87R26352 JXC-D
By: Schwertner, et al. S.B. No. 3
(Paddie)
Substitute the following for S.B. No. 3: No.
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. 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
DURING AN ENERGY EMERGENCY. (a) The commission shall work with the
Public Utility Commission of Texas to designate certain natural gas
facilities and entities associated with providing natural gas in
this state as critical during an energy emergency.
(b) At a minimum, the commission's rules must:
(1) establish eligibility and designation
requirements for 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 designation and
critical natural gas supply information, as defined by the
commission, to the entities described by Section 38.077(c)(1),
Utilities Code;
(2) 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; and
(3) consider essential operational elements when
defining critical customer designations and critical natural gas
supply information, including natural gas production, processing,
and transportation and related produced water handling and disposal
facilities and the delivery of natural gas to generators.
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) 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
included on the electricity supply chain map created under Section
38.203, Utilities Code.
(c) The commission by rule shall require a gas supply chain
facility operator to implement measures to prepare to operate
during a weather emergency.
(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 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 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 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 8. 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 38.075;
(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 38.075; and
(4) reducing electricity use at times when involuntary
load shedding events may be implemented.
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, critical load industrial
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, a critical load
industrial 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, critical load industrial
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, a critical load
industrial 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, 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;
(2) evaluate whether additional voluntary seasonal,
month-ahead, or other forward products would enhance reliability in
the ERCOT power region while providing adequate incentives for
dispatchable generation; and
(3) ensure that all generation resources, energy
storage resources, and loads in the ERCOT power region are allowed
to provide ancillary services on a voluntary basis and that the
ancillary services are procured and costs recovered on an equitable
and nondiscriminatory basis.
(h) The commission may 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 14. 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. 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.
(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 during extreme weather where the independent
organization certified under Section 39.151 for the ERCOT power
region has declared an emergency. 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. 38.075. 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. 38.076. 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.
Sec. 38.077. CRITICAL NATURAL GAS FACILITIES AND ENTITIES
DURING AN ENERGY EMERGENCY. (a) The commission shall work with the
Railroad Commission of Texas and 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 an
energy emergency.
(b) The commission by rule shall require each electric
cooperative, municipally owned utility, and transmission and
distribution utility to exclude any circuits that provide power to
an entity or facility designated under Section 81.073, Natural
Resources Code, from participation in the cooperative's or
utility's attempt to shed load in response to a rolling blackout
initiated by an independent organization certified under Section
39.151 or another reliability council or power pool in which the
cooperative or utility operates.
(c) At a minimum, the commission's rules must:
(1) ensure that electric cooperatives, municipally
owned utilities, transmission and distribution utilities, and the
independent organization certified under Section 39.151 for the
ERCOT power region are provided with the information required by
Section 81.073, Natural Resources Code;
(2) provide for a prioritization for load-shed
purposes of the entities and facilities designated under Subsection
(a) during an energy emergency; and
(3) provide discretion to electric cooperatives,
municipally owned utilities, and transmission and distribution
utilities to prioritize power delivery and power restoration among
the customers on their respective systems, as circumstances
require.
SECTION 15. 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 subject to Chapters 2001, 551, and 552, Government
Code.
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.
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,
and the legislature 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 16. Subchapter C, Chapter 39, Utilities Code, is
amended by adding Section 39.110 to read as follows:
Sec. 39.110. WHOLESALE INDEXED PRODUCTS. (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) Except as provided by Subsection (c), a retail electric
provider may not offer a wholesale indexed product to a residential
or small commercial customer.
(c) A retail electric provider may enroll a residential or
small commercial customer in a wholesale indexed product only if:
(1) the enrollment complies with any other applicable
law or commission rule;
(2) the product caps the monthly average all-in price
per kilowatt hour of electricity charged to the customer at a
maximum of 200 percent more than the monthly average price of
electricity in this state during the same month for the prior year,
as determined by monthly electric power industry reports required
by the United States Energy Information Administration;
(3) the retail electric provider provides to each
potential customer before enrollment notice of the highest monthly
average price for the next six months for the product;
(4) the retail electric provider provides to each
customer in each billing statement notice of the highest monthly
average price for the next six months; and
(5) for service starting at the beginning of the next
month, the retail electric provider allows the customer to switch
without charge or penalty at the beginning of the next month to a
fixed rate product offered by the provider to other residential and
small commercial customers.
(d) This section does not apply to accounts of a customer on
the same property or contiguous properties in which one or more of
the accounts has a peak demand of at least 250 kilowatts.
SECTION 17. Subchapter D, Chapter 39, Utilities Code, is
amended by adding Section 39.159 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 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.
SECTION 18. 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 19. 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 20. 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 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 directly serves a natural gas electric
generation facility operating solely to provide power to the
electric grid for the ERCOT power region and is included on the
electricity supply chain map created under Section 38.203.
(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 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 21. 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 22. 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 23. 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 24. 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 25. Chapter 186, Utilities Code, is amended by
adding Subchapter F to read as follows:
SUBCHAPTER F. TEXAS ENERGY DISASTER RELIABILITY COUNCIL
Sec. 186.101. DEFINITIONS. In this subchapter:
(1) "Council" means the Texas Energy Disaster
Reliability Council established under this subchapter.
(2) "Disaster" means:
(A) a disaster defined by Section 418.004,
Government Code; or
(B) an extended power outage.
(3) "Division" means the Texas Division of Emergency
Management.
(4) "Extended power outage" means an interruption in
electric service lasting more than 24 hours.
(5) "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.
(6) "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.
(7) "Railroad commission" means the Railroad
Commission of Texas.
(8) "Utility commission" means the Public Utility
Commission of Texas.
Sec. 186.102. COUNCIL. The Texas Energy Disaster
Reliability Council is established to:
(1) prevent extended natural gas supply failures or
power outages caused by disasters;
(2) implement procedures to manage emergencies caused
by disasters;
(3) maintain records of critical infrastructure
facilities to maintain service in a disaster;
(4) coordinate the delivery of fuel to serve human
needs natural gas customers and providers of electric generation
service in a disaster;
(5) monitor supply chains for the electric grid in
this state to minimize service disruptions; and
(6) study and make recommendations on methods to
maintain the reliability of the electric grid in this state during a
disaster, including methods for maintaining the reliability of
natural gas supply networks.
Sec. 186.103. MEMBERS. (a) The council consists of:
(1) the presiding officer of the utility commission;
(2) the executive director of the utility commission;
(3) the chairman of the railroad commission;
(4) the executive director of the railroad commission;
(5) the chief executive officer of the independent
organization certified under Section 39.151 for the ERCOT power
region; and
(6) the chief of the division.
(b) The chief of the division shall serve as the presiding
officer of the council.
(c) The council shall hold meetings during the weeks of
March 1 and September 1 of each year.
(d) In addition to the meetings required by Subsection (c),
the council shall convene as soon as reasonably possible during or
in anticipation of a disaster to address an actual or potential
extended power outage caused by a disaster in order to coordinate
fuel supplies and minimize the duration of the outage.
(e) In carrying out its functions, the council may consult
and coordinate with:
(1) the United States Department of Energy;
(2) the United States Department of Homeland Security;
(3) the North American Electric Reliability
Corporation;
(4) the Texas Reliability Entity;
(5) federal and state agencies;
(6) local governmental officials, including mayors,
county judges, and emergency management officials;
(7) members of the electric industry;
(8) members of the natural gas industry; and
(9) grid security experts.
(f) 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 for the ERCOT power region or federal law.
(g) Except as provided by Subsection (g-1), the meetings of
the council and information obtained or created by the council are
not subject to the requirements of Chapter 551 or 552, Government
Code.
(g-1) 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, Government Code, in the same
manner as public information.
(h) Chapter 2110, Government Code, does not apply to the
council.
Sec. 186.104. 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
electric supply chain in this state.
(b) The report must include recommendations on methods to
strengthen the electric supply chain in this state and to decrease
the frequency of extended power outages caused by a disaster in this
state.
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 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; or
(11) 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 may grant a waiver of the requirements of
this section to an affected utility if the commission determines
that compliance with this section will cause a significant
financial burden on customers of the affected utility.
(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 13.1396, 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 29. 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 10 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 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 30. Section 13.414, Water Code, is amended by
adding Subsection (d) to read as follows:
(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.
SECTION 31. Section 13.1396(a)(1), Water Code, is repealed.
SECTION 32. (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 33. 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 34. (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, 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 35. 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 36. 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 37. 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.