S.B. No. 3
 
 
 
 
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; DISASTER PREPAREDNESS
  EDUCATION. (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.
         (c)  The division shall develop disaster preparedness
  educational materials that include instructions for preparing a
  disaster kit containing supplies most needed in a disaster or
  emergency, such as water, nonperishable food, medical supplies,
  flashlights, and other essential items, to assist families and
  businesses in adequately preparing for winter storms, hurricanes,
  floods, drought, fires, and other potential disasters.
         (d)  The division shall post on the division's Internet
  website and distribute to local governments and businesses the
  educational materials and instructions developed under Subsection
  (c).
         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. (a)  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.
         (b)  Chapter 2110 does not apply to the council.
         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.  INFORMATION.  (a)  In this section:
               (1)  "Gas provider" means:
                     (A)  a natural gas pipeline facility operator;
                     (B)  an operator of a natural gas well; or
                     (C)  an entity that produces, treats, processes,
  pressurizes, stores, or transports natural gas in this state or
  otherwise participates in the natural gas supply chain in this
  state.
               (2)  "Public utility" means an entity that generates,
  transmits, or distributes electric energy to the public, including
  an electric cooperative, an electric utility, a municipally owned
  utility, or a river authority.
         (b)  A public utility or gas provider shall provide to the
  council any information related to a disaster requested by the
  council. Information obtained by the council under this subsection
  is confidential and not subject to disclosure by the council if the
  information is critical energy infrastructure information as
  defined by the independent organization certified under Section
  39.151, Utilities Code, for the ERCOT power region or federal law.
         (c)  Except as provided by Subsection (d), the meetings of
  the council and information obtained or created by the council are
  not subject to the requirements of Chapter 551 or 552.
         (d)  Information written, produced, collected, assembled, or
  maintained under law or in connection with the transaction of
  official business by the council or an officer or employee of the
  council is subject to Section 552.008 in the same manner as public
  information.
         Sec. 418.310.  REPORT. (a)  Not later than November 1 of
  each even-numbered year, the council shall submit to the
  legislature a report on the reliability and stability of the
  electricity supply chain in this state.
         (b)  The report must include recommendations on methods to
  strengthen the electricity supply chain in this state and to
  decrease the frequency of extended power outages caused by a
  disaster in this state.
         SECTION 4.  Subchapter C, Chapter 81, Natural Resources
  Code, is amended by adding Section 81.073 to read as follows:
         Sec. 81.073.  CRITICAL NATURAL GAS FACILITIES AND ENTITIES.
  (a) The commission shall collaborate with the Public Utility
  Commission of Texas to adopt rules to establish a process to
  designate certain natural gas facilities and entities associated
  with providing natural gas in this state as critical customers or
  critical gas suppliers during energy emergencies.
         (b)  The rules must:
               (1)  establish criteria for designating persons who own
  or operate a facility under the jurisdiction of the commission
  under Section 81.051(a) or engage in an activity under the
  jurisdiction of the commission under Section 81.051(a) who must
  provide critical customer and critical gas supply information, as
  defined by the commission, to the entities described by Section
  38.074(b)(1), Utilities Code;
               (2)  consider essential operational elements when
  defining critical customer designations and critical gas supply
  information for the purposes of Subdivision (1), including natural
  gas production, processing, and transportation, related produced
  water handling and disposal facilities, and the delivery of natural
  gas to generators of electric energy; and
               (3)  require that only facilities and entities that are
  prepared to operate during a weather emergency may be designated as
  a critical customer under this section.
         SECTION 5.  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)  not primarily used to support liquefied natural
  gas pretreatment, liquefaction, or regasification facilities in
  the business of exporting or importing liquefied natural gas to or
  from foreign countries;
               (3)  otherwise regulated by the commission under this
  subtitle; and
               (4)  not regulated by the commission under Chapter 121,
  Utilities Code.
         (b)  This section applies only to a gas supply chain facility
  that is:
               (1)  included on the electricity supply chain map
  created under Section 38.203, Utilities Code; and
               (2)  designated as critical by the commission in the
  manner provided by Section 81.073.
         (c)  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 weather predictions produced by the
  office of the state climatologist.
         (d)  The commission shall:
               (1)  inspect gas supply chain facilities for compliance
  with rules adopted under Subsection (c);
               (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.
         (e)  The commission shall prioritize inspections conducted
  under Subsection (d)(1) based on risk level, as determined by the
  commission.
         (f)  The commission by rule shall require an operator of a
  gas supply chain facility that experiences repeated
  weather-related or major weather-related forced interruptions of
  production to:
               (1)  contract with a person who is not an employee of
  the operator to assess the operator's weatherization plans,
  procedures, and operations; and
               (2)  submit the assessment to the commission.
         (g)  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 (f).
         (h)  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 6.  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 7.  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 Section 35.0021 or 38.075 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 8.  Section 17.002, Utilities Code, is amended by
  adding Subdivisions (3-a) and (3-b) to read as follows:
               (3-a)  "Critical care residential customer" means a
  residential customer who has a person permanently residing in the
  customer's home who has been diagnosed by a physician as being
  dependent upon an electric-powered medical device to sustain life.
               (3-b)  "Critical load industrial customer" means an
  industrial customer for whom an interruption or suspension of
  electric service will create a dangerous or life-threatening
  condition on the customer's premises.
         SECTION 9.  Section 17.003, Utilities Code, is amended by
  adding Subsection (d-1) 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, information about:
               (1)  the electric utility's procedures for implementing
  involuntary load shedding initiated by the independent
  organization certified under Section 39.151 for the ERCOT power
  region;
               (2)  the types of customers who may be considered
  critical care residential customers, critical load industrial
  customers, or critical load according to commission rules adopted
  under Section 38.076;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer, a critical load
  industrial customer, or critical load according to commission rules
  adopted under Section 38.076; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         SECTION 10.  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, critical load industrial
  customers, or critical load according to commission rules adopted
  under Section 38.076;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer, a critical load
  industrial customer, or critical load according to commission rules
  adopted under Section 38.076; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         SECTION 11.  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, critical load industrial
  customers, or critical load according to commission rules adopted
  under Section 38.076;
               (3)  the procedure for a customer to apply to be
  considered a critical care residential customer, a critical load
  industrial customer, or critical load according to commission rules
  adopted under Section 38.076; and
               (4)  reducing electricity use at times when involuntary
  load shedding events may be implemented.
         SECTION 12.  The heading to Chapter 35, Utilities Code, is
  amended to read as follows:
  CHAPTER 35. [ALTERNATIVE] ENERGY PROVIDERS
         SECTION 13.  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. In adopting the rules, the commission shall take into
  consideration weather predictions produced by the office of the
  state climatologist.
         (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 14.  Section 35.004, Utilities Code, is amended by
  amending Subsection (e) and adding Subsections (f), (g), and (h) to
  read as follows:
         (e)  In this section, "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.
         (f)  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. [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.
         (g)  The commission shall:
               (1)  review the type, volume, and cost of ancillary
  services to determine whether those services will continue to meet
  the needs of the electricity market in the ERCOT power region; and
               (2)  evaluate whether additional services are needed
  for reliability in the ERCOT power region while providing adequate
  incentives for dispatchable generation.
         (h)  The commission shall require the independent
  organization certified under Section 39.151 for the ERCOT power
  region to modify the design, procurement, and cost allocation of
  ancillary services for the region in a manner consistent with
  cost-causation principles and on a nondiscriminatory basis.
         SECTION 15.  Subchapter B, Chapter 35, Utilities Code, is
  amended by adding Section 35.037 to read as follows:
         Sec. 35.037.  FACILITATING CERTAIN INTERCOMPANY LANDFILL
  GAS-TO-ELECTRICITY USE. (a) This section only applies in a county
  with a population of more than one million in which a national
  wildlife refuge is wholly or partly located.
         (b)  Notwithstanding any other provision of this title, and
  for the purposes of reducing environmental emissions, putting to a
  beneficial purpose landfill gas as an electric generation fuel that
  would otherwise be flared, enabling the operation of electric
  generation to a greater degree, and enhancing the reliability and
  resilience of electric service in this state, a person who is not an
  electric utility and who owns and operates equipment or facilities
  to produce, generate, transmit, distribute, store, sell, or furnish
  electricity produced by the use of landfill methane gas may:
               (1)  use the equipment or facilities to provide
  electricity and electric service to the person and to the person's
  affiliates without being considered to be an electric utility, a
  public utility, a retail electric provider, a power marketer, or a
  person providing aggregation;
               (2)  interconnect the equipment or facilities in a
  timely manner and on reasonable and nondiscriminatory terms and
  conditions with any electric utility, municipally owned utility, or
  electric cooperative that has a retail service area for any portion
  of the equipment or facilities; and
               (3)  receive backup, supplemental, or other electric
  service for any of the person's or the person's affiliates'
  facilities that consume electricity from any electric utility,
  municipally owned utility, or electric cooperative that has a
  retail service area for any portion of the person's facilities or
  equipment that are interconnected regardless of whether those
  facilities are in the same retail service area as the location of
  the interconnection point.
         (c)  Backup, supplemental, or other electric service
  provided under this section through an interconnection for a
  person's electricity-consuming facilities that are connected to
  the person's interconnected equipment or facilities does not
  constitute a service area encroachment or other violation of law by
  the electric utility, municipally owned utility, or electric
  cooperative supplying the backup, supplemental, or other electric
  service.
         SECTION 16.  Subchapter D, Chapter 38, Utilities Code, is
  amended by adding Sections 38.074, 38.075, 38.076, and 38.077 to
  read as follows:
         Sec. 38.074.  CRITICAL NATURAL GAS FACILITIES AND ENTITIES.
  (a) The commission shall collaborate with the Railroad Commission
  of Texas to adopt rules to establish a process to designate certain
  natural gas facilities and entities associated with providing
  natural gas in this state as critical during energy emergencies.
         (b)  The rules must:
               (1)  ensure that the independent organization
  certified under Section 39.151 for the ERCOT power region and each
  electric utility, municipally owned utility, and electric
  cooperative providing service in the ERCOT power region is provided
  with the information required by Section 81.073, Natural Resources
  Code;
               (2)  provide for prioritizing for load-shed purposes
  during an energy emergency the facilities and entities designated
  under Subsection (a); and 
               (3)  provide discretion to an electric utility,
  municipally owned utility, or electric cooperative providing
  service in the ERCOT power region to prioritize power delivery and
  power restoration among the facilities and entities designated
  under Subsection (a) on the utility's or cooperative's systems, as
  circumstances require.
         Sec. 38.075.  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.  
  In adopting the rules, the commission shall take into consideration
  weather predictions produced by the office of the state
  climatologist.
         (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.
         (e)  Notwithstanding any other provision of this subtitle,
  the commission shall allow a transmission and distribution utility
  to design and operate a load management program for nonresidential
  customers to be used where the independent organization certified
  under Section 39.151 for the ERCOT power region has declared a Level
  2 Emergency or a higher level of emergency or has otherwise directed
  the transmission and distribution utility to shed load. A
  transmission and distribution utility implementing a load
  management program under this subsection shall be permitted to
  recover the reasonable and necessary costs of the load management
  program under Chapter 36. A load management program operated under
  this subsection is not considered a competitive service.
         Sec. 38.076.  INVOLUNTARY AND VOLUNTARY 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 the 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. 38.077.  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 17.  Chapter 38, Utilities Code, is amended by
  adding Subchapter F to read as follows:
  SUBCHAPTER F. TEXAS ELECTRICITY SUPPLY CHAIN SECURITY AND MAPPING
  COMMITTEE
         Sec. 38.201.  TEXAS ELECTRICITY SUPPLY CHAIN SECURITY AND
  MAPPING COMMITTEE. (a) In this subchapter, "electricity supply
  chain" means:
               (1)  facilities and methods used for producing,
  treating, processing, pressurizing, storing, or transporting
  natural gas for delivery to electric generation facilities; and
               (2)  critical infrastructure necessary to maintain
  electricity service.
         (b)  The Texas Electricity Supply Chain Security and Mapping
  Committee is established to:
               (1)  map this state's electricity supply chain;
               (2)  identify critical infrastructure sources in the
  electricity supply chain;
               (3)  establish best practices to prepare facilities
  that provide electric service and natural gas service in the
  electricity supply chain to maintain service in an extreme weather
  event and recommend oversight and compliance standards for those
  facilities; and
               (4)  designate priority service needs to prepare for,
  respond to, and recover from an extreme weather event.
         (c)  The committee is composed of:
               (1)  the executive director of the commission; 
               (2)  the executive director of the Railroad Commission
  of Texas;
               (3)  the president and the chief executive officer of
  the independent organization certified under Section 39.151 for the
  ERCOT power region; and
               (4)  the chief of the Texas Division of Emergency
  Management.
         (d)  Each member of the committee may designate a personal
  representative from the member's organization to represent the
  member on the committee. A member is responsible for the acts and
  omissions of the designee related to the designee's representation
  on the committee.
         (e)  The executive director of the commission serves as the
  chair of the committee. The executive director of the Railroad
  Commission of Texas serves as vice chair of the committee.
         Sec. 38.202.  ADMINISTRATION. (a) The committee shall meet
  at least once each calendar quarter at a time determined by the
  committee and at the call of the chair.
         (b)  A member who is an ex officio member from a state agency
  shall be reimbursed for actual and necessary expenses in carrying
  out committee responsibilities from money appropriated for that
  purpose in the agency's budget. Other members of the committee may
  receive reimbursement for actual and necessary expenses in carrying
  out committee responsibilities from money appropriated for that
  purpose. 
         (c)  The commission, the Railroad Commission of Texas, and
  the Texas Division of Emergency Management shall provide staff as
  necessary to assist the committee in carrying out the committee's
  duties and responsibilities.
         (d)  The independent organization certified under Section
  39.151 for the ERCOT power region shall provide staff as necessary
  to assist the committee in carrying out the committee's duties and
  responsibilities.
         (e)  Except as otherwise provided by this subchapter, the
  committee is not subject to Chapters 2001, 551, and 552, Government
  Code.
         (f)  Information written, produced, collected, assembled, or
  maintained under law or in connection with the transaction of
  official business by the committee or an officer or employee of the
  committee is subject to Section 552.008, Government Code.  This
  subsection does not apply to the physical locations of critical
  facilities, maps created under this subchapter, or proprietary
  information created or gathered during the mapping process.
         Sec. 38.203.  POWERS AND DUTIES OF COMMITTEE. (a) The
  committee shall:
               (1)  map the state's electricity supply chain in order
  to designate priority electricity service needs during extreme
  weather events;
               (2)  identify and designate the sources in the
  electricity supply chain necessary to operate critical
  infrastructure, as defined by Section 421.001, Government Code;
               (3)  develop a communication system between critical
  infrastructure sources, the commission, and the independent
  organization certified under Section 39.151 for the ERCOT power
  region to ensure that electricity and natural gas supplies in the
  electricity supply chain are prioritized to those sources during an
  extreme weather event; and
               (4)  establish best practices to prepare facilities
  that provide electric service and natural gas service in the
  electricity supply chain to maintain service in an extreme weather
  event and recommend oversight and compliance standards for those
  facilities.
         (b)  The committee shall update the electricity supply chain
  map at least once each year.
         (c)  The commission shall:
               (1)  create and maintain a database identifying
  critical infrastructure sources with priority electricity needs to
  be used during an extreme weather event; and
               (2)  update the database at least once each year.
         (d)  The information maintained in the database is
  confidential under Section 418.181, Government Code, and not
  subject to disclosure under Chapter 552, Government Code.
         (e)  The committee shall provide the Texas Energy
  Reliability Council with access to the electricity supply chain
  map.
         Sec. 38.204.  MAPPING REPORT. (a) Not later than January 1,
  2022, the committee shall submit a report to the governor, the
  lieutenant governor, the speaker of the house of representatives,
  the legislature, and the Texas Energy Reliability Council on the
  activities and findings of the committee. The report must:
               (1)  provide an overview of the committee's findings
  regarding mapping the electricity supply chain and identifying
  sources necessary to operate critical infrastructure;
               (2)  recommend a clear and thorough communication
  system for the commission, the Railroad Commission of Texas, the
  Texas Division of Emergency Management, and the independent
  organization certified under Section 39.151 for the ERCOT power
  region and critical infrastructure sources in this state to ensure
  that electricity supply is prioritized to those sources during
  extreme weather events; and
               (3)  include a list of the established best practices
  and recommended oversight and compliance standards adopted under
  Section 38.203(a)(4).
         (b)  The report is public information except for portions
  considered confidential under Chapter 552, Government Code, or
  other state or federal law.
         SECTION 18.  Subchapter D, Chapter 39, Utilities Code, is
  amended by adding Sections 39.159 and 39.160 to read as follows:
         Sec. 39.159.  DISPATCHABLE GENERATION. (a)  For the
  purposes of this section, a generation facility is considered to be
  non-dispatchable if the facility's output is controlled primarily
  by forces outside of human control.
         (b)  The commission shall ensure that the independent
  organization certified under Section 39.151 for the ERCOT power
  region:
               (1)  establishes requirements to meet the reliability
  needs of the power region;
               (2)  periodically, but at least annually, determines
  the quantity and characteristics of ancillary or reliability
  services necessary to ensure appropriate reliability during
  extreme heat and extreme cold weather conditions and during times
  of low non-dispatchable power production in the power region;
               (3)  procures ancillary or reliability services on a
  competitive basis to ensure appropriate reliability during extreme
  heat and extreme cold weather conditions and during times of low
  non-dispatchable power production in the power region;
               (4)  develops appropriate qualification and
  performance requirements for providing services under Subdivision
  (3), including appropriate penalties for failure to provide the
  services; and
               (5)  sizes the services procured under Subdivision (3)
  to prevent prolonged rotating outages due to net load variability
  in high demand and low supply scenarios.
         (c)  The commission shall ensure that:
               (1)  resources that provide services under Subsection
  (b) are dispatchable and able to meet continuous operating
  requirements for the season in which the service is procured;
               (2)  winter resource capability qualifications for a
  service described by Subsection (b) include on-site fuel storage,
  dual fuel capability, or fuel supply arrangements to ensure winter
  performance for several days; and
               (3)  summer resource capability qualifications for a
  service described by Subsection (b) include facilities or
  procedures to ensure operation under drought conditions.
         Sec. 39.160.  WHOLESALE PRICING PROCEDURES. (a) The
  commission by rule shall establish an emergency pricing program for
  the wholesale electric market.
         (b)  The emergency pricing program must take effect if the
  high system-wide offer cap has been in effect for 12 hours in a
  24-hour period after initially reaching the high system-wide offer
  cap. The commission by rule shall determine the criteria for the
  emergency pricing program to cease.
         (c)  The emergency pricing program may not allow an emergency
  pricing program cap to exceed any nonemergency high system-wide
  offer cap.
         (d)  The commission by rule shall establish an ancillary
  services cap to be in effect during the period an emergency pricing
  program is in effect.
         (e)  Any wholesale pricing procedure that has a low
  system-wide offer cap may not allow the low system-wide offer cap to
  exceed the high system-wide offer cap.
         (f)  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.
         (g)  The emergency pricing program must allow generators to
  be reimbursed for reasonable, verifiable operating costs that
  exceed the emergency cap.
         SECTION 19.  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 20.  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 21.  Section 121.2015, Utilities Code, is amended by
  amending Subsection (a) and adding Subsections (a-1), (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 a gas pipeline facility operator must
  implement to prepare the gas pipeline facility to maintain service
  quality and reliability during extreme weather conditions if the
  gas pipeline facility:
                     (A)  directly serves a natural gas electric
  generation facility operating solely to provide power to the
  electric grid for the ERCOT power region or for the ERCOT  power
  region and an adjacent power region; and
                     (B)  is included on the electricity supply chain
  map created under Section 38.203.
         (a-1)  In adopting rules under Subsection (a)(3), the
  railroad commission shall take into consideration weather
  predictions produced by the office of the state climatologist.
         (c-1)  The railroad commission shall:
               (1)  inspect gas pipeline facilities described by
  Subsection (a)(3) for compliance with rules adopted under
  Subsection (a)(3);
               (2)  provide the owner of a facility described by
  Subsection (a)(3) 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 described by Subsection (a)(3) that
  experiences repeated or major weather-related forced interruptions
  of service to:
               (1)  contract with a person who is not an employee of
  the operator 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
  pipeline facility described by Subsection (a)(3) 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 this subchapter.
         SECTION 22.  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 23.  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 24.  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 25.  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 facilities that produce, treat, process,
  pressurize, store, or transport natural gas and are included on the
  electricity supply chain map created under Section 38.203 and
  prepare a weather emergency preparedness report on weatherization
  preparedness of those facilities. 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
  electricity supply chain, as mapped under Section 38.203, 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 for the electricity supply chain, as mapped
  under Section 38.203.
         (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 26.  Subchapter E, Chapter 13, Water Code, is
  amended by adding Section 13.1394 to read as follows:
         Sec. 13.1394.  STANDARDS OF EMERGENCY OPERATIONS. (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:
                     (A)  furnishes water service to more than one
  customer; and
                     (B)  is not an affected utility under Section
  13.1395.
               (2)  "Emergency operations" means the operation of a
  water system during an extended power outage that impacts the
  operating affected utility.
               (3)  "Extended power outage" means a power outage
  lasting for more than 24 hours.
         (b)  An affected utility shall:
               (1)  ensure the emergency operation of its water system
  during an extended power outage at a minimum water pressure of 20
  pounds per square inch, or at a water pressure level approved by the
  commission, as soon as safe and practicable following the
  occurrence of a natural disaster; and
               (2)  adopt and submit to the commission for its
  approval:
                     (A)  an emergency preparedness plan that
  demonstrates the utility's ability to provide the emergency
  operations described by Subdivision (1); and
                     (B)  a timeline for implementing the plan
  described by Paragraph (A).
         (c)  The commission shall review an emergency preparedness
  plan submitted under Subsection (b). If the commission determines
  that the plan is not acceptable, the commission shall recommend
  changes to the plan. The commission must make its recommendations
  on or before the 90th day after the commission receives the plan.
  In accordance with commission rules, an emergency preparedness plan
  for a provider of potable water shall provide for one or more of the
  following:
               (1)  the maintenance of automatically starting
  auxiliary generators;
               (2)  the sharing of auxiliary generator capacity with
  one or more affected utilities, including through participation in
  a statewide mutual aid program;
               (3)  the negotiation of leasing and contracting
  agreements, including emergency mutual aid agreements with other
  retail public utilities, exempt utilities, or providers or
  conveyors of potable or raw water service, if the agreements
  provide for coordination with the division of emergency management
  in the governor's office;
               (4)  the use of portable generators capable of serving
  multiple facilities equipped with quick-connect systems;
               (5)  the use of on-site electrical generation or
  distributed generation facilities;
               (6)  hardening the electric transmission and
  distribution system serving the water system;
               (7)  for existing facilities, the maintenance of direct
  engine or right angle drives;
               (8)  designation of the water system as a critical load
  facility or redundant, isolated, or dedicated electrical feeds;
               (9)  water storage capabilities;
               (10)  water supplies delivered from outside the service
  area of the affected utility;
               (11)  the ability to provide water through artesian
  flows;
               (12)  redundant interconnectivity between pressure
  zones;
               (13)  emergency water demand rules to maintain
  emergency operations; or
               (14)  any other alternative determined by the
  commission to be acceptable.
         (d)  Each affected utility that supplies, provides, or
  conveys raw surface water shall include in its emergency
  preparedness plan under Subsection (b) provisions for
  demonstrating the capability of each raw water intake pump station,
  pump station, and pressure facility to provide raw water service to
  its wholesale customers during emergencies. This subsection does
  not apply to raw water services that are unnecessary or otherwise
  subject to interruption or curtailment during emergencies under a
  contract.
         (e)  The commission shall adopt rules to implement this
  section as an alternative to any rule requiring elevated storage.
         (f)  The commission shall provide an affected utility with
  access to the commission's financial, managerial, and technical
  contractors to assist the utility in complying with the applicable
  emergency preparedness plan submission deadline.
         (g)  The commission by rule shall create an emergency
  preparedness plan template for use by an affected utility when
  submitting a plan under this section. The emergency preparedness
  plan template shall contain:
               (1)  a list and explanation of the preparations an
  affected utility may make under Subsection (c) for the commission
  to approve the utility's emergency preparedness plan; and
               (2)  a list of all commission rules and standards
  pertaining to emergency preparedness plans.
         (h)  An emergency generator used as part of an approved
  emergency preparedness plan under Subsection (c) must be operated
  and maintained according to the manufacturer's specifications.
         (i)  The commission shall inspect each utility to ensure that
  the utility complies with the approved plan.
         (j)  The commission shall consider whether compliance with
  this section will cause a significant financial burden on customers
  of an affected utility when making recommended changes under
  Subsection (c).
         (k)  An affected utility may adopt and enforce limitations on
  water use while the utility is providing emergency operations.
         (l)  Except as specifically required by this section,
  information provided by an affected utility under this section is
  confidential and is not subject to disclosure under Chapter 552,
  Government Code.
         (m)  The commission shall coordinate with the utility
  commission in the administration of this section.
         SECTION 27.  The heading to Section 13.1395, Water Code, is
  amended to read as follows:
         Sec. 13.1395.  STANDARDS OF EMERGENCY OPERATIONS IN CERTAIN
  COUNTIES.
         SECTION 28.  Section 13.1395(d), Water Code, is amended to
  read as follows:
         (d)  This subsection does not apply to raw water services
  that are unnecessary or otherwise subject to interruption or
  curtailment during emergencies under a contract. Each affected
  utility that supplies, provides, or conveys surface water shall
  include in its emergency preparedness plan under Subsection (b)
  provisions:
               (1)  for the actual installation and maintenance of
  automatically starting auxiliary generators or distributive
  generation facilities for each raw water intake pump station, water
  treatment plant, pump station, and pressure facility necessary to
  provide water to its wholesale customers during emergencies; or
               (2)  that demonstrate the capability of each raw water
  intake pump station, water treatment plant, pump station, and
  pressure facility to provide water to its wholesale customers
  during emergencies through alternative means acceptable to the
  commission.
         SECTION 29.  Section 13.1396, Water Code, is amended by
  adding Subsection (a-1) to read as follows:
         (a-1)  This section applies only to an affected utility, as
  defined by Section 13.1394 or 13.1395.
         SECTION 30.  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 the previous day's highest
  temperature did not exceed 28 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.
         (b)  A retail public utility that is required to possess a
  certificate of public convenience and necessity or a district or
  affected county that furnishes retail water or sewer utility
  service shall not impose late fees or disconnect service for
  nonpayment of bills that are due during an extreme weather
  emergency until after the emergency is over and shall work with
  customers that request to establish a payment schedule for unpaid
  bills that are due during the extreme weather emergency.
         SECTION 31.  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
  $50,000 for each violation.
         (d)  The utility 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 32.  Section 13.1396(a)(1), Water Code, is repealed.
         SECTION 33.  (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) of this subsection and using the
  methods described by Subdivision (2) of this subsection; 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 34.  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 35.  The Public Utility Commission of Texas shall
  complete the first review required by Section 39.160(f), Utilities
  Code, as added by this Act, not later than December 31, 2021.
         SECTION 36.  (a) Not later than November 1, 2021, each
  affected utility, as defined by Section 13.1394, Water Code, as
  added 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 13.1394, Water
  Code, as added by this Act.
         (c)  Not later than July 1, 2022, or upon final approval by
  the commission, each affected utility shall implement the emergency
  preparedness plan approved by the Texas Commission on Environmental
  Quality under Section 13.1394, Water Code, as added by this Act.
         (d)  An affected utility, as defined by Section 13.1394,
  Water Code, as added by this Act, 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 37.  The Texas Electricity Supply Chain Security and
  Mapping Committee shall produce the map required under Section
  38.203, Utilities Code, as added by this Act, not later than
  September 1, 2022.
         SECTION 38.  Not later than six months after the date the
  Texas Electricity Supply Chain Security and Mapping Committee
  produces the map required under Section 38.203, Utilities 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 39.  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 38.075, Utilities Code, as added by this
  Act.
         SECTION 40.  It is the intent of the legislature that this
  Act not restrict or amend the sole jurisdiction of the Railroad
  Commission of Texas to establish rules or requirements relating to
  curtailment orders for facilities and entities in the commission's
  jurisdiction under the Natural Resources Code or the Utilities
  Code.
         SECTION 41.  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.
 
 
 
 
 
 
  ______________________________ ______________________________
     President of the Senate Speaker of the House     
 
         I hereby certify that S.B. No. 3 passed the Senate on
  March 29, 2021, by the following vote:  Yeas 31, Nays 0;
  May 27, 2021, Senate refused to concur in House amendments and
  requested appointment of Conference Committee; May 28, 2021, House
  granted request of the Senate; May 30, 2021, Senate adopted
  Conference Committee Report by the following vote:  Yeas 31,
  Nays 0.
 
 
  ______________________________
  Secretary of the Senate    
 
         I hereby certify that S.B. No. 3 passed the House, with
  amendments, on May 24, 2021, by the following vote:  Yeas 142,
  Nays 1, one present not voting; May 28, 2021, House granted request
  of the Senate for appointment of Conference Committee;
  May 30, 2021, House adopted Conference Committee Report by the
  following vote:  Yeas 142, Nays 0, two present not voting.
 
 
  ______________________________
  Chief Clerk of the House   
 
 
 
  Approved:
 
  ______________________________ 
             Date
 
 
  ______________________________ 
            Governor