PART 2. PUBLIC UTILITY COMMISSION OF TEXAS
CHAPTER 22. PROCEDURAL RULES
The Public Utility Commission of Texas (commission) proposes amendments to §22.51 relating to Notice for Public Utility Regulatory Act, Chapter 36, Subchapters C - E; Chapter 51, §51.009; and Chapter 53, Subchapters C - E, Proceedings; §22.52, relating to Notice in Licensing Proceedings; and §22.142 relating to Limitations on Discovery and Protective Orders. The proposed amendments are administrative in nature to update contact resources used by individuals with hearing or speech difficulties and also make other minor and conforming amendments.
Growth Impact Statement
The agency provides the following governmental growth impact statement for the proposed rules, as required by Texas Government Code §2001.0221. The agency has determined that for each year of the first five years that the proposed rules are in effect, the following statements will apply:
(1) the proposed rules will not create a government program and will not eliminate a government program;
(2) implementation of the proposed rules will not require the creation of new employee positions and will not require the elimination of existing employee positions;
(3) implementation of the proposed rules will not require an increase and will not require a decrease in future legislative appropriations to the agency;
(4) the proposed rules will not require an increase and will not require a decrease in fees paid to the agency;
(5) the proposed rules will not, in effect, create a new regulation, because it is replacing a similar regulation;
(6) the proposed rules will repeal an existing regulation, but it will replace that regulation with a similar regulation;
(7) the same number of individuals will be subject to the proposed rules' applicability as were subject to the applicability of the rule it is being proposed to replace; and
(8) the proposed rules will not affect this state's economy.
Takings Impact Analysis
The commission has determined that the proposed rules will not be a taking of private property as defined in chapter 2007 of the Texas Government Code.
Public Benefits
Iliana De La Fuente, Attorney, Rules and Projects Division, has determined that for each year of the first five-year period the proposed sections are in effect there will be no fiscal implications for state or local government as a result of enforcing or administering the section.
Iliana De La Fuente has determined that for each year of the first five years the proposed sections are in effect the public benefit anticipated as a result of enforcing the section will be to provide individuals with hearing or speech difficulties with accurate agency contact resources. There will be no adverse economic effect on small businesses, micro-businesses or rural communities as a result of enforcing these sections. There is no anticipated economic cost to persons who are required to comply with these sections as proposed. Any economic costs would vary from person to person and are difficult to ascertain. However, it is believed that the benefits accruing from implementation of the proposed sections will outweigh these costs.
Iliana De La Fuente has also determined that for each year of the first five years the proposed sections are in effect there should be no effect on a local economy, and therefore no local employment impact statement is required under Administrative Procedure Act §2001.022.
Costs to Regulated Persons
Texas Government Code §2001.0045(b) does not apply to this rulemaking because the commission is expressly excluded under §2001.0045(c)(7).
Public Hearing
The commission staff will conduct a public hearing on this rulemaking if requested in accordance with Texas Government Code §2001.029. The request for a public hearing must be received by May 26, 2023. If a request for public hearing is received, commission staff will file in this project a notice of hearing.
Public Comments
Interested persons may file comments electronically through the interchange on the commission's website. Comments must be filed by May 26, 2023. Comments should be organized in a manner consistent with the organization of the proposed rules. The commission invites specific comments regarding the costs associated with, and benefits that will be gained by, implementation of the proposed rules. All comments should refer to Project Number 54844, Chapter 22.
SUBCHAPTER D. NOTICE
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act §14.002 and §14.052, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction, including rules of practice and procedure.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002 and §14.052.
§22.51.Notice for Public Utility Regulatory Act, Chapter 36, Subchapters C - E; Chapter 51, §51.009; and Chapter 53, Subchapters C - E, Proceedings.
(a) Notice in a proceeding seeking a rate increase.
In proceedings under PURA, Chapter 36, Subchapters C and E; Chapter
51, §51.009; or Chapter 53, Subchapters C and E involving the
commission's original jurisdiction over a utility's proposed increase
in rates, the applicant must [shall] give notice
in the following manner:
(1) Publication of notice. The applicant must [shall] publish notice of its statement of intent to change rates
in a conspicuous form and place at least once a week for four consecutive
weeks prior to the effective date of the proposed rate change, in
a newspaper having general circulation in each county containing territory
affected by the proposed rate change. The published notice must [shall] contain the following information:
(A) - (E) (No change.)
(F) the following language: "Persons who wish to intervene
in or comment upon these proceedings should notify the Public Utility
Commission of Texas (commission) as soon as possible, as an intervention
deadline will be imposed. A request to intervene or for further information
should be mailed to the Public Utility Commission of Texas, P.O. Box
13326, Austin, Texas 78711-3326. Further information may also be obtained
by calling the Public Utility Commission at (512) 936-7120 or (888)
782-8477. Hearing- and speech-impaired individuals [with text
telephones (TTY)] may contact the commission through Relay
Texas at 1-800-735-2989 [at (512) 936-7136]. The
deadline for intervention in the proceeding is 45 days after the date
the application was filed with the commission."
(2) Notice by mail. The applicant must [shall
] mail notice of its statement of intent to change rates to
all of the applicant's affected customers. This notice may be mailed
separately or may be mailed with customer billings. At the top of
this notice, the following language must [shall]
be printed in prominent lettering: "Notice of Rate Change Request."
The notice must meet the requirements of paragraph (1) of this subsection.
Whenever possible, the established intervention deadline must [shall] be included in the notice.
(3) Notice to municipalities. The applicant must [shall] mail or deliver a copy of the statement of intent to
the appropriate officer of each affected municipality at least 35
days prior to the effective date of the proposed rate change.
(b) Notice in PURA, Chapter 36, Subchapters C and E;
Chapter 51, §51.009; or Chapter 53, Subchapters C and E proceeding
seeking a rate decrease. In proceedings initiated pursuant to PURA,
Chapter 36, Subchapters C and E; Chapter 51, §51.009; or Chapter
53, Subchapters C and E in which a rate reduction that does not involve
a rate increase for any customer is sought, the applicant must [shall] give notice in the following manner:
(1) (No change.)
(2) Notice by mail to affected customers. The applicant must [shall] mail notice of the proposed rate decrease
to all of the applicant's affected customers. This notice may be mailed
separately or may be mailed with customer billings. At the top of
this notice, the following language must [shall]
be printed in prominent lettering: "Notice of Rate Decrease Request."
The notice must [shall] contain the following information:
(A) - (E) (No change.)
(F) the following language: "Persons who wish to intervene
in or comment upon these proceedings should notify the Public Utility
Commission of Texas (commission) as soon as possible, as an intervention
deadline will be imposed. A request to intervene or for further information
should be mailed to the Public Utility Commission of Texas, P.O. Box
13326, Austin, Texas 78711-3326. Further information may also be obtained
by calling the Public Utility Commission at (512) 936-7120 or (888)
782-8477. Hearing- and speech-impaired individuals [with text
telephones (TTY)] may contact the commission through Relay
Texas at 1-800-735-2989 [at (512) 936-7136]. The
deadline for intervention in the proceeding is 45 days after the date
the application was filed with the commission."
(3) Notice to municipalities. The applicant must [shall] mail or deliver a copy of the statement of intent to
the appropriate officer of each affected municipality at least 35
days prior to the effective date of the proposed rate decrease.
(c) (No change.)
(d) Affidavits regarding notice. The applicant must [shall] submit affidavits attesting to the provision of the notice
required or ordered pursuant to this section within a reasonable time
and by such date as may be established by the presiding officer.
(1) Publisher's affidavits. Proof of publication of
notice must [shall] be made in the form of a
publisher's affidavit which must [shall] specify
the newspaper(s) in which the notice was published; the county or
counties in which the newspaper(s) is or are of general circulation;
and the dates upon which the notice was published.
(2) Affidavit for notice to affected customers. If
notice to affected customers has been provided, an affidavit attesting
to the provision of notice to affected customers must [shall
] specify the dates of the provision of such notice; the means
by which such notice was provided; and the affected customer classes
to which such notice was provided.
(3) Affidavit for notice to municipality. An affidavit
attesting to the provision of notice to municipalities must [shall] specify the dates of the provision of notice and the
identity of the individual cities to which such notice was provided.
§22.52.Notice in Licensing Proceedings.
(a) Notice in electric licensing proceedings. In all
electric licensing proceedings except minor boundary changes, the
applicant must [shall] give notice in the following ways:
(1) Applicant must [shall] publish
notice once of the applicant's intent to secure a certificate of convenience
and necessity in a newspaper having general circulation in the county
or counties where a certificate of convenience and necessity is being
requested, no later than the week after the application is filed with
the commission. This notice must [shall] identify
the commission's docket number and the style assigned to the case
by Central Records. In electric transmission line cases, the applicant must [shall] obtain the docket number and style no
earlier than 25 days prior to making the application by filing a preliminary
pleading requesting a docket assignment. The notice must [shall] identify in general terms the type of facility if applicable,
and the estimated expense associated with the project. The notice must
[shall] describe all routes without designating
a preferred route or otherwise suggesting that a particular route
is more or less likely to be selected than one of the other routes.
(A) The notice must [shall] include
all the information required by the standard format established by
the commission for published notice in electric licensing proceedings.
The notice must [shall] state the date established
for the deadline for intervention in the proceeding (date 45 days
after the date the formal application was filed with the commission;
or date 30 days after the date the formal application was filed with
the commission for an application for certificate of convenience and
necessity filed under PURA §39.203(e)) and that a letter requesting
intervention should be received by the commission by that date.
(B) The notice must [shall] describe
in clear, precise language the geographic area for which the certificate
is being requested and the location of all alternative routes of the
proposed facility. This description must [shall]
refer to area landmarks, including but not limited to geographic landmarks,
municipal and county boundary lines, streets, roads, highways, railroad
tracks, and any other readily identifiable points of reference, unless
no such references exist for the geographic area. In addition, the
notice must [shall] include a map that identifies
all of the alternative locations of the proposed routes and all major
roads, transmission lines, and other features of significance to the
areas that are used in the utility's written notice description.
(C) The notice must [shall] state
a location where a detailed routing map may be reviewed. The map must
[shall] clearly and conspicuously illustrate the
location of the area for which the certificate is being requested
including all the alternative locations of the proposed routes, and must [shall] reflect area landmarks, including but
not limited to geographic landmarks, municipal and county boundary
lines, streets, roads, highways, railroad tracks, and any other readily
identifiable points of reference, unless no such references exist
for the geographic area.
(D) Proof of publication of notice must [shall
] be in the form of a publisher's affidavit which must [shall] specify the newspaper(s) in which the notice was published,
the county or counties in which the newspaper(s) is or are of general
circulation, the dates upon which the notice was published, and a
copy of the notice as published. Proof of publication must [shall] be submitted to the commission as soon as available.
(E) The applicant must [shall]
provide a copy of each environmental impact study and/or assessment
for the project to the Texas Parks and Wildlife Department (TPWD)
for its review within seven days of filing the application. Proof
of submission of the information to TPWD must [shall]
be provided in the form of an affidavit to the commission, which must
[shall] specify the date the information was mailed
or otherwise provided to TPWD, and must [shall]
provide a copy of the cover letter or other documentation that confirms
that the information was provided to TPWD.
(2) Applicant must [shall], upon
filing an application, also mail notice of its application to municipalities
within five miles of the requested territory or facility, neighboring
utilities providing the same utility service within five miles of
the requested territory or facility, the county government(s) of all
counties in which any portion of the proposed facility or requested
territory is located, and the Department of Defense Siting Clearinghouse.
In addition, the applicant must [shall], upon
filing the application, serve the notice on the Office of Public Utility
Counsel using a method specified in §22.74(b) of this title (relating
to Service of Pleadings and Documents). The notice must [shall] contain the information as set out in paragraph (1) of
this subsection and a map as described in paragraph (1)(C) of this
subsection. An affidavit attesting to the provision of notice to municipalities,
utilities, counties, the Department of Defense Siting Clearinghouse,
and the Office of Public Utility Counsel must [shall]
specify the dates of the provision of notice and the identity of the
individual municipalities, utilities, and counties to which such notice
was provided. Before final approval of any modification in the applicant's
proposed route(s), applicant must [shall] provide
notice as required under this paragraph to municipalities, utilities,
and counties affected by the modification which have not previously
received notice. The notice of modification must [shall]
state such entities will have 20 days to intervene.
(3) Applicant must [shall], on
the date it files an application, mail notice of its application to
the owners of land, as stated on the current county tax roll(s), who
would be directly affected by the requested certificate. For purposes
of this paragraph, land is directly affected if an easement or other
property interest would be obtained over all or any portion of it,
or if it contains a habitable structure that would be within 300 feet
of the centerline of a transmission project of 230kV or less, or within
500 feet of the centerline of a transmission project greater than 230kV.
(A) The notice must contain all information required
in paragraph (1) of this subsection and must [shall]
include all the information required by the standard notice letter
to landowners prescribed by the commission. The commission's docket
number pertaining to the application must be stated in all notices.
The notice must also include a copy of the "Landowners and Transmission
Line Cases at the PUC" brochure prescribed by the commission.
(B) The notice must include a map as described in paragraph (1)(C) of this subsection.
(C) Before final approval of any modification in the
applicant's proposed route(s), applicant must [shall]
provide notice as required under subparagraphs (A) and (B) of this
paragraph to all directly affected landowners who have not already
received such notice.
(D) Proof of notice may be established by an affidavit
affirming that the applicant sent notice by first-class mail to each
of the persons listed as an owner of directly affected land on the
current county tax roll(s). The proof of notice must [shall
] include a list of all landowners to whom notice was sent and
a statement of whether any formal contact related to the proceeding
between the utility and the landowner other than the notice has occurred.
This proof of notice must [shall] be filed with
the commission no later than 20 days after the filing of the application.
(E) Upon the filing of proof of notice as described
in subparagraph (D) of this paragraph, the lack of actual notice to
any individual landowner will not in and of itself support a finding
that the requirements of this paragraph have not been satisfied. If,
however, the utility finds that an owner of directly affected land
has not received notice, it must [shall] immediately
advise the commission by written pleading and must [shall
] provide notice to such landowner(s) by priority mail, with
delivery confirmation, in the same form described in subparagraphs
(A) and (B) of this paragraph, except that the notice must [shall] state that the person has fifteen days from the date
of delivery to intervene. The utility must [shall]
immediately file a supplemental affidavit of notice with the commission.
(4) The utility must [shall]
hold at least one public meeting prior to the filing of its licensing
application if 25 or more persons would be entitled to receive direct
mail notice of the application. Direct mail notice of the public meeting must [shall] be sent by first-class mail to each
of the persons listed on the current county tax rolls as an owner
of land within 300 feet of the centerline of a transmission project
of 230kV or less, or within 500 feet of the centerline of a transmission
project greater than 230kV. The utility must [shall]
also provide written notice to the Department of Defense Siting Clearinghouse
of the public meeting. In the notice for the public meeting, at the
public meeting, and in other communications with a potentially affected
person, the utility must [shall] not describe
routes as preferred routes or otherwise suggest that a particular
route is more or less likely to be selected than one of the other
routes. In the event that no public meeting is held, the utility must
[shall] provide written notice to the Department
of Defense Siting Clearinghouse of the planned filing of an application
prior to completion of the routing study.
(5) Failure to provide notice in accordance with this
section will [shall] be cause for day-for-day
extension of deadlines for intervention and for commission action
on the application.
(6) Upon entry of a final, appealable order by the
commission approving an application, the utility must [shall
] provide notice to all owners of land who previously received
direct notice. Proof of notice under this subsection must [shall] be provided to the commission's staff.
(A) If the owner's land is directly affected by the
approved route, the notice must [shall] consist
of a copy of the final order.
(B) If the owner's land is not directly affected by
the approved route, the notice must [shall]
consist of a brief statement that the land is no longer the subject
of a pending proceeding and will not be directly affected by the facility.
(7) All notices of an applicant's intent to secure
a certificate of convenience and necessity whether provided by publication
or direct mail must [shall] include the following
language: "All routes and route segments included in this notice are
available for selection and approval by the Public Utility Commission of Texas."
(b) Notice in telephone licensing proceedings. In all
telephone licensing proceedings, except minor boundary changes, applications
for a certificate of operating authority, or applications for a service
provider certificate of operating authority, the applicant must [shall] give notice in the following ways:
(1) Applicants must [shall] publish
in a newspaper having general circulation in the county or counties
where a certificate of convenience and necessity is being requested,
once each week for two consecutive weeks, beginning the week after
the application is filed, notice of the applicant's intent to secure
a certificate of convenience and necessity. This notice must [shall] identify in general terms the types of facilities, if
applicable, the area for which the certificate is being requested,
and the estimated expense associated with the project. Whenever possible,
the notice should state the established intervention deadline. The
notice must [shall] also include the following
statement: "Persons with questions about this project should contact
(name of utility contact) at (utility contact telephone number). Persons
who wish to intervene in the proceeding or comment upon action sought,
should contact the Public Utility Commission, P.O. Box 13326, Austin,
Texas 78711-3326, or call the Public Utility Commission at (512) 936-7120
or (888) 782-8477. Hearing- and speech-impaired individuals [with
text telephones (TTY)] may contact the commission through
Relay Texas at 1-800-735-2989 [at (512) 936-7136].
The deadline for intervention in the proceeding is (date 70 days after
the date the application was filed with the commission) and you must
send a letter requesting intervention to the commission which is received
by that date." Proof of publication of notice must [shall
] be in the form of a publisher's affidavit, which must [shall] specify the newspaper or newspapers in which the notice
was published; the county or counties in which the newspaper or newspapers
is or are of general circulation; the dates upon which the notice
was published and a copy of the notice as published. Proof of publication must [shall] be submitted to the commission as soon
as available.
(2) Applicant must [shall] also
mail notice of its application, which must [shall]
contain the information as set out in paragraph (1) of this subsection,
to cities and to neighboring utilities providing the same service
within five miles of the requested territory or facility. Applicant must [shall] also provide notice to the county government
of all counties in which any portion of the proposed facility or territory
is located. The notice provided to county governments must [shall] be identical to that provided to cities and to neighboring
utilities. An affidavit attesting to the provision of notice to counties must [shall] specify the dates of the provision of
notice and the identity of the individual counties to which such notice
was provided.
(3) Failure to provide notice in accordance with this
section will [shall] be cause for day-for-day
extension of deadlines for intervention.
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301511
Adriana Gonzales
Rules Coordinator
Public Utility Commission
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act §14.002 and §14.052, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction, including rules of practice and procedure.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002 and §14.052.
§22.142.Limitations on Discovery and Protective Orders.
(a) Limitation of discovery requests. The presiding officer may limit discovery, by order, to protect a party against unreasonable or unwarranted discovery requests.
(1) (No change.)
(2) Any person from whom discovery is sought may file
a motion for a protective order, specifying the grounds on which a
protective order is justified. Motions or responses must [shall] include affidavits, discovery pleadings, or other pertinent
documents to support the allegations made therein.
(3) - (4) (No change.)
(b) (No change.)
(c) Protection of confidential or proprietary information.
The presiding officer may issue a protective order governing the production
of confidential or proprietary information as is appropriate in each
proceeding before the commission. The order must [shall]
be in the form adopted by the commission as the standard protective
order. In addition, the parties may enter into agreements regarding
protection of confidential or proprietary information. Entry of a
protective order is not a determination that any documents produced
under the protective order are proprietary or confidential.
(d) Limitations on requests for information.
(1) Before setting limitations on RFIs, the presiding
officer must [shall] consider the factors set
out in subparagraphs (A)-(K) of this paragraph.
(A) - (K) (No change.)
(2) For purposes of calculating the number of RFIs,
each answer is [shall be] considered a separate
request for information.
(3) If a party is not required to answer a question,
that question may not be included in the calculation of whether the
propounding party has reached its limit. However, if the presiding
officer determines that a party is intentionally propounding frivolous,
irrelevant, or otherwise objectionable requests, the question will [shall] be included in the calculation of a propounding party'slimit.
(4) To discourage duplicate RFIs, any party that does
not use its entire allotment of RFIs directed toward another party
may transfer, by written notice to the presiding officer, that portion
of its allotment to any other party in the proceeding. The requirements
of this paragraph do not apply to RFIs originating from commission
staff [the Office of Regulatory Affairs] or directed
to commission staff [the Office of Regulatory Affairs].
(5) The presiding officer may use discretion in determining
whether to limit the number of RFIs that may be propounded upon commission
staff [the Office of Regulatory Affairs] or the Office
of Public Utility Counsel by another party. In making this determination,
the presiding officer must [shall] consider
the limited resources available to each agency, and specifically that commission staff [the Office of Regulatory Affairs]
is required by law to represent the public interest in all proceedings
before the commission.
(6) The presiding officer may limit or expand the number
of RFIs that commission staff [the Office of Regulatory
Affairs] may propound upon any other party, and must [shall] consider that commission staff [the Office
of Regulatory Affairs] is required by law to represent the public
interest in all proceedings before the commission, and thus may require
more questions than other parties to ensure that it adequately explores
all of the issues presented in the case.
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301512
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
SUBCHAPTER H. CERTIFICATES OF CONVENIENCE AND NECESSITY
The Public Utility Commission of Texas (commission) proposes §24.235, relating to Notice Requirements for Certificate of Convenience and Necessity Applications. The proposed amendment is administrative in nature to update contact resources used by individuals with hearing or speech difficulties and also to make other minor and conforming amendments.
Growth Impact Statement
The agency provides the following governmental growth impact statement for the proposed rule, as required by Texas Government Code §2001.0221. The agency has determined that for each year of the first five years that the proposed rule is in effect, the following statements will apply:
(1) the proposed rule will not create a government program and will not eliminate a government program;
(2) implementation of the proposed rule will not require the creation of new employee positions and will not require the elimination of existing employee positions;
(3) implementation of the proposed rule will not require an increase and will not require a decrease in future legislative appropriations to the agency;
(4) the proposed rule will not require an increase and will not require a decrease in fees paid to the agency;
(5) the proposed rule will not, in effect, create a new regulation, because it is replacing a similar regulation;
(6) the proposed rule will repeal an existing regulation, but it will replace that regulation with a similar regulation;
(7) the same number of individuals will be subject to the proposed rule's applicability as were subject to the applicability of the rule it is being proposed to replace; and
(8) the proposed rule will not affect this state's economy.
Takings Impact Analysis
The commission has determined that the proposed rule will not be a taking of private property as defined in chapter 2007 of the Texas Government Code.
Public Benefits
Iliana De La Fuente, Attorney, Rules and Projects Division, has determined that for each year of the first five-year period the proposed section is in effect there will be no fiscal implications for state or local government as a result of enforcing or administering the section.
Iliana De La Fuente has determined that for each year of the first five years the proposed section is in effect the public benefit anticipated as a result of enforcing the section will be to provide individuals with hearing or speech difficulties with accurate agency contact resources. There will be no adverse economic effect on small businesses, micro-businesses or rural communities as a result of enforcing this section. There is no anticipated economic cost to persons who are required to comply with the section as proposed. Any economic costs would vary from person to person and are difficult to ascertain. However, it is believed that the benefits accruing from implementation of the proposed section will outweigh these costs.
Iliana De La Fuente has also determined that for each year of the first five years the proposed section is in effect there should be no effect on a local economy, and therefore no local employment impact statement is required under Administrative Procedure Act §2001.022.
Costs to Regulated Persons
Texas Government Code §2001.0045(b) does not apply to this rulemaking because the commission is expressly excluded under §2001.0045(c)(7).
Public Hearing
The commission staff will conduct a public hearing on this rulemaking if requested in accordance with Texas Government Code §2001.029. The request for a public hearing must be received by May 26, 2023. If a request for public hearing is received, commission staff will file in this project a notice of hearing.
Public Comments
Interested persons may file comments electronically through the interchange on the commission's website. Comments must be filed by May 26, 2023. Comments should be organized in a manner consistent with the organization of the proposed rules. The commission invites specific comments regarding the costs associated with, and benefits that will be gained by, implementation of the proposed rule. All comments should refer to Project Number 54844, Chapter 24.
Statutory Authority
This amendment is proposed under the Texas Water Code §13.041(b), which provides the commission with the authority to adopt and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Texas Water Code §13.041(b).
§24.235.Notice Requirements for Certificate of Convenience and Necessity Applications.
(a) If an application to obtain or amend a certificate of convenience and necessity (CCN) is filed, the applicant will prepare the notice prescribed in the commission's application form, which will include the following:
(1) - (2) (No change.)
(3) the following statement: "Persons who wish to intervene
in the proceeding or comment upon action sought should contact the
Public Utility Commission, P.O. Box 13326, Austin, Texas 78711-3326,
or call the Public Utility Commission at (512) 936-7120 or (888) 782-8477.
Hearing- and speech-impaired individuals [with text telephones
(TTY)] may contact the commission through Relay Texas at
1-800-735-2989 [at (512) 936-7136]. The deadline
for intervention in the proceeding is (30 days from the mailing or
publication of notice, whichever occurs later, unless otherwise provided
by the presiding officer). You must send a letter requesting intervention
to the commission which is received by that date."; and
(4) (No change.)
(b) After reviewing and, if necessary, modifying the proposed notice, the commission will provide the notice to the applicant for publication and/or mailing.
(1) (No change.)
(2) Except as otherwise provided by this subsection,
in addition to the notice required by subsection (a) of this section,
the applicant must [shall] mail notice to each
owner of a tract of land that is at least 25 acres and is wholly or
partially included in the requested area. Notice required under this
subsection must be mailed by first class mail to the owner of the
tract of land according to the most current tax appraisal rolls of
the applicable central appraisal district at the time the commission
received the application for the CCN. Good faith efforts to comply
with the requirements of this subsection may [shall]
be considered adequate mailed notice to landowners. Notice under this
subsection is not required for a matter filed with the commission under:
(A) - (B) (No change.)
(3) (No change.)
(4) Within 30 days of the date of the notice, the applicant must [shall] file in the docket an affidavit specifying
every person and entity to whom notice was provided and the date that
the notice was provided.
(c) The applicant must [shall]
publish the notice in a newspaper having general circulation in the
county where a CCN is being requested, once each week for two consecutive
weeks beginning with the week after the proposed notice is approved
by the commission. Proof of publication in the form of a publisher's
affidavit must [shall] be filed with the commission
within 30 days of the last publication date. The affidavit must [shall] state with specificity each county in which the newspaper
is of general circulation.
(d) - (e) (No change.)
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301513
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
The Public Utility Commission of Texas (commission) proposes amendments to §25.31 relating to Information to Applicants and Customers, §25.231, relating to Cost of Service; §25.238, relating to Purchased Power Capacity Cost Recovery Factor (PCRF); §25.240, relating to Contribution Disclosure Statements in Appeals of Municipal Utility Rates, §25.271, relating to Foreign Utility Company Ownership by Exempt Holding Companies, §25.301, relating to Nuclear Decommissioning Trusts; §25.483, relating to Disconnection of Service, and §25.486, relating to Customer Protections for Brokerage Services. The proposed amendments are administrative in nature to update contact resources used by persons with hearing or speech difficulties and also to make other minor and conforming amendments.
Growth Impact Statement
The agency provides the following governmental growth impact statement for the proposed rules, as required by Texas Government Code §2001.0221. The agency has determined that for each year of the first five years that the proposed rules are in effect, the following statements will apply:
(1) the proposed rules will not create a government program and will not eliminate a government program;
(2) implementation of the proposed rules will not require the creation of new employee positions and will not require the elimination of existing employee positions;
(3) implementation of the proposed rules will not require an increase and will not require a decrease in future legislative appropriations to the agency;
(4) the proposed rules will not require an increase and will not require a decrease in fees paid to the agency;
(5) the proposed rules will not, in effect, create a new regulation, because it is replacing a similar regulation;
(6) the proposed rules will repeal an existing regulation, but it will replace that regulation with a similar regulation;
(7) the same number of individuals will be subject to the proposed rules' applicability as were subject to the applicability of the rules they are being proposed to replace; and
(8) the proposed rules will not affect this state's economy.
Takings Impact Analysis
The commission has determined that the proposed rules will not be a taking of private property as defined in chapter 2007 of the Texas Government Code.
Public Benefits
Iliana De La Fuente, Attorney, Rules and Projects Division, has determined that for each year of the first five-year period the proposed sections are in effect there will be no fiscal implications for state or local government as a result of enforcing or administering the sections.
Iliana De La Fuente has determined that for each year of the first five years the proposed sections are in effect the public benefit anticipated as a result of enforcing the section will be to provide individuals with hearing or speech difficulties with accurate agency contact resources. There will be no adverse economic effect on small businesses or micro-businesses as a result of enforcing these sections. There is no anticipated economic cost to persons who are required to comply with the sections as proposed. Any economic costs would vary from person to person and are difficult to ascertain. However, it is believed that the benefits accruing from implementation of the proposed sections will outweigh these costs.
Iliana De La Fuente has also determined that for each year of the first five years the proposed sections are in effect there should be no effect on a local economy, and therefore no local employment impact statement is required under Administrative Procedure Act §2001.022.
Costs to Regulated Persons
Texas Government Code §2001.0045(b) does not apply to this rulemaking because the commission is expressly excluded under §2001.0045(c)(7).
Public Hearing
The commission staff will conduct a public hearing on this rulemaking if requested in accordance with Texas Government Code §2001.029. The request for a public hearing must be received by May 26, 2023. If a request for public hearing is received, commission staff will file in this project a notice of hearing.
Public Comments
Interested persons may file comments electronically through the interchange on the commission's website. Comments must be filed by May 26, 2023. Comments should be organized in a manner consistent with the organization of the proposed rules. The commission invites specific comments regarding the costs associated with, and benefits that will be gained by, implementation of the proposed rules. All comments should refer to Project Number 54844, Chapter 25.
SUBCHAPTER B. CUSTOMER SERVICE AND PROTECTION
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act, Texas Utilities Code Annotated §14.002, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002.
§25.31.Information to Applicants and Customers.
(a) Information to applicants. Each electric utility must [shall] provide this information to applicants
when they request new service or transfer existing service to a new location:
(1) the electric utility's lowest-priced alternatives
available at the applicant's location. [,] The
information must [shall] begin with the lowest-priced
alternative and give full consideration to applicable equipment options
and installation charges;
(2) - (3) (No change.)
(b) Information regarding rate schedules and classifications and electric utility facilities.
(1) Each utility must [shall]
notify customers affected by a change in rates or schedule of classifications.
(2) Each electric utility must [shall]
maintain copies of its rate schedules and rules in each office where
applications are received.
(3) Each electric utility must [shall]
post a notice in a conspicuous place in each office where applications
are received, informing the public that copies of the rate schedules
and rules relating to the service of the electric utility, as filed
with the commission, are available for inspection.
(4) Each electric utility must [shall]
maintain a current set of maps showing the physical locations of its
facilities that includes an accurate description of all facilities
(substations, transmission lines, etc.). These maps must [shall] be kept by the electric utility in a central location
and will be available for commission inspection during normal working
hours. Each business office or service center must [shall
] have available up-to-date maps, plans, or records of its immediate
service area, with other information as may be necessary to enable
the electric utility to advise applicants, and others entitled to
the information, about the facilities serving that locality.
(c) Customer information packets.
(1) The information packet must [shall]
be entitled "Your Rights as a Customer". Cooperatives may use the
title, "Your Rights as a Member".
(2) The information packet, containing the information
required by this section, must [shall] be mailed
to all customers on at least every other year at no charge to the customer.
(3) The information must [shall]
be written in plain, non-technical language.
(4) The information must [shall]
be provided in English and Spanish; however, an electric utility is
exempt from the Spanish language requirement if 10% or fewer of its
customers are exclusively Spanish-speaking. If the utility is exempt
from the Spanish language requirement, it must [shall]
notify all customers through a statement in both English and Spanish,
in the packet, that the information is available in Spanish from the
electric utility, both by mail and at the electric utility's offices.
(5) The information packet must [shall]
include all of the following:
(A) - (H) (No change.)
(I) the customer's right to file a complaint with the
electric utility, the procedures for a supervisory review, and right
to file a complaint with the commission, regarding any matter concerning
the electric utility's service. The commission's contact information:
Public Utility Commission of Texas, Office of Customer Protection,
P.O. Box 13326, Austin, Texas 78711-3326, (512) 936-7120 or in Texas
(toll-free) 1-888-782-8477, fax (512) 936-7003, e-mail address: customer@puc.state.tx.us,
internet address: www.puc.state.tx.us, [TTY (512) 936-7136, ]
and Relay Texas (toll-free) 1-800-735-2989, must [shall]
accompany this information;
(J) - (P) (No change.)
(Q) a statement that funded financial assistance may
be available for persons in need of assistance with their electric
utility payments, and that additional information may be obtained
by contacting the local office of the electric utility, Texas Department
of Housing and Community Affairs, or the Public Utility Commission
of Texas. The main office telephone number (toll-free number, if available)
and address for each state agency must [shall]
also be provided; and
(R) information that explains how a residential customer
can be recognized as a critical load customer, the benefits of being
a critical load customer in an emergency situation, and the process
for being placed on the critical load list. For the purposes of this
section a "critical load residential customer" is [shall
be] defined as a residential customer who has a critical need
for electric service because a resident on the premises requires electric
service to maintain life.
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301514
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
DIVISION 1. RETAIL RATES
16 TAC §§25.231, 25.238, 25.240
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act, Texas Utilities Code Annotated §14.002, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002.
§25.231.Cost of Service.
(a) (No change.)
(b) Allowable expenses. Only those expenses which are
reasonable and necessary to provide service to the public will [shall] be included in allowable expenses. In computing an electric
utility's allowable expenses, only the electric utility's historical
test year expenses as adjusted for known and measurable changes will
be considered, except as provided for in any section of these rules
dealing with fuel expenses.
(1) Components of allowable expenses. Allowable expenses, to the extent they are reasonable and necessary, and subject to this section, may include, but are not limited to the following general categories:
(A) Operations and maintenance expense incurred in
furnishing normal electric utility service and in maintaining electric
utility plant used by and useful to the electric utility in providing
such service to the public. Payments to affiliated interests for costs
of service, or any property, right or thing, or for interest expense will [shall] not be allowed as an expense for cost
of service except as provided in the Public Utility Regulatory Act
§36.058.
(B) Depreciation expense based on original cost and computed on a straight line basis as approved by the commission. Other methods of depreciation may be used when it is determined that such depreciation methodology is a more equitable means of recovering the cost of the plant.
(C) Assessments and taxes other than income taxes.
(D) Federal income taxes on a normalized basis. Federal
income taxes must [shall] be computed according
to the provisions of the Public Utility Regulatory Act §36.060.
(E) Advertising, contributions and donations. The actual
expenditures for ordinary advertising, contributions, and donations
may be allowed as a cost of service provided that the total sum of
all such items allowed in the cost of service must [shall
] not exceed three-tenths of 1.0% (0.3%) of the gross receipts
of the electric utility for services rendered to the public. The following
expenses must [shall] be included in the calculation
of the three-tenths of 1.0% (0.3%) maximum:
(i) - (iv) (No change.)
(F) Nuclear decommissioning expense. The following
restrictions must [shall] apply to the inclusion
of nuclear decommissioning costs that are placed in an electric utility's
cost of service.
(i) An electric utility owning or leasing an interest
in a nuclear-fueled generating unit must [shall]
include its cost of nuclear decommissioning in its cost of service.
Funds collected from ratepayers for decommissioning must [shall] be deposited monthly in irrevocable trusts external to
the electric utility, in accordance with §25.301 of this title
(relating to Nuclear Decommissioning Trusts). All funds held in short-term
investments must bear interest. The level of the annual cost of decommissioning
for ratemaking purposes will be determined in each rate case based
on an allowance for contingencies of 10% of the cost of decommissioning,
the most current information reasonably available regarding the cost
of decommissioning, the balance of funds in the decommissioning trust,
anticipated escalation rates, the anticipated return on the funds
in the decommissioning trust, and other relevant factors. The annual
amount for the cost of decommissioning determined pursuant to the
preceding sentence must [shall] be expressly
included in the cost of service established by the commission's order.
(ii) In the event that an electric utility implements
an interim rate increase, including an increase filed under bond,
an incremental change in decommissioning funding must [shall
] be included in the increase.
(iii) An electric utility's decommissioning fund and
trust balances will be reviewed in general rate cases. In the event
that an electric utility does not have a rate case within a five-year
period, the commission, on its own motion or on the motion of commission
staff [the commission's Office of Regulatory Affairs],
the Office of Public Utility Counsel, or any affected person, may
initiate a proceeding to review the electric utility's decommissioning
cost study and plan, and the balance of the trust.
(iv) An electric utility must [shall]
perform, or cause to be performed, a study of the decommissioning
costs of each nuclear generating unit that it owns or in which it
leases an interest. A study or a redetermination of the previous study must [shall] be performed at least every five years.
The study or redetermination should consider the most current information
reasonably available on the cost of decommissioning. A copy of the
study or redetermination must [shall] be filed
with the commission and a copy [copies] provided
to [the commission's Office of Regulatory Affairs and ]
the Office of Public Utility Counsel. An electric utility's most recent
decommissioning study or redeterminations must [shall]
be filed with the commission within 30 days of the effective date
of this subsection. The five-year requirement for a new study or redetermination must [shall] begin from the date of the last study
or redetermination.
(G) Accruals credited to reserve accounts for self-insurance
under a plan requested by an electric utility and approved by the
commission. The commission may [shall] consider
approval of a self insurance plan in a rate case in which expenses
or rate base treatment are requested for a such a plan. For the purposes
of this section, a self insurance plan is a plan providing for accruals
to be credited to reserve accounts. The reserve accounts are to be
charged with property and liability losses which occur, and which
could not have been reasonably anticipated and included in operating
and maintenance expenses, and are not paid or reimbursed by commercial
insurance. The commission will approve a self insurance plan to the
extent it finds it to be in the public interest. In order to establish
that the plan is in the public interest, the electric utility must
present a cost benefit analysis performed by a qualified independent
insurance consultant who demonstrates that, with consideration of
all costs, self-insurance is a lower-cost alternative than commercial
insurance and the ratepayers will receive the benefits of the self
insurance plan. The cost benefit analysis must [shall]
present a detailed analysis of the appropriate limits of self insurance,
an analysis of the appropriate annual accruals to build a reserve
account for self insurance, and the level at which further accruals
should be decreased or terminated.
(H) Postretirement benefits other than pensions (known
in the electric utility industry as "OPEB"). For ratemaking purposes,
expense associated postretirement benefits other than pensions (OPEB) must [shall] be treated as follows:
(i) OPEB expense must [shall]
be included in an electric utility's cost of service for ratemaking
purposes based on actual payments made.
(ii) An electric utility may request a one-time conversion
to inclusion of current OPEB expense in cost of service for ratemaking
purposes on an accrual basis in accordance with generally accepted
accounting principles (GAAP). Rate recognition of OPEB expense on
an accrual basis must [shall] be made only in
the context of a full rate case.
(iii) An electric utility will [shall]
not be allowed to recover current OPEB expense on an accrual basis
until GAAP requires that electric utility to report OPEB expense on
an accrual basis.
(iv) For ratemaking purposes, the transition obligation must [shall] be amortized over 20 years.
(v) OPEB amounts included in rates must [shall
] be placed in an irrevocable external trust fund dedicated
to the payment of OPEB expenses. The trust must [shall]
be established no later than six months after the order establishing
the OPEB expense amount included in rates. The electric utility must
[shall] make deposits to the fund at least once
per year. Deposits on the fund must [shall]
include, in addition to the amount included in rates, an amount equal
to fund earnings that would have accrued if deposits had been made
monthly. The funding requirement can be met with deposits made in
advance of the recognition of the expense for ratemaking purposes.
The electric utility must [shall], to the extent
permitted by the Internal Revenue Code, establish a postretirement
benefit plan that allows for current federal income tax deductions
for contributions and allows earnings on the trust funds to accumulate
tax free.
(vi) When an electric utility terminates an OPEB trust
fund established pursuant to clause (v) of this subparagraph, it must
[shall] notify the commission in writing. If excess
assets remain after the OPEB trust fund is terminated and all trust
related liabilities are satisfied, the electric utility must [shall] file, for commission approval, a proposed plan for the
distribution of the excess assets. The electric utility must [shall] not distribute any excess assets until the commission
approves the disbursement plan.
(2) Expenses not allowed. The following expenses must
[shall] never be allowed as a component of cost
of service:
(A) - (J) (No change.)
(c) Return on invested capital. The return on invested capital is the rate of return times invested capital.
(1) Rate of return. The commission will [shall
] allow each electric utility a reasonable opportunity to earn
a reasonable rate of return, which is expressed as a percentage of
invested capital, and will [shall] fix the rate
of return in accordance with the following principles.
(A) The return should be reasonably sufficient to assure confidence in the financial soundness of the electric utility and should be adequate, under efficient and economical management, to maintain and support its credit and enable it to raise the money necessary for the proper discharge of its public duties. A rate of return may be reasonable at one time and become too high or too low because of changes affecting opportunities for investment, the money market, and business conditions generally.
(B) The commission may [shall]
consider efforts by the electric utility to comply with the statewide
integrated resource plan, the efforts and achievements of the electric
utility in the conservation of resources, the quality of the electric
utility's services, the efficiency of the electric utility's operations,
and the quality of the electric utility's management, along with other
applicable conditions and practices.
(C) The commission may, in addition, consider inflation,
deflation, the growth rate of the service area, and the need for the
electric utility to attract new capital. The rate of return must be
high enough to attract necessary capital but need not go beyond that.
In each case, the commission will [shall] consider
the electric utility's cost of capital, which is the weighted average
of the costs of the various classes of capital used by the electric utility.
(i) (No change.)
(ii) Equity capital. For companies with ownership expressed in terms of shares of stock, equity capital commonly consists of the following classes of stock.
(I) Common stock capital. The cost of common stock
capital must [shall] be based upon a fair return
on its market value.
(II) Preferred stock capital. The cost of preferred stock capital is the actual cost of preferred stock at the time of issuance, plus an adjustment for premiums, discounts, and refunding and issuance costs.
(2) Invested capital; rate base. The rate of return is applied to the rate base. The rate base, sometimes referred to as invested capital, includes as a major component the original cost of plant, property, and equipment, less accumulated depreciation, used and useful in rendering service to the public. Components to be included in determining the overall rate base are as set out in subparagraphs (A)-(F) of this paragraph.
(A) Original cost, less accumulated depreciation, of electric utility plant used by and useful to the electric utility in providing service.
(i) Original cost must [shall]
be the actual money cost, or the actual money value of any consideration
paid other than money, of the property at the time it would [shall] have been dedicated to public use, whether by the electric
utility which is the present owner or by a predecessor.
(ii) Reserve for depreciation is the accumulation of
recognized allocations of original cost, representing recovery of
initial investment, over the estimated useful life of the asset. Depreciation must [shall] be computed on a straight line basis
or by such other method approved under subsection (b)(1)(B) of this
section over the expected useful life of the item or facility.
(iii) Payments to affiliated interests must [shall] not be allowed as a capital cost except as provided in
the Public Utility Regulatory Act §36.058.
(B) Working capital allowance to be composed of, but not limited to the following:
(i) (No change.)
(ii) Reasonable prepayments for operating expenses.
Prepayments to affiliated interests will [shall]
be subject to the standards set forth in the Public Utility Regulatory §36.058.
(iii) A reasonable allowance for cash working capital.
The following applies [shall apply] in determining
the amount to be included in invested capital for cash working capital:
(I) Cash working capital for electric utilities must [shall] in no event be greater than one-eighth of total annual
operations and maintenance expense, excluding amounts charged to operations
and maintenance expense for materials, supplies, fuel, and prepayments.
(II) - (III) (No change.)
(IV) For all investor-owned electric utilities a reasonable allowance for cash working capital, including a request of zero, will be determined by the use of a lead-lag study. A lead-lag study will be performed in accordance with the following criteria:
(-a-) - (-c-) (No change.)
(-d-) All funds received by the electric utility except
electronic transfers must [shall] be considered
available for use no later than the business day following the receipt
of the funds in any repository of the electric utility (e.g. lockbox,
post office box, branch office). All funds received by electronic
transfer will be considered available the day of receipt.
(-e-) For electric utilities the balance of cash and
working funds included in the working cash allowance calculation must
[shall] consist of the average daily bank balance
of all non-interest bearing demand deposits and working cash funds.
(-f-) The lead on federal income tax expense must [shall] be calculated by measurement of the interval between
the mid-point of the annual service period and the actual payment
date of the electric utility.
(-g-) If the cash working capital calculation results
in a negative amount, the negative amount must [shall]
be included in rate base.
(V) (No change.)
(C) (No change.)
(D) Construction work in progress (CWIP). The inclusion
of construction work in progress is an exceptional form of rate relief.
Under ordinary circumstances the rate base must [shall]
consist only of those items which are used and useful in providing
service to the public. Under exceptional circumstances, the commission
will include construction work in progress in rate base to the extent that:
(i) the electric utility has proven that:
(I) (No change.)
(II) major projects under construction have been efficiently
and prudently planned and managed. However, construction work in progress must [shall] not be allowed for any portion of a
major project which the electric utility has failed to prove was efficiently
and prudently planned and managed; or
(ii) (No change.)
(E) Self-insurance reserve accounts. If a self insurance
plan is approved by the commission, any shortages to the reserve account
will be an increase to the rate base and any surpluses will be a decrease
to the rate base. The electric utility must [shall]
maintain appropriate books and records to permit the commission to
properly review all charges to the reserve account and determine whether
the charges being booked to the reserve account are reasonable and correct.
(F) (No change.)
§25.238.Purchased Power Capacity Cost Recovery Factor (PCRF).
(a) - (b) (No change.)
(c) Establishment, adjustment, and termination of a PCRF.
(1) (No change.)
(2) The application in which the utility applies for
the establishment, adjustment, or termination of a PCRF rider must [shall] be limited to issues related to the establishment, adjustment,
or termination of the PCRF rider.
(3) The PCRF must [shall] not include:
(A) - (D) (No change.)
(4) Upon the establishment of a utility's PCRF, the
utility must [shall] annually file an application
for an adjustment of the PCRF. The cost year used in an annual PCRF
adjustment must [shall] be the 12-month period
that immediately follows the cost year used to set the existing PCRF.
In addition, the utility must [shall] file the
application to adjust the PCRF promptly after the relevant cost-year
data become available. The commission may establish a schedule for
the filing of such applications.
(5) A utility may terminate its PCRF as part of any
annual PCRF adjustment proceeding. The final order including the termination
of a PCRF must [shall] specify the date by which
the utility must [shall] be required to file
an application for the final reconciliation of the costs and revenues
associated with the terminated PCRF.
(6) (No change.)
(7) A utility's request to establish, adjust, terminate,
or reconcile a PCRF must [shall] include the
utility's direct testimony supporting the request.
(d) Pre-approval of purchased power agreements.
(1) - (3) No change.)
(4) An application in which the utility applies for
pre-approval of purchased power capacity agreements under this subsection must [shall] be limited to issues related to the
pre-approval of such agreements.
(5) A utility may apply for pre-approval of purchased power agreements under this subsection no more than once per year, and no more than three times between comprehensive base-rate proceedings.
(e) Notice of PCRF proceeding.
(1) Within one commission working day of filing an
application limited to establishing, adjusting, or terminating a PCRF,
a utility must [shall] provide notice of the
application in accordance with the following:
(A) Method of notice.
(i) The utility must [shall]
serve notice of the application on the parties to the utility's last
PCRF reconciliation proceeding or, if there has been no PCRF reconciliation
proceeding, on the parties to the utility's last comprehensive base-rate proceeding.
(ii) The utility must [shall]
issue a news release and post the news release on its website.
(B) Content of notice. Notice provided pursuant to
paragraph (1) of this subsection must [shall]
include the following:
(i) - (ii) (No change.)
(iii) The date of the intervention and hearing request
deadline. The date of the intervention and hearing request deadline must [shall] be 30 days after the application was
filed, except that if the date would fall on a day that is not a commission
working day, the intervention and hearing request deadline must [shall] be the first commission working day after the 30th day
after the application was filed;
(iv) - (vi) (No change.)
(vii) The statement, "Persons who wish to intervene
in the proceeding for this application, or who wish to provide their
comments concerning this application, should contact the Public Utility
Commission of Texas, Customer Protection Division, P.O. Box 13326,
Austin, Texas 78711-3326, or call (512) 936-7120 or toll-free at (888)
782-8477. Hearing and speech-impaired individuals may [with
text telephones (TTY) may call (512) 936-7136 or] use Relay
Texas (toll-free) 1-800-735-2989."
(C) Proof of notice. Within five commission working
days from the filing of the application limited to establishing or
adjusting a PCRF, the utility must [shall] file
proof in the form of an affidavit that it complied with this paragraph.
(2) If a utility applies to reconcile a PCRF in a base-rate
proceeding, the appropriate method and proof of notice set forth in
§22.51 of this title (relating to Notice for Public Utility Regulatory
Act, Chapter 36, Subchapters C-E; Chapter 51, §51.009; and Chapter
53, Subchapters C-E Proceedings) must [shall]
apply. The notice must [shall] include a description
of the requested change to the PCRF.
(3) If a utility applies to reconcile a PCRF outside
of a base-rate proceeding, the method of notice set forth in §25.235(b)(1)(B)
of this title (relating to Fuel Costs-General) applies [shall
apply]. The proof of notice set forth in §25.235(b)(3)
of this title must [shall] apply. The notice must
[shall] include a description of the requested reconciliation
of the PCRF.
(f) Procedural schedule. Upon the filing of an application
limited to the annual adjustment of a PCRF pursuant to this section,
the presiding officer must [shall] set a procedural
schedule that will enable the commission to issue a final order in
the proceeding as follows, except where good cause supports a different
procedural schedule:
(1) - (2) (No change.)
(g) Exclusion from fuel factor. Costs that are recovered
through a PCRF must [shall] be excluded in calculating
the utility's fixed fuel factor as defined in §25.237 of this
title (relating to Fuel Factors).
(h) PCRF formula.
(1) The PCRF for each rate class must [shall
] be calculated using the following formula:
Figure: 16 TAC §25.238(h)(1) (No change.)
(2) Where the cost year used in setting a PCRF includes
a change in base rates due to a comprehensive base-rate proceeding,
parameters in the PCRF formula that refer to values from the utility's
last comprehensive base-rate proceeding must [shall]
be calculated by prorating the values from the relevant base rate-proceedings
across the cost-year.
(i) True-up. After establishment of an initial PCRF,
a subsequent PCRF cost year is expected to contain portions of two
different PCRF rate years. Therefore, for purposes of calculating
class over- or under-recoveries for use in a proceeding to adjust
the PCRF, previous PCRF revenue requirements from PCRF rate years
in effect during the cost year must [shall]
be prorated across the cost year. For each rate class, the difference
between the prorated cost-year PCRF revenue requirement that previous
PCRFs were set to recover from that class and the actual cost-year
PCRF revenues recovered from that class, with interest on the balance
calculated at the rate established annually by the commission pursuant
to §25.28(c) and (d) of this title (relating to Bill Payment
and Adjustments), must [shall] be credited or
charged to that class when calculating the adjusted PCRF. In the event
that a PCRF rider is terminated, any over- or under-recovery amounts,
with interest applied, must [shall] be included
in a separate rider.
(j) Reconciliation of PCRF expenses.
(1) The reasonableness and necessity of expenses recovered
through the PCRF must [shall] be reviewed, and
such costs and corresponding PCRF revenues must [shall]
be reconciled, as part of any proceeding initiated under §25.236(b)
of this title. Upon motion and showing of good cause, a PCRF reconciliation
proceeding may be severed from or consolidated with other proceedings.
(2) (No change.)
(3) Any refunds or surcharges resulting from a PCRF
reconciliation, with interest applied, must [shall],
in the annual PCRF proceeding immediately subsequent to the filing
of the final order in the reconciliation proceeding, be incorporated
into the true-up balances described in subsection (i) of this section.
In the event that no PCRF rider is in effect subsequent to a PCRF
reconciliation, such refunds or surcharges, with interest applied, must
[shall] be included in a separate rider.
(k) Transition Issues. For a utility subject to a commission
order to transition to retail competition as of the effective date
of this section, the utility's existing power cost recovery factor
in its tariff approved under the prior rule continues [shall
continue] to be effective until the effective date of new unbundled
retail delivery tariffs for the utility, at which time the power cost
recovery factor must [shall] be terminated.
Any over- or under-recovery amounts, with interest applied, must [shall] be included in a separate rider to the utility's retail
delivery tariffs to be established in the proceeding that approves
such tariffs and must [shall] be credited or
charged to customers as appropriate. The utility must [shall
] file monthly reports with the commission showing all such
amounts until no remaining amounts remain to be credited or charged,
at which time the utility must [shall] file
a final report with the commission.
§25.240.Contribution Disclosure Statements in Appeals of Municipal Utility Rates.
(a) Pursuant to Chapter 33, Subchapter D. Each party
to an appeal proceeding under the Public Utility Regulatory Act (PURA),
Chapter 33, Subchapter D must file a statement with the commission
disclosing all expenditures made by that party and all contributions
made to that party, whether the expenditures or contributions are
financial or in-kind, related to preparation of and filing of a petition
for appeal, the preparation of expert testimony, and legal representation
in the proceeding. The municipality whose rates are the subject of
the appeal, commission staff [the Office of Regulatory
Affairs], and the Office of Public Utility Counsel are not required
to file a statement. The statement must list with particularity the
name and address of each contributor and provide a description of
each contribution. The statement will be available to the public.
The statement must be filed within 30 days after a final appealable
order is entered by the commission or the petition of appeal is withdrawn.
(b) - (c) (No change.)
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301515
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act, Texas Utilities Code Annotated §14.002, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002.
§25.271.Foreign Utility Company Ownership by Exempt Holding Companies.
(a) - (b) (No change.)
(c) Safe harbor investments. The following safe harbor
provisions apply [shall be applicable] to investments
in FUCOs by exempt holding companies that are affiliated with electric
utilities subject to the regulatory jurisdiction of the commission:
(1) The commission must [shall]
certify to the SEC that the commission has the authority and resources
to protect ratepayers subject to its jurisdiction and that it intends
to exercise its authority, provided that all holding companies of
electric utilities that are subject to the regulatory jurisdiction
of this commission must [shall] have filed with
the commission corporate undertakings, signed under oath by an authorized
executive officer of the holding company agreeing to adhere to the
covenants and to make the filings specified in paragraph (2) of this subsection.
(2) The holding company must [shall]
adhere to the following covenants:
(A) - (F) (No change.)
(G) That the holding company will file with the commission quarterly a report listing the total amount of the aggregate investments by the holding company and its subsidiaries and the percentage of the holding company's consolidated net worth, from the company's most recent SEC form 10-Q, represented by such investments;
(i) "Aggregate investment" means all amounts invested,
or committed to be invested, in exempt wholesale generators located
outside the United States (foreign EWGs) and FUCOs, for which there
is recourse, directly or indirectly, to the holding company. Among
other things, the term must [shall] include
preliminary development expenses that culminate in the acquisition
of a foreign EWG or a FUCO.
(ii) Such report must [shall]
be filed no later than ten days following the filing of the 10-Q for
the quarter.
(H) That in the event the holding company anticipates
making any investment in a FUCO that would result in the aggregate
investment as defined in subparagraph (G) of this paragraph of such
holding company exceeding 30% of the consolidated net worth of such
holding company, the holding company must [shall]
so advise the commission before a final commitment to ownership of
such FUCO is made;
(I) - (L) (No change.)
(d) Other investments. For any occasion for which a holding company has undertaken to notify the commission of an event specified in subsection (c)(2)(H) or (K) of this section, the following provisions apply:
(1) The holding company must [shall]
provide the following information, to the extent such information
is reasonably available at the time of submission of the filing, at
least 30 days before the date when it anticipates making a final commitment
to ownership of a FUCO not already covered by a certification letter:
(A) - (D) (No change.)
(E) A statement that the electric utility has effective
written policies and accounting procedures which insure that any use
by the FUCO of assets or personnel of an affiliate of the electric
utility, or other transactions between the FUCO and an affiliate of
the electric utility will [shall] not negatively
affect Texas ratepayers; and a statement that the electric utility
will demonstrate in each subsequent rate proceeding before the commission,
and each subsequent audit, that no FUCO investment increased the cost
of capital or revenue requirement of the electric utility;
(F) - (H) (No change.)
(2) The notification prescribed in this subsection
may be submitted less than 30 days before the date when the holding
company anticipates making a final commitment to ownership of a FUCO
not already covered by a certification letter upon a showing of good
cause. Good cause for purposes of the preceding sentence must [shall] be deemed to include, without limitation, a representation
that the holding company lacked the information required to make a
submission at an earlier date or a representation that making the
submission at an earlier date would have unreasonably jeopardized
the ability of the holding company to go forward with the contemplated investment.
(3) (No change.)
(e) Post-investment reporting. The electric utility must
[shall] comply with the following post-investment
reporting obligations:
(1) With respect to any investment in a FUCO for which
an informational filing was made pursuant to subsection (d)(1) of
this section, the electric utility or holding company must [shall] notify the commission no later than ten days after the
holding company makes a final commitment to ownership of a FUCO that
such a commitment has been made. Such notice must [shall]
include any material corrections, additions, and supplementation of
previously-provided information; and
(2) For any FUCO investment covered by a certification,
the electric utility or holding company must [shall]
notify the commission no later than 30 days after any material change
in the circumstances or nature of an investment in a FUCO. Such notice must [shall] include all appropriate corrections,
additions, and supplementation of previously-provided information.
A material change would include, but is not limited to, any change
that would have an adverse impact of greater than 1.0% of consolidated
net worth most recently reported; full or partial divestiture of the
investment; a catastrophic event that destroys a significant amount
of FUCO property or results in loss of life that could result in a
significant liability claim; a change in the laws or government policy
having a material impact on the FUCO; or an event which would place
a significant restriction on the repatriation of earnings of the FUCO.
(3) Unless included in SEC reports, each exempt utility
holding company which directly or indirectly holds an interest in
FUCOs or foreign EWGs must [shall] provide the
following information: A consolidating statement of income of the
exempt holding company and its subsidiary companies for the last calendar
year, together with a consolidating balance sheet of the exempt holding
company and its subsidiary companies as of the close of such calendar year.
(A) The information must [shall]
be provided in English, monetary amounts in U.S. dollars, and according
to generally accepted accounting principles.
(B) Such information must be received by the commission annually no later than March 15.
(f) Commission standards for granting or maintaining certification.
(1) (No change.)
(2) With respect to any investment in a FUCO for which
an informational filing was made pursuant to subsection (d)(1) of
this section, the commission must [shall] determine
on a case-by-case [case by case] basis whether
to issue a certification to the SEC or maintain a previously issued
certification. The commission must [shall] endeavor
to make such a determination prior to the date when the holding company
anticipates having to make a final commitment to ownership of the
FUCO. If the commission determines that it does not intend to continue
certification, it may inform the SEC that maintaining a previously-issued
certification would be inappropriate.
(3) The commission must [shall]
notify the holding company requesting the certification or retention
of certification of its decision within 45 days of receiving the request.
If no action is taken by the commission within 45 days of receiving
the request, the certification is [shall be]
deemed granted or affirmed.
(4) Any information submitted by a holding company
pursuant to this section may be submitted by the holding company under
seal. Each page tendered under seal must [shall]
have the words "Confidential Information" typed or stamped on its
face. The holding company must [shall] clearly
identify each portion of the application alleged to be Confidential
Information; identify the exemption to the Public Information Act,
Texas Government Code Annotated, Chapter 552 (Vernon Supp. 1998),
applicable to the alleged Confidential Information; and provide a
detailed explanation of why the alleged Confidential Information is
exempt from public disclosure under the Public Information Act. If
the commission receives a Public Information Act request for disclosure
of Confidential Information, then the Executive Director must [shall] promptly so notify the holding company. The Executive
Director must [shall] timely request an Attorney
General's opinion as to whether the information falls within any of
the exemptions identified in Subchapter C of the Public Information
Act. The Executive Director must [shall] promptly
provide to the holding company a copy of an Attorney General opinion
regarding the claim of confidentiality. If an Attorney General opinion
recommends disclosure of Confidential Information, either in whole
or in part, then the Executive Director must [shall]
not release such information for ten calendar days, in order to allow
the holding company time to pursue any legal remedies that it may
have. The holding company may require the execution of an appropriate
confidentiality agreement prior to providing access to such confidential
information to commission staff [the Legal Division
of the Office of Regulatory Affairs] or any other interested
party. The form of any such confidentiality agreement must [shall] be approved by commission staff legal counsel [the Legal Division] prior to filing and included with the informational filing.
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301516
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act, Texas Utilities Code Annotated §14.002, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002.
§25.301.Nuclear Decommissioning Trusts.
(a) Duties of electric utilities.
(1) Each electric utility collecting funds for a nuclear
decommissioning trust must [shall] assure that
the nuclear decommissioning trust is managed so that the funds are
secure and earn a reasonable return; and, that the funds provided
from the utility's cost of service, plus the amounts earned from investment
of the funds, will be available at the time of decommissioning.
(2) Each electric utility collecting funds for a nuclear
decommissioning trust must [shall] place the
funds in an external, irrevocable trust fund. The utility must [shall] appoint an institutional trustee and may appoint an investment
manager(s). Unless otherwise specified in subsection (b) of this section,
the Texas Trust Code controls the administration and management of
the nuclear decommissioning trusts, except that the appointed trustee(s)
need not be qualified to exercise trust powers in Texas.
(3) The utility must [shall]
retain the right to replace the trustee with or without cause. In
appointing a trustee, the electric utility must [shall]
have the following duties, which will be of a continuing nature:
(A) - (E) (No change.)
(4) The utility must [shall]
retain the right to replace the investment manager with or without
cause. In appointing an investment manager, the utility must [shall] have the following duties, which will be of a continuing
nature:
(A) - (E) (No change.)
(b) Agreements between the electric utility and the institutional trustee or investment manager.
(1) The utility must [shall]
execute an agreement with the institutional trustee. The agreement must
[shall] include the restrictions in subparagraphs
(A) - (E) of this paragraph and may include additional restrictions
on the trustee. An electric utility must [shall]
not grant the trustee powers that are greater than those provided
to trustees under the Texas Trust Code or that are inconsistent with
the limitations of this section.
(A) (No change.)
(B) A trustee must [shall] have
a continuing duty to review the trust portfolio for compliance with
investment guidelines and governing regulations.
(C) A trustee must [shall] not
lend funds from the decommissioning trust with itself, its officers,
or its directors.
(D) A trustee must [shall] not
invest or reinvest decommissioning trust funds in instruments issued
by the trustee, except for time deposits, demand deposits, or money
market accounts of the trustee. However, investments of a decommissioning
trust may include mutual funds that contain securities issued by the
trustee if the securities of the trustee constitute no more than five
percent of the fair market value of the assets of such mutual funds
at the time of the investment.
(E) The agreement must [shall]
comply with all applicable requirements of the Nuclear Regulatory Commission.
(2) The utility must [shall]
execute an agreement with the investment manager. (If the trustee
performs investment management functions, the contractual provisions
governing those functions must be included in either the trust agreement
or a separate investment management agreement.) The agreement must [shall] include the restrictions set forth in subparagraphs (A)
- (E) of this paragraph and may include additional restrictions on
the manager. An electric utility must [shall]
not grant the manager powers that are greater than those provided
to trustees under the Texas Trust Code or that are inconsistent with
the limitations of this section.
(A) An investment manager must [shall],
in investing and reinvesting the funds in the trust, comply with subsection
(c) of this section.
(B) (No change.)
(C) An investment manager must [shall]
have a continuing duty to review the trust portfolio to determine
the appropriateness of the investments.
(D) An investment manager must [shall]
not invest funds from the decommissioning trust with itself, its officers,
or its directors.
(E) The agreement must [shall]
comply with all applicable requirements of the Nuclear Regulatory Commission.
(3) A copy of the trust agreement, any investment management
agreement, and any amendments must [shall] be
filed with the commission within 30 days after the execution or modification
of the agreement, and copies provided to the commission's [Office
of Regulatory Affairs' ] Legal Division and Rate Regulation [Financial Review] Division and the Office of Public Utility
Counsel. All previously executed agreements and amendments must be
filed within 30 days of the effective date of this section.
(4) Within 90 days after the effective date of this
section, a utility that is a party to a trust agreement or an investment
management agreement that is not in compliance with this section must
[shall] revise the agreement to comply with this section.
(c) Trust investments.
(1) Investment portfolio goals. The funds should be invested consistent with the following goals. The utility may apply additional prudent investment goals to the funds so long as they are not inconsistent with the stated goals of this subsection.
(A) (No change.)
(B) In keeping with prudent investment practices, the
portfolio of securities held in the decommissioning trust must [shall] be diversified to the extent reasonably feasible given
the size of the trust.
(C) - (D) (No change.)
(2) General requirements. The following requirements must [shall] apply to all decommissioning trusts.
Where a utility has multiple trusts for a single generating unit,
the restrictions contained in this subsection apply to all trusts
in the aggregate for that generating unit. For purposes of this section,
a commingled fund is defined as a professionally managed investment
fund of fixed-income or equity securities established by an investment
company regulated by the Securities Exchange Commission or a bank
regulated by the Office of the Comptroller of the Currency.
(A) Fees limitation. The total trustee and investment
manager fees paid on an annual basis by the utility for the entire
portfolio including commingled funds must [shall]
not exceed 0.7% of the entire portfolio's average annual balance.
(B) Diversification. For the purpose of this subparagraph,
a commingled or mutual fund is not considered a security; rather,
the diversification standard applies to all securities, including
the individual securities held in commingled or mutual funds. Once
the portfolio of securities (including commingled funds) held in the
decommissioning trust(s) contains securities with an aggregate value
in excess of $20 million, it must [shall] be
diversified such that:
(i) no more than 5.0 % of the securities held may be issued by one entity, with the exception of the federal government, its agencies and instrumentalities, and;
(ii) the portfolio must [shall]
contain at least 20 different issues of securities. Municipal securities
and real estate investments must [shall] be
diversified as to geographic region.
(C) Qualified trusts. The utility may invest the decommissioning
funds by means of qualified or unqualified nuclear decommissioning
trusts; however, the utility must [shall], to
the extent permitted by the Internal Revenue Service, invest its decommissioning
funds in "qualified" nuclear decommissioning trusts, in accordance
with the Internal Revenue Service Code §468A.
(D) - (E) (No change.)
(F) Investment limits in equity securities. The following
investment limits must [shall] apply to the
percentage of the aggregate market value of all non-fixed income investments
relative to the total portfolio market value.
(i) (No change.)
(ii) When the weighted average remaining life of the
liability ranges between 5 years and 2.5 years, the equity cap must [shall] be 30%. Additionally, during all years in which expenditures
for decommissioning the nuclear units occur, the equity cap must [shall] also be 30%;
(iii) When the weighted average remaining life of the
liability is less than 2.5 years, the equity cap must [shall
] be 0%;
(iv) (No change.)
(v) Should the market value of non-fixed income investments,
measured monthly, exceed the appropriate cap due to market fluctuations,
the utility must [shall], as soon as practicable,
reduce the market value of the non-fixed income investments below
the cap. Such reductions may be accomplished by investing all future
contributions to the fund in debt securities as is necessary to reduce
the market value of the non-fixed income investments below the cap,
or if prudent, by the sale of equity securities.
(G) A decommissioning trust must [shall]
not invest in securities issued by the electric utility collecting
the funds or any of its affiliates; however, investments of a decommissioning
trust may include commingled funds that contain securities issued
by the electric utility if the securities of the utility constitute
no more than 5.0% of the fair market value of the assets of such commingled
funds at the time of the investment.
(3) Specific investment restrictions. The following
restrictions must [shall] apply to all decommissioning
trusts. Where a utility has multiple trusts for a single generating
unit, the restrictions contained in this subsection apply to all trusts
in the aggregate for that generating unit.
(A) Fixed-income investments. A decommissioning trust must [shall] not invest trust funds in corporate
or municipal debt securities that have a bond rating below investment
grade (below "BBB-" by Standard and Poor's Corporation or "Baa3" by
Moody's Investor's Service) at the time that the securities are purchased
and must [shall] reexamine the appropriateness
of continuing to hold a particular debt security if the debt rating
of the company in question falls below investment grade at some time
after the debt security has been purchased. Commingled funds may contain
some below investment grade bonds; however, the overall portfolio
of debt instruments must [shall] have a quality
level, measured quarterly, not below a "AA" grade by Standard and
Poor's Corporation or "Aa2" by Moody's Investor's Service. In calculating
the quality of the overall portfolio, debt securities issued by the
federal government must [shall] be considered
as having a "AAA" rating.
(B) Equity investments.
(i) At least 70% of the aggregate market value of the
equity portfolio, including the individual securities in commingled
funds, must [shall] have a quality ranking from
a major rating service such as the earnings and dividend ranking for
common stock by Standard and Poor's or the quality rating of Ford
Investor Services. Further, the overall portfolio of ranked equities must [shall] have a weighted average quality rating
equivalent to the composite rating of the Standard and Poor's 500
index assuming equal weighting of each ranked security in the index.
If the quality rating, measured quarterly, falls below the minimum
quality standard, the utility must [shall] as
soon as practicable and prudent to do so, increase the quality level
of the equity portfolio to the required level.
(ii) A decommissioning trust must [shall]
not invest in equity securities where the issuer has a capitalization
of less than $100 million.
(C) Commingled funds. The following guidelines must [shall] apply to the investments made through commingled funds.
Examples of commingled funds appropriate for investment by nuclear
decommissioning trust funds include United States equity-indexed funds,
actively managed United States equity funds, balanced funds, bond
funds, real estate investment trusts, and international funds.
(i) (No change.)
(ii) In evaluating the appropriateness of a particular
commingled fund, the utility has the following duties, which must [shall] be of a continuing nature:
(I) - (III) (No change.)
(iii) The payment of load fees must [shall
] be avoided.
(iv) Commingled funds focused on specific market sectors
or concentrated in a few holdings must [shall]
be used only as necessary to balance the trust's overall investment portfolio mix.
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301517
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322
Statutory Authority
These amendments are proposed under the Public Utility Regulatory Act, Texas Utilities Code Annotated §14.002, which provides the Public Utility Commission with the authority to make and enforce rules reasonably required in the exercise of its powers and jurisdiction.
Cross Reference to Statutes: Public Utility Regulatory Act §14.002.
§25.483.Disconnection of Service.
(a) Disconnection and reconnection policy. Only a transmission
and distribution utility (TDU), municipally owned utility, or electric
cooperative may [shall] perform physical disconnections
and reconnections. Unless otherwise stated, it is the responsibility
of a retail electric provider (REP) to request such action from the
appropriate TDU, municipally owned utility, or electric cooperative
in accordance with that entity's relevant tariffs, in accordance with
the protocols established by the registration agent, and in compliance
with the requirements of this section. If a REP chooses to have a
customer's electric service disconnected, it must [shall]
comply with the requirements in this section. Nothing in this section
requires a REP to request that a customer's service be disconnected.
(b) Disconnection authority.
(1) (No change.)
(2) Except as provided in subsection (d) of this section,
all REPs may [shall have the authority to] authorize
the disconnection of residential and small non-residential customers
pursuant to commission rules. Prior to authorizing disconnections
for non-payment in accordance with this paragraph, a REP must
[shall]:
(A) - (B) (No change.)
(c) (No change.)
(d) Disconnection without prior notice. Any REP or TDU may, at any time, authorize disconnection of a customer's electric service without prior notice for any of the following reasons:
(1) Where a known dangerous condition exists for as
long as the condition exists. Where reasonable, given the nature of
the hazardous condition, the REP [,] or its agent [,] must [shall] post a notice of disconnection and the
reason for the disconnection at the place of common entry or upon
the front door of each affected residential unit as soon as possible
after service has been disconnected;
(2) - (5) (No change.)
(e) Disconnection prohibited. A REP having disconnection
authority under the provisions of subsection (b) of this section must
[shall] not authorize a disconnection for nonpayment
of a customer's electric service for any of the following reasons:
(1) - (7) (No change.)
(f) Disconnection on holidays or weekends.
(1) A REP having disconnection authority under the
provisions of subsection (b) of this section must [shall]
not request disconnection of a customer's electric service for nonpayment
on a holiday or weekend, or the day immediately preceding a holiday
or weekend, unless the REP's personnel are available on those days
to take payments, make payment arrangements with the customer, and
request reconnection of service.
(2) Unless a dangerous condition exists or the customer
requests disconnection, a TDU must [shall] not
disconnect a customer's electric service on a holiday or weekend,
or the day immediately preceding a holiday or weekend, unless the
personnel of the TDU are available to reconnect service on all of
those days.
(g) Disconnection of Critical Care Residential Customers.
A REP having disconnection authority under the provisions of subsection
(b) of this section must [shall] not authorize
a disconnection for nonpayment of electric service at a permanent,
individually metered dwelling unit of a delinquent Critical Care Residential
Customer when that customer establishes that disconnection of service
will cause some person at that residence to become seriously ill or
more seriously ill.
(1) Each time a Critical Care Residential Customer
seeks to avoid disconnection of service under this subsection, the
customer must [shall] accomplish all of the
following by the stated date of disconnection:
(A) Have the person's attending physician (for purposes
of this subsection, the "physician" means [shall mean]
any public health official, including medical doctors, doctors of
osteopathy, nurse practitioners, registered nurses, and any other
similar medical professional) contact the REP to confirm that the
customer is a Critical Care Residential Customer;
(B) - (C) (No change.)
(2) The prohibition against service disconnection of
a Critical Care Residential Customer provided by this subsection lasts
[shall last] 63 days from the issuance of the bill
for electric service or a shorter period agreed upon by the REP and
the customer, emergency (secondary) contact listed on the commission-approved
application form, or attending physician. If the Critical Care Residential
Customer does not accomplish the requirements of paragraph (1) of
this subsection:
(A) The REP must [shall] provide
written notice to the Critical Care Residential Customer and the emergency
contact listed on the commission-approved application form of its
intention to disconnect service not later than 21 days prior to the
date that service would be disconnected. Such notice must [shall] be a separate mailing or hand delivered notice with a
stated date of disconnection with the words "disconnection notice"
or similar language prominently displayed. If the REP has offered
and the customer has agreed for the customer and/or emergency contact
to receive disconnection notices from the REP by email, a separate
email with the words "disconnection notice" or similar language in
the subject line must [shall] be sent in addition
to the separate mailing or hand delivered notice. Except as provided
in this subsection, the notice must [shall]
comply with the requirements of subsections (l) and (m) of this section; and
(B) Prior to disconnecting a Critical Care Residential
Customer, a TDU must [shall] contact the customer
and the emergency contact listed on the commission-approved application
form. If the TDU does not reach the customer and emergency contact
by phone, the TDU must [shall] visit the premises,
and, if there is no response, must [shall] leave
a door hanger containing the pending disconnection information and
information on how to contact the REP and TDU.
(3) If, in the normal performance of its duties, a
TDU obtains information that a customer scheduled for disconnection
may qualify for delay of disconnection pursuant to this subsection,
and the TDU reasonably believes that the information may be unknown
to the REP, the TDU must [shall] delay the disconnection
and promptly communicate the information to the REP. The TDU must [shall] disconnect such customer if it subsequently receives
a confirmation of the disconnect notice from the REP. Nothing herein
should be interpreted as requiring a TDU to assess or to inquire as
to the customer's status before performing a disconnection when not
otherwise required.
(4) If a TDU refuses to disconnect a Critical Care
Residential Customer pursuant to this subsection, it must [shall] cease charging all transmission and distribution charges
and surcharges, except securitization-related charges, for that premises
to the REP.
(h) Disconnection of Chronic Condition Residential
Customers. A REP having disconnection authority under the provisions
of subsection (b) of this section must [shall]
not authorize a disconnection for nonpayment of electric service at
a permanent, individually metered dwelling unit of a delinquent customer
when that customer has been designated as a Chronic Condition Residential
Customer pursuant to §25.497 of this title (relating to Critical
Load Industrial Customers, Critical Load Public Safety Customers,
Critical Care Residential Customers, and Chronic Condition Residential
Customers), except as provided in this subsection. The REP must [shall] notify the Chronic Condition Residential Customer and
the emergency contact listed on the commission-approved application
form with a written notice of its intention to disconnect service
not later than 21 days prior to the date that service would be disconnected.
Such notice must [shall] be a separate mailing
or hand delivered notice with a stated date of disconnection with
the words "disconnection notice" or similar language prominently displayed.
If the REP has offered and the customer has agreed for the customer
and/or emergency contact to receive disconnection notices from the
REP by email, a separate email with the words "disconnection notice"
or similar language in the subject line must [shall
be] also be sent in addition to the separate mailing or hand
delivered notice. Except as provided in this subsection, the notice must [shall] comply with the requirements of subsections
(l) and (m) of this section.
(i) Disconnection of energy assistance clients.
(1) A REP having disconnection authority under the
provisions of subsection (b) of this section must [shall]
not authorize a disconnection for nonpayment of electric service to
a delinquent residential customer for a billing period in which the
REP receives a pledge, letter of intent, purchase order, or other
notification that the energy assistance provider is forwarding sufficient
payment to continue service provided that such pledge, letter of intent,
purchase order, or other notification is received by the due date
stated on the disconnection notice, and the customer, by the due date
on the disconnection notice, either pays or makes payment arrangements
to pay any outstanding debt not covered by the energy assistance provider.
(2) If an energy assistance provider has requested
monthly usage data pursuant to §25.472(b)(4) of this title (relating
to Privacy of Customer Information), the REP must [shall]
extend the final due date on the disconnection notice, day for day,
from the date the usage data was requested until it is provided.
(3) A REP must [shall] allow
at least 45 days for an energy assistance provider to honor a pledge,
letter of intent, purchase order, or other notification before submitting
the disconnection request to the TDU.
(4) (No change.)
(j) Disconnection during extreme weather. A REP having
disconnection authority under the provisions of subsection (b) of
this section must [shall] not authorize a disconnection
for nonpayment of electric service for any customer in a county in
which an extreme weather emergency occurs. A REP must [shall
] offer residential customers a deferred payment plan upon request
by the customer that complies with the requirements of §25.480
of this title (relating to Bill Payment and Adjustments) for bills
that become due during the weather emergency.
(1) The term "extreme weather emergency" means [shall mean] a day when:
(A) - (B) (No change.)
(2) A TDU must [shall] notify
the commission of an extreme weather emergency in a method prescribed
by the commission, on each day that the TDU has determined that an
extreme weather emergency has been issued for a county in its service
area. The initial notice must [shall] include
the county in which the extreme weather emergency occurred and the
name and telephone number of the utility contact person.
(k) Disconnection of master-metered apartments. When a bill for electric service is delinquent for a master-metered apartment complex:
(1) The REP having disconnection authority under the
provisions of subsection (b) of this section must [shall]
send a notice to the customer as required by this subsection. At the
time such notice is issued, the REP, or its agents, must [shall] also inform the customer that notice of possible disconnection
will be provided to the tenants of the apartment complex in six days
if payment is not made before that time.
(2) At least six days after providing notice to the
customer and at least four days before disconnecting, the REP must [shall] post a minimum of five notices in English and Spanish
in conspicuous areas in the corridors or other public places of the
apartment complex. Language in the notice must [shall]
be in large type and must [shall] read: "Notice
to residents of (name and address of apartment complex): Electric
service to this apartment complex is scheduled for disconnection on
(date), because (reason for disconnection)."
(l) Disconnection notices. A disconnection notice for
nonpayment must [shall]:
(1) - (3) (No change.)
(4) include a statement notifying the customer that
if the customer needs assistance paying the bill by the due date,
or is ill and unable to pay the bill, the customer may be able to
make some alternate payment arrangement, establish a deferred payment
plan, or possibly secure payment assistance. The notice must [shall] also advise the customer to contact the provider for
more information.
(m) Contents of disconnection notice. Any disconnection
notice must [shall] include the following information:
(1) - (4) (No change.)
(5) A toll-free telephone number that the customer
can use to contact the REP to discuss the notice of disconnection
or to file a complaint with the REP, and the following statement:
"If you are not satisfied with our response to your inquiry or complaint,
you may file a complaint by calling or writing the Public Utility
Commission of Texas, P.O. Box 13326, Austin, Texas, 78711-3326; Telephone:
(512) 936-7120 or toll-free in Texas at (888) 782-8477. Hearing and
speech impaired individuals [with text telephones (TTY) ]
may contact the commission through Relay Texas at 1-800-735-2989 [at (512) 936-7136]. Complaints may also be filed electronically
at www.puc.texas.gov/ocp/complaints/complain.cfm;"
(6) - (8) (No change.)
(n) Reconnection of service. Upon a customer's satisfactory
correction of the reasons for disconnection, the REP must [shall] request the TDU, municipally owned utility, or electric
cooperative to reconnect the customer's electric service as quickly
as possible. The REP must [shall] inform the
customer when reconnection is expected to occur in accordance with
the timelines set forth in this subsection and in §25.214 of
this title (relating to Terms and Conditions of Retail Delivery Service
Provided by Investor Owned Transmission and Distribution Utilities).
For premises without a provisioned advanced meter with remote disconnect/reconnect
capabilities, if a REP submits a standard reconnect request and the
TDU completes the reconnect the same day, the TDU may [shall
] assess a standard reconnect fee. A TDU may assess a same-day
reconnect fee only when the REP expressly requests a same-day reconnect
and a REP may pass through a same-day reconnect fee to the customer
only when the customer expressly requests a same-day reconnect. A
REP must [shall] send a reconnection request
no later than the timelines in this subsection. The TDU must [shall] complete the reconnection in accordance with the timelines
in §25.214 of this title.
(1) For payments made before 12:00 p.m. on a business
day, a REP must [shall] send a reconnection
request to the TDU no later than 2:00 p.m. on the same day.
(2) For payments made after 12:00 p.m. but before 5:00
p.m. on a business day, a REP must [shall] send
a reconnection request to the TDU by 7:00 p.m. on the same day.
(3) For payments made after 5:00 p.m. but before 7:00
p.m. on a business day, a REP must [shall] send
a reconnection request to the TDU by 9:00 p.m. on the same day.
(4) For payments made after 7:00 p.m. on a business
day, a REP must [shall] send a reconnection
request to the TDU by 2:00 p.m. on the next business day.
(5) For payments made on a weekend day or a holiday,
a REP must [shall] send a reconnection request
to the TDU by 2:00 p.m. on the first business day after the payment
was made.
(6) In no event must [shall]
a REP fail to send a reconnection notice within 48 hours after the
customer's satisfactory correction of the reasons for disconnection
as specified in the disconnection
notice.
(o) Electric service disconnection of a non-submetered master metered multifamily property.
(1) (No change.)
(2) A REP must [shall] send a
written notice of service disconnection to a municipality before authorizing
disconnection of service to a non-submetered master metered multifamily
property for nonpayment if:
(A) - (B) (No change.)
(3) No later than January 1st of every year, a municipality
wishing to receive notice of disconnection of electric service to
a non-submetered master metered multifamily property must [shall] provide the commission with the contact information for
the municipality's authorized representative referenced by paragraph
(2) of this subsection by submitting that person's name, title, direct
mailing address, telephone number, and email address in a P.U.C. Project
Number to be established annually for that purpose. The email address
provided by the municipality may be for a general mailbox accessible
by the authorized representative established for the purpose of receiving
such notices.
(4) After January 1st, but no later than January 15th
of every year, the commission must [shall] post
on its public website the contact information received from every
municipality pursuant to paragraph (3) of this subsection. The contact
information posted by the commission must [shall]
remain in effect during the subsequent 12-month period of February
1 through January 31 for the purpose of the written notice of disconnection
required by paragraph (2) of this subsection.
(5) The retail electric provider must [shall
] email the written notice required by this subsection to the
municipality's authorized representative not later than the 10th day
before the date electric service is scheduled for disconnection. Additional
notice may be provided by third-party commercial carrier delivery
or certified mail.
(6) - (7) (No change.)
§25.486Customer Protections for Brokerage Services.
(a) - (j) (No change.)
(k) Client Access and Complaint Handling.
(1) Client Access. Each broker must ensure that clients
have reasonable access to its service representatives to make inquiries
and complaints, discuss charges on bills or any other aspect of the
brokerage services provided to the client by the broker, terminate
an agreement to provide services, and transact any other pertinent
business. A broker must promptly investigate client complaints and
advise the complainant of the results. A broker must inform the complainant
of the commission's informal complaint resolution process and the
following contact information for the commission within 21 days of
receiving the complaint: Public Utility Commission of Texas, Customer
Protection Division, P.O. Box 13326, Austin, Texas 78711-3326; (512)
936-7120 or in Texas (toll-free) 1-888-782-8477, fax (512) 936-7003,
e-mail address: customer@puc.texas.gov, Internet website address:
www.puc.texas.gov, [TTY (512) 936-7136,] and Relay Texas
(toll-free) 1-800-735-2989.
(2) (No change.)
(3) Informal Complaints.
(A) A person may file an informal complaint with the
commission by contacting the commission at: Public Utility Commission
of Texas, Customer Protection Division, P.O. Box 13326, Austin, Texas
78711-3326; (512) 936-7120 or in Texas (toll-free) 1-888-782-8477,
fax (512) 936-7003, e-mail address: customer@puc.texas.gov, Internet
website address: www.puc.texas.gov, [TTY (512) 936-7136, ]
and Relay Texas (toll-free) 1-800-735-2989.
(B) - (G) (No change.)
(4) (No change.)
(l) (No change.)
The agency certifies that legal counsel has reviewed the proposal and found it to be within the state agency's legal authority to adopt.
Filed with the Office of the Secretary of State on April 27, 2023.
TRD-202301518
Adriana Gonzales
Rules Coordinator
Public Utility Commission of Texas
Earliest possible date of adoption: June 11, 2023
For further information, please call: (512) 936-7322