By: Schwertner, et al. S.B. No. 3
 
 
A BILL TO BE ENTITLED
 
AN ACT
  relating to preparing for, preventing, and responding to weather
  emergencies and power outages; increasing the amount of
  administrative and civil penalties.
         BE IT ENACTED BY THE LEGISLATURE OF THE STATE OF TEXAS:
         SECTION 1.  Chapter 411, Government Code, is amended by
  adding Subchapter K-1 to read as follows:
  SUBCHAPTER K-1. POWER OUTAGE ALERT
         Sec. 411.301.  POWER OUTAGE ALERT. (a) With the cooperation
  of the Texas Department of Transportation, the Texas Division of
  Emergency Management, the office of the governor, and the Public
  Utility Commission of Texas, the department shall develop and
  implement an alert to be activated when the power supply in this
  state may be inadequate to meet demand.
         (b)  The Public Utility Commission of Texas by rule shall
  adopt criteria for the content, activation, and termination of the
  alert described by Subsection (a). The criteria must provide for an
  alert to be regional or statewide.
         Sec. 411.302.  ADMINISTRATION. (a) The director is the
  statewide coordinator of the power outage alert.
         (b)  The director shall adopt rules and issue directives as
  necessary to ensure proper implementation of the power outage
  alert. The rules and directives must include the procedures to be
  used by the Public Utility Commission of Texas and the independent
  organization certified under Section 39.151, Utilities Code, to
  communicate with the director about the power outage alert.
         Sec. 411.303.  DEPARTMENT TO RECRUIT PARTICIPANTS. The
  department shall recruit public and commercial television and radio
  broadcasters, private commercial entities, state or local
  governmental entities, the public, and other appropriate persons to
  assist in developing and implementing the power outage alert
  system.
         Sec. 411.304.  STATE AGENCIES. (a) A state agency
  participating in the power outage alert system shall:
               (1)  cooperate with the department and assist in
  developing and implementing the alert system; and
               (2)  establish a plan for providing relevant
  information to its officers, investigators, or employees, as
  appropriate, once the power outage alert system has been activated.
         (b)  In addition to its duties as a state agency under
  Subsection (a), the Texas Department of Transportation shall
  establish a plan for providing relevant information to the public
  through an existing system of dynamic message signs located across
  the state.
         Sec. 411.305.  ACTIVATION OF POWER OUTAGE ALERT. (a) When
  the Public Utility Commission of Texas or an independent
  organization certified under Section 39.151, Utilities Code,
  notifies the department that the criteria adopted under Section
  411.301(b) for the activation of the alert has been met, the
  department shall confirm the accuracy of the information and, if
  confirmed, immediately issue a power outage alert under this
  subchapter in accordance with department rules.
         (b)  In issuing the power outage alert, the department shall
  send the alert to designated media outlets in this state. Following
  receipt of the alert, participating radio stations and television
  stations and other participating media outlets may issue the alert
  at designated intervals.
         Sec. 411.306.  CONTENT OF POWER OUTAGE ALERT. The power
  outage alert must include a statement that electricity customers
  may experience a power outage.
         Sec. 411.307.  TERMINATION OF POWER OUTAGE ALERT. The
  director shall terminate any activation of the power outage alert
  as soon as practicable after the Public Utility Commission of Texas
  or the Electric Reliability Council of Texas notifies the
  department that the criteria adopted under Section 411.301(b) for
  the termination of the alert has been met.
         Sec. 411.308.  LIMITATION ON PARTICIPATION BY TEXAS
  DEPARTMENT OF TRANSPORTATION. Notwithstanding Section 411.304(b),
  the Texas Department of Transportation is not required to use any
  existing system of dynamic message signs in a statewide alert
  system created under this subchapter if that department receives
  notice from the United States Department of Transportation Federal
  Highway Administration that the use of the signs would result in the
  loss of federal highway funding or other punitive actions taken
  against this state due to noncompliance with federal laws,
  regulations, or policies.
         SECTION 2.  Section 418.048, Government Code, is amended to
  read as follows:
         Sec. 418.048.  MONITORING WEATHER. (a) The division shall
  keep continuously apprised of weather conditions that present
  danger of climatic activity, such as precipitation, severe enough
  to constitute a disaster.
         (b)  The division shall create a list of suggested actions
  for state agencies and the public to take to prepare for winter
  storms, organized by severity of storm based on the National
  Weather Service Winter Storm Severity Index.
         SECTION 3.  Chapter 418, Government Code, is amended by
  adding Subchapter J to read as follows:
  SUBCHAPTER J. TEXAS ENERGY RELIABILITY COUNCIL
         Sec. 418.301.  DEFINITIONS. In this subchapter:
               (1)  "Chief" means the division's chief.
               (2)  "Council" means the Texas Energy Reliability
  Council.
         Sec. 418.302.  COUNCIL ESTABLISHED. The Texas Energy
  Reliability Council is established to:
               (1)  ensure that the energy and electric industries in
  this state meet high priority human needs and address critical
  infrastructure concerns; and
               (2)  enhance coordination and communication in the
  energy and electric industries in this state.
         Sec. 418.303.  MEMBERSHIP. (a) The council is composed of:
               (1)  the chairman of the Railroad Commission of Texas;
               (2)  the presiding officer of the Public Utility
  Commission of Texas;
               (3)  the chief executive of the Office of Public
  Utility Counsel;
               (4)  the presiding officer of the Texas Commission on
  Environmental Quality;
               (5)  the chair of the Texas Transportation Commission;
               (6)  a person to represent the independent organization
  certified under Section 39.151, Utilities Code, for the ERCOT power
  region, appointed by the governor;
               (7)  the chief;
               (8)  five persons to represent participants in the
  natural gas supply chain in this state, appointed by the Railroad
  Commission of Texas to represent as many types of participants as
  possible;
               (9)  five persons to represent the electric industry,
  appointed by the Public Utility Commission of Texas, including:
                     (A)  one person to represent entities that provide
  dispatchable electric energy to the power grid in this state;
                     (B)  one person to represent transmission and
  distribution utilities, as defined by Section 31.002, Utilities
  Code;
                     (C)  one person to represent retail electric
  providers, as defined by Section 31.002, Utilities Code;
                     (D)  one person to represent municipally owned
  utilities, as defined by Section 11.003, Utilities Code; and
                     (E)  one person to represent electric
  cooperatives;
               (10)  three persons to represent energy sectors not
  otherwise represented on the council, appointed by the Public
  Utility Commission of Texas; and
               (11)  five persons to represent industrial concerns,
  appointed by the governor, including:
                     (A)  one person to represent motor fuel producers;
  and
                     (B)  one person to represent chemical
  manufacturers.
         (b)  A member of the council described by Subsection (a)(1),
  (2), (3), (4), (5), (6), or (7) may designate a person from the
  member's agency to represent the member in any meeting.
         (c)  The council may request that a person collaborate with
  the council to achieve the purposes described by Section 418.302.
         Sec. 418.304.  OFFICERS. (a) The chief shall serve as
  presiding officer of the council.
         (b)  The council may select an assistant presiding officer
  and secretary from among its members.
         Sec. 418.305.  COMPENSATION; REIMBURSEMENT. A member of the
  council is not entitled to compensation or reimbursement of
  expenses for service on the council.
         Sec. 418.306.  MEETINGS. (a) After its initial meeting, the
  council shall meet at least twice each year at a time and place
  determined by the chief.
         (b)  The council may meet at other times the council
  considers appropriate. The presiding officer may call a meeting on
  the officer's own motion.
         Sec. 418.307.  ADMINISTRATIVE SUPPORT. The division shall
  provide administrative support to the council.
         Sec. 418.308.  GENERAL DUTIES OF COUNCIL. (a) The council
  shall foster communication and planning to ensure preparedness for
  making available and delivering energy and electricity in this
  state to ensure that high priority human needs are met and critical
  infrastructure needs are addressed.
         (b)  The council shall foster communication and coordination
  between the energy and electric industries in this state.
         Sec. 418.309.  SUPPLY CHAIN MAP. The council shall:
               (1)  map the natural gas supply chain for this state in
  order to designate priority service needs during extreme weather
  events, including electric generation facilities powered by
  natural gas; and
               (2)  identify and designate the sources in the supply
  chain necessary to operate critical infrastructure, as defined by
  Section 421.001.
         SECTION 4.  Subchapter C, Chapter 86, Natural Resources
  Code, is amended by adding Section 86.044 to read as follows:
         Sec. 86.044.  WEATHER EMERGENCY PREPAREDNESS. (a) In this
  section, "gas supply chain facility" means a facility that is:
               (1)  used for producing, treating, processing,
  pressurizing, storing, or transporting natural gas;
               (2)  otherwise regulated by the commission under this
  subtitle; and
               (3)  not regulated by the commission under Chapter 121,
  Utilities Code.
         (b)  The commission by rule shall require a gas supply chain
  facility operator to implement measures to prepare to operate
  during a weather emergency. In adopting the rules, the commission
  shall take into consideration the supply chain map created under
  Section 418.309, Government Code.
         (b-1)  The commission shall:
               (1)  inspect gas supply chain facilities that are
  identified in the map created under Section 418.309, Government
  Code, as necessary to operate critical infrastructure for
  compliance with the reliability standards;
               (2)  provide the owner of a facility described by
  Subdivision (1) with a reasonable period of time in which to remedy
  any violation the commission discovers in an inspection; and
               (3)  report to the attorney general any violation that
  is not remedied in a reasonable period of time.
         (b-2)  The commission shall prioritize inspections conducted
  under Subsection (b-1)(1) based on risk level, as determined by the
  commission.
         (c)  The commission by rule shall require an operator of a
  gas supply chain facility that experiences repeated or major
  weather-related forced interruptions of production to:
               (1)  contract with a person who is not an employee of
  the provider to assess the operator's weatherization plans,
  procedures, and operations; and
               (2)  submit the assessment to the commission.
         (d)  The commission may require an operator of a gas supply
  chain facility to implement appropriate recommendations included
  in an assessment submitted to the commission under Subsection (c).
         (e)  If the commission determines that a person has violated
  a rule adopted under this section, the commission shall notify the
  attorney general of a violation that is not remedied in a reasonable
  amount of time. The attorney general shall initiate a suit to
  recover a penalty for the violation in the manner provided by
  Subchapter G.
         SECTION 5.  Section 86.222, Natural Resources Code, is
  amended by adding Subsections (a-1), (c), and (d) to read as
  follows:
         (a-1)  Notwithstanding Subsection (a), a person who violates
  a provision of a rule adopted under Section 86.044 is liable for a
  penalty of not more than $1,000,000 for each offense.
         (c)  The commission by rule shall establish a classification
  system to be used by a court under this subchapter for violations of
  rules adopted under Section 86.044 that includes a range of
  penalties that may be recovered for each class of violation based
  on:
               (1)  the seriousness of the violation, including:
                     (A)  the nature, circumstances, extent, and
  gravity of a prohibited act; and
                     (B)  the hazard or potential hazard created to the
  health, safety, or economic welfare of the public;
               (2)  the history of previous violations;
               (3)  the amount necessary to deter future violations;
               (4)  efforts to correct the violation; and
               (5)  any other matter that justice may require.
         (d)  The classification system established under Subsection
  (c) shall provide that a penalty in an amount that exceeds $5,000
  may be recovered only if the violation is included in the highest
  class of violations in the classification system.
         SECTION 6.  Section 15.023, Utilities Code, is amended by
  adding Subsection (b-1) to read as follows:
         (b-1)  Notwithstanding Subsection (b), the penalty for a
  violation of a provision of Subtitle B may be in an amount not to
  exceed $1,000,000 for a violation. Each day a violation continues
  or occurs is a separate violation for purposes of imposing a
  penalty.
         SECTION 7.  Section 17.002, Utilities Code, is amended by
  adding Subdivision (3-a) to read as follows:
               (3-a)  "Critical care residential customer" has the
  meaning assigned by commission rules.
         SECTION 8.  Section 17.003, Utilities Code, is amended by
  adding Subsections (d-1) and (e) to read as follows:
         (d-1)  An electric utility providing electric delivery
  service for a retail electric provider, as defined by Section
  31.002, shall provide to the retail electric provider and the
  retail electric provider shall periodically provide to the retail
  electric provider's retail customers together with bills sent to
  the customers:
               (1)  the electric utility's procedures for implementing
  involuntary load shedding initiated by the independent
  organization certified for the ERCOT power region;
               (2)  the types of customers who may be considered
  critical care residential customers or critical load according to
  commission rules adopted under Section 38.075;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer or critical load
  according to commission rules adopted under Section 38.075; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         (e)  The commission by rule shall require each retail
  electric provider to:
               (1)  provide to the provider's customers clear and
  understandable information about the requirements for voluntary
  load shedding participation before the provider accepts a
  customer's agreement to volunteer to participate in voluntary load
  shedding;
               (2)  inform the provider's transmission and
  distribution utilities whether the retail electric provider serves
  customers willing to voluntarily participate in load shedding
  during an energy emergency; and
               (3)  coordinate with the provider's transmission and
  distribution utilities regarding the potential total amounts of
  electricity that may be available if voluntary load shedding is
  needed.
         SECTION 9.  Section 17.005, Utilities Code, is amended to
  read as follows:
         Sec. 17.005.  PROTECTIONS FOR CUSTOMERS OF MUNICIPALLY OWNED
  UTILITIES. (a) A municipally owned utility may not be deemed to be
  a "service provider" or "billing agent" for purposes of Sections
  17.156(b) and (e).
         (b)  The governing body of a municipally owned utility shall
  adopt, implement, and enforce rules that shall have the effect of
  accomplishing the objectives set out in Sections 17.004(a) and (b)
  and 17.102, as to the municipally owned utility within its
  certificated service area.
         (c)  The governing body of a municipally owned utility or its
  designee shall perform the dispute resolution function provided for
  by Section 17.157 for disputes arising from services provided by
  the municipally owned utility to electric customers served within
  the municipally owned utility's certificated service area.
         (d)  With respect to electric customers served by a
  municipally owned utility outside its certificated service area or
  otherwise served through others' distribution facilities, after
  retail competition begins as authorized by the legislature, the
  provisions of this chapter as administered by the commission apply.
         (e)  Nothing in this chapter shall be deemed to apply to a
  wholesale customer of a municipally owned utility.
         (f)  A municipally owned utility shall periodically provide
  with bills sent to retail customers of the utility information
  about:
               (1)  the utility's procedure for implementing
  involuntary load shedding;
               (2)  the types of customers who may be considered
  critical care residential customers or critical load according to
  commission rules adopted under Section 38.075;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer or critical load
  according to commission rules adopted under Section 38.075; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         SECTION 10.  Section 17.006, Utilities Code, is amended to
  read as follows:
         Sec. 17.006.  PROTECTIONS FOR CUSTOMERS OF ELECTRIC
  COOPERATIVES. (a) An electric cooperative shall not be deemed to
  be a "service provider" or "billing agent" for purposes of Sections
  17.156(b) and (e).
         (b)  The electric cooperative shall adopt, implement, and
  enforce rules that shall have the effect of accomplishing the
  objectives set out in Sections 17.004(a) and (b) and 17.102.
         (c)  The board of directors of the electric cooperative or
  its designee shall perform the dispute resolution function provided
  for by Section 17.157 for electric customers served by the electric
  cooperative within its certificated service area.
         (d)  With respect to electric customers served by an electric
  cooperative outside its certificated service area or otherwise
  served through others' distribution facilities, after the
  legislature authorizes retail competition, the provisions of this
  chapter as administered by the commission shall apply.
         (e)  Nothing in this chapter shall be deemed to apply to a
  wholesale customer of an electric cooperative.
         (f)  An electric cooperative shall periodically provide with
  bills sent to retail customers of the cooperative information
  about:
               (1)  the cooperative's procedure for implementing
  involuntary load shedding;
               (2)  the types of customers who may be considered
  critical care residential customers or critical load according to
  commission rules adopted under Section 38.075;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer or critical load
  according to commission rules adopted under Section 38.075; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         SECTION 11.  The heading to Chapter 35, Utilities Code, is
  amended to read as follows:
  CHAPTER 35. [ALTERNATIVE] ENERGY PROVIDERS
         SECTION 12.  Subchapter A, Chapter 35, Utilities Code, is
  amended by adding Section 35.0021 to read as follows:
         Sec. 35.0021.  WEATHER EMERGENCY PREPAREDNESS. (a) This
  section applies only to a municipally owned utility, electric
  cooperative, power generation company, or exempt wholesale
  generator that sells electric energy at wholesale in the ERCOT
  power region.
         (b)  The commission by rule shall require each provider of
  electric generation service described by Subsection (a) to
  implement measures to prepare the provider's generation assets to
  provide adequate electric generation service during a weather
  emergency according to reliability standards adopted by the
  commission.
         (c)  The independent organization certified under Section
  39.151 for the ERCOT power region shall:
               (1)  inspect generation assets in the ERCOT power
  region for compliance with the reliability standards;
               (2)  provide the owner of a generation asset with a
  reasonable period of time in which to remedy any violation the
  independent organization discovers in an inspection; and
               (3)  report to the commission any violation.
         (c-1)  The independent organization certified under Section
  39.151 for the ERCOT power region shall prioritize inspections
  conducted under Subsection (c)(1) based on risk level, as
  determined by the organization.
         (d)  The commission by rule shall require a provider of
  electric generation service described by Subsection (a) for a
  generation asset that experiences repeated or major
  weather-related forced interruptions of service to:
               (1)  contract with a person who is not an employee of
  the provider to assess the provider's weatherization plans,
  procedures, and operations for that asset; and
               (2)  submit the assessment to the commission and the
  independent organization certified under Section 39.151 for the
  ERCOT power region.
         (e)  The commission may require a provider of electric
  generation service described by Subsection (a) to implement
  appropriate recommendations included in an assessment submitted to
  the commission under Subsection (d).
         (f)  The independent organization certified under Section
  39.151 for the ERCOT power region shall review, coordinate, and
  approve or deny requests by providers of electric generation
  service described by Subsection (a) for a planned power outage
  during any season and for any period of time.
         (g)  The commission shall impose an administrative penalty
  on an entity, including a municipally owned utility or an electric
  cooperative, that violates a rule adopted under this section and
  does not remedy that violation within a reasonable period of time.
         SECTION 13.  Section 35.004(e), Utilities Code, is amended
  to read as follows:
         (e)  The commission shall ensure that ancillary services
  necessary to facilitate the transmission of electric energy are
  available at reasonable prices with terms and conditions that are
  not unreasonably preferential, prejudicial, discriminatory,
  predatory, or anticompetitive. The commission shall require
  intermittent generation resources in the ERCOT power region to
  purchase ancillary services and replacement power sufficient to
  manage net load variability.  In this subsection, "ancillary
  services" means services necessary to facilitate the transmission
  of electric energy including load following, standby power, backup
  power, reactive power, and any other services as the commission may
  determine by rule. On the introduction of customer choice in the
  ERCOT power region, acquisition of generation-related ancillary
  services on a nondiscriminatory basis by the independent
  organization in ERCOT on behalf of entities selling electricity at
  retail shall be deemed to meet the requirements of this subsection.
         SECTION 14.  Subchapter D, Chapter 38, Utilities Code, is
  amended by adding Sections 38.074, 38.075, and 38.076 to read as
  follows:
         Sec. 38.074.  WEATHER EMERGENCY PREPAREDNESS. (a) The
  commission by rule shall require each electric cooperative,
  municipally owned utility, and transmission and distribution
  utility providing transmission service in the ERCOT power region to
  implement measures to prepare the cooperative's or utility's
  facilities to maintain service quality and reliability during a
  weather emergency according to standards adopted by the commission.
         (b)  The independent organization certified under Section
  39.151 for the ERCOT power region shall:
               (1)  inspect the facilities of each electric
  cooperative, municipally owned utility, and transmission and
  distribution utility providing transmission service in the ERCOT
  power region for compliance with the reliability standards;
               (2)  provide the owner of a facility described by
  Subdivision (1) with a reasonable period of time in which to remedy
  any violation the independent organization discovers in an
  inspection; and
               (3)  report to the commission any violation that is not
  remedied in a reasonable period of time.
         (c)  The independent organization certified under Section
  39.151 for the ERCOT power region shall prioritize inspections
  conducted under Subsection (b)(1) based on risk level, as
  determined by the organization.
         (d)  The commission shall impose an administrative penalty
  on an entity, including a municipally owned utility or an electric
  cooperative, that violates a rule adopted under this section and
  does not remedy that violation within a reasonable period of time.
         Sec. 38.075.  INVOLUNTARY LOAD SHEDDING. (a) The
  commission by rule shall adopt a system to allocate load shedding
  among electric cooperatives, municipally owned utilities, and
  transmission and distribution utilities providing transmission
  service in the ERCOT power region during an involuntary load
  shedding event initiated by an independent organization certified
  under Section 39.151 for the region during an energy emergency.
         (b)  The system must provide for allocation of the load
  shedding obligation to each electric cooperative, municipally
  owned utility, and transmission and distribution utility in
  different seasons based on historical seasonal peak demand in the
  service territory of the electric cooperative, municipally owned
  utility, or transmission and distribution utility.
         (c)  The commission by rule shall:
               (1)  categorize types of critical load that may be
  given the highest priority for power restoration; and
               (2)  require electric cooperatives, municipally owned
  utilities, and transmission and distribution utilities providing
  transmission service in the ERCOT power region to submit to the
  commission and the independent organization certified under
  Section 39.151 for the region:
                     (A)  customers or circuits the cooperative or
  utility has designated as critical load; and
                     (B)  a plan for participating in load shedding in
  response to an involuntary load shedding event described by
  Subsection (a).
         (d)  The commission by rule shall require electric
  cooperatives and municipally owned utilities providing
  transmission service in the ERCOT power region to:
               (1)  maintain lists of customers willing to voluntarily
  participate in voluntary load reduction; and
               (2)  coordinate with municipalities, businesses, and
  customers that consume large amounts of electricity to encourage
  voluntary load reduction.
         (e)  This section does not abridge, enlarge, or modify the
  obligation of an electric cooperative, a municipally owned utility,
  or a transmission and distribution utility to comply with federal
  reliability standards.
         (f)  After each load shedding event, the commission may
  conduct an examination of the implementation of load shedding,
  including whether each electric cooperative, municipally owned
  utility, and transmission and distribution utility complied with
  its plan as filed with the commission under Subsection (c)(2).
         Sec. 38.076.  LOAD SHEDDING EXERCISES. (a) The commission
  and the independent organization certified for the ERCOT power
  region shall conduct simulated or tabletop load shedding exercises
  with providers of electric generation service and transmission and
  distribution service in the ERCOT power region.
         (b)  The commission shall ensure that each year at least one
  simulated or tabletop exercise is conducted during a summer month
  and one simulated or tabletop exercise is conducted during a winter
  month.
         SECTION 15.  Subchapter C, Chapter 39, Utilities Code, is
  amended by adding Section 39.110 to read as follows:
         Sec. 39.110.  WHOLESALE INDEXED PRODUCTS PROHIBITED. (a)
  In this section, "wholesale indexed product" means a retail
  electric product in which the price a customer pays for electricity
  includes a direct pass-through of real-time settlement point prices
  determined by the independent organization certified under Section
  39.151 for the ERCOT power region.
         (b)  A retail electric provider may not offer a wholesale
  indexed product to a residential or small commercial customer.
         SECTION 16.  Subchapter D, Chapter 39, Utilities Code, is
  amended by adding Section 39.159 to read as follows:
         Sec. 39.159.  WHOLESALE PRICING PROCEDURES. (a) The
  commission by rule shall establish an emergency pricing program for
  the wholesale electric market.
         (b)  The emergency pricing program shall compensate
  generators based on their actual costs of generation during the
  time of the emergency.
         (c)  The emergency pricing program shall take effect if the
  high system-wide offer cap has been in effect for 12 hours within a
  24 hour period after initially reaching the high system-wide offer
  cap.  The commission by rule shall determine when the emergency
  pricing program shall cease.
         (d)  The emergency pricing program may not allow an emergency
  pricing program cap to exceed any nonemergency high system-wide
  offer cap.
         (e)  The emergency pricing program may include a true-up
  after the operating day.
         (f)  The price of ancillary services may not exceed 150
  percent of any high system-wide offer cap or emergency pricing
  program in effect at the time. 
         (g)  Any wholesale pricing procedure that has a low
  system-wide offer cap may not have the low system-wide offer cap
  exceed the high system-wide offer cap. 
         (h)  The commission shall review each system-wide offer cap
  program adopted by the commission, including the emergency pricing
  program, at least once every five years to determine whether to
  update aspects of the program.
         SECTION 17.  Subchapter Z, Chapter 39, Utilities Code, is
  amended by adding Section 39.9165 to read as follows:
         Sec. 39.9165.  DISTRIBUTED GENERATION REPORTING. (a) In
  this section, "distributed generation" is an electrical generating
  facility that:
               (1)  may be located at a customer's point of delivery;
               (2)  is connected at a voltage less than 60 kilovolts;
  and
               (3)  may be connected in parallel operation to the
  utility system.
         (b)  An independent organization certified under Section
  39.151 shall require an owner or operator of distributed generation
  to register with the organization and interconnecting transmission
  and distribution utility information necessary for the
  interconnection of the distributed generator.
         (c)  This section does not apply to distributed generation
  serving a residential property.
         SECTION 18.  Section 105.023, Utilities Code, is amended by
  adding Subsections (b-1), (e), and (f) to read as follows:
         (b-1)  Notwithstanding Subsection (b), a civil penalty under
  this section shall be in an amount of not less than $1,000 and not
  more than $1,000,000 for each violation of Section 104.258(c).
         (e)  The railroad commission by rule shall establish a
  classification system to be used by a court under this subchapter
  for violations of Section 104.258(c) that includes a range of
  penalties that may be recovered for each class of violation based
  on:
               (1)  the seriousness of the violation, including:
                     (A)  the nature, circumstances, extent, and
  gravity of a prohibited act; and
                     (B)  the hazard or potential hazard created to the
  health, safety, or economic welfare of the public;
               (2)  the history of previous violations;
               (3)  the amount necessary to deter future violations;
               (4)  efforts to correct the violation; and
               (5)  any other matter that justice may require.
         (f)  The classification system established under Subsection
  (e) shall provide that a penalty in an amount that exceeds $5,000
  may be recovered only if the violation is included in the highest
  class of violations in the classification system.
         SECTION 19.  Section 121.2015, Utilities Code, is amended by
  amending Subsection (a) and adding Subsections (c-1), (c-2), (d),
  (e), and (f) to read as follows:
         (a)  The railroad commission shall adopt rules regarding:
               (1)  public education and awareness relating to gas
  pipeline facilities; [and]
               (2)  community liaison for responding to an emergency
  relating to a gas pipeline facility; and
               (3)  measures gas pipeline facility operators must
  implement to prepare gas pipeline facilities to maintain service
  quality and reliability during extreme weather conditions, taking
  into consideration the supply chain map created under Section
  418.309, Government Code.
         (c-1)  The railroad commission shall:
               (1)  inspect the gas pipeline facilities that are
  identified in the map created under Section 418.309, Government
  Code, as necessary to operate critical infrastructure for
  compliance with the reliability standards;
               (2)  provide the owner of a facility described by
  Subdivision (1) with a reasonable period of time in which to remedy
  any violation the railroad commission discovers in an inspection;
  and
               (3)  report to the attorney general any violation that
  is not remedied in a reasonable period of time.
         (c-2)  The railroad commission shall prioritize inspections
  conducted under Subsection (c-1)(1) based on risk level, as
  determined by the railroad commission.
         (d)  The railroad commission by rule shall require a gas
  pipeline facility operator that experiences repeated or major
  weather-related forced interruptions of service to:
               (1)  contract with a person who is not an employee of
  the provider to assess the operator's weatherization plans,
  procedures, and operations; and
               (2)  submit the assessment to the commission.
         (e)  The railroad commission may require an operator of a gas
  supply chain facility to implement appropriate recommendations
  included in an assessment submitted to the commission under
  Subsection (d).
         (f)  The railroad commission shall assess an administrative
  penalty against a person who violates a rule adopted under
  Subsection (a)(3) if the violation is not remedied in a reasonable
  period of time in the manner provided by Subchapter E.
         SECTION 20.  Section 121.206, Utilities Code, is amended by
  adding Subsections (b-1) and (e) to read as follows:
         (b-1)  Notwithstanding Subsection (b), the penalty for each
  violation may not exceed $1,000,000 for a violation of a rule
  adopted under Section 121.2015(a)(3). Each day a violation
  continues may be considered a separate violation for the purpose of
  penalty assessment.
         (e)  The guidelines must provide that a penalty in an amount
  that exceeds $5,000 for a violation of a rule adopted under Section
  121.2015(a)(3) may be assessed only if circumstances justify the
  enhancement of the penalty.
         SECTION 21.  The heading to Section 186.007, Utilities Code,
  is amended to read as follows:
         Sec. 186.007.  PUBLIC UTILITY COMMISSION WEATHER EMERGENCY
  PREPAREDNESS REPORTS [REPORT].
         SECTION 22.  Sections 186.007(a-1), (b), (d), (e), and (f),
  Utilities Code, are amended to read as follows:
         (a-1)  The commission shall analyze emergency operations
  plans developed by electric utilities as defined by Section 31.002,
  power generation companies as defined by Section 31.002,
  municipally owned utilities, and electric cooperatives that
  operate generation facilities in this state and retail electric
  providers as defined by Section 31.002 and prepare a weather
  emergency preparedness report on power [generation] weatherization
  preparedness. In preparing the report, the commission shall:
               (1)  review [the] emergency operations plans
  [currently] on file with the commission;
               (2)  analyze and determine the ability of the electric
  grid to withstand extreme weather events in the upcoming year;
               (3)  consider the anticipated weather patterns for the
  upcoming year as forecasted by the National Weather Service or any
  similar state or national agency; and
               (4)  make recommendations on improving emergency
  operations plans and procedures in order to ensure the continuity
  of electric service.
         (b)  The commission shall [may] require an [electric
  generation] entity subject to this section to file an updated
  emergency operations plan if it finds that an emergency operations
  plan on file does not contain adequate information to determine
  whether the [electric generation] entity can provide adequate
  electric [generation] services.
         (d)  The commission shall submit the report described by
  Subsection (a-1) to the lieutenant governor, the speaker of the
  house of representatives, and the members of the legislature not
  later than September 30 of each even-numbered year[, 2012].
         (e)  The commission may submit additional [subsequent]
  weather emergency preparedness reports if the commission finds that
  significant changes to weatherization techniques have occurred or
  are necessary to protect consumers or vital services, or if there
  have been changes to statutes or rules relating to weatherization
  requirements. A report under this subsection must be submitted not
  later than:
               (1)  March 1 for a summer weather emergency
  preparedness report; and
               (2)  September 1 for a winter weather emergency
  preparedness report.
         (f)  The emergency operations plans submitted for a [the]
  report described by Subsection (a-1) and any additional
  [subsequent] plans submitted under Subsection (e) are public
  information except for the portions of the plan considered
  confidential under Chapter 552, Government Code, or other state or
  federal law. If portions of a plan are designated as confidential,
  the plan shall be provided to the commission in a redacted form for
  public inspection with the confidential portions removed. An
  [electric generation] entity within the ERCOT power region shall
  provide the entity's plan to ERCOT in its entirety.
         SECTION 23.  Subchapter A, Chapter 186, Utilities Code, is
  amended by adding Section 186.008 to read as follows:
         Sec. 186.008.  RAILROAD COMMISSION WEATHER EMERGENCY
  PREPAREDNESS REPORTS. (a) In this section, "commission" means the
  Railroad Commission of Texas.
         (b)  The commission shall analyze emergency operations plans
  developed by operators of gas supply chain facilities, as defined
  by Section 86.044, Natural Resources Code, and by gas pipeline
  facility operators regulated under Chapter 121 and prepare a
  weather emergency preparedness report on natural gas supply chain
  weatherization preparedness. In preparing the report, the
  commission shall:
               (1)  review any emergency operations plans on file with
  the commission;
               (2)  analyze and determine the ability of the natural
  gas supply chain, as mapped under Section 418.309, Government Code,
  to withstand extreme weather events in the upcoming year;
               (3)  consider the anticipated weather patterns for the
  upcoming year as forecasted by the National Weather Service or any
  similar state or national agency; and
               (4)  make recommendations on improving emergency
  operations plans and procedures in order to ensure the continuity
  of natural gas service.
         (c)  The commission shall require an entity subject to this
  section to file an updated emergency operations plan if it finds
  that an emergency operations plan on file does not contain adequate
  information to determine whether the entity can provide adequate
  natural gas services.
         (d)  The commission may adopt rules relating to the
  implementation of the report described by Subsection (b).
         (e)  The commission shall submit the report described by
  Subsection (b) to the lieutenant governor, the speaker of the house
  of representatives, and the members of the legislature not later
  than September 30 of each even-numbered year.
         (f)  The commission may submit additional weather emergency
  preparedness reports if the commission finds that significant
  changes to weatherization techniques have occurred or are necessary
  to protect consumers or vital services, or if there have been
  changes to statutes or rules relating to weatherization
  requirements. A report under this subsection must be submitted not
  later than:
               (1)  March 1 for a summer weather emergency
  preparedness report; and
               (2)  September 1 for a winter weather emergency
  preparedness report.
         (g)  The emergency operations plans submitted for a report
  described by Subsection (b) and any additional plans submitted
  under Subsection (f) are public information except for the portions
  of the plan considered confidential under Chapter 552, Government
  Code, or other state or federal law. If portions of a plan are
  designated as confidential, the plan shall be provided to the
  commission in a redacted form for public inspection with the
  confidential portions removed.
         SECTION 24.  Section 13.1395(a), Water Code, is amended to
  read as follows:
         (a)  In this section:
               (1)  "Affected utility" means a retail public utility,
  exempt utility, or provider or conveyor of potable or raw water
  service that furnishes water service to more than one customer[:
                     [(A)  in a county with a population of 3.3 million
  or more; or
                     [(B)  in a county with a population of 550,000 or
  more adjacent to a county with a population of 3.3 million or more].
               (2)  "Emergency operations" means the operation of a
  water system during an extended power outage at a minimum water
  pressure of 35 pounds per square inch.
               (3)  "Extended power outage" means a power outage
  lasting for more than 24 hours.
         SECTION 25.  Subchapter E, Chapter 13, Water Code, is
  amended by adding Section 13.151 to read as follows:
         Sec. 13.151.  BILLING FOR SERVICES PROVIDED DURING EXTREME
  WEATHER EMERGENCY. (a) In this section, "extreme weather
  emergency" means a period when:
               (1)  the previous day's highest temperature did not
  exceed 32 degrees Fahrenheit and the temperature is predicted to
  remain at or below that level for the next 24 hours according to the
  nearest National Weather Service reports; or
               (2)  the National Weather Service issues a heat
  advisory for any county in the relevant service territory, or when
  such an advisory has been issued on any one of the previous two
  calendar days.
         (b)  A retail public utility that is required to possess a
  certificate of public convenience and necessity or a district and
  affected county that furnishes retail water or sewer utility
  service shall defer collection of the full payment of bills that are
  due during an extreme weather emergency until after the emergency
  is over and shall work with customers to establish a pay schedule
  for deferred bills.
         SECTION 26.  Section 13.414, Water Code, is amended by
  adding Subsections (a-1), (d), and (e) to read as follows:
         (a-1)  Notwithstanding Subsection (a), a retail public
  utility or affiliated interest that violates Section 13.151 is
  subject to a civil penalty of not less than $100 nor more than
  $1,000,000 for each violation.
         (d)  The commission by rule shall establish a classification
  system to be used by a court under this section for violations of
  Section 13.151 that includes a range of penalties that may be
  recovered for each class of violation based on:
               (1)  the seriousness of the violation, including:
                     (A)  the nature, circumstances, extent, and
  gravity of a prohibited act; and
                     (B)  the hazard or potential hazard created to the
  health, safety, or economic welfare of the public;
               (2)  the history of previous violations;
               (3)  the amount necessary to deter future violations;
               (4)  efforts to correct the violation; and
               (5)  any other matter that justice may require.
         (e)  The classification system established under Subsection
  (d) shall provide that a penalty in an amount that exceeds $5,000
  may be recovered only if the violation is included in the highest
  class of violations in the classification system.
         SECTION 27.  Section 13.4151, Water Code, is amended by
  adding Subsection (a-1) to read as follows:
         (a-1)  Notwithstanding Subsection (a), the penalty for a
  violation of Section 13.151 may be in an amount not to exceed
  $1,000,000 a day. The utility commission may assess a penalty in an
  amount that exceeds $5,000 under this subsection only if the
  utility commission determines that a penalty in an amount that
  exceeds $5,000 is justified based on the seriousness of the
  violation as classified under Subsection (b). Each day a violation
  continues may be considered a separate violation.
         SECTION 28.  (a) The State Energy Plan Advisory Committee is
  composed of 12 members. The governor, lieutenant governor, and
  speaker of the house of representatives each shall appoint four
  members to the advisory committee.
         (b)  Not later than September 1, 2022, the State Energy Plan
  Advisory Committee shall prepare a comprehensive state energy plan.
  The plan must:
               (1)  evaluate barriers in the electricity and natural
  gas markets that prevent sound economic decisions;
               (2)  evaluate methods to improve the reliability,
  stability, and affordability of electric service in this state;
               (3)  provide recommendations for removing the barriers
  described by Subdivision (1) and using the methods described by
  Subdivision (2); and
               (4)  evaluate the electricity market structure and
  pricing mechanisms used in this state, including the ancillary
  services market and emergency response services.
         (c)  The state energy plan prepared under this section must
  be submitted to the legislature not later than September 1, 2022.
         SECTION 29.  The Public Utility Commission of Texas and the
  independent organization certified under Section 39.151, Utilities
  Code, shall annually review statutes, rules, protocols, and bylaws
  that apply to conflicts of interest for commissioners and for
  members of the governing body of the independent organization and
  submit to the legislature a report on the effects the statutes,
  rules, protocols, and bylaws have on the ability of the commission
  and the independent organization to fulfill their duties.
         SECTION 30.  The Public Utility Commission of Texas shall
  complete the first review required by Section 39.159(h), Utilities
  Code, as added by this Act, not later than December 31, 2021.
         SECTION 31.  (a) Not later than November 1, 2021, each
  affected utility, as defined by Section 13.1395, Water Code, as
  amended by this Act, shall complete the submissions required by
  Section 13.1396(c), Water Code.
         (b)  Not later than March 1, 2022, each affected utility
  shall submit to the Texas Commission on Environmental Quality the
  emergency preparedness plan required by Section 13.1395, Water
  Code, as amended by this Act.
         (c)  Not later than July 1, 2022, each affected utility shall
  implement the emergency preparedness plan approved by the Texas
  Commission on Environmental Quality under Section 13.1395, Water
  Code, as amended by this Act.
         (d)  An affected utility may file with the Texas Commission
  on Environmental Quality a written request for an extension, not to
  exceed 90 days, of the date by which the affected utility is
  required under Subsection (b) of this section to submit the
  affected utility's emergency preparedness plan or of the date by
  which the affected utility is required under Subsection (c) of this
  section to implement the affected utility's emergency preparedness
  plan. The Texas Commission on Environmental Quality shall approve
  the requested extension for good cause shown.
         SECTION 32.  Not later than six months after the date the
  Texas Energy Reliability Council produces the map required under
  Section 418.309, Government Code, as added by this Act, the
  Railroad Commission of Texas shall adopt rules necessary to
  implement:
               (1)  Section 86.044, Natural Resources Code, as added
  by this Act; and
               (2)  Section 121.2015, Utilities Code, as amended by
  this Act.
         SECTION 33.  Not later than six months after the effective
  date of this Act, the Public Utility Commission of Texas shall adopt
  rules necessary to implement:
               (1)  Section 35.0021, Utilities Code, as added by this
  Act; and
               (2)  Section 38.074, Utilities Code, as added by this
  Act.
         SECTION 34.  This Act takes effect immediately if it
  receives a vote of two-thirds of all the members elected to each
  house, as provided by Section 39, Article III, Texas Constitution.
  If this Act does not receive the vote necessary for immediate
  effect, this Act takes effect September 1, 2021.