    combine capacity owned and controlled by a power generation company
37-21    and any entity that is affiliated with that power generation
37-22    company.
37-23          Sec. 39.155.  COMMISSION ASSESSMENT OF MARKET POWER.
37-24    (a)  Each person, municipally owned utility, electric cooperative
37-25    corporation, and river authority that owns generation facilities
37-26    and offers electricity for sale in this state shall report to the
 38-1    commission its installed generation capacity, the total amount of
 38-2    capacity available for sale to others, the total amount of capacity
 38-3    under contract to others, the total amount of capacity dedicated to
 38-4    its own use, its annual wholesale power sales in the state, its
 38-5    annual retail power sales in the state, and any other information
 38-6    necessary for the commission to assess market power or the
 38-7    development of a competitive retail market in Texas.  The
 38-8    commission shall by rule prescribe the nature and detail of such
 38-9    reporting requirements.
38-10          (b)  The ERCOT independent system operator shall submit an
38-11    annual report to the commission identifying existing and potential
38-12    transmission and distribution constraints and system needs,
38-13    alternatives for meeting system needs, and recommendations for
38-14    meeting system needs.  The first report shall be submitted on or
38-15    before October 1, 1999.  Subsequent reports shall be submitted by
38-16    January 15 of each year or as determined necessary by the
38-17    commission.
38-18          (c)  Before the date of introduction of customer choice in a
38-19    power region other than ERCOT, each electric utility owning
38-20    transmission and distribution facilities in that region shall
38-21    submit an annual report to the commission identifying existing and
38-22    potential transmission and distribution constraints and system
38-23    needs, alternatives for meeting system needs, and recommendations
38-24    for meeting system needs as directed by the commission.
38-25          (d)  After the introduction of customer choice in a
38-26    qualifying power region, the reports required by this section shall
 39-1    be submitted by the independent organization or organizations
 39-2    having authority over the power region or discrete areas thereof.
 39-3          Sec. 39.156.  MARKET POWER MITIGATION PLAN.  (a)  In this
 39-4    section, "market power mitigation plan" or "plan" means a written
 39-5    proposal by an electric utility or a power generation company for
 39-6    reducing its ownership and control of installed generation capacity
 39-7    as required by Section 39.154.
 39-8          (b)  An electric utility or power generation company owning
 39-9    and controlling more than 20 percent of the generation capacity
39-10    located in, or capable of delivering electricity to, a power region
39-11    shall file a market power mitigation plan with the commission no
39-12    later than December 31, 2000.
39-13          (c)  The plan may provide for:
39-14                (1)  an independent sale of generation plants;
39-15                (2)  a sale of generation capacity at an auction
39-16    subject to commission approval; or
39-17                (3)  any reasonable method of mitigation.
39-18          (d)  For the purposes of this section, generation capacity
39-19    shall be net of the generation capacity subject to an auction under
39-20    Section 39.153.
39-21          (e)  The plan shall be in a form prescribed by the commission
39-22    and shall provide any information the commission considers
39-23    necessary to evaluate the plan.
39-24          (f)  The commission shall approve, modify, or reject a plan
39-25    within 180 days after the date of a filing under Subsection (b).
39-26          (g)  In reaching its determination under Subsection (f), the
 40-1    commission shall consider:
 40-2                (1)  the degree to which the electric utility's or
 40-3    power generation company's stranded costs, if any, are minimized;
 40-4                (2)  whether on disposition of the generation assets
 40-5    the reasonable value is likely to be received;
 40-6                (3)  the effect of the plan on the electric utility's
 40-7    or power generation company's federal income taxes;
 40-8                (4)  the effect of the plan on the environment;
 40-9                (5)  the effect of the plan on current and potential
40-10    competitors in the generation market; and
40-11                (6)  whether the plan is consistent with the public
40-12    interest.
40-13          (h)  If an electric utility's or a power generation company's
40-14    market power mitigation plan is not approved before January 1,
40-15    2002, the commission may order the utility or company to conduct
40-16    capacity auctions according to Section 39.153, subject to
40-17    commission approval, of any capacity exceeding the maximum
40-18    allowable capacity described by Section 39.154.
40-19          (i)  An auction under Subsection (h) shall be held no later
40-20    than July 1, 2002.
40-21          Sec. 39.157.  COMMISSION AUTHORITY TO ADDRESS MARKET POWER.
40-22    (a)  The commission shall monitor market power associated with the
40-23    generation, transmission, distribution, and sale of electricity in
40-24    this state.  On a finding, after notice and opportunity for
40-25    hearing, that undue market power abuses are occurring, the
40-26    commission shall require reasonable mitigation of the market power
 41-1    by ordering the construction of additional transmission or
 41-2    distribution facilities, by requiring a reduction of generation
 41-3    capacity at auction or by some other form of disposition, by
 41-4    instituting price cap regulation, by setting appropriate
 41-5    restrictions on sales of electricity, by establishing limitations
 41-6    on the use of generation, transmission, or distribution facilities,
 41-7    or by any other reasonable remedy.
 41-8          (b)  Beginning on the date of introduction of customer
 41-9    choice, no person that owns generation facilities may own
41-10    transmission or distribution facilities in this state except for
41-11    those facilities necessary to interconnect a generation facility
41-12    with the transmission or distribution network.  However, nothing in
41-13    this chapter shall prohibit a power generation company affiliated
41-14    with a transmission and distribution utility from owning generation
41-15    facilities.
41-16          (c)  In order to avoid potential market power abuses and
41-17    cross-subsidizations between regulated and unregulated activities,
41-18    the commission shall adopt rules to govern transactions or
41-19    activities between a transmission and distribution utility and its
41-20    affiliates.
41-21          (d)  The commission shall by rule establish a code of conduct
41-22    that must be observed by all market participants and their
41-23    affiliates to protect against anticompetitive practices.
41-24          Sec. 39.158.  MERGERS AND CONSOLIDATIONS.  (a)  An owner of
41-25    electric generation facilities that offers electricity for sale in
41-26    the state and proposes to merge, consolidate, or otherwise become
 42-1    affiliated with another owner of electric generation facilities
 42-2    that offers electricity for sale in this state shall obtain the
 42-3    approval of the commission prior to closing.  Such approval shall
 42-4    be requested at least 120 days prior to the proposed closing.  The
 42-5    commission shall approve the transaction unless the commission
 42-6    finds that the transaction is inconsistent with the public interest
 42-7    or state or federal antitrust laws.  If the commission finds that
 42-8    the transaction as proposed is inconsistent with the public
 42-9    interest, the commission may condition approval of the transaction
42-10    on adoption of reasonable modifications to the transaction as
42-11    prescribed by the commission to mitigate potential market power
42-12    abuses.
42-13          (b)  A retail electric provider that proposes to merge,
42-14    consolidate, or otherwise become affiliated with another retail
42-15    electric provider in the state shall obtain the approval of the
42-16    commission prior to closing.  Such approval shall be requested at
42-17    least 120 days prior to the proposed closing.  The commission shall
42-18    approve the transaction unless the commission finds that the
42-19    transaction is inconsistent with the public interest or state or
42-20    federal antitrust laws or finds that the merged entity has failed
42-21    to satisfy the requirements of Section 39.352.  If the commission
42-22    finds that the transaction as proposed is inconsistent with the
42-23    public interest, the commission may condition approval of the
42-24    transaction on adoption of reasonable modifications to the
42-25    transaction as prescribed by the commission to mitigate potential
42-26    market power abuses.
 43-1          (c)  Owners of electric generation facilities and retail
 43-2    electric providers shall obtain commission approval as provided by
 43-3    this section as a condition of doing business in the state.
 43-4          (d)  Nothing in this section shall be construed to confer
 43-5    immunity from state or federal antitrust laws.  This section is
 43-6    intended to complement other state and federal antitrust
 43-7    provisions.  Therefore, antitrust remedies may also be sought in
 43-8    state or federal court to remedy anticompetitive activities.
 43-9             SUBCHAPTER E.  PRICE REGULATION AFTER COMPETITION
43-10          Sec. 39.201.  COST OF SERVICE TARIFFS AND CHARGES.  (a)  Each
43-11    electric utility shall, on or before September 1, 2000, file
43-12    proposed tariffs for its proposed transmission and distribution
43-13    utility.
43-14          (b)  The filing under this section shall include supporting
43-15    cost data for determination of nonbypassable delivery charges,
43-16    which shall be the sum of:
43-17                (1)  transmission and distribution utility charges by
43-18    customer class based on a forecasted 2002 test year;
43-19                (2)  a system benefit fund charge; and
43-20                (3)  an expected competition transition charge, if any.
43-21          (c)  Each electric utility shall also identify the unbundled
43-22    generation and retail energy service costs by customer class.
43-23          (d)  On or before July 1, 2001, and in accordance with a
43-24    schedule and procedures it establishes, the commission shall hold a
43-25    hearing and approve or modify and make effective as of January 1,
43-26    2002, the transmission and distribution utility's proposed tariffs
 44-1    for transmission and distribution services, the system benefit fund
 44-2    charge, and the expected competition transition charge, if any.
 44-3          (e)  The system benefit fund charge shall be that established
 44-4    by the commission pursuant to Section 39.603.
 44-5          (f)  The expected competition transition charge shall be that
 44-6    as determined under Subsections (g) and (h) and as implemented
 44-7    under Subsections (i)-(l).
 44-8          (g)  The expected competition transition charge approved by
 44-9    the commission shall be calculated from the amount of stranded
44-10    costs as defined in Subchapter F which are reasonably projected to
44-11    exist on the last day of the freeze period modified to reflect any
44-12    adjustments determined appropriate by the commission pursuant to
44-13    Section 39.261(c).
44-14          (h)  The electric utility shall use the ECOM administrative
44-15    model referenced in Section 39.262(h) to determine estimated
44-16    stranded costs.  The model must include updated company-specific
44-17    inputs, and updated natural gas price forecasts, as determined by
44-18    the commission.
44-19          (i)  An electric utility may, on commission approval:
44-20                (1)  securitize no more than 75 percent of its
44-21    estimated stranded costs and recover such charges through a
44-22    qualified intangible charge, pursuant to a qualified rate order
44-23    issued by the commission pursuant to Section 39.303;
44-24                (2)  implement, under bond, a nonbypassable charge of
44-25    up to 100 percent of its estimated stranded costs; or
44-26                (3)  use a combination of the two methods under
 45-1    Subdivisions (1) and (2).
 45-2          (j)  Any competition transition charge shall be allocated
 45-3    among retail customer classes based on the relevant customer class
 45-4    characteristics as of May 1, 1999, in accordance with the
 45-5    methodology used to allocate the costs of the underlying assets in
 45-6    the electric utility's most recent rate order.
 45-7          (k)  In determining the length of time over which costs under
 45-8    Subsection (h) may be recovered, the commission shall consider:
 45-9                (1)  the electric utility's rates as of the end of the
45-10    freeze period;
45-11                (2)  the sum of the transmission, distribution, and
45-12    system benefit fund charges;
45-13                (3)  the proportion of estimated stranded costs to the
45-14    invested capital of the electric utility; and
45-15                (4)  any other factor consistent with the public
45-16    interest as expressed in this chapter.
45-17          (l)  Two years after customer choice is introduced in the
45-18    electric utility's power region, the stranded cost estimate under
45-19    this section shall be reviewed and, if necessary, adjusted to
45-20    reflect a final, actual valuation in the true-up proceeding under
45-21    Section 39.262.  If, based on that proceeding, the competition
45-22    transition charge is not sufficient, the commission may extend the
45-23    collection period for the charge or, if necessary, increase the
45-24    charge.  Alternatively, if it is found in the true-up proceeding
45-25    that the competition transition charge is larger than is needed to
45-26    recover any remaining stranded costs, the commission may:
 46-1                (1)  reduce the competition transition charge, to the
 46-2    extent it has not been securitized;
 46-3                (2)  reverse, in whole or in part, the depreciation
 46-4    expense which has been redirected pursuant to Section 39.256;
 46-5                (3)  reduce the transmission and distribution utility's
 46-6    rates; or
 46-7                (4)  implement a combination of the elements in
 46-8    Subdivisions (1)-(3).
 46-9          (m)  If the commission determines that a power region will
46-10    not qualify for customer choice under Section 39.152 by January 1,
46-11    2002, it may adjust the filing and implementation dates in this
46-12    section for utilities in that region.
46-13          Sec. 39.202.  PRICE TO BEAT.  (a)  On and after January 1,
46-14    2002, in areas in which customer choice has been introduced, an
46-15    affiliated retail electric provider shall charge residential and
46-16    small commercial customers of its affiliated transmission and
46-17    distribution utility rates which, on a bundled basis, are five
46-18    percent less than the affiliated electric utility's corresponding
46-19    average residential and small commercial rates, on a bundled basis,
46-20    that were in effect on September 1, 1999, adjusted to reflect the
46-21    fuel factor determined as provided by Subsection (b).  These rates
46-22    on a bundled basis shall be known as the "price to beat" for
46-23    residential and small commercial customers.
46-24          (b)  For an area where customer choice is to be introduced on
46-25    January 1, 2002, the commission shall determine the fuel factor for
46-26    each electric utility in the area as of December 31, 2001.  For an
 47-1    area where customer choice is to be introduced subsequent to
 47-2    January 1, 2002, the commission shall determine the fuel factor for
 47-3    each electric utility in the area on the day prior to the day
 47-4    customer choice is introduced.
 47-5          (c)  Subsequent to the introduction of customer choice, each
 47-6    power generation company shall file a final fuel reconciliation for
 47-7    the period ending the day prior to the day customer choice is
 47-8    introduced.  The final fuel balance from that reconciliation shall
 47-9    be included in the true-up proceeding pursuant to Section 39.262.
47-10          (d)  An affiliated retail electric provider shall make public
47-11    its price to beat in a manner that provides adequate disclosure as
47-12    determined by the commission.
47-13          (e)  The affiliated retail electric provider may not charge
47-14    rates that are different from the price to beat until the earlier
47-15    of 60 months after the date customer choice is introduced in the
47-16    power region or the date the commission determines that 40 percent
47-17    or more of the electric power consumed by residential and small
47-18    commercial customers within the affiliated transmission and
47-19    distribution utility's certificated service area before the onset
47-20    of customer choice is provided by nonaffiliated retail electric
47-21    providers.
47-22          (f)  The commission shall establish procedures and reporting
47-23    requirements as necessary to monitor residential and small
47-24    commercial consumption in the transmission and distribution
47-25    utility's certificated service area for the purpose of determining
47-26    the duration of the continuation of the price to beat.
 48-1          (g)  The commission shall notify an affiliated retail
 48-2    electric provider at such time as the commission determines that
 48-3    the price to beat no longer applies to the retail electric
 48-4    provider.
 48-5          (h)  Following the true-up proceedings conducted pursuant to
 48-6    Section 39.262, the commission may adjust the price to beat
 48-7    consistent with the results of that proceeding.
 48-8          (i)  In this section, "small commercial customer" means a
 48-9    commercial customer having a peak demand of 1,000 kilowatts or
48-10    less.
48-11          Sec. 39.203.  TRANSMISSION AND DISTRIBUTION SERVICE.
48-12    (a)  All transmission and distribution utilities shall provide
48-13    transmission service at wholesale under Subchapter A, Chapter 35.
48-14    In addition, on and after January 1, 2002, the commission by rule
48-15    shall require a transmission and distribution utility to provide
48-16    transmission or distribution service, or both, at retail to an
48-17    electric utility, a power generation company, a retail electric
48-18    provider, a qualifying facility, an exempt wholesale generator, a
48-19    power marketer, a municipally owned utility, an electric
48-20    cooperative corporation, or an end-use customer at rates, terms of
48-21    access, and conditions that are comparable to those that apply to
48-22    the transmission and distribution utility and its affiliates.
48-23          (b)  An electric utility, an electric cooperative corporation
48-24    that has not opted for customer choice, or a municipally owned
48-25    utility that has not opted for customer choice shall provide
48-26    distribution service at wholesale.
 49-1          (c)  On or before January 1, 2002, the commission shall
 49-2    establish reasonable and comparable terms of access, conditions,
 49-3    and rates for open access on distribution facilities.
 49-4          (d)  The terms of access, conditions, and rates established
 49-5    under Subsection (c) shall be comparable to the terms of access,
 49-6    conditions, and rates that the utility applies to itself or its
 49-7    affiliates.  The rules shall also provide that all ancillary
 49-8    services provided by the utility to itself and its affiliates are
 49-9    also provided to third parties on request.
49-10          (e)  The commission may require an electric utility or a
49-11    transmission and distribution utility to construct or enlarge
49-12    facilities to ensure safe and reliable service for the state's
49-13    electric markets.
49-14          (f)  The commission's rules must be consistent with the
49-15    standards of this title and may not be contrary to an applicable
49-16    decision, rule, or policy statement of a federal regulatory agency
49-17    having jurisdiction.
49-18          (g)  Each qualifying power region shall have a generally
49-19    applicable tariff approved by the commission that guarantees open
49-20    and nondiscriminatory access as required by Section 39.152.
49-21          Sec. 39.204.  TARIFFS FOR OPEN ACCESS.  All transmission and
49-22    distribution utilities shall file tariffs implementing the open
49-23    access rules with the commission or federal regulatory authority
49-24    having jurisdiction over the transmission and distribution service
49-25    of the utility not later than the 90th day before the date customer
49-26    choice is offered.
 50-1          Sec. 39.205.  REGULATION OF COSTS FOLLOWING THE FREEZE
 50-2    PERIOD.  At the conclusion of the freeze period, any remaining
 50-3    costs associated with nuclear decommissioning obligations continue
 50-4    to be subject to cost of service rate regulation and shall be
 50-5    included as a nonbypassable charge to retail customers.
 50-6                 SUBCHAPTER F.  RECOVERY OF STRANDED COSTS
 50-7          Sec. 39.251.  DEFINITIONS.  In this subchapter:
 50-8                (1)  "Above market purchased power costs" means
 50-9    wholesale demand and energy costs that a utility is obligated to
50-10    pay under an existing purchased power contract to the extent the
50-11    costs are greater than the purchased power market value.
50-12                (2)  "Below market cost" means the excess of the market
50-13    value of generation assets over the net book value of the assets.
50-14                (3)  "Existing purchased power contract" means a
50-15    purchased power contract in effect on January 1, 1999.
50-16                (4)  "Generation assets" includes generation plants and
50-17    generation-related regulatory assets.
50-18                (5)  "Market value" means, for nonnuclear assets and
50-19    certain nuclear assets, the value the assets would have if bought
50-20    and sold in a bona fide third-party transaction or transactions on
50-21    the open market under Section 39.262(g) or, for certain nuclear
50-22    assets, as described by Section 39.262(h), the value determined
50-23    under the method provided by that subsection.
50-24                (6)  "Purchased power market value" means the value of
50-25    demand and energy bought and sold in a bona fide third-party
50-26    transaction or transactions on the open market and determined by
 51-1    using the weighted average costs of the highest three offers from
 51-2    the market for purchase of the demand and energy available under
 51-3    the existing purchased power contracts.
 51-4                (7)  "Regulatory assets" means costs that have been
 51-5    deferred for future recovery as a result of the practice of
 51-6    regulatory authorities, or by order of regulatory authorities, as
 51-7    offset by the applicable portion of investment tax credits
 51-8    permitted under the Internal Revenue Code, including:
 51-9                      (A)  unrecovered deferred income taxes recorded
51-10    under Statement of Financial Accounting Standard No. 109
51-11    ("Accounting for Income Taxes");
51-12                      (B)  plant accounting deferrals, including mirror
51-13    construction work in progress; and
51-14                      (C)  costs associated with reacquisition of
51-15    securities, canceled plants, litigation and settlement costs, and
51-16    voluntary retirement and severance programs.
51-17                (8)  "Retail stranded costs" means that part of net
51-18    stranded cost, taking into account below market costs, associated
51-19    with the provision of retail service.
51-20                (9)  "Stranded cost" means the excess of the net book
51-21    value of generation assets over the market value of the assets and
51-22    any above market purchased power costs.
51-23          Sec. 39.252.  RIGHT TO RECOVER STRANDED COSTS.  (a)  An
51-24    electric utility is allowed to recover all of its net, verifiable,
51-25    nonmitigable stranded costs incurred in purchasing power and
51-26    providing electric generation service.
 52-1          (b)  Recovery of retail stranded costs by an electric utility
 52-2    shall be from all existing or future retail customers, including
 52-3    the facilities, premises, and loads of such retail customers,
 52-4    within the utility's geographical certificated service area as it
 52-5    existed on May 1, 1999.
 52-6          (c)  In multiply certificated areas, a retail customer may
 52-7    not avoid stranded costs recovery charges by switching to another
 52-8    electric utility or a municipally owned utility.  A customer in a
 52-9    multiply certificated service area that was not taking service from
52-10    a particular electric utility on May 1, 1999, and does not do so
52-11    after that date is not responsible for paying retail stranded costs
52-12    of that utility.
52-13          Sec. 39.253.  ALLOCATION OF STRANDED COSTS.  Stranded costs
52-14    and below market costs shall be allocated among retail customer
52-15    classes, based on the relevant customer class characteristics as of
52-16    May 1, 1999, in accordance with the methodology used to allocate
52-17    the costs of the underlying assets in the electric utility's most
52-18    recent rate order.
52-19          Sec. 39.254.  USE OF REVENUES FOR UTILITIES WITH STRANDED
52-20    COSTS.  This subchapter provides a number of tools to an electric
52-21    utility to mitigate stranded costs.  Each electric utility that was
52-22    reported by the commission to have positive "excess costs over
52-23    market" (ECOM), denoted as the "base case" for the amount of
52-24    stranded costs before full retail competition in 2001 with respect
52-25    to its Texas jurisdiction, in the April 1998 Report to the Texas
52-26    Senate Interim Committee on Electric Utility Restructuring entitled
 53-1    "Potentially Strandable Investment (ECOM) Report:  1998 Update,"
 53-2    must use these tools to reduce the net book value of, otherwise
 53-3    referred to as "accelerate" the cost recovery of, its stranded
 53-4    costs each year.  Any positive difference under the report required
 53-5    by Section 39.257(b) shall be applied to the net book value of
 53-6    generation assets.
 53-7          Sec. 39.255.  USE OF REVENUES FOR UTILITIES WITH NO STRANDED
 53-8    COSTS.  Electric utilities that do not have stranded costs
 53-9    described by Section 39.254 shall flow any positive difference
53-10    under the report required by Section 39.257(b) back to its Texas
53-11    jurisdictional customers through the power cost recovery factor.
53-12          Sec. 39.256.  OPTION TO REDIRECT DEPRECIATION.  (a)  During
53-13    the freeze period, an electric utility described in Section 39.254
53-14    may redirect all or a part of the depreciation expense relating to
53-15    transmission and distribution assets to its net generation plant
53-16    assets.
53-17          (b)  The electric utility shall report a decision under
53-18    Subsection (a) to the commission and any other applicable
53-19    regulatory authority.
53-20          (c)  Any adjustments made to the book value of transmission
53-21    and distribution assets or the creation of any related regulatory
53-22    assets resulting from the redirection under this section shall be
53-23    accepted and applied by the commission for establishing net
53-24    invested capital and transmission and distribution rates for retail
53-25    customers in any proceeding occurring after the freeze period.
53-26          (d)  Notwithstanding the provisions of Subsection (c), the
 54-1    design of post-freeze-period retail rates may not:
 54-2                (1)  shift the allocation of responsibility for
 54-3    stranded costs;
 54-4                (2)  include the adjusted costs in wholesale
 54-5    transmission and distribution rates; or
 54-6                (3)  apply the adjustments for the purpose of
 54-7    establishing net invested capital and transmission and distribution
 54-8    rates for wholesale customers.
 54-9          Sec. 39.257.  ANNUAL REPORT.  (a)  Beginning with the 1999
54-10    calendar year, each electric utility shall file a report with the
54-11    commission at the end of each year during the freeze period under a
54-12    schedule and a format determined by the commission.
54-13          (b)  The report shall identify any positive difference
54-14    between annual revenues, reduced by the amount of annual revenues
54-15    under Section 36.205 and the revenues received under the
54-16    interutility billing process as adopted by the commission to
54-17    implement Sections 35.004, 35.006, and 35.007, and annual costs.
54-18          Sec. 39.258.  ANNUAL REPORT:  DETERMINATION OF ANNUAL COSTS.
54-19    For the purposes of determining the annual costs in each annual
54-20    report, the following amounts shall be used:
54-21                (1)  the Texas jurisdictional operation and maintenance
54-22    expense reflected in each utility's 1996 Federal Energy Regulatory
54-23    Commission Form 1, adjusted for costs under Sections 36.062,
54-24    36.203, and 36.205, and not indexed for inflation or load growth;
54-25                (2)  the amount of nuclear decommissioning expense
54-26    approved in the electric utility's last rate proceeding before the
 55-1    commission, as may be required to be adjusted to comply with
 55-2    applicable federal regulatory requirements;
 55-3                (3)  the depreciation rates approved in the electric
 55-4    utility's last rate proceeding before the commission;
 55-5                (4)  the amortization expense approved in the electric
 55-6    utility's last rate proceeding before the commission, except that
 55-7    if the items are fully amortized during the freeze period, the
 55-8    expense shall be adjusted accordingly;
 55-9                (5)  taxes and fees, including municipal franchise fees
55-10    to the extent not included in Subdivision (1), other than federal
55-11    income taxes, and assessments incurred that year;
55-12                (6)  federal income tax expense, computed according to
55-13    the stand-alone methodology; and
55-14                (7)  return on invested capital, computed by
55-15    multiplying invested capital as of December 31 of the report year,
55-16    determined as provided by Section 39.259, by the cost of capital
55-17    approved in the electric utility's most recent rate proceeding in
55-18    which the cost of capital was specifically adopted, or, in the case
55-19    of a range, the midpoint of the range, if the final rate order for
55-20    the proceeding was issued on or after January 1, 1992.  If such an
55-21    order does not exist, a cost of capital of 9.6 percent shall be
55-22    used.
55-23          Sec. 39.259.  ANNUAL REPORT:  DETERMINATION OF INVESTED
55-24    CAPITAL.  (a)  For the purposes of determining invested capital in
55-25    each annual report, the net plant in service, regulatory assets,
55-26    and deferred federal income taxes shall be updated each year.
 56-1          (b)  Capital additions to a plant in an amount less than
 56-2    1-1/2 percent of the electric utility's net plant in service on
 56-3    December 31, 1998, less plant items previously excluded by the
 56-4    commission, for each of the years 1999 through 2001 are presumed
 56-5    prudent.
 56-6          (c)  All other items in invested capital shall be as approved
 56-7    in the electric utility's last rate proceeding before the
 56-8    commission.
 56-9          Sec. 39.260.  USE OF GENERALLY ACCEPTED ACCOUNTING
56-10    PRINCIPLES.  (a)  The definition and identification of invested
56-11    capital and other terms used in this subchapter that affect the net
56-12    book value of generation assets and the treatment of transactions
56-13    performed under Section 35.035 and other transactions authorized by
56-14    this title or approved by the regulatory authority that affect the
56-15    net book value of generation assets during the freeze period shall
56-16    be treated in accordance with generally accepted accounting
56-17    principles as modified by regulatory accounting rules generally
56-18    applicable to utilities.
56-19          (b)  The principles and criteria described by Subsection (a),
56-20    including the criteria for applicability of Statement of Financial
56-21    Accounting Standards No. 71, shall be applied for purposes of this
56-22    subchapter as they existed on January 1, 1999.
56-23          Sec. 39.261.  REVIEW OF ANNUAL REPORT.  (a)  The annual
56-24    report filed under this subchapter is a public document and shall
56-25    be reviewed by the staff of the commission and the office of public
56-26    utility counsel.  Both staffs may review work papers and supporting
 57-1    documents and engage in discussions with the utility about the data
 57-2    underlying the reports.
 57-3          (b)  The staff of the commission and the office of public
 57-4    utility counsel shall communicate in writing to an electric utility
 57-5    not later than the 180th day after the date the report is filed if
 57-6    they have any disagreements with the data or computations.
 57-7          (c)  The commission shall finalize and resolve any
 57-8    disagreements related to the annual reports as follows:
 57-9                (1)  for each calendar year, the commission shall
57-10    finalize the annual reports prior to establishing the competition
57-11    transition charge pursuant to Section 39.201; and
57-12                (2)  for each calendar year, the commission shall
57-13    finalize the annual report and reflect the result as part of the
57-14    true-up proceeding pursuant to Section 39.262.
57-15          Sec. 39.262.  TRUE-UP PROCEEDING.  (a)  An electric utility,
57-16    together with its affiliated retail electric provider and its
57-17    affiliated transmission and distribution utility, may not be
57-18    permitted to overrecover stranded costs through the procedures
57-19    established by this section or through the application of the
57-20    measures provided by the other sections of this subchapter.
57-21          (b)  After the freeze period, an electric utility located in
57-22    a power region not subject to competition pursuant to Section
57-23    39.152 shall continue to file annual reports pursuant to Sections
57-24    39.257, 39.258, and 39.259 as if the freeze period remained in
57-25    effect, until such time as the power region qualifies for
57-26    competition under Section 39.152.  In addition, the commission
 58-1    staff and office of public utility counsel shall continue to review
 58-2    the annual reports as provided by Section 39.261.
 58-3          (c)  After January 1, 2004, or after two years following the
 58-4    beginning of competition in a power region, whichever is later, at
 58-5    a schedule and under procedures to be determined by the commission,
 58-6    each transmission and distribution utility, its affiliated retail
 58-7    electric provider, and its affiliated power generation company
 58-8    shall jointly file to finalize stranded costs pursuant to
 58-9    Subsections (g) and (h) and reconcile those costs with the
58-10    estimated stranded costs used to develop the competition transition
58-11    charge in the proceeding held under Section 39.201.  Any resulting
58-12    difference shall be applied to the nonbypassable delivery rates of
58-13    the transmission and distribution utility.
58-14          (d)  The affiliated power generation company shall reconcile,
58-15    and either credit or bill to the transmission and distribution
58-16    utility, the net sum of:
58-17                (1)  the former electric utility's final fuel balance
58-18    determined pursuant to Section 39.202(c); and
58-19                (2)  any difference between the price of power obtained
58-20    through the capacity auctions under Sections 39.153 and 39.156 and
58-21    the power cost projections which were employed for the same time
58-22    period in the ECOM model to estimate stranded costs in the
58-23    proceeding under Section 39.201.
58-24          (e)  The affiliated retail electric provider shall reconcile,
58-25    and either credit or bill to the transmission and distribution
58-26    utility, any difference between the price to beat established under
 59-1    Section 39.202, reduced by the nonbypassable delivery charge
 59-2    established under Section 39.201, and the prevailing market price
 59-3    of electricity during the same time period.
 59-4          (f)  Based on the credits or bills received from its
 59-5    affiliates pursuant to Subsections (d) and (e), the transmission
 59-6    and distribution utility shall make necessary adjustments to the
 59-7    nonbypassable delivery rates it charges to retail electric
 59-8    providers.  If the commission determines that the nonbypassable
 59-9    delivery rates are not sufficient, the commission may extend the
59-10    original collection period for the charge or, if necessary,
59-11    increase the charge.  Alternatively, if the commission determines
59-12    that the nonbypassable delivery rates are larger than are needed to
59-13    recover the transmission and distribution utility's costs, the
59-14    commission shall correspondingly reduce:
59-15                (1)  the competition transition charge, to the extent
59-16    it has not been securitized;
59-17                (2)  depreciation expense which has been redirected
59-18    pursuant to Section 39.256;
59-19                (3)  the transmission and distribution utility's rates;
59-20    or
59-21                (4)  a combination of the elements in Subdivisions
59-22    (1)-(3).
59-23          (g)  For the purpose of finalizing the stranded cost estimate
59-24    used to establish the competition transition charge under Section
59-25    39.201, and, except as provided in Subsection (h), the affiliated
59-26    power generation company shall quantify its stranded costs using
 60-1    one or more of the following methods:
 60-2                (1)  Sale of Assets.  If, at any time after December
 60-3    31, 1999, an electric utility or its affiliated power generation
 60-4    company has sold some or all of its generation assets, including,
 60-5    at the election of the electric utility or power generation
 60-6    company, any fuel and fuel transportation contracts related to
 60-7    those assets, in a bona fide third-party transaction under a
 60-8    competitive offering, the total net value realized from the sale
 60-9    establishes the market value of the generation assets sold.  If not
60-10    all assets are sold, the market value of the remaining generation
60-11    assets shall be established by one or more of the other methods in
60-12    this section.
60-13                (2)  Stock Valuation Method. If, at any time after
60-14    December 31, 1999, an electric utility or its affiliated power
60-15    generation company has sold some or all of its generation assets,
60-16    including, at the election of the electric utility or power
60-17    generation company, any fuel and fuel transportation contracts
60-18    related to those assets, to a separate affiliated or nonaffiliated
60-19    corporation, not less than 51 percent of the common stock of the
60-20    corporation is spun off and sold to public investors through a
60-21    national stock exchange, and the common stock has been traded for
60-22    not less than one year, the resulting average daily closing price
60-23    of the common stock over 30 consecutive trading days chosen by the
60-24    commission out of the last 180 consecutive trading days before the
60-25    filing required under Subsection (c) establishes the market value
60-26    of the common stock equity in the transferee corporation.  The book
 61-1    value of the transferee corporation's debt and preferred stock
 61-2    securities shall be added to the market value of its assets.  The
 61-3    market value of the transferee corporation's assets shall be
 61-4    reduced by the corresponding net book value of the assets acquired
 61-5    by the transferee corporation from any entity other than the
 61-6    affiliated electric utility or power generation company.  The
 61-7    resulting market value of the assets establishes the market value
 61-8    of the generation assets transferred by the electric utility or
 61-9    power generation company to the separate corporation.  If not all
61-10    assets are disposed of in this manner, the market value of the
61-11    remaining assets shall be established by one or more of the other
61-12    methods in this section.
61-13                (3)  Partial Stock Valuation Method.  If, at any time
61-14    after December 31, 1999, an electric utility or its affiliated
61-15    power generation company has sold some or all of its generation
61-16    assets, including, at the election of the electric utility or power
61-17    generation company, any fuel and fuel transportation contracts
61-18    related to those assets, to a separate affiliated or nonaffiliated
61-19    corporation, at least 19 percent, but less than 51 percent, of the
61-20    common stock of the corporation is spun off and sold to public
61-21    investors through a national stock exchange, and the common stock
61-22    has been traded for not less than one year, the resulting average
61-23    daily closing price of the common stock over 30 consecutive trading
61-24    days chosen by the commission out of the last 180 consecutive
61-25    trading days before the filing required under Subsection (c) shall
61-26    be presumed to establish the market value of the common stock
 62-1    equity in the transferee corporation.  The commission may accept
 62-2    the market valuation to conclusively establish the value of the
 62-3    common stock equity in the transferee corporation or convene a
 62-4    valuation panel of three independent financial experts to determine
 62-5    whether the percentage of common stock sold is fairly
 62-6    representative of the total common stock equity or whether a
 62-7    control premium exists for the retained interest.  The valuation
 62-8    panel must consist of financial experts chosen from proposals
 62-9    submitted in response to commission requests from the top 10
62-10    nationally recognized investment banks with demonstrated experience
62-11    in the United States electric industry as indicated by the dollar
62-12    amount of public offerings of long-term debt and equity of United
62-13    States investor-owned electric companies over the immediately
62-14    preceding three years as ranked by the publications "Securities
62-15    Data" or "Institutional Investor."  If the panel determines that a
62-16    control premium exists for the retained interest, the panel shall
62-17    determine the amount of the control premium, and the commission
62-18    shall adopt the determination but may not increase the market value
62-19    by a control premium greater than 20 percent.  The costs and
62-20    expenses of the panel, as approved by the commission, shall be paid
62-21    by the transferee corporation.  The determination of the commission
62-22    based on the finding of the panel conclusively establishes the
62-23    value of the common stock of the transferee corporation.  The book
62-24    value of the transferee corporation's debt and preferred stock
62-25    securities shall be added to the market value of its assets.  The
62-26    market value of the transferee corporation's assets shall be
 63-1    reduced by the corresponding net book value of the assets acquired
 63-2    by the transferee corporation from any entity other than the
 63-3    affiliated electric utility or power generation company.  The
 63-4    resulting market value of the assets establishes the market value
 63-5    of the generation assets transferred by the electric utility or
 63-6    power generation company to the separate corporation.
 63-7          (h)  Unless an electric utility or power generation company
 63-8    combines all of its generation assets into a transferee corporation
 63-9    as described in Subsections (g)(2) and (g)(3), the electric utility
63-10    shall quantify its stranded costs for nuclear assets using the ECOM
63-11    method.  The ECOM method is the estimation model prepared for and
63-12    described by the commission's April 1998 Report to the Texas Senate
63-13    Interim Committee on Electric Restructuring entitled "Potentially
63-14    Strandable Investment (ECOM) Report:  1998 Update."  The
63-15    methodology used in the model must be the same as that used in the
63-16    1998 report to determine the "base case."  At the time of the
63-17    proceeding under this section, the ECOM model shall be rerun using
63-18    updated company-specific inputs required by the model, updating the
63-19    market price of electricity, and using updated natural gas price
63-20    forecasts and the capacity cost based on the long-run marginal cost
63-21    of the most economic new generation technology then available.
63-22    Natural gas price projections used in the model must be based on
63-23    the most credible publicly available market-based data.  The
63-24    commission by rule shall establish, before June 1, 2000, the
63-25    precise methodology to be used by the commission in updating
63-26    natural gas forecasts.
 64-1          (i)  The commission shall conduct the hearing in this case as
 64-2    a contested case.
 64-3          (j)  The commission shall issue a final order not later than
 64-4    the 150th day after the date of the filing under this section by
 64-5    the transmission and distribution utility, its affiliated retail
 64-6    electric provider, and its affiliated power generation company, and
 64-7    the resulting order shall be subject to judicial review under
 64-8    Chapter 2001, Government Code.
 64-9          (k)  Notwithstanding Section 39.252, to the extent that a
64-10    customer's actual load has been lawfully served by a fully
64-11    operational qualifying facility before September 1, 2001, any
64-12    charge for recovery of stranded costs under this section or
64-13    Subchapter G assessed on that customer after the facility becomes
64-14    fully operational shall be included only in those tariffs or
64-15    charges associated with the services actually provided by the
64-16    transmission and distribution utility, if any, to the customer
64-17    after the qualifying facility became fully operational and may not
64-18    include any costs associated with the service provided to the
64-19    customer by the electric utility or its affiliated transmission and
64-20    distribution utility under their tariffs before the operation of
64-21    that qualifying facility.  To qualify under this subsection, a
64-22    qualifying facility must have made substantially complete filings
64-23    on or before December 31, 1998, for all necessary site specific
64-24    environmental permits under the rules of the Texas Natural Resource
64-25    Conservation Commission in effect at the time of filing.
64-26          Sec. 39.263.  STRANDED COST RECOVERY OF ENVIRONMENTAL CLEANUP
 65-1    COSTS.  (a)  Subject to the provisions of Subsection (c), capital
 65-2    costs incurred by an electric utility to improve air quality prior
 65-3    to January 1, 2002, are eligible for inclusion as net invested
 65-4    capital under Section 39.259, notwithstanding the limitations
 65-5    imposed under Sections 39.259(b) and (c).
 65-6          (b)  Subject to the provisions of Subsection (c), capital
 65-7    costs incurred by an electric utility to improve air quality
 65-8    subsequent to January 1, 2002, and prior to May 1, 2003, are
 65-9    eligible for inclusion in the determination of invested capital in
65-10    the true-up proceeding under Section 39.262.
65-11          (c)  Costs incurred under Subsections (a) and (b) shall be
65-12    included as invested capital and considered in an electric
65-13    utility's stranded cost determination only to the extent that:
65-14                (1)  the cost is applied to reduce the emission of
65-15    airborne pollutants from an electric generating facility for which
65-16    air quality authorization pursuant to 30 T.A.C. Chapter 116 has not
65-17    been obtained as of January 1, 1999;
65-18                (2)  the retrofit decision is most cost-effective on
65-19    consideration of alternative measures, including but not limited to
65-20    the retirement of the generating facility; and
65-21                (3)  the electric utility conveys 100 percent of any
65-22    resulting emissions credits to the state.
65-23          (d)  If the retirement of a generating facility is the most
65-24    cost-effective alternative, the net book value, including
65-25    retirement costs and offsetting salvage value, of the affected
65-26    facility shall be included in the electric utility's stranded cost
 66-1    determination if the electric utility complies with Subsection
 66-2    (c)(3), notwithstanding the provisions of Section 39.259(c).
 66-3          Sec. 39.264.  RIGHTS NOT AFFECTED.  This chapter is not
 66-4    intended to alter any rights of utilities to recover stranded costs
 66-5    from wholesale customers.
 66-6                       SUBCHAPTER G.  SECURITIZATION
 66-7          Sec. 39.301.  PURPOSE.  The primary purpose of this
 66-8    subchapter is to enable electric utilities to engage in financing
 66-9    transactions for the recovery of stranded costs that lower carrying
66-10    costs to be recovered over the life of the asset, as the cost of
66-11    this type of debt would be less than the cost that would be
66-12    incurred using conventional utility financing methods.
66-13          Sec. 39.302.  DEFINITION.  "Securitized financing
66-14    transaction" means the issuance of bonds, notes, or other forms of
66-15    indebtedness with a term of 15 years or less from the date of
66-16    issuance with the lowest interest cost reasonably attainable.  This
66-17    indebtedness shall be secured by revenues collected pursuant to a
66-18    qualified rate order.
66-19          Sec. 39.303.  QUALIFIED RATE ORDER.  The commission may issue
66-20    a qualified rate order for a utility in the proceeding under
66-21    Section 39.201.  Such qualified rate order shall authorize a
66-22    securitized financing transaction for recovery of no more than 75
66-23    percent of expected stranded costs and shall contain, at a minimum,
66-24    the following provisions:
66-25                (1)  quantification of the amount that may be recovered
66-26    through a securitized financing transaction as determined under
 67-1    Section 39.201;
 67-2                (2)  authorization for the electric utility or its
 67-3    assignee to impose upon and collect from all retail electric
 67-4    providers a separate nonbypassable charge to recover the principal,
 67-5    interest, and all reasonable expenses associated with issuing,
 67-6    servicing, refinancing, and retiring the bonds issued in a
 67-7    securitized financing transaction that are providing recovery for
 67-8    the amount determined under Subdivision (1);
 67-9                (3)  the period, not to exceed 15 years, over which the
67-10    nonbypassable charge shall be collected;
67-11                (4)  a mechanism for adjusting the nonbypassable charge
67-12    periodically to assure that the principal, interest, and reasonable
67-13    expenses may be paid in accordance with the terms of the bonds;
67-14                (5)  a finding that the revenues received through the
67-15    nonbypassable charge set out in the qualified rate order represent
67-16    property rights that can be transferred to others, who may transfer
67-17    and pledge such property rights to third parties in order to
67-18    provide security for the bonds issued pursuant to the qualified
67-19    rate order;
67-20                (6)  a finding that the total amount of revenues to be
67-21    collected pursuant to the qualified rate order is less than the
67-22    revenue requirement that would be required over the remaining life
67-23    of the expected stranded costs using conventional financing
67-24    methods;
67-25                (7)  a finding that issuance of the qualified rate
67-26    order is in the public interest; and
 68-1                (8)  a finding that the qualified rate order is
 68-2    irrevocable and shall not be subject to reversal or amendment by
 68-3    the commission in a way that would reduce or impair the collection
 68-4    of the nonbypassable charge authorized by a qualified rate order so
 68-5    long as the securities supported by the qualified rate order are
 68-6    outstanding.
 68-7          Sec. 39.304.  EFFECT OF RATE ORDER.  A qualified rate order
 68-8    remains in full force and effect notwithstanding any bankruptcy,
 68-9    reorganization, or other insolvency proceeding with respect to the
68-10    electric utility or assignee.
68-11          Sec. 39.305.  PLEDGE OF STATE.  The bonds issued in the
68-12    securitized financing transaction are not backed by the credit of
68-13    the state.  The state, however, pledges not to limit, alter, or in
68-14    any way impair or reduce the collection of the nonbypassable charge
68-15    authorized by a qualified rate order so long as the securities
68-16    supported by the qualified rate order are outstanding.
68-17          Sec. 39.306.  CHARACTERIZATION OF NONBYPASSABLE CHARGE.  The
68-18    property right created by this subchapter is not an account or
68-19    general intangible under Section 9.106, Business & Commerce Code.
68-20         SUBCHAPTER H.  CERTIFICATION AND REGISTRATION; PENALTIES
68-21          Sec. 39.351.  CERTIFICATION OF POWER GENERATION COMPANIES.
68-22    (a)  A person may not generate electricity for resale unless the
68-23    person is certified by the commission as a power generation company
68-24    in accordance with this section.  A person may apply for
68-25    certification as a power generation company by filing the following
68-26    information with the commission:
 69-1                (1)  a description of the location of any facility used
 69-2    to generate electricity;
 69-3                (2)  a description of the type of services provided;
 69-4                (3)  a copy of any information filed with the Federal
 69-5    Energy Regulatory Commission in connection with registration with
 69-6    that commission; and
 69-7                (4)  any other information required by commission rule.
 69-8          (b)  A power generation company shall comply with the
 69-9    reliability standards adopted by an independent organization
69-10    certified by the commission to ensure the reliability of the
69-11    regional electrical network for a power region in which the power
69-12    generation company is generating or selling electricity.
69-13          Sec. 39.352.  CERTIFICATION OF RETAIL ELECTRIC PROVIDERS.
69-14    (a)  In areas where customer choice has been introduced, no person,
69-15    including an affiliate of an electric utility, may provide retail
69-16    electric service in this state unless the person is certified by
69-17    the commission as a retail electric provider, in accordance with
69-18    this section.
69-19          (b)  The commission shall issue a certificate to provide
69-20    retail electric service to a person applying for certification who
69-21    demonstrates:
69-22                (1)  the financial and technical resources to provide
69-23    continuous and reliable electric service to customers in the area
69-24    for which the certification is sought; and
69-25                (2)  the organization, personnel, and other resources
69-26    needed to meet the customer protection requirements of this title.
 70-1          (c)  A person applying for certification under this section
 70-2    shall comply with all customer protection provisions, all
 70-3    disclosure requirements, and all marketing guidelines established
 70-4    by the commission and by this subtitle.
 70-5          Sec. 39.353.  CERTIFICATION OF AGGREGATORS.  (a)  A person
 70-6    may not provide aggregation services in the state unless the person
 70-7    is certified by the commission as an aggregator.
 70-8          (b)  In this subchapter, "aggregator" means a person joining
 70-9    two or more customers, other than municipalities, into a single
70-10    purchasing unit to negotiate the purchase of electricity from
70-11    retail electric providers.
70-12          (c)  A person applying for certification under this section
70-13    shall comply with all customer protection provisions, all
70-14    disclosure requirements, and all marketing guidelines established
70-15    by the commission and by this subtitle.
70-16          (d)  The commission may establish terms and conditions it
70-17    determines necessary to regulate the reliability and integrity of
70-18    aggregation services in the state.
70-19          Sec. 39.354.  REGISTRATION OF MUNICIPAL AGGREGATORS.  (a)  A
70-20    municipal aggregator may not provide aggregation services in the
70-21    state unless the municipal aggregator registers with the
70-22    commission.
70-23          (b)  In this section, "municipal aggregator" means a person
70-24    authorized by two or more municipal governing bodies to join the
70-25    bodies into a single purchasing unit to negotiate the purchase of
70-26    electricity from retail electric providers.
 71-1          Sec. 39.355.  REGISTRATION OF POWER MARKETERS.  A person may
 71-2    not sell electric energy at wholesale as a power marketer unless
 71-3    the person registers with the commission.
 71-4          Sec. 39.356.  REVOCATION OF CERTIFICATION.  (a)  The
 71-5    commission may suspend, revoke, or amend a retail electric
 71-6    provider's certificate for significant violations of this title or
 71-7    the rules adopted pursuant to this title or of any reliability
 71-8    standard adopted by an independent organization certified by the
 71-9    commission to ensure the reliability of a power region's electrical
71-10    network, including the failure to observe any scheduling,
71-11    operating, or settlement protocols established by the independent
71-12    organization.  The commission may also suspend or revoke a retail
71-13    electric provider's certificate if the provider no longer has the
71-14    financial or technical capability to provide continuous and
71-15    reliable electric service.
71-16          (b)  The commission may suspend or revoke a power generation
71-17    company's certificate for significant violations of this title or
71-18    the rules adopted pursuant to this title or of the reliability
71-19    standards adopted by an independent organization certified by the
71-20    commission to ensure the reliability of a power region's electrical
71-21    network, including the failure to observe any scheduling,
71-22    operating, or settlement protocols established by the independent
71-23    organization.
71-24          (c)  The commission may suspend, revoke, or amend an
71-25    aggregator's certificate for significant violations of this title
71-26    or of the rules adopted pursuant to this title.
 72-1          Sec. 39.357.  ADMINISTRATIVE PENALTY.  In addition to the
 72-2    suspension, revocation, or amendment of a certification, the
 72-3    commission may impose an administrative penalty, as provided by
 72-4    Section 15.023, for violations described by Section 39.356.
 72-5                  SUBCHAPTER I.  MISCELLANEOUS PROVISIONS
 72-6          Sec. 39.601.  SCHOOL FUNDING LOSS MECHANISM.  (a)  Not later
 72-7    than March 1 each year, the comptroller shall certify to the Texas
 72-8    Education Agency any property wealth reductions, determined by
 72-9    taking the difference between current year and prior year appraisal
72-10    values in the property value study conducted under Subchapter M,
72-11    Chapter 403, Government Code, attributable to electric utility
72-12    restructuring.
72-13          (b)  The Texas Education Agency shall determine the reduction
72-14    of the amount of property taxes recaptured by the state from school
72-15    districts subject to wealth equalization under Chapter 41,
72-16    Education Code, as a result of the property wealth reductions
72-17    certified under Subsection (a) and shall notify the commission of
72-18    the amount necessary to compensate the state for the reduction.
72-19          (c)  Not later than May 1 of each year, the commission shall
72-20    transfer from the system benefit fund to the foundation school fund
72-21    the amount necessary to compensate the state for the reduction
72-22    specified by Subsection (b).
72-23          Sec. 39.602.  CUSTOMER EDUCATION.  Before January 1, 2002,
72-24    the commission shall develop and implement an educational program
72-25    to inform customers of changes in the provision of electric
72-26    services resulting from the opening of the retail electric market
 73-1    under this chapter.  The educational program shall provide
 73-2    customers with the information necessary to make informed decisions
 73-3    relating to the source and type of electric service purchased and
 73-4    other information the commission considers necessary.
 73-5          Sec. 39.603.  SYSTEM BENEFIT FUND.  (a)  The commission shall
 73-6    establish the system benefit fund.
 73-7          (b)  The system benefit fund is financed by a nonbypassable
 73-8    charge set by the commission in an amount not to exceed 30 cents
 73-9    per MWh.
73-10          (c)  The system benefit fund shall provide funding for:
73-11                (1)  customer education programs;
73-12                (2)  programs to assist low-income electric customers;
73-13    and
73-14                (3)  the property tax replacement mechanism provided by
73-15    Section 39.601.
73-16          (d)  For the purposes of this section, a "low-income electric
73-17    customer," is an electric customer who is a qualifying low-income
73-18    consumer as defined by the commission.
73-19          Sec. 39.604.  GOAL FOR RENEWABLE CAPACITY.  (a)  It is the
73-20    intent of the legislature that by January 1, 2007, renewable energy
73-21    technologies shall constitute not less than five percent of the
73-22    installed electric generation capacity that is physically located
73-23    in the state and available to sell power at wholesale or retail.
73-24          (b)  The introduction of competition and retail customer
73-25    choice is expected to create opportunities that will stimulate the
73-26    economic development of renewable energy technologies in the state
 74-1    to a level that achieves the goal of Subsection (a) through
 74-2    reliance on market forces alone.
 74-3          (c)  Beginning on January 1, 2004, each retail electric
 74-4    provider operating in the state shall include a minimum of one
 74-5    percent of capacity from renewable energy technologies in its
 74-6    supply portfolio.
 74-7          (d)  The commission shall establish a renewable energy
 74-8    credits trading program.  Any retail electric provider that does
 74-9    not satisfy the requirement of Subsection (c) shall purchase
74-10    sufficient renewable energy credits to satisfy the requirement by
74-11    holding renewable energy credits in lieu of capacity from renewable
74-12    energy technologies.
74-13          (e)  In this section, "renewable energy technology" means any
74-14    technology that exclusively relies on an energy source that is
74-15    naturally regenerated over a short time and derived directly from
74-16    the sun, indirectly from the sun, or from other natural movements
74-17    and mechanisms of the environment.  A renewable energy technology
74-18    does not rely on energy resources derived from fossil fuels, waste
74-19    products from fossil fuels, or waste products from inorganic
74-20    sources.
74-21          Sec. 39.605.  EFFECT OF SUNSET PROVISION.  (a)  If the
74-22    commission is abolished and the other provisions of this title
74-23    expire as provided by Chapter 325, Government Code (Texas Sunset
74-24    Act), this subchapter, including the provisions of this title
74-25    referred to in this subchapter, continues in full force and effect
74-26    and does not expire.
 75-1          (b)  The authorities, duties, and functions of the commission
 75-2    under this chapter shall be performed and carried out by a
 75-3    successor agency to be designated by the legislature before
 75-4    abolishment of the commission or, if the legislature does not
 75-5    designate the successor, by the secretary of state.
 75-6         CHAPTER 40.  COMPETITION FOR MUNICIPALLY OWNED UTILITIES
 75-7                           AND RIVER AUTHORITIES
 75-8                     SUBCHAPTER A.  GENERAL PROVISIONS
 75-9          Sec. 40.001.  APPLICABLE LAW.  Notwithstanding any other
75-10    provision of law, this chapter governs the transition to and the
75-11    establishment of a fully competitive electric power industry for
75-12    municipally owned utilities.  This chapter controls over any other
75-13    provision of this title, except Sections 39.155, 39.157(d), and
75-14    39.203.
75-15          Sec. 40.002.  DEFINITION.  For purposes of this chapter,
75-16    "body vested with the power to manage and operate a municipally
75-17    owned utility" shall mean that body created in accordance with
75-18    Article 1115 or 1115a, Revised Statutes.
75-19          Sec. 40.003.  SECURITIZATION.  (a)  Municipally owned
75-20    utilities and river authorities may adopt and use securitization
75-21    provisions having the effect of the provisions set out in
75-22    Subchapter G, Chapter 39, to recover through rates stranded costs,
75-23    at a recovery level deemed appropriate by the municipally owned
75-24    utility or river authority up to 100 percent, under rules and
75-25    procedures that shall be established:
75-26                (1)  in the case of a municipally owned utility, by the
 76-1    municipal governing body or a body vested with the power to operate
 76-2    and manage the municipally owned utility, including procedures
 76-3    providing for rate orders of such body having the effect of
 76-4    qualified rate orders, providing for a separate nonbypassable
 76-5    charge to be collected from all retail electric customers of the
 76-6    municipally owned utility to fund the recovery of the stranded
 76-7    investment and all reasonable related expenses, and providing for
 76-8    the issuance of bonds necessary to recover the amount deemed
 76-9    appropriate by the municipally owned utility through a securitized
76-10    financing transaction; and
76-11                (2)  in the case of a river authority, by the
76-12    commission.
76-13          (b)  The rules and procedures for securitization established
76-14    by the commission under Subsection (a)(2) shall include procedures
76-15    for the recovery of stranded costs pursuant to the terms of a rate
76-16    order adopted by the governing body of the river authority, which
76-17    rate order shall have the effect of a qualified rate order.
76-18          (c)  The rules and procedures for securitization established
76-19    by the commission under Subsection (a)(2) shall include rules and
76-20    procedures for the issuance of bonds issued in a securitized
76-21    financing transaction.  The issuance of any bonds issued in a
76-22    securitized financing transaction by a river authority is hereby
76-23    expressly authorized and shall be governed by the laws governing
76-24    the issuance of bonds or other obligations by the river authority.
76-25    Findings made by the governing body of a river authority in a
76-26    qualified rate order issued pursuant to the rules and procedures
 77-1    described in this subsection shall be conclusive, and any
 77-2    nonbypassable charge incorporated in such rate order to recover the
 77-3    principal, interest, and all reasonable expenses associated with
 77-4    any securitized financing transaction shall constitute property
 77-5    rights, as described in Subchapter G, Chapter 39, and otherwise
 77-6    conform in all material respects to the nonbypassable charges set
 77-7    forth in Subchapter G, Chapter 39.
 77-8          (d)  The rules and procedures established under this section
 77-9    shall be consistent with other law applicable to municipally owned
77-10    utilities and river authorities and with the terms of any
77-11    resolutions, orders, or ordinances authorizing outstanding bonds or
77-12    other indebtedness of the municipalities or river authorities.
77-13              SUBCHAPTER B.  MUNICIPALLY OWNED UTILITY CHOICE
77-14          Sec. 40.051.  GOVERNING BODY DECISION.  (a)  The municipal
77-15    governing body or a body vested with the power to operate and
77-16    manage a municipally owned utility has the discretion to decide
77-17    when or if the municipally owned utility will provide customer
77-18    choice.
77-19          (b)  Municipally owned utilities that choose to participate
77-20    in customer choice may do so at any time on or after January 1,
77-21    2002, by adoption of an appropriate resolution of the municipal
77-22    governing body or a body vested with power to manage and operate
77-23    the municipally owned utility.  The decision to participate in
77-24    customer choice by the adoption of a resolution is irrevocable.
77-25          (c)  After a decision to offer customer choice has been made,
77-26    Subchapters C, D, and E, Chapter 33, do not apply to any action
 78-1    taken under this chapter.
 78-2          Sec. 40.052.  UTILITY NOT OFFERING CUSTOMER CHOICE.  (a)  A
 78-3    municipally owned utility that chooses not to participate in
 78-4    customer choice may not offer electric energy at unregulated prices
 78-5    directly to retail customers outside its certificated retail
 78-6    service area.
 78-7          (b)  A municipally owned utility under Subsection (a) retains
 78-8    the right to offer and provide a full range of customer service and
 78-9    pricing programs to the customers within its certificated area and
78-10    to purchase and sell electric energy at wholesale without
78-11    geographic restriction.
78-12          Sec. 40.053.  RETAIL CUSTOMER'S RIGHT OF CHOICE.  (a)  If a
78-13    municipally owned utility chooses to participate in customer
78-14    choice, after that choice all retail customers served by the
78-15    municipally owned utility within the certificated retail service
78-16    area of the municipally owned utility shall have the right of
78-17    customer choice, and the municipally owned utility shall provide
78-18    open access for retail service.
78-19          (b)  Notwithstanding Section 39.107, the metering function
78-20    shall not be deemed a competitive service for customers of the
78-21    municipally owned utility within such service area and may, at the
78-22    option of the municipally owned utility, continue to be offered by
78-23    the municipally owned utility as sole provider.
78-24          (c)  Upon its initiation of customer choice, a municipally
78-25    owned utility shall designate itself or another entity as the
78-26    provider of last resort for customers within the municipally owned
 79-1    utility's certificated service area as that area existed on the
 79-2    date of the utility's initiation of customer choice.  The
 79-3    municipally owned utility shall fulfill the role of default
 79-4    provider of last resort in the event no other entity is available
 79-5    to act in that capacity.
 79-6          (d)  If a customer is unable to obtain service from a retail
 79-7    electric provider, upon request by the customer, the provider of
 79-8    last resort shall offer the customer the standard retail service
 79-9    package for the appropriate customer class, with no interruption of
79-10    service, at a fixed, nondiscountable rate approved by the governing
79-11    body of the municipally owned utility which has the authority to
79-12    set rates.
79-13          (e)  The governing body of a municipally owned utility may
79-14    establish the procedures and criteria for designating the provider
79-15    of last resort and may redesignate the provider of last resort
79-16    according to a schedule it considers appropriate.
79-17          Sec. 40.054.  SERVICE OUTSIDE AREA.  (a)  A municipally owned
79-18    utility participating in customer choice shall have the right to
79-19    offer electric energy and related services at unregulated prices
79-20    directly to retail customers without regard to geographic location.
79-21          (b)  In providing service under Subsection (a) to retail
79-22    customers outside its certificated retail service area as that area
79-23    exists on the date of adoption of customer choice, a municipally
79-24    owned utility is subject to the commission's rules establishing a
79-25    code of conduct regulating anticompetitive practices.
79-26          (c)  For municipally owned utilities participating in
 80-1    customer choice, the commission shall have jurisdiction to
 80-2    establish terms and conditions, but not rates, for access by other
 80-3    retail electric providers to the municipally owned utility's
 80-4    distribution facilities.
 80-5          (d)  Notwithstanding Subsections (b) and (c), accommodation
 80-6    shall be made in the code of conduct for specific legal
 80-7    requirements imposed by state or federal law applicable to
 80-8    municipally owned utilities.
 80-9          (e)  The commission does not have jurisdiction to require
80-10    unbundling of services or functions of, or to regulate the recovery
80-11    of stranded investment of, a municipally owned utility or, except
80-12    as provided by this section, jurisdiction with respect to the
80-13    rates, terms, and conditions of service for retail customers of a
80-14    municipally owned utility within the utility's certificated service
80-15    area.
80-16          (f)  A municipally owned utility shall maintain separate
80-17    books and records of its operations from those of the operations of
80-18    any affiliate.
80-19          Sec. 40.055.  JURISDICTION OF MUNICIPAL GOVERNING BODY.  The
80-20    municipal governing body or a body vested with the power to manage
80-21    and operate a municipally owned utility has exclusive jurisdiction
80-22    to:
80-23                (1)  set all terms of access, conditions, and rates
80-24    applicable to services provided by the municipally owned utility,
80-25    except as provided by Sections 40.054 and 40.056, including
80-26    nondiscriminatory and comparable terms of access, conditions, and
 81-1    rates for distribution but excluding wholesale transmission rates,
 81-2    terms of access, and conditions for wholesale transmission service
 81-3    set by the commission under this subtitle, provided that the rates
 81-4    for distribution access established by the municipal governing body
 81-5    shall be comparable to the distribution access rates that apply to
 81-6    the municipally owned utility and the municipally owned utility's
 81-7    affiliates;
 81-8                (2)  determine whether to unbundle any energy-related
 81-9    activities, and if the municipally owned utility chooses to
81-10    unbundle, whether to do so structurally or functionally;
81-11                (3)  reasonably determine the amount of the municipally
81-12    owned utility's stranded investment;
81-13                (4)  establish nondiscriminatory transition charges
81-14    reasonably designed to recover the stranded investment over an
81-15    appropriate period of time;
81-16                (5)  determine the extent to which the municipally
81-17    owned utility will provide various customer services at the
81-18    distribution level or accept the services from other providers;
81-19                (6)  manage and operate the municipality's electric
81-20    utility systems, including exercise of control over resource
81-21    acquisition and any related expansion programs;
81-22                (7)  establish and enforce service quality standards
81-23    and consumer safeguards designed to protect retail electric
81-24    customers;
81-25                (8)  determine whether a base rate reduction is
81-26    appropriate for the municipally owned utility;
 82-1                (9)  determine any other utility matters that the
 82-2    municipal governing body or body vested with power to manage and
 82-3    operate the municipally owned utility believes should be included;
 82-4    and
 82-5                (10)  make any other decisions affecting the
 82-6    municipally owned utility's participation in customer choice that
 82-7    are not inconsistent with the provisions of this chapter.
 82-8          Sec. 40.056.  ANTICOMPETITIVE ACTIONS.  (a)  If, upon
 82-9    complaint by a retail electric provider, the commission finds that
82-10    a municipal rule, action, or order relating to customer choice is
82-11    anticompetitive or does not provide other retail electric providers
82-12    with nondiscriminatory terms and conditions of access to
82-13    distribution facilities or customers within the municipally owned
82-14    utility's certificated retail service area that are comparable to
82-15    the municipally owned utility's and its affiliates' terms and
82-16    conditions of access to distribution facilities or customers, the
82-17    commission shall notify the municipally owned utility.
82-18          (b)  The municipally owned utility shall have three months to
82-19    cure the anticompetitive or noncompliant behavior described in
82-20    Subsection (a), following opportunity for hearing on the complaint.
82-21    If the rule, action, or order is not fully remedied within that
82-22    time, the commission may prohibit the municipally owned utility or
82-23    affiliate from providing retail service outside its certificated
82-24    retail service area until the rule, action, or order is remedied.
82-25          Sec. 40.057.  BILLING.  (a)  A municipally owned utility that
82-26    opts for customer choice may continue to bill directly electric
 83-1    customers located in its certificated retail service area, as that
 83-2    area exists on the date of adoption of customer choice, for all
 83-3    transmission and distribution services.  The municipally owned
 83-4    utility may also bill directly for generation services and customer
 83-5    services provided by the municipally owned utility to those
 83-6    customers.
 83-7          (b)  A municipally owned utility that opts for customer
 83-8    choice shall not adopt anticompetitive billing practices that would
 83-9    discourage customers in its service area from choosing a retail
83-10    electric provider.
83-11          (c)  A customer served by a municipally owned utility for
83-12    distribution service and by a retail electric provider for retail
83-13    service has the option of being billed directly by each service
83-14    provider or to receive a single bill for distribution,
83-15    transmission, and generation services from the municipally owned
83-16    utility.
83-17          Sec. 40.058.  TARIFFS FOR OPEN ACCESS.  A municipally owned
83-18    utility that owns or operates transmission and distribution
83-19    facilities shall file tariffs implementing the open access rules
83-20    established by the commission under Section 39.203 with the
83-21    appropriate regulatory authority having jurisdiction over the
83-22    transmission and distribution service of the municipally owned
83-23    utility before the 90th day preceding the date the utility offers
83-24    customer choice.  The commission has no authority to determine the
83-25    rates for distribution access service for a municipally owned
83-26    utility.
 84-1          Sec. 40.059.  MUNICIPAL POWER AGENCY; RECOVERY OF STRANDED
 84-2    COSTS.  (a)  In this section, "member city" means a municipality
 84-3    that participated in the creation of a municipal power agency
 84-4    formed pursuant to Chapter 163 by the adoption of a concurrent
 84-5    resolution by the municipality on or before August 1, 1975.
 84-6          (b)  After a member city adopts a resolution choosing to
 84-7    participate in customer choice under Section 40.051(b), a member
 84-8    city may include stranded costs described in Subsection (c) in its
 84-9    distribution costs and may recover such costs through a
84-10    nonbypassable charge.  The nonbypassable charge shall be as
84-11    determined by the member city's governing body and may be spread
84-12    over 16 years.
84-13          (c)  The stranded costs that may be recovered under this
84-14    section are those costs that were determined by the commission and
84-15    set forth in the commission's April 1998 Report to the Texas Senate
84-16    Interim Committee on Electric Utility Restructuring entitled
84-17    "Potentially Strandable Investment (ECOM) Report:  1998 Update" and
84-18    specifically set forth in the report at Appendix A (ECOM Estimates
84-19    Including the Effects of Transition Plans) under the commission
84-20    base case benchmark price for the year 2002.
84-21          (d)  The stranded cost amounts described in this section
84-22    shall not be included in the generation costs used in setting rates
84-23    by the member city's governing body.
84-24          Sec. 40.060.  NO POWER TO AMEND CERTIFICATES.  Nothing in
84-25    this chapter empowers a municipal governing body or a body vested
84-26    with the power to manage and operate a municipally owned utility to
 85-1    issue, amend, or rescind a certificate of public convenience and
 85-2    necessity granted by the commission.  This subsection does not
 85-3    affect the ability of a municipal governing body or a body vested
 85-4    with the power to manage and operate the municipally owned utility
 85-5    to pass a resolution under Section 40.051(b).
 85-6                    SUBCHAPTER C.  RIGHTS NOT AFFECTED
 85-7          Sec. 40.101.  INTERFERENCE WITH CONTRACT.  (a)  This subtitle
 85-8    shall not interfere with or abrogate the rights or obligations of
 85-9    parties, including a retail or wholesale customer, to a contract
85-10    with a municipally owned utility or river authority.
85-11          (b)  This subtitle shall not interfere with or abrogate the
85-12    rights or obligations of a party under a contract or agreement
85-13    concerning certificated utility service areas.
85-14          Sec. 40.102.  ACCESS TO WHOLESALE MARKET.  Nothing in this
85-15    subtitle shall limit the access of municipally owned utilities to
85-16    the wholesale electric market.
85-17          Sec. 40.103.  PROTECTION OF BONDHOLDERS.  Nothing in this
85-18    subtitle or any rule adopted under this subtitle shall impair
85-19    contracts, covenants, or obligations between this state, river
85-20    authorities, municipalities, and the bondholders of revenue bonds
85-21    issued by the river authorities or municipalities.
85-22          Sec. 40.104.  TAX-EXEMPT STATUS.  Nothing in this subtitle
85-23    may impair the tax-exempt status of municipalities, electric
85-24    cooperatives, or river authorities, nor shall anything in this
85-25    subtitle compel any municipality, electric cooperative, or river
85-26    authority to use its facilities in a manner which violates any
 86-1    contractual provisions, bond covenants, or other restrictions
 86-2    applicable to facilities financed by tax-exempt debt.
 86-3    Notwithstanding any other provision of law, the decision to
 86-4    participate in customer choice by the adoption of a resolution in
 86-5    accordance with Section 40.051(b) is irrevocable.
 86-6            CHAPTER 41.  ELECTRIC COOPERATIVES AND COMPETITION
 86-7                     SUBCHAPTER A.  GENERAL PROVISIONS
 86-8          Sec. 41.001.  APPLICABLE LAW.  Notwithstanding any other
 86-9    provision of law, except Sections 39.155, 39.157(d), and 39.203,
86-10    this chapter governs the transition to and the establishment of a
86-11    fully competitive electric power industry for electric
86-12    cooperatives.  Regarding the regulation of electric cooperatives,
86-13    this chapter shall control over any other provision of this title,
86-14    except for sections in which the term "electric cooperative" is
86-15    specifically used.
86-16          Sec. 41.002.  DEFINITION.  In this chapter, "board of
86-17    directors" means the board of directors of an electric cooperative
86-18    as described in Section 161.071.
86-19          Sec. 41.003.  SECURITIZATION.  (a)  Electric cooperatives may
86-20    use securitization provisions generally consistent with Subchapter
86-21    G, Chapter 39, to recover through rates stranded costs under rules
86-22    and procedures that shall be established by the board of directors.
86-23          (b)  The rules and procedures for securitization established
86-24    under Subsection (a) shall include rules and procedures for the
86-25    issuance of bonds.
86-26          (c)  The rules and procedures established as provided by
 87-1    Subsection (b) shall be consistent with other law and with the
 87-2    terms of any resolutions or orders authorizing outstanding bonds or
 87-3    other indebtedness of the electric cooperative.
 87-4          Sec. 41.004.  JURISDICTION OF THE COMMISSION.  Except as
 87-5    specifically provided otherwise in this chapter, the commission has
 87-6    jurisdiction over electric cooperatives only as follows:
 87-7                (1)  to regulate wholesale transmission rates and
 87-8    service including terms of access, to the extent provided in
 87-9    Subchapter A, Chapter 35;
87-10                (2)  to regulate certification of service areas to the
87-11    extent provided in Chapter 37; and
87-12                (3)  to require reports of electric cooperative
87-13    operations only to the extent necessary to:
87-14                      (A)  ensure the public safety;
87-15                      (B)  enable the commission to satisfy its
87-16    responsibilities relating to electric cooperatives under this
87-17    chapter;
87-18                      (C)  enable the commission to determine the
87-19    aggregate electric load and energy requirements in the state and
87-20    the resources available to serve that load; or
87-21                      (D)  enable the commission to determine
87-22    information relating to market power under Chapter 39.
87-23          Sec. 41.005.  LIMITATION ON MUNICIPAL AUTHORITY.
87-24    Notwithstanding any other provision of this title, a municipality
87-25    may not directly or indirectly regulate the rates, operations, and
87-26    services of an electric cooperative.
 88-1            SUBCHAPTER B.  ELECTRIC COOPERATIVE UTILITY CHOICE
 88-2          Sec. 41.051.  BOARD DECISION.  (a)  The board of directors
 88-3    has the discretion to decide when or if the electric cooperative
 88-4    will provide customer choice.
 88-5          (b)  Electric cooperatives that choose to participate in
 88-6    customer choice may do so at any time on or after January 1, 2002,
 88-7    by adoption of an appropriate resolution of the board of directors.
 88-8    The decision to participate in customer choice by the adoption of
 88-9    such a resolution may be revoked only if no customer has opted for
88-10    choice within four years of the resolution's adoption.
88-11          Sec. 41.052.  ELECTRIC COOPERATIVES NOT OFFERING CUSTOMER
88-12    CHOICE.  (a)  An electric cooperative that chooses not to
88-13    participate in customer choice may not offer electric energy at
88-14    unregulated prices directly to retail customers outside its
88-15    certificated retail service area.
88-16          (b)  An electric cooperative under Subsection (a) retains the
88-17    right to offer and provide a full range of customer service and
88-18    pricing programs to the customers within its certificated retail
88-19    service area and to purchase and sell electric energy at wholesale
88-20    without geographic restriction.
88-21          (c)  A generation and transmission electric cooperative may
88-22    offer electric energy at unregulated prices directly to retail
88-23    customers outside of its parent electric cooperatives' certificated
88-24    service areas only if a majority of the parent electric
88-25    cooperatives of the generation and transmission electric
88-26    cooperative have chosen to offer customer choice.
 89-1          Sec. 41.053.  RETAIL CUSTOMER RIGHT OF CHOICE.  (a)  If an
 89-2    electric cooperative chooses to participate in customer choice,
 89-3    after that choice, all retail customers within the certificated
 89-4    service area of the electric cooperative shall have the right of
 89-5    customer choice, and the electric cooperative shall provide
 89-6    nondiscriminatory open access for retail service.
 89-7          (b)  Upon its initiation of customer choice, an electric
 89-8    cooperative shall designate itself or another entity as the
 89-9    provider of last resort for retail customers within the electric
89-10    cooperative's certificated service area and shall fulfill the role
89-11    of default provider of last resort in the event no other entity is
89-12    available to act in that capacity.
89-13          (c)  If a retail electric provider fails to serve a customer
89-14    described in Subsection (b), upon request by the customer, the
89-15    provider of last resort shall offer the customer the standard
89-16    retail service package for the appropriate customer class, with no
89-17    interruption of service, at a fixed, nondiscountable rate approved
89-18    by the board of directors.
89-19          (d)  The board of directors may establish the procedures and
89-20    criteria for designating the provider of last resort and may
89-21    redesignate the provider of last resort according to a schedule it
89-22    considers appropriate.
89-23          Sec. 41.054.  SERVICE OUTSIDE CERTIFICATED AREA.  (a)  An
89-24    electric cooperative participating in customer choice shall have
89-25    the right to offer electric energy and related services at
89-26    unregulated prices directly to retail customers without regard to
 90-1    geographic location.
 90-2          (b)  In providing service under Subsection (a) to retail
 90-3    customers outside its certificated service area as that area exists
 90-4    on the date of adoption of customer choice, an electric cooperative
 90-5    becomes subject to commission jurisdiction as to the commission's
 90-6    rules establishing a code of conduct regulating anticompetitive
 90-7    practices under Section 39.157(d), except to the extent such rules
 90-8    conflict with this chapter.
 90-9          (c)  For electric cooperatives participating in customer
90-10    choice, the commission shall have jurisdiction to establish terms
90-11    and conditions, but not rates, for access by other electric
90-12    providers to the electric cooperative's distribution facilities.
90-13          (d)  Notwithstanding Subsections (b) and (c), the commission
90-14    shall make accommodation in the code of conduct for specific legal
90-15    requirements imposed by state or federal law applicable to electric
90-16    cooperatives.  The commission shall accommodate the organizational
90-17    structures of electric cooperatives and shall not prohibit an
90-18    electric cooperative and any related entity from sharing officers,
90-19    directors, or employees.
90-20          (e)  The commission does not have jurisdiction to require
90-21    unbundling of services or functions of, or to regulate the recovery
90-22    of stranded investment of, an electric cooperative or, except as
90-23    provided by this section, jurisdiction with respect to the rates,
90-24    terms, and conditions of service for retail customers of an
90-25    electric cooperative within the electric cooperative's certificated
90-26    service area.
 91-1          (f)  An electric cooperative shall maintain separate books
 91-2    and records of its operations and the operations of any subsidiary
 91-3    and shall ensure that the rates charged for provision of electric
 91-4    service do not include any costs of its subsidiary or any other
 91-5    costs not related to the provision of electric service.
 91-6          Sec. 41.055.  JURISDICTION OF BOARD OF DIRECTORS.  A board of
 91-7    directors has exclusive jurisdiction to:
 91-8                (1)  set all terms of access, conditions, and rates
 91-9    applicable to services provided by the electric cooperative, except
91-10    as provided by Sections 41.054 and 41.056, including
91-11    nondiscriminatory and comparable terms of access, conditions, and
91-12    rates for distribution but excluding wholesale transmission rates,
91-13    terms of access, and conditions for wholesale transmission service
91-14    set by the commission under Subchapter A, Chapter 35, provided that
91-15    the rates for distribution established by the electric cooperative
91-16    shall be comparable to the distribution rates that apply to the
91-17    electric cooperative and its subsidiaries;
91-18                (2)  determine whether to unbundle any energy-related
91-19    activities, and if the board of directors chooses to unbundle,
91-20    whether to do so structurally or functionally;
91-21                (3)  reasonably determine the amount of the electric
91-22    cooperative's stranded investment;
91-23                (4)  establish nondiscriminatory transition charges
91-24    reasonably designed to recover the stranded investment over an
91-25    appropriate period of time;
91-26                (5)  determine the extent to which the electric
 92-1    cooperative will provide various customer services, including
 92-2    nonelectric services, or accept the services from other providers;
 92-3                (6)  manage and operate the electric cooperative's
 92-4    utility systems, including exercise of control over resource
 92-5    acquisition and any related expansion programs;
 92-6                (7)  establish and enforce service quality standards
 92-7    and consumer safeguards designed to protect retail electric
 92-8    customers;
 92-9                (8)  determine whether a base rate reduction is
92-10    appropriate for the electric cooperative;
92-11                (9)  determine any other utility matters that the board
92-12    of directors believes should be included; and
92-13                (10)  make any other decisions affecting the electric
92-14    cooperative's participation in customer choice that are not
92-15    inconsistent with the provisions of this chapter.
92-16          Sec. 41.056.  ANTICOMPETITIVE ACTIONS.  (a)  If, after notice
92-17    and hearing, the commission finds that an electric cooperative
92-18    providing customer choice has engaged in anticompetitive behavior
92-19    by not providing other retail electric providers with
92-20    nondiscriminatory terms and conditions of access to distribution
92-21    facilities or customers within the electric cooperative's
92-22    certificated service area that are comparable to the electric
92-23    cooperative's and its subsidiaries' terms and conditions of access
92-24    to distribution facilities or customers, the commission shall
92-25    notify the electric cooperative.
92-26          (b)  The electric cooperative shall have three months to cure
 93-1    the anticompetitive or noncompliant behavior described in
 93-2    Subsection (a).  If the behavior is not fully remedied within that
 93-3    time, the commission may prohibit the electric cooperative or its
 93-4    subsidiary from providing retail service outside its certificated
 93-5    retail service area until the behavior is remedied.
 93-6          Sec. 41.057.  BILLING.  (a)  An electric cooperative that
 93-7    opts for customer choice may continue to bill directly electric
 93-8    customers located in its certificated service area for all
 93-9    transmission and distribution services.  The electric cooperative
93-10    may also bill directly for generation and customer services
93-11    provided by the electric cooperative or its subsidiaries to those
93-12    customers.
93-13          (b)  A customer served by an electric cooperative for
93-14    transmission and distribution services and by a retail electric
93-15    provider for retail service has the option of being billed directly
93-16    by each service provider or receiving a single bill for
93-17    distribution, transmission, and generation services from the
93-18    electric cooperative.
93-19          Sec. 41.058.  TARIFFS FOR OPEN ACCESS.  An electric
93-20    cooperative that opts for customer choice and that owns or operates
93-21    transmission and distribution facilities shall file with the
93-22    commission, before the 90th day preceding the date the electric
93-23    cooperative offers customer choice, tariffs implementing the open
93-24    access rules established by the commission.  This filing shall be
93-25    for informational purposes only.
93-26          Sec. 41.059.  NO POWER TO AMEND CERTIFICATES.  Nothing in
 94-1    this chapter empowers a board of directors to issue, amend, or
 94-2    rescind a certificate of public convenience and necessity granted
 94-3    by the commission.
 94-4          Sec. 41.060.  CUSTOMER SERVICE INFORMATION.  (a)  The
 94-5    commission shall keep information submitted by customers and retail
 94-6    electric providers pertaining to the provision of electric service
 94-7    by electric cooperatives.
 94-8          (b)  The commission shall notify the appropriate electric
 94-9    cooperative of information submitted by a customer or retail
94-10    electric provider and the electric cooperative shall respond to the
94-11    customer or retail electric provider.  The electric cooperative
94-12    shall notify the commission of its response.
94-13          (c)  The commission shall prepare a report for the Sunset
94-14    Advisory Commission that includes information submitted and
94-15    responses by electric cooperatives pursuant to the Sunset Advisory
94-16    Commission's schedule for reviewing the commission.
94-17                    SUBCHAPTER C.  RIGHTS NOT AFFECTED
94-18          Sec. 41.101.  INTERFERENCE WITH CONTRACT.  (a)  This subtitle
94-19    shall not interfere with or abrogate the rights or obligations of
94-20    parties, including a retail or wholesale customer, to a contract
94-21    with an electric cooperative or its subsidiary.
94-22          (b)  No provision of this subtitle may interfere with or be
94-23    deemed to abrogate the rights or obligations of a party under a
94-24    contract or an agreement concerning certificated service areas.
94-25          Sec. 41.102.  ACCESS TO WHOLESALE MARKET.  Nothing in this
94-26    subtitle shall limit the access of an electric cooperative or its
 95-1    subsidiary, either on its own behalf or on behalf of its customers,
 95-2    to the wholesale electric market.
 95-3          Sec. 41.103.  PROTECTION OF BONDHOLDERS.  Nothing in this
 95-4    subtitle or any rule adopted under this subtitle shall impair
 95-5    contracts, covenants, or obligations between electric cooperatives,
 95-6    a lender, and the holders of bonds issued on behalf of or by one or
 95-7    more electric cooperatives.
 95-8          Sec. 41.104.  TAX-EXEMPT STATUS.  Nothing in this subtitle
 95-9    may impair the tax-exempt status of electric cooperatives, nor
95-10    shall anything in this subtitle compel any electric cooperative to
95-11    use its facilities in a manner which violates any contractual
95-12    provisions, bond covenants, or other restrictions applicable to
95-13    facilities financed by tax-exempt debt.
95-14          SECTION 25.  Section 252.022, Local Government Code, is
95-15    amended by adding Subsection (c) to read as follows:
95-16          (c)  This chapter does not apply to expenditures by a
95-17    municipally owned electric or gas utility or unbundled divisions of
95-18    a municipally owned electric or gas utility in connection with any
95-19    purchases by the municipally owned utility or divisions of a
95-20    municipally owned utility made in accordance with procurement
95-21    procedures adopted by the body vested with authority for management
95-22    and operation of the municipally owned utility or its divisions.
95-23    For purposes of this subsection, "municipally owned utility"
95-24    includes a river authority engaged in the generation, transmission,
95-25    or distribution of electric energy to the public.
95-26          SECTION 26.  Section 272.001, Local Government Code, is
 96-1    amended by adding Subsection (j) to read as follows:
 96-2          (j)  This section does not apply to sales or exchanges of
 96-3    land owned by a municipality operating a municipally owned electric
 96-4    or gas utility if the land is held or managed by the municipally
 96-5    owned utility, or by a division of the municipally owned electric
 96-6    or gas utility that constitutes the unbundled electric or gas
 96-7    operations of the utility.  For purposes of this subsection,
 96-8    "municipally owned utility" includes a river authority engaged in
 96-9    the generation, transmission, or distribution of electric energy to
96-10    the public, and "unbundled" operations are those operations of the
96-11    utility that have, in the discretion of the utility's governing
96-12    body, been functionally separated.
96-13          SECTION 27.  Subsection (c), Section 402.002, Local
96-14    Government Code, is amended to read as follows:
96-15          (c)  The municipality may manufacture its own electricity,
96-16    gas, or anything else needed or used by the public.  It may
96-17    purchase, and make contracts for the purchase of, gas, electricity,
96-18    oil, or any other commodity or article used by the public and may
96-19    sell it to the public on terms as provided by the municipal charter
96-20    or by ordinance.
96-21          SECTION 28.  Subdivision (3), Section 551.001, Government
96-22    Code, is amended to read as follows:
96-23                (3)  "Governmental body":
96-24                      (A)  means:
96-25                            (i) [(A)]  a board, commission, department,
96-26    committee, or agency within the executive or legislative branch of
 97-1    state government that is directed by one or more elected or
 97-2    appointed members;
 97-3                            (ii) [(B)]  a county commissioners court in
 97-4    the state;
 97-5                            (iii) [(C)]  a municipal governing body in
 97-6    the state;
 97-7                            (iv) [(D)]  a deliberative body that has
 97-8    rulemaking or quasi-judicial power and that is classified as a
 97-9    department, agency, or political subdivision of a county or
97-10    municipality;
97-11                            (v) [(E)]  a school district board of
97-12    trustees;
97-13                            (vi) [(F)]  a county board of school
97-14    trustees;
97-15                            (vii) [(G)]  a county board of education;
97-16                            (viii) [(H)]  the governing board of a
97-17    special district created by law; and
97-18                            (ix) [(I)]  a nonprofit corporation
97-19    organized under Chapter 76, Acts of the 43rd Legislature, 1st
97-20    Called Session, 1933 (Article 1434a, Vernon's Texas Civil
97-21    Statutes), that provides a water supply or wastewater service, or
97-22    both, and is exempt from ad valorem taxation under Section 11.30,
97-23    Tax Code;
97-24                      (B)  does not include the governing board of a
97-25    special district created by law, or the governing board of a
97-26    special district's affiliate corporation, with respect to
 98-1    deliberations relating to competitive activity, including trade
 98-2    secrets or privileged or confidential commercial or financial
 98-3    information, if disclosure of the information, as determined in the
 98-4    discretion of the governing board of the district or the district's
 98-5    affiliate, could give advantage to competitors and if those
 98-6    deliberations relate to electric utility operations; and
 98-7                      (C) does not include the governing body of a
 98-8    municipally owned electric or gas utility or unbundled division of
 98-9    a municipally owned electric or gas utility, or a separate
98-10    policy-making body of a municipality or its affiliate the sole
98-11    function of which is management and operation of the unbundled
98-12    divisions of a municipally owned electric or gas utility, with
98-13    respect to deliberations relating to competitive activity,
98-14    including but not limited to trade secrets or privileged or
98-15    confidential commercial or financial information, if disclosure of
98-16    the information, as determined in the discretion of the governing
98-17    body in question, could give advantage to competitors.  In this
98-18    paragraph, "unbundled divisions" are those that have been
98-19    functionally separated as provided by the entity's governing body.
98-20          SECTION 29.  Subdivision (1), Section 552.003, Government
98-21    Code, is amended to read as follows:
98-22                (1)  "Governmental body":
98-23                      (A)  means:
98-24                            (i)  a board, commission, department,
98-25    committee, institution, agency, or office that is within or is
98-26    created by the executive or legislative branch of state government
 99-1    and that is directed by one or more elected or appointed members;
 99-2                            (ii)  a county commissioners court in the
 99-3    state;
 99-4                            (iii)  a municipal governing body in the
 99-5    state;
 99-6                            (iv)  a deliberative body that has
 99-7    rulemaking or quasi-judicial power and that is classified as a
 99-8    department, agency, or political subdivision of a county or
 99-9    municipality;
99-10                            (v)  a school district board of trustees;
99-11                            (vi)  a county board of school trustees;
99-12                            (vii)  a county board of education;
99-13                            (viii)  the governing board of a special
99-14    district;
99-15                            (ix)  the governing body of a nonprofit
99-16    corporation organized under Chapter 76, Acts of the 43rd
99-17    Legislature, 1st Called Session, 1933 (Article 1434a, Vernon's
99-18    Texas Civil Statutes), that provides a water supply or wastewater
99-19    service, or both, and is exempt from ad valorem taxation under
99-20    Section 11.30, Tax Code; and
99-21                            (x)  the part, section, or portion of an
99-22    organization, corporation, commission, committee, institution, or
99-23    agency that spends or that is supported in whole or in part by
99-24    public funds; [and]
99-25                      (B)  does not include the judiciary;
99-26                      (C)  does not include the governing board of a
 100-1   special district, or the governing board of a special district's
 100-2   affiliate corporation, with respect to records relating to
 100-3   competitive activity, including trade secrets or privileged or
 100-4   confidential commercial or financial information, if disclosure of
 100-5   the information, as determined in the discretion of the governing
 100-6   board of the district or the district's affiliate, could give
 100-7   advantage to competitors and if the records relate to electric
 100-8   utility operations; and
 100-9                     (D)  does not include a governing body of any
100-10   entity listed in Paragraph (A) vested with the power to manage and
100-11   operate electric or gas utility activities, whether bundled or
100-12   unbundled, of the entity, or by a separate policy-making body of
100-13   the entity or its affiliate the sole function of which is
100-14   management and operation of the unbundled generating and marketing
100-15   divisions for electric or gas services, with respect to records
100-16   held by or on behalf of the governing body relating to competitive
100-17   activity, including trade secrets or privileged or confidential
100-18   commercial or financial information, if disclosure of the
100-19   information, as determined in the discretion of the governing body
100-20   of the entity in question, could give advantage to competitors.  In
100-21   this paragraph, "unbundled" activities or divisions are those that
100-22   have been functionally separated as provided by the entity's
100-23   governing body.
100-24         SECTION 30.  Subsection (d), Section 791.011, Government
100-25   Code, is amended to read as follows:
100-26         (d)  An interlocal contract must:
 101-1               (1)  be authorized by the governing body of each party
 101-2   to the contract; however, if a party to the contract is a
 101-3   municipally owned electric utility, authorization by the governing
 101-4   body of each party is  required only for contracts that exceed
 101-5   $100,000;
 101-6               (2)  state the purpose, terms, rights, and duties of
 101-7   the contracting parties; and
 101-8               (3)  specify that each party paying for the performance
 101-9   of governmental functions or services must make those payments from
101-10   current revenues available to the paying party.
101-11         SECTION 31.  Subchapter A, Chapter 2256, Government Code, is
101-12   amended by adding Section 2256.0201 to read as follows:
101-13         Sec. 2256.0201.  AUTHORIZED INVESTMENTS; MUNICIPAL UTILITY.
101-14   (a)  A municipality that owns a municipal electric utility that is
101-15   engaged in the distribution and sale of electric energy or natural
101-16   gas to the public may enter into a hedging contract and related
101-17   security and insurance agreements in relation to fuel oil, natural
101-18   gas, and electric energy to protect against loss due to price
101-19   fluctuations.  A hedging transaction must comply with the
101-20   regulations of the Commodity Futures Trading Commission and the
101-21   Securities and Exchange Commission.  If there is a conflict between
101-22   the municipal charter of the municipality and this chapter, this
101-23   chapter prevails.
101-24         (b)  A payment by a municipally owned electric or gas utility
101-25   under a hedging contract or related agreement in relation to fuel
101-26   supplies or fuel reserves is a fuel expense, and the utility may
 102-1   credit any amounts it receives under the contract or agreement
 102-2   against fuel expenses.
 102-3         (c)  The body vested with power to manage and operate the
 102-4   municipally owned electric or gas utility may set policy regarding
 102-5   hedging transactions.
 102-6         (d)  In this section, "hedging" means the buying and selling
 102-7   of fuel oil, natural gas, and electric energy futures or options or
 102-8   similar contracts on those commodity futures as a protection
 102-9   against loss due to price fluctuation.
102-10         SECTION 32.  Chapter 245, Acts of the 67th Legislature,
102-11   Regular Session, 1981 (Article 717p, Vernon's Texas Civil
102-12   Statutes), is amended by adding Section 4C to read as follows:
102-13         Sec. 4C.  (a)  This section applies only to a river authority
102-14   that is engaged in the distribution and sale of electric energy to
102-15   the public.
102-16         (b)  Notwithstanding any other law, a river authority may:
102-17               (1)  provide transmission services, as defined by the
102-18   Utilities Code or the Public Utility Commission of Texas, on a
102-19   regional basis to any eligible transmission customer at any
102-20   location within or outside the boundaries of the river authority;
102-21   and
102-22               (2)  acquire, including by lease-purchase; lease from
102-23   or to any person; finance; construct; rebuild; operate; or sell
102-24   electric transmission facilities at any location within or outside
102-25   the boundaries of the river authority; provided, however, that
102-26   nothing in this section shall allow a river authority to construct
 103-1   transmission facilities to an ultimate consumer of electricity to
 103-2   enable an ultimate consumer to bypass the transmission or
 103-3   distribution facilities of its existing provider.
 103-4         (c)  For purposes of this section, "electric transmission
 103-5   facilities" includes telecommunications systems that are attached
 103-6   or incidental to facilities used to transmit electric energy;
 103-7   provided, however, that this section does not authorize a river
 103-8   authority to serve as a common carrier of telecommunications
 103-9   services.
103-10         SECTION 33.  Sections 1 and 2, Article 1115a, Revised
103-11   Statutes, are amended to read as follows:
103-12         Sec. 1.  This article applies only to a home-rule
103-13   municipality that owns an electric utility system, that by
103-14   ordinance or charter elects to have the management and control of
103-15   the system governed by this article, and that:
103-16               (1)  has outstanding obligations payable in whole or
103-17   part [solely] from and secured by a lien on and pledge of net
103-18   revenues of the system; or
103-19               (2)  issues obligations that are payable in whole or
103-20   part [solely] from and secured by a lien on and pledge of the net
103-21   revenues of the system and that are approved by the attorney
103-22   general.
103-23         Sec. 2.  A municipality by ordinance may transfer management
103-24   and control of the electric utility system to a [five-member] board
103-25   of trustees appointed by the municipality's governing body.  The
103-26   municipality by ordinance shall determine [set] the qualifications
 104-1   for appointment to the board and the number of members.  The
 104-2   municipality may by ordinance vest the power to establish rates and
 104-3   related terms and conditions for its municipally owned electric
 104-4   utility in the board of trustees appointed under this section,
 104-5   notwithstanding any charter provision to the contrary.
 104-6         SECTION 34.  The following provisions are repealed:
 104-7         (1)  Chapter 34, Utilities Code;
 104-8         (2)  Subchapters F and G, Chapter 36, Utilities Code; and
 104-9         (3)  Section 37.058, Utilities Code.
104-10         SECTION 35.  (a)  Nothing in this Act shall restrict or limit
104-11   a municipality's historical right to control and receive reasonable
104-12   compensation for use of public streets, alleys, rights-of-way, or
104-13   other public property to convey or provide electricity.
104-14         (b)  Nothing in this Act shall affect a retail public
104-15   utility's right to provide electric service pursuant to a
104-16   certificate of public convenience and necessity.
104-17         SECTION 36.  The Public Utility Commission of Texas shall
104-18   study and make recommendations by December 15, 2000, to the 77th
104-19   Legislature for additional legislation that would move to and
104-20   establish a competitive electric market on January 1, 2002, in
104-21   accordance with the changes in law made by this Act.
104-22         SECTION 37.  No later than 180 days after the effective date
104-23   of this Act, the Public Utility Commission of Texas shall establish
104-24   rules and procedures for the securitization of stranded costs for
104-25   river authorities, as provided by Subdivision (2), Subsection (a),
104-26   Section 40.003, Utilities Code, as added by this Act.
 105-1         SECTION 38.  This Act takes effect September 1, 1999.
 105-2         SECTION 39.  The importance of this legislation and the
 105-3   crowded condition of the calendars in both houses create an
 105-4   emergency and an imperative public necessity that the
 105-5   constitutional rule requiring bills to be read on three several
 105-6   days in each house be suspended, and this rule is hereby suspended.