Current through Register Vol. 49, No. 6, March 15, 2024
PURPOSE: This rule allows the establishment and
operation of Demand-Side Programs Investment Mechanisms (DSIM), which allow
periodic rate adjustments related to recovery of costs and utility incentives
for investments in demand-side programs.
(1) The definitions of terms used in this
section can be found in
4 CSR
240-20.092 Definitions for Demand-Side Programs and
Demand-Side Programs Investment Mechanisms.
(2) Applications to establish, continue, or
modify a Demand-Side Programs Investment Mechanism (DSIM). Pursuant to the
provisions of this rule,
4 CSR
240-2.060, and section
393.1075,
RSMo, an electric utility shall file an application with the commission to
establish, continue, or modify a DSIM in a utility's filing for demand-side
program approval.
(A) An application to
establish a DSIM shall include the following supporting information as part of,
or in addition to, its direct testimony. Supporting workpapers shall be
submitted with all models and spreadsheets provided as executable versions in
native format with all links and formulas intact.
1. The notice provided to customers
describing how the proposed DSIM will work, how any proposed DSIM rate will be
determined, and how any DSIM rate will appear on customers' bills;
2. An example customer bill showing how the
proposed DSIM shall be separately identified on affected customers'
bills;
3. A complete, reasonably
detailed, description and explanation of the design, rationale, and intended
operation of the proposed DSIM;
4.
Estimates of the effect of the DSIM and all other impacts of the demand-side
program spending, in aggregate, on customer rates and average bills for each of
the next five (5) years, and as a net present value of net benefits over the
lifetime of the demand-side program impacts, for each rate class;
5. Estimates of the effect of the DSIM on
earnings and key credit metrics for each of the next three (3) years including
the level of earnings and key credit metrics expected to occur for each of the
next three (3) years with and without the DSIM;
6. A complete, reasonably detailed,
explanation of all the costs that shall be considered for recovery under the
proposed DSIM and the specific account used for each cost item on the electric
utility's books and records;
7. A
complete, reasonably detailed, explanation of any change in business risk to
the electric utility resulting from implementation of a DSIM in setting the
electric utility's allowed return on equity, in addition to any other changes
in business risk experienced by the electric utility;
8. A proposal for how the commission can
determine if the DSIM is aligned with helping customers use energy more
efficiently;
9. If the utility
proposes to adjust its DSIM rates between general rate proceedings, proposed
DSIM rate adjustment clause tariff sheets; and
10. If the utility proposes to adjust the
DSIM amount between general rate proceedings, a complete, reasonably detailed,
explanation of how the DSIM rates shall be established and how they will be
adjusted for any over- and/or under-recovery amounts, as well as the impact on
the DSIM amount as a result of, established, modified, or discontinued
demand-side programs.
(B) If an electric utility files to modify
its approved DSIM, the electric utility shall file with the commission and
serve upon parties, as provided in section (15) below, the following supporting
information as part of, or in addition to, direct testimony. Supporting
workpapers shall be submitted with all models and spreadsheets provided as
executable versions in native format with all links and formulas intact;
1. Information as required by subsection
(2)(A), above;
2. Explanation of
any proposed modification to the DSIM and why the proposed modification is
being requested;
3. A complete,
reasonably detailed, explanation of any change in business risk to the electric
utility resulting from modification of a DSIM in setting the electric utility's
allowed return on equity, in addition to any other changes in business risk
experienced by the electric utility; and
4. Any additional information the commission
orders to be provided.
(C) Any party to the application for a
utility's filing for demand-side program approval may support or oppose the
establishment, continuation, or modification of a DSIM and/or may propose an
alternative DSIM for the commission's consideration including, but not limited
to, modifications to any electric utility's proposed DSIM.
(D) The commission shall approve the
establishment, continuation, or modification of a DSIM and associated tariff
sheets if it finds the electric utility's approved demand-side programs are
expected to result in energy and demand savings and are beneficial to all
customers in the customer class in which the programs are proposed, regardless
of whether the programs are utilized by all customers and will assist the
commission's efforts to implement state policy contained in section
393.1075,
RSMo, to-
1. Provide the electric utility
with timely recovery of all reasonable and prudent costs of delivering
cost-effective demand-side programs;
2. Ensure that utility financial incentives
are aligned with helping customers use energy more efficiently and in a manner
that sustains or enhances utility customers' incentives to use energy more
efficiently; and
3. Provide timely
earnings opportunities associated with cost-effective measurable and/or
verifiable energy and demand savings;
(E) In addition to any other changes in
business risk experienced by the electric utility, the commission shall
consider changes in the utility's business risk resulting from establishment,
continuation, or modification of the DSIM in setting the electric utility's
allowed return on equity in general rate proceedings.
(F) In determining to approve a request to
establish, modify, or continue a DSIM, the commission may consider, but is not
limited to only considering, the expected magnitude of the impact of the
utility's approved demand-side programs on the utility's costs, revenues, and
earnings, the ability of the utility to manage all aspects of the approved
demand-side programs, the ability to measure and verify the approved
demand-side programs' impacts, any interaction among the various components of
the DSIM that the utility may propose, and the incentives or disincentives
provided to the utility as a result of the inclusion or exclusion of DSIM
components as defined in
4 CSR
240-20.092(N). In this context the
word "disincentives" means any barrier to the implementation of a DSIM. There
is no penalty authorized in this section.
(G) Any cost recovery component of a DSIM
shall be based on costs of demand-side programs approved by the commission in
accordance with 4 CSR 240-20.094 Demand-Side
Programs. Indirect costs associated with demand-side programs, including but
not limited to, costs of evaluation, measurement, and verification (EM&V),
and/or utility's portion of statewide technical reference manual, shall be
allocated to demand-side programs and thus shall be eligible for recovery
through an approved DSIM. The commission shall approve any cost recovery
component of a DSIM simultaneously with the programs approved in accordance
with 4 CSR
240-20.094 Demand-Side Programs.
(H) Any throughput disincentive component of
DSIM shall be based on energy or energy and demand savings from utility
demand-side programs approved by the commission in accordance with
4 CSR
240-20.094 Demand-Side Programs and will be determined
as a result of energy and demand savings determined through EM&V.
1. The commission shall order any throughput
disincentive component of a DSIM simultaneously with the demand-side programs
approved in accordance with
4 CSR
240-20.094 Demand-Side Programs.
2. In a utility's filing in which a
throughput disincentive component of a DSIM is considered, there is no
requirement for any implicit or explicit utility throughput disincentive
component of a DSIM or for a particular form of a throughput disincentive
component of a DSIM.
3. Any
explicit throughput disincentive component of a DSIM shall be implemented on a
prospective basis.
(I)
Any earnings opportunity component of a DSIM shall be based on the performance
of demand-side programs approved by the commission in accordance with
4 CSR
240-20.094 Demand-Side Programs and shall include a
methodology for determining the utility's earnings opportunity amount for
individual demand-side programs based upon program performance relative to
commission-approved performance metrics for each demand-side program.
1. Energy and demand savings targets approved
by the commission for use in the earnings opportunity component of a DSIM are
not necessarily the same as the incremental energy and demand savings goals and
cumulative energy and demand savings goals specified in
4 CSR
240-20.094(2).
2. The commission shall order any earnings
opportunity component of a DSIM simultaneously with the approval of the
demand-side programs in accordance with
4 CSR
240-20.094 Demand-Side Programs.
3. Any earnings opportunity component of a
DSIM shall be implemented on a retrospective basis and all energy and demand
savings used to determine a DSIM earnings opportunity amount must be measured
and verified through EM&V.
(J) If the DSIM proposed by the utility
includes adjustments to DSIM rates between general rate proceedings, the DSIM
shall include a provision to adjust the DSIM rates not less than annually to
include a true-up for over- and under-recovery of the DSIM amount as well as
the impact on the DSIM amount as a result of approved new, modified, or
discontinued demand-side programs.
(K) If the commission approves an earnings
opportunity component of a DSIM, such earnings opportunity component shall be
binding on the commission for the entire term of the DSIM, and such DSIM shall
be binding on the electric utility for the entire term of the DSIM, unless
otherwise ordered or conditioned by the commission when approved.
(L) The commission shall apportion the DSIM
amount to each customer class.
(3) Application for Discontinuation of a
DSIM. The commission shall allow or require a DSIM to be discontinued or any
component of a DSIM to be discontinued only after providing the opportunity for
a hearing.
(A) When submitting an application
to discontinue a DSIM, the electric utility shall file with the commission and
serve on parties as provided in section (15), the following supporting
information as part of, or in addition to, direct testimony. Supporting
workpapers shall be submitted with all models and spreadsheets provided as
executable versions in native format with all links and formulas intact:
1. An example of the notice to be provided to
customers;
2. If the utility's DSIM
allows adjustments of the DSIM rates between general rate proceedings, a
complete, reasonably detailed, explanation of how the over-/under-recovery of
the DSIM amount that the electric utility is proposing to discontinue shall be
handled;
3. A complete, reasonably
detailed, explanation of why the DSIM is no longer necessary to provide the
electric utility a sufficient opportunity to recover demand-side programs
costs, throughput disincentive, and/or to receive an earnings
opportunity;
4. A complete,
reasonably detailed, explanation of any change in business risk to the electric
utility resulting from discontinuation of the DSIM in setting the electric
utility's allowed return on equity, in addition to any other changes in
business risk experienced by the electric utility; and
5. Any additional information the commission
orders to be provided.
(B) Any party to the utility's filing for
demand-side program approval may oppose the discontinuation of a DSIM or any
component of a DSIM.
(C) In
addition to any other changes in business risk experienced by the electric
utility, the commission may take into account any change in business risk to
the electric utility resulting from discontinuance of the DSIM in setting the
electric utility's allowed return on equity in a general rate
proceeding.
(D) If the utility
requests that cost recovery be discontinued, in its notice to customers, the
electric utility shall include a commission-approved description of why it
believes the cost recovery component of the DSIM should be
discontinued.
(4)
Requirements for Adjustments of DSIM Rates Between General Rate Proceedings. An
electric utility with a DSIM shall file to adjust its DSIM rated no less often
than annually.
(A) The electric utility shall
file tariff sheets to adjust its DSIM rates accompanied by supporting testimony
and contain at least the following supporting information. All models and
spreadsheets shall be provided as executable versions in native format with all
links and formulas intact.
1. Amount of
revenue that it has over/under-recovered through the most recent recovery
period by rate class.
2. Proposed
positive or negative adjustments by rate class.
3. Electric utility's short-term borrowing
rate.
4. Proposed adjustments to
the current DSIM rates.
5. Complete
documentation for the proposed adjustments to the current DSIM rates.
6. Any additional information the commission
ordered to be provided.
(B) The staff shall examine and analyze the
information filed by the electric utility and additional information obtained
through discovery, if any, to determine if the proposed adjustments to the DSIM
amount and DSIM rates are in accordance with the provisions of this rule,
section
393.1075,
RSMo, and the DSIM established, modified, or continued in the most recent
filing for demand-side program approval. The staff shall submit a
recommendation regarding its examination and analysis to the commission not
later than thirty (30) days after the electric utility files its tariff sheets
to adjust its DSIM rates. If the adjustments to the DSIM rates are in
accordance with the provisions of this rule, section
393.1075,
RSMo, and the DSIM established, modified, or continued in the most recent
filing for demand-side program approval, the commission shall either issue an
interim rate adjustment order approving the tariff sheets within sixty (60)
days of the electric utility's filing or, if no such order is issued, the
adjustments to the DSIM rates shall take effect sixty (60) days after the
tariff sheets were filed. If the adjustments to the DSIM rates are not in
accordance with the provisions of this rule, section
393.1075,
RSMo, or the DSIM established, modified, or continued in the most recent filing
for demand-side program approval, the commission shall reject the proposed
tariff sheets within sixty (60) days of the electric utility's filing and may
instead order the filing of interim tariff sheets that implement its
decision.
(C) Adjustments to the
DSIM rates shall reflect a comprehensive measurement of both increases and
decreases to the DSIM amount established in the most recent demand-side program
approval or DSIM rate adjustment case plus the increases and decreases to the
DSIM amount which occurred since the most recent demand-side program approval
or DSIM rate adjustment case. All DSIM rate adjustments shall include a true-up
of past DSIM collections based on the latest EM&V results where applicable.
Any over-/under-recovered amounts will be accounted for in the going forward
DSIM rates.
(D) The electric
utility shall be current on its submission of its Surveillance Monitoring
Reports as required in section (10) and its annual reports as required in
section (9) in order to increase the DSIM rates.
(E) If the staff, public counsel, or other
party believes the electric utility has not met the filing requirements of
subsection (4)(A), it shall notify the electric utility within ten (10) days of
the electric utility's filing of an application or tariff sheets to adjust DSIM
rates and identify the information required. The electric utility shall submit
the information identified by the party, or shall notify the party that it
believes the information submitted was in compliance with the requirements of
subsection (4)(A), within ten (10) days of the request. A party who notifies
the electric utility it believes the electric utility has not submitted all the
information required by subsection (4)(A) and as ordered by the commission in a
previous proceeding and receives notice from the electric utility that the
electric utility believes it has submitted all required information may file a
motion with the commission for an order directing the electric utility to
produce that information, i.e., a motion to compel. While the commission is
considering the motion to compel, the processing timeline for the adjustment to
increase DSIM rates shall be suspended. If the commission then issues an order
requiring the information be submitted, the time necessary for the information
to be submitted shall further extend the processing timeline for the adjustment
to increase DSIM rates. For good cause shown, the commission may further
suspend this timeline. Any delay in submitting sufficient information in
compliance with subsection (4)(A) or a commission order in a previous
proceeding in a request to decrease DSIM rates shall not alter the processing
timeline.
(5)
Implementation of DSIM. Once a DSIM is established, modified, or discontinued,
in lieu of contemporaneous rate recovery the utility may request use of
deferral accounting for MEEIA financial impacts using the utility's latest
approved weighted average cost of capital until the cut-off date for cost
recognition ordered in the utility's next general rate proceeding.
(6) Duration of DSIM. Once a DSIM is approved
by the commission, it shall remain in effect for the term established by the
commission in the order approving that DSIM so as to allow full recovery of all
DSIM amounts. During the term of an approved DSIM the utility or any party to
the application for the utility's filing for approval of a demand-side program
may propose modifications to the DSIM. No modification of a utility's DSIM
shall be made without the assent of the utility.
(7) Disclosure. Regardless of whether or not
the utility requests adjustments of its DSIM rates between general rate
proceedings, any amounts charged under a DSIM approved by the commission,
including any earnings opportunity allowed by the commission, shall be
separately disclosed on each customer's bill. Proposed language regarding this
disclosure shall be submitted to and approved by the commission before it
appears on customers' bills. The disclosure shall also appear on the utility's
websites.
(8) Evaluation,
Measurement, and Verification (EM&V) of the Process and Impact of
Demand-Side Programs. Each electric utility shall hire an independent
contractor to perform and report EM&V of each commission-approved
demand-side program in accordance with
4 CSR
240-20.094 Demand-Side Programs. The utility shall
provide oversight and guidance to the independent EM&V contractor, but
shall not influence the independent EM&V contractor's report(s). The
commission shall hire an independent contractor to audit and report on the work
of each utility's independent EM&V contractor. The commission staff shall
provide oversight and guidance to the independent commission contractor, but
shall not influence the independent contractor's audit(s). Staff counsel shall
provide legal representation to the independent contractor in the event the
independent contractor is required to testify before the commission.
(A) Each utility's EM&V budget shall not
exceed five percent (5%) of the utility's total budget for all approved
demand-side program costs.
(B) The
cost of the commission's EM&V contractor shall-
1. Not be a part of the utility's budget for
demand-side programs; and
2. Be
included in the Missouri Public Service Commission Assessment for each
utility.
(C) EM&V
draft reports from the utility's contractor for each approved demand-side
program shall be delivered simultaneously to the utility and to parties of the
case in which the demand-side program was approved.
(D) EM&V final reports from the utility's
contractor of each approved demand-side program shall-
1. Document, include analysis, and present
any applicable recommendations for at least the following. All models and
spreadsheets shall be provided as executable versions in native format with all
links and formulas intact:
A. Process
evaluation and recommendations, if any; and
B. Impact evaluation-
(I) The annual gross and net demand savings
and energy savings achieved under each demand-side program and the techniques
used to estimate annual demand savings and energy savings;
(II) For demand-side programs subject to
cost-effectiveness tests, include total resource cost test, societal cost test,
utility cost test, participant cost test, and nonparticipant cost test of each
demand-side program; and
(III)
Determine the net benefits achieved for each demand-side program subject to
cost-effectiveness tests and for the portfolio of such programs using the
utility cost test (UCT) methodology;
2. Be completed by the EM&V contractor on
a schedule approved by the commission at the time of demand-side program
approval in accordance with
4 CSR
240-20.094(4); and
3. Be filed with the commission in the case
in which the utility's demand-side program approval was received and delivered
simultaneously to the utility and the parties of the case in which the
demand-side program was approved.
(E) Electric utility's EM&V contractors
shall-
1. Include specific methodology for
performing EM&V work; and
2.
Utilize the TRM approved with the utility's application for its DSIM and
demand-side portfolio.
(9) Demand-Side Program Annual Report. Each
electric utility with one (1) or more approved demand-side programs shall file
an annual report by no later than ninety (90) days after the end of each
program year, make a public version available for publication on the
commission's website, and serve a copy on each party to the case in which the
demand-side programs were last established, modified, or continued. Interested
parties may file comments with the commission concerning the content of the
utility's annual report within thirty (30) days of its filing. Annual reports
shall include at a minimum the following information, and all models and
spreadsheets shall be provided as executable versions in native format with all
links and formulas intact:
(A) An affidavit
attesting to the veracity of the information; and
(B) A list of all approved demand-side
programs and the following information for each approved demand-side program:
1. Actual amounts expended by year, including
customer incentive payments;
2.
Peak demand and energy savings impacts and the techniques used to estimate
those impacts;
3. A comparison of
the estimated actual annual peak demand and energy savings impacts to the
annual demand and energy savings targets approved by the commission under
4 CSR
240-20.094(4)(I) or
4 CSR
240-20.094(5)(A) 5.;
4. For market transformation demand-side
programs, a quantitative and qualitative assessment of the progress being made
in transforming the market;
5. A
comparison of actual and budgeted demand-side program costs, including an
explanation of any increase or decrease of more than twenty percent (20%) in
the cost of a demand-side program;
6. The avoided costs and the techniques used
to estimate those costs;
7. The
estimated cost-effectiveness of the demand-side program and a comparison to the
estimates made by the utility at the time the demand-side program was
approved;
8. The estimated net
benefits of each demand-side program and the demand-side portfolio;
9. For each demand-side program where one (1)
or more customers have opted out of demand-side programs pursuant to section
393.1075.7, RSMo, a listing of the customer(s) who have opted out of
participating in demand-side programs;
10. As part of its annual report, the
electric utility shall file or provide a reference to the commission case that
contains a copy of the EM&V report for the most recent annual reporting
period; and
11. Demonstration of
relationship of the demand-side programs to demand-side resources in latest
filed 4 CSR 240-22 compliance filing.
(10) Submission of Surveillance Monitoring
Reports. Each electric utility with an approved DSIM shall submit to staff,
public counsel, and parties approved by the commission a Surveillance
Monitoring Report. Each electric utility with a DSIM shall submit, as page 6 of
the Surveillance Monitoring Report, a quarterly progress report in a format
agreed upon by the utility and staff, and all models and spreadsheets shall be
provided as executable versions in native format with all links and formulas
intact. The report shall be submitted to the staff, public counsel, and
stakeholders approved by the commission.
(A)
The Surveillance Monitoring Report shall be submitted within fifteen (15) days
of the electric utility's next scheduled United States Securities and Exchange
Commission (SEC) 10-Q or 10-K filing with the initial submission within fifteen
(15) days of the electric utility's next scheduled SEC 10-Q or 10-K filing
following the effective date of the commission order establishing the
DSIM.
(B) If the electric utility
also has an approved environmental cost recovery mechanism or a fuel cost
adjustment mechanism, the electric utility shall submit a single Surveillance
Monitoring Report for all mechanisms.
(C) Upon a finding that a utility has
knowingly or recklessly provided materially false or inaccurate information to
the commission regarding the surveillance data prescribed in this section,
after notice and an opportunity for a hearing, the commission may suspend a
DSIM or order other appropriate remedies as provided by law.
(D) Disagreements about the report format or
content shall be settled by the commission.
(11) Prudence Reviews. A prudence review of
the costs subject to the DSIM shall be conducted no less frequently than at
twenty-four-(24-) month intervals.
(A) All
amounts ordered refunded by the commission shall include interest at the
electric utility's short-term borrowing rate.
(B) The staff shall submit a recommendation
regarding its examination and analysis to the commission not later than one
hundred fifty (150) days after the staff initiates its prudence audit. The
timing and frequency of prudence audits for DSIM shall be established in the
utility's filing for demand-side program approval in which the DSIM is
established. The staff shall file notice within ten (10) days of starting its
prudence audit. The commission shall issue an order not later than two hundred
ten (210) days after the staff commences its prudence audit if no party to the
proceeding in which the prudence audit is occurring files, within one hundred
sixty (160) days of the staff's commencement of its prudence audit, a request
for a hearing.
1. If the staff, public
counsel, or other party auditing the DSIM believes that insufficient
information has been supplied to make a recommendation regarding the prudence
of the electric utility's DSIM, it may utilize discovery to obtain the
information it seeks. If the electric utility does not timely supply the
information, the party asserting the failure to provide the required
information must timely file a motion to compel with the commission. While the
commission is considering the motion to compel, the processing timeline shall
be suspended. If the commission then issues an order requiring the information
to be provided, the time necessary for the information to be provided shall
further extend the processing timeline. For good cause shown, the commission
may further suspend this timeline.
2. If the timeline is extended due to an
electric utility's failure to timely provide sufficient responses to discovery
and a refund is due to the customers, the electric utility shall refund all
imprudently incurred costs plus interest at the electric utility's short-term
borrowing rate.
(12) Tariffs and Regulatory Plans. The
provisions of this rule shall not affect-
(A)
Any adjustment mechanism, rate schedule, tariff, incentive plan, or other
ratemaking mechanism that was approved by the commission and in effect prior to
the effective date of this rule; and
(B) Any experimental regulatory plan that was
approved by the commission and in effect prior to the effective date of this
rule.
(13) Nothing in
this rule shall preclude a complaint case from being filed, as provided by
law.
(14) Variances. Upon request
and for good cause shown, the commission may grant a variance from any
provision of this rule.
(15) Party
status and providing to other parties affidavits, testimony, information,
reports, and workpapers in related proceedings subsequent to the utility's
filing for demand-side program approval, modification, or continuation of a
DSIM.
(A) A person or entity granted
intervention in a utility's filing for demand-side program approval in which a
DSIM is approved by the commission shall have the right to be a party to any
subsequent related periodic rate adjustment proceeding without the necessity of
applying to the commission for intervention; however, such person or entity
shall file a notice of intention to participate within the intervention period.
Public Counsel and the commission's staff do not need to file a notice of
intention to participate. In any subsequent utility's filing for demand-side
program approval, such person or entity must seek and be granted status as an
intervenor to be a party to that proceeding.
(B) Affidavits, testimony, information,
reports, and workpapers to be filed or submitted in connection with a
subsequent related annual DSIM rate adjustment proceeding or utility's filing
for demand-side program approval to modify, continue, or discontinue the same
DSIM shall be served on or submitted to all parties from the prior related
demand-side program approval proceeding and on all parties from any subsequent
related periodic rate adjustment proceeding or utility's filing for demand-side
program approval to modify, continue, or discontinue the same DSIM,
concurrently with filing the same with the commission or submitting the same to
the manager of the energy resource analysis section of the staff and public
counsel.
(C) A person or entity not
a party to the utility's filing for demand-side program approval in which a
DSIM is approved by the commission may timely apply to the commission for
intervention, pursuant to
4 CSR
240-2.075(2) through (4) of the
commission's rule on intervention, respecting any related subsequent periodic
rate adjustment proceeding or, pursuant to
4 CSR
240-2.075(1) through (5), respecting
any subsequent utility's filing for demand-side program approval to modify,
continue, or discontinue the same DSIM.
(16) Missouri Energy Efficiency Investment
Act (MEEIA) Rate Design Modifications.
(A) An
electric utility may request modification of its DSIM rates by filing tariff
schedule(s) with the commission as part of-
1. An application for approval of demand-side
programs or a demand-side program plan and a DSIM; or
2. A general rate case proceeding.
(B) Any request for modification
of a rate design shall include with the filing supporting documentation for the
request, including but not limited to, workpapers, data, computer model
documentation, analysis, and other supporting information to support and
explain the modification of the rate design. All information shall be labeled
and all spreadsheets shall be provided as executable versions with all links
and formulas intact.
(C) Right to
Discovery Unaffected. In addressing certain discovery matters and the provision
of certain information by electric utilities, this rule is not intended to
restrict the discovery rights of any party.
*Original authority: 393.1075, RSMo
2009.