Florida Public Service Commission native order document 09741-2024

FILED 10/31/2024
DOCUMENT NO. 09741-2024
FPSC - COMMISSION CLERK
BEFORE THE FLORIDA PUBLIC SERVICE COMMISSION
In re: Fuel and purchased power cost recovery
clause with generating performance incentive
factor.
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DOCKET NO. 20240001-EI
ORDER NO. PSC-2024-0465-PHO-EI
ISSUED: October 31, 2024
PREHEARING ORDER
Pursuant to Notice and in accordance with Rule 28-106.209, Florida Administrative Co de
(F.A.C.), a Prehearing Conference was held on October 24, 2024, in Tallahassee, Florida, before
Commissioner Gabriella Passidomo, as Prehearing Officer.
APPEARANCES:
MATTHEW BERNIER, and STEPHANIE CUELLO, 	ESQUIRES, 	106 East
College Avenue, Suite 800, Tallahassee, Florida 32301-7740; and DIANNE M .
TRIPLETT, ESQUIRE, 299 First Avenue North, St. Petersburg, Florida 33701
On behalf of Duke Energy Florida, LLC (DEF).
MARIA 	JOSE 	MONCADA, 	WILLIAM 	P. 	COX, 	and 	DAVID 	M. 	LEE,
ESQUIRES, Florida Power & Light Company, 700 Universe Boulevard, Juno
Beach, Florida 33408-0420
On behalf of Florida Power & Light Company (FPL).
BETH KEATING, ESQUIRE, Gunster, Yoakley & Stewart, P.A., 215 South
Monroe St., Suite 601, Tallahassee, Florida 32301
On behalf of Florida Public Utilities Company (FPUC).
MALCOLM N. 	MEANS, J. JEFFRY WAHLEN, and 	VIRGINIA PONDER,
ESQUIRES, Ausley McMullen, Post Office Box 391, Tallahassee, Florida 32302
On behalf of Tampa Electric Company (TECO).
WALT 	TRIERWEILER, 	CHARLES 	REHWINKEL, 	PATRICIA 	A.
CHRISTENSEN, 	MARY 	WESSLING, 	OCTAVIO 	SIMOES-PONCE, 	and
AUSTIN WATROUS, ESQUIRES, Office of Public Counsel, c/o The Florida
Legislature, 111 West Madison Street, Room 812, Tallahassee, Florida 32399-
1400
On behalf of the Citizens of the State of Florida (OPC).
JON C. MOYLE, JR., and KAREN A. PUTNAL, ESQUIRES, Moyle Law Firm,
PA, The Perkins House, 11 8 North Gadsden Street, Tallahassee, Florida 32301
On behalf of the Florida Industrial Power Users Group (FIPUG).

ORDER NO. PSC-2024-0465-PHO-EI
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ROBERT SCHEFFEL WRIGHT and JOHN T. LAVIA, III, ESQUIRES, Gardner
Bist, Bowden, Dee, LaVia, Wright, Perry, and Harper, PA., 1300 Thomaswood
Drive, Tallahassee, Florida 32308
On behalf of Florida Retail Federation (FRF).
JAMES W. BREW, LAURA WYNN BAKER, and SARAH B. NEWMAN,
ESQUIRES, Stone Mattheis Xenopoulos & Brew, PC, 1025 Thomas Jefferson
St., NW, Eighth Floor, West Tower, Washington, DC 20007
On behalf of White Springs Agricultural Chemicals, Inc. d/b/a PCS Phosphate –
White Springs (PCS Phosphate).
PETER J. MATTHEIS, MICHAEL K. LAVANGA, and JOSEPH R. BRISCAR,
ESQUIRES, Stone Mattheis Xenopoulos & Brew, PC, 1025 Thomas Jefferson
St., NW, Eighth Floor, West Tower, Washington, DC 20007
On behalf of Nucor Steel Florida, Inc. (NUCOR).
SUZANNE BROWNLESS, and RYAN SANDY, ESQUIRES, Florida Public
Service Commission, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-
0850
On behalf of the Florida Public Service Commission (Staff).
MARY ANNE HELTON, ESQUIRE, Deputy General Counsel, Florida Public
Service Commission, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-
0850
Advisor to the Florida Public Service Commission.
KEITH C. HETRICK, ESQUIRE, General Counsel, Florida Public Service
Commission, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850
Florida Public Service Commission General Counsel.
I. 	CASE BACKGROUND
As 	part 	of 	the 	continuing 	fuel 	and 	purchased 	power 	adjustment 	and 	generating
performance incentive clause proceedings, an administrative hearing will be held by the Florida
Public Service Commission (Commission) on November 5-7, 2024. The purpose of this docket is
to review and approve purchased wholesale electric power charges, electric generation facilities’
fuel and fuel related costs, and incentives associated with the efficient operation of generation
facilities which are passed through to ratepayers through the fuel adjustment factor. The
Commission will address those issues listed in this prehearing order. The Commission has the
option to render a bench decision with agreement of the parties on any or all of the issues listed
below.

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II. 	CONDUCT OF PROCEEDINGS
Pursuant to Rule 28-106.211, F.A.C., this Prehearing Order is issued to prevent delay and
to promote the just, speedy, and inexpensive determination of all aspects of this case.
III. 	JURISDICTION
This Commission is vested with jurisdiction over the subject matter by the provisions of
Chapter 366, Florida Statutes (F.S.). 	This hearing will be governed by said Chapter, Chapter
120, F.S., and Chapters 25-6, 25-22, and 28-106, F.A.C., as well as any other applicable
provisions of law.
IV. 	PROCEDURE FOR HANDLING CONFIDENTIAL INFORMATION
Information for which proprietary confidential business information status is requested
pursuant to Section 366.093, F.S., and Rule 25-22.006, F.A.C., shall be treated by the
Commission as confidential. 	The information shall be exempt from Section 119.07(1), F.S.,
pending a formal ruling on such request by the Commission or pending return of the information
to the person providing the information. 	If no determination of confidentiality has been made
and the information has not been made a part of the evidentiary record in this proceeding, it shall
be returned to the person providing the information. 	If a determination of confidentiality has
been made and the information was not entered into the record of this proceeding, it shall be
returned to the person providing the information within the time period set forth in Section
366.093, F.S. 	The Commission may determine that continued possession of the information is
necessary for the Commission to conduct its business.
It is the policy of this Commission that all Commission hearings be open to the public at
all times. 	The Commission also recognizes its obligation pursuant to Section 366.093, F.S., to
protect proprietary confidential business information from disclosure outside the proceeding.
Therefore, any party wishing to use any proprietary confidential business information, as that
term is defined in Section 366.093, F.S., at the hearing shall adhere to the following:
(1) 	When confidential information is used in the hearing that has not been filed as
prefiled 	testimony 	or 	prefiled 	exhibits, 	parties 	must 	have 	copies 	for 	the
Commissioners, necessary staff, and the court reporter, in red envelopes clearly
marked with the nature of the contents and with the confidential information
highlighted. 	Any party wishing to examine the confidential material that is not
subject to an order granting confidentiality shall be provided a copy in the same
fashion as provided to the Commissioners, subject to execution of any appropriate
protective agreement with the owner of the material.

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(2) 	Counsel and witnesses are cautioned to avoid verbalizing confidential information
in such a way that would compromise confidentiality. 	Therefore, confidential
information should be presented by written exhibit when reasonably possible.
At the conclusion of that portion of the hearing that involves confidential information, all
copies of confidential exhibits shall be returned to the proffering party. If a confidential exhibit
has been admitted into evidence, the copy provided to the court reporter shall be retained in the
Office of Commission Clerk’s confidential files. If such material is admitted into the evidentiary
record at hearing and is not otherwise subject to a request for confidential classification filed
with the Commission, the source of the information must file a request for confidential
classification of the information within 21 days of the conclusion of the hearing, as set forth in
Rule 25-22.006(8)(b), F.A.C., if continued confidentiality of the information is to be maintained.
V. 	PREFILED TESTIMONY AND EXHIBITS; WITNESSES
Testimony of all witnesses to be sponsored by the parties has been prefiled and will be
inserted into the record as though read after the witness has taken the stand and affirmed the
correctness of the testimony and associated exhibits. All testimony remains subject to timely and
appropriate objections. 	Upon insertion of a witness’ testimony, exhibits appended thereto may
be marked for identification. Each witness will have the opportunity to orally summarize his or
her testimony at the time he or she takes the stand. Summaries of testimony shall be limited to
three minutes.
Witnesses are reminded that, on cross-examination, responses to questions calling for a
simple yes or no answer shall be so answered first, after which the witness may explain his or her
answer. 	After all parties and Staff have had the opportunity to cross-examine the witness, the
exhibit may be moved into the record. All other exhibits may be similarly identified and entered
into the record at the appropriate time during the hearing.
The Commission frequently administers the testimonial oath to more than one witness at
a time. 	Therefore, when a witness takes the stand to testify, the attorney calling the witness is
directed to ask the witness to affirm whether he or she has been sworn.
The parties shall avoid duplicative or repetitious cross-examination. Further, friendly
cross-examination will not be allowed. 	Cross-examination shall be limited to witnesses whose
testimony is adverse to the party desiring to cross-examine. Any party conducting what appears
to be a friendly cross-examination of a witness should be prepared to indicate why that witness’s
direct testimony is adverse to its interests.

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DOCKET NO. 20240001-EI
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VI. 	ORDER OF WITNESSES
Witness 	Proffered By 	Issues #
Direct
+Gary P. Dean 	DEF 	1B-1C, 5-10, 16-20,
21A, and 24-32
+Adam R. Bingham 	DEF 	14 and 15
+James (“Jim”) McClay 	DEF 	1A
+Amin Mohomed 	FPL 	2E, 2H, 7-10, 16-20, 22A
+Michael V. Cashman 	FPL 	2A-2D, 2F, 5-10
+Daniel DeBoer 	FPL 	10
+Charles Rote 	FPL 	14, 15
+Kelly Fagan 	FPL 	2G
+Andrew W. Whitley 	FPL 	2G
+Edward J. Anderson 	FPL 	2I, 2J
+Brittnee Baker* 	FPUC 	7
+Brittnee Baker 	FPUC 	8, 9, 10, 16, 17, 18, 19, 20,
31,32,33
+P. Mark Cutshaw 	FPUC 	9, 10
+Zel D. Jones 	TECO 	5-10, 16-20, 24-30, 31-33
+Elena B. Vance 	TECO 	14, 15
+Benjamin F. Smith 	TECO 	28
+John C. Heisey 	TECO 	4A, 4B, 16
* Adopting the testimony of Phuong T. Nguyen.
+ These witnesses have been excused from attending the final hearing.

ORDER NO. PSC-2024-0465-PHO-EI
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VII. 	BASIC POSITIONS
DEF: 	Not applicable. DEF’s positions on specific issues are listed below.
FPL: 	FPL’s 2025 Fuel and Purchased Power Cost Recovery factors and Capacity Cost
Recovery factors are appropriate and reasonable and should be approved. FPL’s
proposed FCR factors for the period January 2025 through December 2025 reflect
the recovery of projected total net fuel costs of $3,431,589,874. 	This amount
includes an estimated 2024 net true-up, the Generating Performance Incentive
Factor (“GPIF”) reward, FPL’s 2025 projected fuel costs, FPL’s portion of the
2023 Jurisdictional Asset Optimization Gains, and the projected 2025 FPL
SolarTogether Credit. 	FPL’s proposed CCR factors for the period January 2025
through December 2025 reflect the recovery of projected total net capacity costs
of $117,186,652. 	This amount includes the 2023 final true-up, the 2024
actual/estimated under-recovery, FPL’s 2025 projected fuel costs, and a revenue
requirement reduction to reflect incremental tax savings (for 2025) stemming
from the Inflation Reduction Act. 	In addition, FPL’s 2025 Risk Management
Plan and GPIF targets and ranges are reasonable and should be approved.
FPL’s request for a Solar Base Rate Adjustment (“SoBRA”) to be effective 2025,
satisfies the requirements set forth in Order No. PSC-2021-0446-S-EI (the “2021
Rate Settlement” or “Settlement”), and should therefore be approved. 	FPL will
place 894 MW1 of solar generation into service in 2025 (the “2025 Project”),
which is projected to save FPL customers approximately $911 million on a
cumulative present value of revenue requirements (“CPVRR”) basis. In addition,
FPL’s costs are reasonable, and it is limiting the amount of construction costs to
be recovered through the SoBRA to $1,159 per kW in accordance with the
“Adjusted Cap” prescribed by the Settlement. Finally, the revenue requirement of
$61.087 million and SoBRA factor of 0.667% are calculated in accordance with
the terms approved in the 2021 Rate Settlement. 	Accordingly, the Commission
should approve the proposed tariff rates reflecting the requested base rate
percentage increase for the 2025 SoBRA.
FPUC: 	The Commission should approve Florida Public Utilities Company’s final net
true-up for the period January through December 2023, the estimated true-up for
the period January through December 2024, and the pruchase power cost recovery
factors for the period January through December 2025, until subsequently revised
by the Commission.
TECO: 	The 	Commission 	should 	approve 	Tampa 	Electric's 	calculation 	of 	its 	fuel
adjustment, capacity cost recovery, and GPIF true-up and projection calculations,
including the proposed fuel adjustment factor of 3.083 cents per kWh before any
application of time of use multipliers for on-peak or off-peak or super off-peak
1 All capacity references for the 2025 Project are measured in alternating current.

ORDER NO. PSC-2024-0465-PHO-EI
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usage for the period January 2025 through May 2025 and the proposed fuel
adjustment factor of 3.391 cents per kWh before any application of time of use
multipliers for on-peak or off-peak or super off-peak usage for the period June
2025 through December 2025; the company's proposed capacity factor for the
period January through December 2025; a GPIF reward of $1,830,750 for
performance during 2023 and the company’s proposed GPIF targets and ranges
for 2025.
OPC: 	The utilities bear the burden of proof to justify the recovery of costs they request
in this docket and must carry this burden regardless of whether or not the
Interveners provide evidence to the contrary. Further, the utilities bear the burden
of proof to support their proposal(s) seeking the Commission's adoption of policy
statements (whether new or changed) or other affirmative relief sought. Even if
the Commission has previously approved a program, recovery of a cost, factor, or
adjustment as meeting the Commission’s own requirements, the utilities still bear
the burden of demonstrating that the costs submitted for final recovery meet any
statutory test(s) and are reasonable in amount and prudently incurred. 	Further,
recovery of all costs is constrained by the Commission’s obligation to set fair,
just, and reasonable rates, based on projects that are prudent in purpose and scope
and costs that are prudently incurred pursuant to Section 366.01, Florida Statutes.
Additionally, the provisions of Chapter 366 must be liberally construed to protect
the public welfare.
FIPUG: 	The utilities bear the burden of proof to justify the recovery of costs they request
in this docket as reasonable and prudent. The utilities must carry this burden
regardless of whether or not FIPUG or other parties introduce evidence to the
contrary. 	The utilities must also carry their burden of proof to support their
proposal(s) asking the Commission's adoption of policy statements (whether new
or changed) or other affirmative relief sought.
FRF: 	The Commission’s task in the Fuel Docket, as in all ratemaking proceedings, is to
ensure that the rates charged by Florida public utilities are fair, just, reasonable,
non-discriminatory, and neither insufficient nor excessive. In this context, Florida
public utilities are only allowed to recover reasonable and prudent costs that are
fully authorized by Florida Statutes, Commission rules, and Commission orders
through 	their 	Fuel 	Cost 	Recovery 	and 	Capacity 	Cost 	Recovery 	charges
(collectively herein, “Fuel Charges”). 	The utilities bear the burden of proof that
their proposed Fuel Charges satisfy the statutory criteria articulated above.
PCS
Phosphate: 	Only costs prudently incurred and legally authorized may be recovered through
the fuel clause. Florida electric utilities, including in particular Duke Energy
Florida, LLC (“DEF”), must satisfy the burden of proving the reasonableness of
any expenditures for which recovery or other relief is sought in this proceeding.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
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NUCOR: 	Nucor’s basic position is that Duke Energy Florida, LLC (“DEF”) bears the
burden of proof to justify the costs it seeks to recover through the fuel clause and
capacity 	cost 	recovery 	clause 	and 	any 	other 	relief 	DEF 	requests 	in 	this
proceeding. Fuel expense makes up a large portion of DEF’s revenues and
therefore a large portion of the charges passed onto customers. The Commission
should carefully review DEF’s fuel costs to ensure that they were reasonably and
prudently incurred.
STAFF: 	Staff's positions are preliminary and based on materials filed by the parties and on
discovery. The preliminary positions are offered to assist the parties in preparing
for the hearing. 	Staff's final positions will be based upon all the evidence in the
record and may differ from the preliminary positions stated herein.
VIII. 	ISSUES AND POSITIONS
I. 	COMPANY-SPECIFIC FUEL ISSUES
Duke Energy Florida, LLC
ISSUE 1A: 	Should the Commission approve DEF’s 2025 Risk Management Plan?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 1B: 	What is the appropriate subscription bill credit associated with DEF’s Clean
Energy Connection Program, approved by Order No. PSC-2021-0059-S-EI,
to be included for recovery in 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 1C: 	What is the appropriate Clean Energy Impact (CEI) credit, approved by
Order No. PSC-2023-0191-TRF-EI, to be included in the fuel clause in 2025?
Stipulation: 	See Section X, Proposed Stipulations.
Florida Power & Light Company
ISSUE 2A: 	What was the total gain under FPL’s Incentive Mechanism approved by
Order No. PSC-2021-0446A-S-EI that FPL may recover for the period
January 2023 through December 2023, and how should that gain to be
shared between FPL and its customers?

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
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Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2B: 	What is the appropriate amount of Incremental Optimization Costs under
FPL’s Incentive Mechanism approved by Order No. PSC-2021-0446A-S-EI
that FPL should be allowed to recover through the fuel clause for Personnel,
Software, 	and 	Hardware 	costs 	for 	the 	period 	January 	2023 	through
December 2023?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2C: 	What is the appropriate amount of Variable Power Plant O&M Attributable
to Off-System Sales under FPL’s Incentive Mechanism approved by Order
No. PSC-2021-0446A-S-EI that FPL should be allowed to recover through
the fuel clause for the period January 2023 through December 2023?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2D: 	What is the appropriate amount of Variable Power Plant O&M Avoided due
to Economy Purchases under FPL’s Incentive Mechanism approved by
Order No. PSC-2021-0446A-S-EI that FPL should be allowed to recover
through the fuel clause for the period January 2023 through December 2023?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2E: 	What 	is 	the 	appropriate 	subscription 	credit 	associated 	with 	FPL’s
SolarTogether Program approved by Order No. PSC-2020-0084-S-EI, to be
included for recovery in 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2F: 	Should the Commission approve FPL’s 2025 Risk Management Plan?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2G: 	Are the 2025 SoBRA units proposed by FPL cost effective?
Stipulation: 	See Section X, Proposed Stipulations.

ORDER NO. PSC-2024-0465-PHO-EI
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ISSUE 2H: 	What 	are 	the 	revenue 	requirements 	associated 	with 	the 	2025 	SoBRA
Project?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2I: 	What is the appropriate base rate percentage increase for the 2025 SoBRA
Project, to be effective when all 2025 units are in service?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2J: 	Should the Commission approve revised tariffs for FPL reflecting the base
rate percentage increases for the 2025 SoBRA project determined to be
appropriate in this proceeding?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 2K: 	Were FPL’s actions related to the forced outage event(s) that occurred at St.
Lucie Nuclear Unit No. 1 in July 2024 prudent? If not, what actions should
the Commission take?
DEF: 	No position.
FPL: 	Resolution of this issue and associated discovery should be deferred to 2026.
FPUC: 	No position.
TECO: 	No position.
OPC: 	Resolution of this issue should be deferred to 2026.
FIPUG: 	Defer the resolution of this issue to a later hearing.
FRF: 	The FRF supports deferring the resolution of this issue to a later hearing.
PCS
Phosphate: 	No position.
NUCOR: 	No position.
STAFF: 	Defer this issue to a later hearing.

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ISSUE 2L: 	How much replacement power cost did FPL incur due to the forced outage
event(s) that occurred at St. Lucie Nuclear Unit No. 1 in July 2024?
DEF: 	No position.
FPL: 	Resolution of this issue and associated discovery should be deferred to 2026.
FPUC: 	No position.
TECO: 	No position.
OPC: 	Resolution of this issue should be deferred until 2026.
FIPUG: 	Defer this issue to a later hearing.
FRF: 	The FRF supports deferring the resolution of this issue to a later hearing.
PCS
Phosphate: 	No position.
NUCOR: 	No position.
STAFF: 	Defer this issue to a later hearing.
ISSUE 2M: 	Were FPL’s actions related to the forced outage event(s) that occurred at St.
Lucie Nuclear Unit No. 2 in May/June 2024 prudent? 	If not, what actions
should the Commission take?
DEF: 	No position.
FPL: 	Resolution of this issue and associated discovery should be deferred to 2026.
FPUC: 	No position.
TECO: 	No position.
OPC: 	Resolution of this issue should be deferred until 2026.
FIPUG: 	Defer this issue to a later hearing.
FRF: 	The FRF supports deferring the resolution of this issue to a later hearing.
PCS
Phosphate: 	No position.

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NUCOR: 	No position.
STAFF: 	Defer this issue to a later hearing.
ISSUE 2N: 	How much replacement power cost did FPL incur due to the forced outage
event(s) that occurred at St. Lucie Nuclear Unit No. 2 in July 2024?
DEF: 	No position.
FPL: 	Resolution of this issue and associated discovery should be deferred to 2026.
FPUC: 	No position.
TECO: 	No position.
OPC: 	Resolution of this issue should be deferred until 2026.
FIPUG: 	Defer this issue to a later hearing.
FRF: 	The FRF supports deferring the resolution of this issue to a later hearing.
PCS
Phosphate: 	No position.
NUCOR: 	No position.
STAFF: 	Defer this issue to a later hearing.
Florida Public Utilities Company
No company-specific fuel issues for Florida Public Utilities Company have been identified at
this time. 	If such issues are identified, they shall be numbered 3A, 3B, 3C, and so forth, as
appropriate.
Tampa Electric Company
ISSUE 4A: 	What was the total gain under TECO’s Optimization Mechanism approved
by Order No. PSC-2021-0423-S-EI that TECO may recover for the period
January 2023 through December 2023, and how should that gain to be
shared between TECO and its customers?

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Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 4B: 	Should the Commission approve TECO’s 2025 Risk Management Plan?
Stipulation: 	See Section X, Proposed Stipulations.
GENERIC FUEL ADJUSTMENT ISSUES
ISSUE 5: 	What are the appropriate actual benchmark levels for calendar year 2024 for
gains on non-separated wholesale energy sales eligible for a shareholder
incentive?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 6: 	What are the appropriate estimated benchmark levels for calendar year 2025
for gains on non-separated wholesale energy sales eligible for a shareholder
incentive?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 7: 	What are the appropriate final fuel adjustment true-up amounts for the
period January 2023 through December 2023?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 8: 	What are the appropriate fuel adjustment actual/estimated true-up amounts
for the period January 2024 through December 2024?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 9: 	What are the appropriate total fuel adjustment true-up amounts to be
collected/refunded from January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 10: 	What are the appropriate projected total fuel and purchased power cost
recovery amounts for the period January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.

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COMPANY-SPECIFIC GENERATING PERFORMANCE INCENTIVE FACTOR
ISSUES
Duke Energy Florida, LLC
No company-specific GPIF issues for Duke Energy Florida, Inc. have been identified at this
time. If such issues are identified, they shall be numbered 11A, 11B, 11C, and so forth, as
appropriate.
Florida Power & Light Company
No company-specific GPIF issues for Florida Power and Light Company have been identified at
this time. If such issues are identified, they shall be numbered 12A, 12B, 12C, and so forth, as
appropriate.
Tampa Electric Company
No company-specific GPIF issues for Tampa Electric Company have been identified at this time.
If such issues are identified, they shall be numbered 13A, 13B, 13C, and so forth, as appropriate.
GENERIC GPIF ISSUES
ISSUE 14: 	What is the appropriate GPIF reward or penalty for performance achieved
during the period January 2023 through December 2023 for each investor-
owned electric utility subject to the GPIF?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 15: 	What should the GPIF targets/ranges be for the period January 2025
through December 2025 for each investor-owned electric utility subject to the
GPIF?
Stipulation: 	See Section X, Proposed Stipulations.
FUEL FACTOR CALCULATION ISSUES
ISSUE 16: 	What are the appropriate projected net fuel and purchased power cost
recovery and Generating Performance Incentive amounts to be included in
the recovery factor for the period January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.

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ISSUE 17: 	What is the appropriate revenue tax factor to be applied in calculating each
investor-owned electric utility’s levelized fuel factor for the projection period
January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 18: 	What are the appropriate levelized fuel cost recovery factors for the period
January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 19: 	What are the appropriate fuel recovery line loss multipliers to be used in
calculating the fuel cost recovery factors charged to each rate class/delivery
voltage level class?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 20: 	What 	are 	the 	appropriate 	fuel 	cost 	recovery 	factors 	for 	each 	rate
class/delivery voltage level class adjusted for line losses?
Stipulation: 	See Section X, Proposed Stipulations.
II. 	CAPACITY ISSUES
COMPANY-SPECIFIC CAPACITY COST RECOVERY FACTOR ISSUES
Duke Energy Florida, LLC
ISSUE 21A: 	What is the appropriate amount of costs for the Independent Spent Fuel
Storage Installation (ISFSI) that DEF should be allowed to recover through
the capacity cost recovery clause pursuant to DEF’s 2017 Settlement for
2025?
Stipulation: 	See Section X, Proposed Stipulations.
Florida Power & Light Company
No company-specific capacity cost recovery factor issues for Florida Power & Light Company
have been identified at this time. If such issues are identified, they will be numbered 22A, 22B,
22C, and so forth, as appropriate.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 16
Tampa Electric Company
No company-specific capacity cost recovery factor issues for Tampa Electric Company have
been identified at this time. If such issues are identified, they will be numbered 23A, 23B, 23C,
and so forth, as appropriate.
GENERIC CAPACITY COST RECOVERY FACTOR ISSUES
ISSUE 24: 	What are the appropriate final capacity cost recovery true-up amounts for
the period January 2023 through December 2023?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 25: 	What are the appropriate capacity cost recovery actual/estimated true-up
amounts for the period January 2024 through December 2024?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 26: 	What are the appropriate total capacity cost recovery true-up amounts to be
collected/refunded during the period January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 27: 	What are the appropriate projected total capacity cost recovery amounts for
the period January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 28: 	What are the appropriate projected net purchased power capacity cost
recovery amounts to be included in the recovery factor for the period
January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 29: 	What are the appropriate jurisdictional separation factors for capacity
revenues and costs to be included in the recovery factor for the period
January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 17
ISSUE 30: 	What are the appropriate capacity cost recovery factors for the period
January 2025 through December 2025?
Stipulation: 	See Section X, Proposed Stipulations.
III. 	EFFECTIVE DATE
ISSUE 31: 	What should be the effective date of the fuel adjustment factors and capacity
cost recovery factors for billing purposes?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 32: 	Should the Commission approve revised tariffs reflecting the fuel adjustment
factors and capacity cost recovery factors determined to be appropriate in
this proceeding?
Stipulation: 	See Section X, Proposed Stipulations.
ISSUE 33: 	Should this docket be closed?
Stipulation: 	See Section X, Proposed Stipulations.
IX. 	EXHIBIT LIST
Witness 	Proffered By 	Description
Direct
Gary Dean 	DEF 	(GPT-1T) 	Fuel Cost Recovery True-Up
(Jan. –Dec. 2023)
Gary Dean 	DEF 	(GPD-2T) 	Capacity Cost Recovery True-
Up (Jan. – Dec. 2023)
Gary Dean 	DEF 	(GPD-3T) 	Schedules A1 through A3, A6
and A12 for Dec. 2023
Gary Dean 	DEF 	(GPD-4T) 	2023 Capital Structure and
Cost Rates Applied to Capital
Projects

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 18
Witness 	Proffered By 	Description
Gary Dean 	DEF 	(GPD-5T) 	Annual Clean Energy Impact
Program report
Gary Dean 	DEF 	(GPD-2) 	Actual/Estimated True-up
Schedules for period January-
December 2024
Gary Dean 	DEF 	(GPD-3) 	Projection Factors for January
–December 2025
Adam R. Bingham 	DEF 	(ARB-1T) 	Calculation of GPIF Reward
for January –December 2023
Adam R. Bingham 	DEF 	(ARB-1P) 	GPIF Targets/Ranges
Schedules for January –
December 2025
James (“Jim”) McClay 	DEF 	(JM-1P) 	2025 Risk Management Plan
CONFIDENTIAL
Amin Mohomed 	FPL 	(AM-1) 	2023 FCR Final True-Up
Amin Mohomed 	FPL 	(AM-2) 	2023 CCR Final True-Up
CONFIDENTIAL
Amin Mohomed 	FPL 	(AM-3) 	2024 FCR Actual Estimated
Amin Mohomed 	FPL 	(AM-4) 	2024 CCR Actual Estimated
Amin Mohomed 	FPL 	(AM-5) 	2025 FCR Projections
(January –December Not
Including SoBRA Fuel
Savings)
Amin Mohomed 	FPL 	(AM-6) 	2025 FCR Projections
(February –December
Including SoBRA Fuel
Savings)
Amin Mohomed 	FPL 	(AM-7) 	2025 FCR Projections
(January –December
Including SoBRA Fuel
Savings)
Amin Mohomed 	FPL 	(AM-8) 	2025 CCR Projections
CONFIDENTIAL

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 19
Witness 	Proffered By 	Description
Amin Mohomed 	FPL 	(AM-9) 	2025 SoBRA Revenue
Requirement Calculation
Michael V. Cashman 	FPL 	(GJY-1) 	2023 Asset Optimization
Program Results
CONFIDENTIAL
Michael V. Cashman 	FPL 	(MVC-1) 	2025 Projected Dispatch Costs
and Availability
Michael V. Cashman 	FPL 	(MVC-2) 	2025 Risk Management Plan
CONFIDENTIAL
Charles R. Rote 	FPL 	(CRR-1) 	2023 GPIF Results (errata
filed Sept. 4)
Charles R. Rote 	FPL 	(CRR-2) 	Generating Performance
Incentive Factor
Charles R. Rote 	FPL 	(CRR-3) 	2023 Revised GPIF Targets
Charles R. Rote 	FPL 	(CRR-4) 	2024 Revised GPIF Targets
Kelly Fagan 	FPL 	(KF-1) 	List of FPL Solar Energy
Centers in Service
Kelly Fagan 	FPL 	(KF-2) 	FPL 2025 Solar Energy
Center Maps
Kelly Fagan 	FPL 	(KF-3) 	Typical Solar Energy Center
Block Diagram
Kelly Fagan 	FPL 	(KF-4) 	Specifications for 2025 Solar
Energy Centers
Kelly Fagan 	FPL 	(KF-5) 	Construction Schedules for
the 2025 Solar Energy Centers
Kelly Fagan 	FPL 	(KF-6) 	Capital Cost Table (errata
filed Sept. 5)
Kelly Fagan 	FPL 	(KF-7) 	Cost Increase Waterfall
Andrew W. Whitley 	FPL 	(AWW-1) 	Load Forecast
Andrew W. Whitley 	FPL 	(AWW-2) 	FPL Fuel Price Forecast
Andrew W. Whitley 	FPL 	(AWW-3) 	FPL Resource Plans

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 20
Witness 	Proffered By 	Description
Andrew W. Whitley 	FPL 	(AWW-4) 	CPVRR – Costs and
(Benefits)
Andrew W. Whitley 	FPL 	(AWW-5) 	Yearly PTC Impact
Andrew W. Whitley 	FPL 	(AWW-6) 	Avoided Natural Gas
Andrew W. Whitley 	FPL 	(AWW-7) 	Avoided Air Emissions
Edward J. Anderson 	FPL 	(EJA-1) 	2025 SoBRA Factor
Calculation
Edward J. Anderson 	FPL 	(EJA-2) 	Typical Bill Projections
Phuong T. Nguyen* 	FPUC 	(PTN-1) 	Final True Up Schedules
(Schedules A, C1 and E1-B
for FPUC’s Divisions)
Brittnee Baker 	FPUC 	(BB-1) 	Estimated/Actual (Schedules
E1-A, E1-B, and E1-B1)
Revised September 5, 2024
Brittnee Baker 	FPUC 	(BB-2) 	Schedules E1, E1A, E2, E7,
E8, E10 and Schedule A
Zel D. Jones 	TECO 	(ZDJ-1) 	Final True-Up Capacity Cost
Recovery -January 2023-
December 2023;
Final True-Up Fuel Cost
Recovery – January 2023-
December 2023;
Actual Fuel True-up
Compared to Original
Estimates
January 2023 – December
2023 ;
Schedules A-1, A-2, A-6
through A-9, and A-12
January 2023 –December
2023

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 21
Witness 	Proffered By 	Description
Zel D. Jones 	TECO 	(ZDJ-2) 	Actual/Estimated True-Up
Fuel Cost Recovery, January
2024 –December 2024;
Actual/Estimated True-Up
Capacity Cost Recovery
January –December 2024
Zel D. Jones 	TECO 	(ZDJ-3) 	Projected Capacity Cost
Recovery
January – December 2025;
Projected Fuel Cost Recovery
January – December 2025;
Levelized and Tiered Fuel
Rate – January –December
2025
Elena B. Vance 	TECO 	(EBV-1) 	Final True-Up Generating
Performance Incentive Factor
January – December 2023;
Actual Unit Performance Data
January – December 2023
Elena B. Vance 	TECO 	(EBV-2) 	Generating Performance
Incentive Factor
January – December 2025;
Summary of Generating
Performance Incentive Factor
Targets
January to December 2025
John C. Heisey 	TECO 	(JCH-1) 	Optimization Mechanism
Results
January – December 2023
John C. Heisey 	TECO 	(JCH-2) 	Risk Management Plan
January – December 2025
* Adopted by Witness Brittnee Baker by letter of August 2, 2024.
X. 	PROPOSED STIPULATIONS
The proposed stipulations are listed in Attachment A to this order.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI
PAGE 22
XI. 	PENDING MOTIONS
There are no pending motions at this time.
XII. 	PENDING CONFIDENTIALITY MATTERS
There are no pending confidentiality matters at this time.
XIII. 	POST-HEARING PROCEDURES
If no bench decision is made, each party shall file a post-hearing statement of issues and
positions. A summary of each position, set off with asterisks, shall be included in that statement.
If a party’s position has not changed since the issuance of this Prehearing Order, the post-hearing
statement may simply restate the prehearing position; however, if the prehearing position is
longer than 50 words, it must be reduced to no more than 50 words. If a party fails to file a post-
hearing statement, that party shall have waived all issues and may be dismissed from the
proceeding.
Pursuant to Rule 28-106.215, F.A.C., a party’s proposed findings of fact and conclusions
of law, if any, statement of issues and positions, and brief, shall together total no more than 40
pages and shall be filed at the same time.
XIV. 	RULINGS
Opening statements, if any, shall not exceed three minutes per party.
It is therefore,
ORDERED by Commissioner Gabriella Passidomo, as Prehearing Officer, that this
Prehearing Order shall govern the conduct of these proceedings as set forth above unless
modified by the Commission.

PSC-2024-0465-PHO-EI
31st
October 2024
ORDER NO.
DOCKET NO. 2024000 l-EI
PAGE 23
By ORDER of Commissioner Gabriella Passidomo, as Prehearing Officer, this __ day
of - 	- 	---- 	-
SBr
Gabriella Passidomo
Commissioner and Prehearing Officer
Florida Public Service Commission
2540 Shumard Oak Boulevard
Tallahassee, Florida 32399
(850) 413-6770
www.floridapsc.com
Copies furnished: 	A copy of thjs document is
provided to the parties of record at the time of
issuance and, if applicable, interested persons.
NOTICE OF FUR THER PROCEEDINGS OR JUDICIAL REVIEW
The Florida Public Service Commission is required by Section 	120.569(1), Florida
Statutes, to notify parties of any administrative hearing or judicial review of Commission orders
that is available under Sections 120.57 or 120.68, Florida Statutes, as well as the procedures and
time limits that apply. 	This notice should not be construed to mean all requests for an
administrative hearing or judicial review will be granted or result in the relief sought.
Mediation may be available on a case-by-case basis. 	If mediation is conducted, it does
not affect a substantially interested person's right Lo a hearing.
Any 	party 	adversely 	affected 	by 	this order, 	which 	is 	preliminary, 	procedural 	or
intermediate in nature, may request: (1) reconsideration within l O days pursuant to Rule 25-
22.0376, Florida Administrative Code; or (2) judicial review by the Florida Supreme Court, in
the case of an electric, gas or telephone utility, or the First District Court of AppeaJ, in the case
of a water or wastewater utility. 	A motion for reconsideration shall be filed with the Office of
Commission Clerk, in the form prescribed by Rule 25-22.0376, Florida Administrative Code.
Judicial review of a preliminary, procedural or intennediate ruling or order is available if review
of the final action will not provide an adequate remedy. Such review may be requested from the
appropriate court, as described above, pursuant to Rule 9.100, Florida Rules of Appellate
Procedure.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 24
BEFORE THE FLORIDA PUBLIC SERVICE COMMISSION
In re: Fuel and purchased power cost recovery
clause with generating performance incentive
factor.
DOCKET NO. 20240001-EI
ORDER NO.
ISSUED:
PROPOSED STIPULATIONS
The following issues are proposed as Type 2 2 stipulations in this proceeding: 3
I. 	COMPANY-SPECIFIC FUEL ISSUES
Duke Energy Florida, LLC.
ISSUE 1A: 	Should the Commission approve DEF’s 2025 Risk Management Plan?
Stipulation: 	Yes. Approve DEF’s 2025 Risk Management Plan without financial hedging.
ISSUE 1B: 	What is the appropriate subscription bill credit associated with DEF’s Clean
Energy Connection Program, approved by Order No. PSC-2021-0059-S-EI, to be
included for recovery in 2025?
Stipulation: 	$70,932,763.
ISSUE 1C: 	What is the appropriate Clean Energy Impact (CEI) credit, approved by Order No.
PSC-2023-0191-TRF-EI, to be included in the fuel clause in 2025?
Stipulation: 	($248,300).
Florida Power & Light Company
ISSUE 2A: 	What was the total gain under FPL’s Incentive Mechanism approved by Order
No. PSC-2021-0446A-S-EI that FPL may recover for the period January 2023
through December 2023, and how should that gain to be shared between FPL and
its customers?
2 A Type 2 stipulation occurs on an issue when the utility and staff, or the utility and at least one party adversarial to
the utility, agree on the resolution of the issue and the remaining parties (including staff if they do not join in the
agreement) do not object to the Commission relying on the agreed language to resolve that issue in a final order.
3 The OPC, FRF, PCS Phosphate, Nucor and FIPUG position on each Type 2 stipulation stated herein is as follows:
The OPC, FRF, PCS Phosphate, Nucor and FIPUG take no position on these issues nor do they have the
burden of proof related to them. As such, the OPC, FRF, PCS Phosphate, Nucor and FIPUG represent that they will
not contest or oppose the Commission taking action approving a proposed stipulation between the Company and
another party or staff as a final resolution of these issues. No person is authorized to state that the OPC, FRF, PCS
Phosphate, Nucor or FIPUG is a participant in, or party to, a stipulation on these issues, either in this docket, in an
order of the Commission or in a representation to a Court.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 25
Stipulation: 	Total 	gain 	was 	$123,207,265. 	Customer 	distribution 	- 	$77,103,632, 	FPL
distribution - $46,103,632.
ISSUE 2B: 	What is the appropriate amount of Incremental Optimization Costs under FPL’s
Incentive Mechanism approved by Order No. PSC-2021-0446A-S-EI that FPL
should be allowed to recover through the fuel clause for Personnel, Software, and
Hardware costs for the period January 2023 through December 2023?
Stipulation: 	$517,530.
ISSUE 2C: 	What is the appropriate amount of Variable Power Plant O&M Attributable to
Off-System Sales under FPL’s Incentive Mechanism approved by Order No.
PSC-2021-0446A-S-EI that FPL should be allowed to recover through the fuel
clause for the period January 2023 through December 2023?
Stipulation: 	$1,603,947.
ISSUE 2D: 	What is the appropriate amount of Variable Power Plant O&M Avoided due to
Economy Purchases under FPL’s Incentive Mechanism approved by Order No.
PSC-2021-0446A-S-EI that FPL should be allowed to recover through the fuel
clause for the period January 2023 through December 2023?
Stipulation: 	($76,763).
ISSUE 2E: 	What is the appropriate subscription credit associated with FPL’s SolarTogether
Program 	approved 	by 	Order 	No. 	PSC-2020-0084-S-EI, 	to 	be 	included 	for
recovery in 2025?
Stipulation: 	$245,377,980.
ISSUE 2F: 	Should the Commission approve FPL’s 2025 Risk Management Plan?
Stipulation: 	Yes. Approve FPL’s 2025 Risk Management Plan without financial hedging.
ISSUE 2G: 	Are the 2025 SoBRA units proposed by FPL cost effective?
Stipulation: 	Yes.
ISSUE 2H: 	What are the revenue requirements associated with the 2025 SoBRA Project?
Stipulation: 	$61,087,293
ISSUE 2I: 	What is the appropriate base rate percentage increase for the 2025 SoBRA
Project, to be effective when all 2025 units are in service?

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 26
Stipulation: 	0.667%.
ISSUE 2J: 	Should the Commission approve revised tariffs for FPL reflecting the base rate
percentage increases for the 2025 SoBRA project determined to be appropriate in
this proceeding?
Stipulation: 	Yes.
Florida Public Utilities Company
No company-specific fuel issues for Florida Public Utilities Company have been identified at
this time. 	If such issues are identified, they shall be numbered 3A, 3B, 3C, and so forth, as
appropriate.
Tampa Electric Company
ISSUE 4A: 	What was the total gain under TECO’s Optimization Mechanism approved by
Order No. PSC-2021-0423-S-EI that TECO may recover for the period January
2023 through December 2023, and how should that gain to be shared between
TECO and its customers?
Stipulation: 	Total 	gain 	was 	$10,045,377. 	Customer 	distribution 	- 	$6,922,689, 	TECO
distribution - $3,122,688.
ISSUE 4B: 	Should the Commission approve TECO’s 2025 Risk Management Plan?
Stipulation: 	Approve TECO’s 2025 Risk Management Plan without financial hedging.
GENERIC FUEL ADJUSTMENT ISSUES
ISSUE 5: 	What are the appropriate actual benchmark levels for calendar year 2024 for gains
on non-separated wholesale energy sales eligible for a shareholder incentive?
Stipulation: 	DEF: $3,806,475.
ISSUE 6: 	What are the appropriate estimated benchmark levels for calendar year 2025 for
gains 	on 	non-separated 	wholesale 	energy 	sales 	eligible 	for 	a 	shareholder
incentive?
Stipulation: 	Drop Issue. There are no participating utilities operating under this incentive
methodology in 2025.
ISSUE 7: 	What are the appropriate final fuel adjustment true-up amounts for the period
January 2023 through December 2023?

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 27
Stipulations:
DEF: 	Under-recovery 	of 	$19,202,150 	(collected 	through 	its 	2024 	Mid-Course
Correction as per Order No. PSC-2024-0171-PCO-EI).4
FPL: 	$0 (actual 2023 fuel cost true-up over-recovery of $37,290,272 was returned
through its 2024 Mid-Course Correction as per Order No. PSC-2024-0091-PCO-
EI).5
FPUC: 	Over-recovery of $1,633,921.
TECO: 	Over-recovery of $30,397,837 (returned through its 2024 Mid-Course Correction
as per Order No. PSC-2024-0172-PCO-EI).6
ISSUE 8: 	What are the appropriate fuel adjustment actual/estimated true-up amounts for the
period January 2024 through December 2024?
Stipulations:
DEF: 	Over-recovery of $163,946,191.
FPL: 	Under-recovery of $19,030,441.
FPUC: 	Over-recovery of $3,060,756.
TECO: 	Over-recovery of $63,853,334.
ISSUE 9: 	What 	are 	the 	appropriate 	total 	fuel 	adjustment 	true-up 	amounts 	to 	be
collected/refunded from January 2025 through December 2025?
Stipulations:
DEF: 	Over-recovery of $8,537,789.
FPL: 	Under-recovery of $19,030,441.
FPUC: 	Over-recovery of $4,694,677.
4Order No. PSC-2024-0171-PCO-EI, issued May 24, 2024, in Docket No. 20240001-EI, In re: Fuel and purchased
power cost recovery clause with generating performance incentive factor.
5Order No. PSC-2024-0091-PCO-EI, issued April 10, 2024, in Docket No. 20240001-EI, In re: Fuel and purchased
power cost recovery clause with generating performance incentive factor.
6Order No. PSC-2024-0172-PCO-EI, issued May 24, 2024, in Docket No. 20240001-EI, In re: Fuel and purchased
power cost recovery clause with generating performance incentive factor.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 28
TECO: 	Over-recovery of $28,431,329.
ISSUE 10: 	What are the appropriate projected total fuel and purchased power cost
recovery amounts for the period January 2025 through December 2025?
Stipulations:
DEF: 	$1,535,664,540.
FPL: 	$3,112,084,981.
FPUC: 	$52,050,622.
TECO: 	$694,330,891.
COMPANY-SPECIFIC 	GENERATING 	PERFORMANCE 	INCENTIVE 	FACTOR
ISSUES
Duke Energy Florida, LLC.
No company-specific GPIF issues for Duke Energy Florida, Inc. have been identified at this
time. If such issues are identified, they shall be numbered 11A, 11B, 11C, and so forth, as
appropriate.
Florida Power & Light Company
No company-specific GPIF issues for Florida Power and Light Company have been identified at
this time. If such issues are identified, they shall be numbered 12A, 12B, 12C, and so forth, as
appropriate.
Tampa Electric Company
No company-specific GPIF issues for Tampa Electric Company have been identified at this time.
If such issues are identified, they shall be numbered 13A, 13B, 13C, and so forth, as appropriate.
GENERIC GPIF ISSUES
ISSUE 14: 	What is the appropriate GPIF reward or penalty for performance achieved during
the period January 2023 through December 2023 for each investor-owned electric
utility subject to the GPIF?
Stipulations:
DEF: 	A reward of $1,603,057.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 29
FPL: 	A reward of $11,145,919.
TECO: 	A reward of $1,830,750.
ISSUE 15: 	What should the GPIF targets/ranges be for the period January 2025 through
December 2025 for each investor-owned electric utility subject to the GPIF?
Stipulations:
DEF:
Table 15-1
GPIF Targets/Ranges for the period January-December, 2025
DEF
Plant/Unit
EAF 	ANOHR
Target 	Maximum 	Target 	Maximum
EAF
( % )
EAF
( % )
Savings
($000's) ANOHR
Btu/kWh
ANOHR
Btu/kWh
Savings
($000's)
Bartow 4 	90.43 	93.25 	1,532 	7,557 	7,758 	5,227
Citrus County 1 	78.33 	79.37 	857 	6,866 	6,967 	2,083
Citrus County 2 	91.14 	91.70 	8 	6,783 	6,870 	2,096
Crystal River 5 	82.52 	88.81 	4,193 	10,328 	10,927 	5,908
Hines 1 	96.14 	97.95 	436 	7,449 	7,578 	1,231
Hines 2 	82.06 	83.79 	109 	7,831 	8,111 	2,412
Hines 3 	95.21 	97.45 	350 	7,177 	7,283 	1,016
Hines 4 	77.29 	80.59 	424 	7,158 	7,287 	1,326
Osprey 1 	85.26 	87.16 	203 	7,223 	7,508 	2,631
Totals 	8,111 	23,931
Source: GPIF Target and Range Summary (Exhibit ARB-1P, Page 4 of 94).
FPL:
Table 15-2
GPIF Targets/Ranges for the period January-December, 2025
FPL
Plant/Unit
EAF 	ANOHR
Target 	Maximum 	Target 	Maximum
EAF
( % )
EAF
( % )
Savings
($000’s)
ANOHR
Btu/kWh
ANOHR
Btu/kWh
Savings
($000’s)
Canaveral 3 	92.3 	94.8 	858 	6,750 	6,837 	1,473
Ft. Myers 2 	91.2 	93.7 	163 	7,394 	7,612 	3,269
Manatee 3 	90.3 	92.8 	670 	6,899 	7,057 	3,503
Martin 8 	91.4 	94.4 	539 	6,954 	7,176 	5,098
Okeechobee 1 	90.9 	93.9 	803 	6,425 	6,510 	2,869
Port Everglades
5 	76.3 	78.8 	1,357 	6,677 	6,834 	3,028

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 30
Table 15-2
GPIF Targets/Ranges for the period January-December, 2025
FPL Plant/Unit
EAF 	ANOHR
Target 	Maximum 	Target 	Maximum
EAF
( % )
EAF
( % )
Savings
($000’s)
ANOHR
Btu/kWh
ANOHR
Btu/kWh
Savings
($000’s)
Riviera 5 	94.3 	96.8 	640 	6,631 	6,706 	1,946
Sanford 4 	93.3 	95.8 	116 	7,312 	7,414 	1,454
Sanford 5 	83.1 	85.6 	149 	7,293 	7,397 	1,400
St. Lucie 1 	82.6 	85.6 	4,404 	10,387 	10,486 	368
St. Lucie 2 	93.6 	96.6 	4,375 	10,341 	10,438 	306
Turkey Point 3 	93.6 	96.6 	4,184 	10,524 	10,679 	561
Turkey Point 4 	84.3 	87.3 	4,011 	10,418 	10,548 	399
Turkey Point 5 	83.6 	86.1 	809 	7,157 	7,257 	1,051
West County 1 	91.0 	94.0 	874 	7,028 	7,152 	2,621
West County 2 	93.5 	96.0 	935 	6,893 	7,001 	2,780
West County 3 	88.0 	90.5 	772 	7,068 	7,173 	2,244
Totals* 	$25,659 	$34,370
Source: GPIF Target and Range Summary, including Errata (Exhibit CRR-2, Pages 8-9 of 46)
TECO:
Table 15-3
GPIF Targets/Ranges for the period January-December, 2025
TECO
Plant/Unit
Target 	Maximum 	Target 	Maximum
EAF
( % )
EAF
( % )
Savings
($000's) ANOHR
Btu/kWh
ANOHR
Btu/kWh
Savings
($000's)
Big Bend CC 1 	93.4 	94.2 	2,497 	6,262 	6,288 	843
Polk 2 	71.9 	74.3 	4,818 	7,456 	7,871 	4,747
Bayside 1 	70.6 	72.3 	2,256 	7,349 	7,617 	9,646
Bayside 2 	93.3 	94.1 	247 	7,723 	8,638 	6,317
Totals 	$9,818 	$21,553
Source: GPIF Target and Range Summary (Exhibit EBV-2, Document 1, Page 4 of 28).

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 31
FUEL FACTOR CALCULATION ISSUES
ISSUE 16: 	What are the appropriate projected net fuel and purchased power cost recovery
and Generating Performance Incentive amounts to be included in the recovery
factor for the period January 2025 through December 2025?
Stipulations:
DEF: 	$1,599,414,275.
FPL: 	$3,431,589,874.
FPUC: 	$47,355,945.
TECO: 	$671,420,329.
ISSUE 17: 	What is the appropriate revenue tax factor to be applied in calculating each
investor-owned electric utility’s levelized fuel factor for the projection period
January 2025 through December 2025?
Stipulations:
DEF: 	N/A.
FPL: 	N/A.
FPUC: 	1.000848
TECO: 	1.000848
ISSUE 18: 	What are the appropriate levelized fuel cost recovery factors for the period
January 2025 through December 2025?
Stipulations:
DEF: 	3.918 cents per kWh.
FPL: 	January 2025, 2.748 cents per kWh.
February - December 2025, 2.710 cents per kWh.
FPUC: 	5.550 cents per kWh.
TECO: 	January – May 2025, 3.078 cents per kWh.
June – December 2025, 3.386 cents per kWh.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 32
ISSUE 19: 	What are the appropriate fuel recovery line loss multipliers to be used in
calculating the fuel cost recovery factors charged to each rate class/delivery
voltage level class?
Stipulations:
DEF:
Table 19-1
DEF Fuel Recovery Line Loss Multipliers
for the period January-December, 2025
Delivery Voltage Level 	Line Loss Multiplier
Transmission 	0.9800
Distribution Primary 	0.9900
Distribution Secondary 	1.0000
Lighting Service 	1.0000
Source: Exhibit GPD-3, Part 2, Page 1 of 1.
FPL: 	The appropriate fuel recovery line loss multipliers to be used in calculating the
fuel cost recovery factors charged to each rate class/delivery voltage level class
are shown in Issue No. 20.
FPUC: 	The appropriate fuel recovery line loss multiplier to be used in calculating the fuel
cost recovery factors charged to each rate class/delivery voltage level class is
1.00000
TECO:
Table 19-4
TECO Fuel Recovery Line Loss Multipliers
for the period January-December, 2025
Delivery Voltage Level 	Line Loss Multiplier
Transmission 	0.98
Distribution Primary 	0.99
Distribution Secondary 	1.00
Lighting Service 	1.00
Source: Exhibit ZDJ-3, Document No. 2, Pages 7-8 of 46.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 33
ISSUE 20: 	What are the appropriate fuel cost recovery factors for each rate class/delivery
voltage level class adjusted for line losses?
Stipulations:
DEF:
Table 20-1
DEF Fuel Cost Recovery Factors for the period January-December, 2025
Delivery
Voltage Level
Fuel Cost Recovery Factors
(cents/kWh)
Time of Use
(cents/kWh)
First Tier Second
Tier Levelized On-Peak
Multiplier
1.137
Off-Peak
Multiplier
0.995
Discount
Multiplier
0.909
Transmission 	-- 	-- 	3.847 	4.374 	3.828 	3.497
Distribution Primary 	-- 	-- 	3.886 	4.418 	3.867 	3.532
Distribution
Secondary 	3.630 	4.700 	3.925 	4.463 	3.905 	3.568
Lighting Service 	-- 	-- 	3.829 	-- 	-- 	--
Source: Schedule E1-E (Exhibit GPD-3, Part 2, Page 1 of 1).

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 34
FPL:
Source: Schedule E1-E, (Exhibit AM-5, 2024 FCR Projections, Pages 7 of 174).
Table 20-2
FPL Fuel Cost Recovery Factors for the period January, 2025
Fuel Recovery Factors – By Rate Group (Adjusted for Line Losses)
Group 	Rate Schedule Avg. Factor
(cents/kWh)
Fuel
Recovery
Loss
Multiplier
Fuel
Recovery
Factor
(cents/kWh)
A
RS-1, first 1,000 kWh 	2.748 	1.00297 	2.446
RS-1, all additional kWh 	2.748 	1.00297 	3.446
GS-1, SL-2, SL-2M, GSCU-1 	2.748 	1.00297 	2.756
A-1 	SL-1, SL-1M, OL-1, PL-1 (1), LT-1, OS I/II 	2.676 	1.00297 	2.684
B 	GSD-1, GSD-1EV 	2.748 	1.00290 	2.756
C 	GSLD-1, GSLD-1EV, CS-1 	2.748 	1.00181 	2.753
D 	GSLD-2, CS-2, OS-2, MET 	2.748 	0.99415 	2.732
E 	GSLD-3, CS-3 	2.748 	0.97310 	2.674
A
GST-1 On-Peak 	3.108 	1.00297 	3.117
GST-1 Off Peak 	2.593 	1.00297 	2.601
RTR-1 On-Peak 	0.361
RTR-1 Off-Peak 	(0.155)
B
GSDT-1, CILC-1(G), SST-1D(1), HLFT-1
On-Peak 	3.108 	1.00289 	3.117
GSDT-1, CILC-1(G), SST-1D(1), HLFT-1
Off-Peak 	2.593 	1.00289 	2.601
C
GSLDT-1, CST-1, SST-1D(2), HLFT-2 On-
Peak 	3.108 	1.00181 	3.114
GSLDT-1, CST-1, SST-1D(2), HLFT-2 Off-
Peak 	2.593 	1.00181 	2.598
D
GSLDT-2, CST-2, SST-1D(3), HLFT-3 On-
Peak 	3.108 	0.99439 	3.091
GSLDT-2, CST-2, SST-1D(3), HLFT-3 Off-
Peak 	2.593 	0.99439 	2.579
E
GSLDT-3, CST-3, CILC-1(T), SST-1(T),
ISST-1(T) On-Peak 	3.108 	0.97310 	3.024
GSLDT-3, CST-3, CILC-1(T), SST-1(T)
ISST-1(T) Off-Peak 	2.593 	0.97310 	2.524
F CILC-1(D), ISST-1(D) On-Peak 	3.108 	0.99459 	3.091
CILC-1(D), ISST-1(D) Off-Peak 	2.593 	0.99459 	2.579

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 35
Table 20-3
FPL Fuel Cost Recovery Factors for the period January, 2025
Seasonal Demand Time of Use Rider (SDTR) Fuel Recovery Factors
Group 	Rate Schedule
Average
Factor
(cents/kWh)
Fuel
Recovery
Loss
Multiplier
Fuel
Recovery
Factor
(cents/kWh)
B GSD(T)-1 On-Peak 	3.135 	1.00290 	3.144
GSD(T)-1 Off-Peak 	2.698 	1.00290 	2.706
C GSLD(T)-1 On-Peak 	3.135 	1.00181 	3.141
GSLD(T)-1 Off-Peak 	2.698 	1.00181 	2.703
D GSLD(T)-2 On-Peak 	3.135 	0.99439 	3.117
GSLD(T)-2 Off-Peak 	2.698 	0.99439 	2.683
Source: Schedule E1-E, (Exhibit AM-5, 2024 FCR Projections, Pages 8 of 174).
Table 20-4
FPL Fuel Cost Recovery Factors for the period February-December, 2025
Fuel Recovery Factors – By Rate Group (Adjusted for Line Losses)
Group 	Rate Schedule Avg. Factor
(cents/kWh)
Fuel
Recovery
Loss
Multiplier
Fuel
Recovery
Factor
(cents/kWh)
A
RS-1, first 1,000 kWh 	2.710 	1.00297 	2.408
RS-1, all additional kWh 	2.710 	1.00297 	3.408
GS-1, SL-2, SL-2M, GSCU-1 	2.710 	1.00297 	2.718
A-1 	SL-1, SL-1M, OL-1, PL-1 (1), LT-1, OS I/II 	2.639 	1.00297 	2.647
B 	GSD-1, GSD-1EV 	2.710 	1.00290 	2.718
C 	GSLD-1, GSLD-1EV, CS-1 	2.710 	1.00181 	2.715
D 	GSLD-2, CS-2, OS-2, MET 	2.710 	0.99415 	2.694
E 	GSLD-3, CS-3 	2.710 	0.97310 	2.637
A
GST-1 On-Peak 	3.065 	1.00297 	3.074
GST-1 Off Peak 	2.558 	1.00297 	2.565
RTR-1 On-Peak 	0.356
RTR-1 Off-Peak 	(0.153)
B
GSDT-1, CILC-1(G), SST-1D(1), HLFT-1
On-Peak 	3.065 	1.00289 	3.074
GSDT-1, CILC-1(G), SST-1D(1), HLFT-1
Off-Peak 	2.558 	1.00289 	2.565
C
GSLDT-1, CST-1, SST-1D(2), HLFT-2 On-
Peak 	3.065 	1.00181 	3.071
GSLDT-1, CST-1, SST-1D(2), HLFT-2 Off-
Peak 	2.558 	1.00181 	2.562
D GSLDT-2, CST-2, SST-1D(3), HLFT-3 On-
Peak 	3.065 	0.99439 	3.048

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 36
Table 20-4
FPL Fuel Cost Recovery Factors for the period February-December, 2025
Fuel Recovery Factors – By Rate Group (Adjusted for Line Losses)
Group 	Rate Schedule Avg. Factor
(cents/kWh)
Fuel
Recovery
Loss
Multiplier
Fuel
Recovery
Factor
(cents/kWh)
GSLDT-2, CST-2, SST-1D(3), HLFT-3 Off-
Peak 	2.558 	0.99439 	2.543
E
GSLDT-3, CST-3, CILC-1(T), SST-1(T),
ISST-1(T) On-Peak 	3.065 	0.97310 	2.983
GSLDT-3, CST-3, CILC-1(T), SST-1(T)
ISST-1(T) Off-Peak 	2.558 	0.97310 	2.489
F CILC-1(D), ISST-1(D) On-Peak 	3.065 	0.99459 	3.049
CILC-1(D), ISST-1(D) Off-Peak 	2.558 	0.99459 	2.544
Source: Schedule E1-E, (Exhibit AM-6, 2024 FCR Projections, Page 4 of 8).
Table 20-5
FPL Fuel Cost Recovery Factors for the period February-December, 2025
Seasonal Demand Time of Use Rider (SDTR) Fuel Recovery Factors
Group 	Rate Schedule
Average
Factor
(cents/kWh)
Fuel
Recovery
Loss
Multiplier
Fuel
Recovery
Factor
(cents/kWh)
B GSD(T)-1 On-Peak 	3.092 	1.00290 	3.101
GSD(T)-1 Off-Peak 	2.661 	1.00290 	2.669
C GSLD(T)-1 On-Peak 	3.092 	1.00181 	3.097
GSLD(T)-1 Off-Peak 	2.661 	1.00181 	2.666
D GSLD(T)-2 On-Peak 	3.092 	0.99439 	3.074
GSLD(T)-2 Off-Peak 	2.661 	0.99439 	2.646
Source: Schedule E1-E, (Exhibit AM-6, 2024 FCR Projections, Page 5 of 8).
FPUC:
Table 20-6
FPUC Fuel Cost Recovery Factors for the period January-December, 2025
Fuel Recovery Factors – By Rate Schedule Fuel Recovery Factors – By Rate Schedule
Rate Schedule 	Levelized Adjustment (cents/kWh)
RS 	7.849
GS 	7.890
GSD 	7.392
GSLD 	7.176
LS 	5.872
Source: Schedule E1, Page 3 of 3 (Exhibit BB-2, Page 3 of 8).

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 37
Table 20-7
FPUC Fuel Cost Recovery Factors for the period January-December, 2025
Step Rate Allocation For Residential Customers (RS Rate Schedule)
Rate Schedule and Allocation Levelized Adjustment
(cents/kWh)
RS Rate Schedule – Sales Allocation 	7.849
RS Rate Schedule with less than or equal to 1,000 kWh/month 	7.505
RS Rate Schedule with greater than 1,000 kWh/month 	8.755
Source: Schedule E1, Page 3 of 3 (Exhibit BB-2, Page 3 of 8).
TECO:
*The rates shown in Tables 20-8 and 20-9 were calculated using the modified
time-of-day periods proposed by TECO in Docket No. 20240026-EI, Petition for
rate increase by Tampa Electric Company. 	If the Commission were to deny the
proposed time-of-day periods in Docket No. 20240026-EI, then TECO should be
required to implement the rates shown in Tables 20-10 and 20-11.
Table 20-8
*TECO Fuel Cost Recovery Factors for the period January-May, 2025
Under Methodology Proposed in Docket No. 20240026-EI
Metering Voltage Level
Fuel Cost Recovery Factors (cents per kWh)
Levelized Fuel
Recovery Factor
First Tier
(First 1,000
kWh)
Second Tier
(Over 1,000
kWh)
STANDARD
Distribution Secondary (RS only) 	-- 	2.852 	3.852
Distribution Secondary 	3.083
Distribution Primary 	3.052
Transmission 	3.021
Lighting Service 	3.068
TIME OF USE
Distribution Secondary- On-Peak 	3.238
Distribution Secondary- Off-Peak 	3.034
Distribution Secondary- Super
Off-Peak
3.001
Distribution Primary- On-Peak 	3.206
Distribution Primary- Off-Peak 	3.004
Distribution Primary- Super Off-
Peak
2.971
Transmission- On-Peak 	3.173
Transmission- Off-Peak 	2.973
Transmission- Super Off-Peak 	2.941
Source: Exhibit ZDJ-3, Document No. 4, Page 2 of 5.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 38
Table 20-9
*TECO Fuel Cost Recovery Factors for the period June-December, 2025
Under Methodology Proposed in Docket No. 20240026-EI
Metering Voltage Level
Fuel Cost Recovery Factors (cents per kWh)
Levelized Fuel
Recovery Factor
First Tier
(First 1,000
kWh)
Second Tier
(Over 1,000
kWh)
STANDARD
Distribution Secondary (RS only) 	-- 	3.044 	4.044
Distribution Secondary 	3.391
Distribution Primary 	3.357
Transmission 	3.323
Lighting Service 	3.374
TIME OF USE
Distribution Secondary- On-Peak 	3.561
Distribution Secondary- Off-Peak 	3.336
Distribution Secondary- Super
Off-Peak 	3.301
Distribution Primary- On-Peak 	3.525
Distribution Primary- Off-Peak 	3.303
Distribution Primary- Super Off-
Peak
3.268
Transmission- On-Peak 	3.490
Transmission- Off-Peak 	3.269
Transmission- Super Off-Peak 	3.235
Source: Exhibit ZDJ-3, Document No. 4, Page 3 of 5.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 39
Table 20-10
TECO Fuel Cost Recovery Factors for the period January-May, 2025
Metering Voltage Level
Fuel Cost Recovery Factors (cents per kWh)
Levelized Fuel
Recovery Factor
First Tier
(First 1,000
kWh)
Second Tier
(Over 1,000
kWh)
STANDARD
Distribution Secondary (RS only) 	-- 	2.852 	3.852
Distribution Secondary 	3.083
Distribution Primary 	3.052
Transmission 	3.021
Lighting Service 	3.059
TIME OF USE
Distribution Secondary- On-Peak 	3.227
Distribution Secondary- Off-Peak 	3.024
Distribution Primary- On-Peak 	3.195
Distribution Primary- Off-Peak 	2.994
Transmission- On-Peak 	3.162
Transmission- Off-Peak 	2.964
Source: Exhibit ZDJ-3, Document No. 2, Page 9 of 46.
Table 20-11
TECO Fuel Cost Recovery Factors for the period June-December, 2025
Metering Voltage Level
Fuel Cost Recovery Factors (cents per kWh)
Levelized Fuel
Recovery Factor
First Tier
(First 1,000
kWh)
Second Tier
(Over 1,000
kWh)
STANDARD
Distribution Secondary (RS only) 	-- 	3.044 	4.044
Distribution Secondary 	3.391
Distribution Primary 	3.357
Transmission 	3.323
Lighting Service 	3.363
TIME OF USE
Distribution Secondary- On-Peak 	3.549
Distribution Secondary- Off-Peak 	3.325
Distribution Primary- On-Peak 	3.514
Distribution Primary- Off-Peak 	3.292
Transmission- On-Peak 	3.478
Transmission- Off-Peak 	3.259
Source: Exhibit ZDJ-3, Document No. 2, Page 10 of 46.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 40
II. 	CAPACITY ISSUES
COMPANY-SPECIFIC CAPACITY COST RECOVERY FACTOR ISSUES
Duke Energy Florida, LLC
ISSUE 21A: 	What is the appropriate amount of costs for the Independent Spent Fuel Storage
Installation (ISFSI) that DEF should be allowed to recover through the capacity
cost recovery clause pursuant to DEF’s 2017 Settlement for 2025?
Stipulation: 	$11,525,180.
Florida Power & Light Company
No company-specific capacity cost recovery factor issues for Florida Power & Light Company
have been identified at this time. If such issues are identified, they will be numbered 22A, 22B,
22C, and so forth, as appropriate.
Tampa Electric Company
No company-specific capacity cost recovery factor issues for Tampa Electric Company have
been identified at this time. If such issues are identified, they will be numbered 23A, 23B, 23C,
and so forth, as appropriate.
GENERIC CAPACITY COST RECOVERY FACTOR ISSUES
ISSUE 24: 	What are the appropriate final capacity cost recovery true-up amounts for the
period January 2023 through December 2023?
Stipulations:
DEF: 	Under-recovery of $8,431,790.
FPL: 	Over-recovery of $7,342,001
TECO: 	Under-recovery of $1,888,665.
ISSUE 25: 	What are the appropriate capacity cost recovery actual/estimated true-up amounts
for the period January 2024 through December 2024?
Stipulations:
DEF: 	Over-recovery of $1,632,844.
FPL: 	Under-recovery of $6,402,666.

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 41
TECO: 	Under -recovery of $9,348,304.
ISSUE 26: 	What are the appropriate total capacity cost recovery true-up amounts to be
collected/refunded during the period January 2025 through December 2025?
Stipulations:
DEF: 	Under-recovery of $6,798,946.
FPL: 	Over-recovery of $939,336.
TECO: 	Under-recovery of $11,236,969.
ISSUE 27: 	What are the appropriate projected total capacity cost recovery amounts for the
period January 2025 through December 2025?
Stipulations:
DEF: 	$127,743,993.
FPL: 	$121,736,404.
TECO: 	$6,019,725.
ISSUE 28: 	What are the appropriate projected net purchased power capacity cost recovery
amounts to be included in the recovery factor for the period January 2025 through
December 2025?
Stipulations:
DEF: 	$146,068,118.
FPL: 	$116,885,784.
TECO: 	$17,271,328.
ISSUE 29: 	What are the appropriate jurisdictional separation factors for capacity revenues
and costs to be included in the recovery factor for the period January 2025
through December 2025?

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 42
Stipulations:
DEF: 	Base: 	100.000 	percent, 	Intermediate: 	95.212 	percent, 	and 	Peaking: 	97.632
percent.
FPL: 	Demand: 	Transmission 	88.7807 	percent, 	Non-Stratified/Base/Solar 	96.0110
percent, Intermediate 95.4157 percent, Peaking 94.9428 percent, Distribution
100.0000 percent.
Energy: Non-Stratified/Base/Solar 95.7062 percent, Intermediate 93.9405 percent,
Peaking 95.6020 percent.
General Plant: Labor 96.9425 percent.
TECO: 	The appropriate jurisdictional separation factor is 1.00
ISSUE 30: 	What are the appropriate capacity cost recovery factors for the period January
2025 through December 2025?
Stipulations:
DEF:
Table 30-1
DEF Capacity Cost Recovery Factors for the period January–December, 2025
Rate Class
Capacity and ISFSI
Cost Recovery Factors
¢/kWh 	$/kW-month
Residential (RS-1, RST-1, RSL-1, RSL-2)
At Secondary Voltage 	0.410
General Service Non-Demand (GS-1, GST-1)
At Secondary Voltage 	0.357
At Primary Voltage 	0.353
At Transmission Voltage 	0.350
General Service (GS-2) 	0.252
Lighting (LS-1) 	0.107
General Service Demand (GSD-1, GSDT-1, SS-1)
At Secondary Voltage 	1.07
At Primary Voltage 	1.06
At Transmission Voltage 	1.05
Curtailable (CS-2, CST-2, CS-3, CST-3, SS-3)
At Secondary Voltage 	0.72
At Primary Voltage 	0.71

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 43
Table 30-1
DEF Capacity Cost Recovery Factors for the period January–December, 2025
Rate Class
Capacity and ISFSI
Cost Recovery Factors
¢/kWh 	$/kW-month
At Transmission Voltage 	0.71
Interruptible (IS-2, IST-2, SS-2)
At Secondary Voltage 	0.88
At Primary Voltage 	0.87
At Transmission Voltage 	0.86
Standby Monthly (SS-1, 2, 3)
At Secondary Voltage 	0.103
At Primary Voltage 	0.102
At Transmission Voltage 	0.101
Standby Daily (SS-1, 2, 3)
At Secondary Voltage 	0.049
At Primary Voltage 	0.049
At Transmission Voltage 	0.048
Source: Schedule E12-E (Exhibit GPD-3, Part 3, Page 1 of 1

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 44
FPL:
Table 30-2
FPL Capacity Cost Recovery Factors (with IRA Refund) for the period January–
December, 2025
Rate Schedule
2025 Capacity Cost Recovery Factors
$/kW 	$/kWh
Reservation
Demand
Charge
(RDC)
$/kW
Sum of
Daily
Demand
Charge
(SDD)
$/kW
RS1/RTR1 	- 	0.00103 	- 	-
GS1/GST1 	- 	0.00092 	- 	-
GSD1/GSDT1/HLFT1/GSD1-EV 	0.32 	- 	- 	-
OS2 	- 	0.00041 	- 	-
GSLD1/GSLDT1/CS1/CST1/HLFT2/GSLD1-
EV
0.35 	- 	- 	-
GSLD2/GSLDT2/CS2/CST2/HLFT3 	0.35 	- 	- 	-
GSLD3/GSLDT3/CS3/CST3 	0.35 	- 	- 	-
SST1T 	- 	- 	0.04 	0.02
SST1D1/SST1D2/SST1D3 	- 	- 	0.05 	0.02
CILC D/CILC G 	0.36 	- 	- 	-
CILC T 	0.36 	- 	- 	-
MET 	0.30 	- 	- 	-
OL1/SL1/SL1M/PL1/OSI/II/LT1 	- 	0.00007 	- 	-
SL2/SL2M/GSCU1 	- 	0.00065 	- 	-

ORDER NO. PSC-2024-0465-PHO-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 45
TECO:
Table 30-3
TECO Capacity Cost Recovery Factors for the period January–December, 2025
Rate Class and Metering Voltage 2025 Capacity Cost Recovery Factors
¢/kWh 	$/kW
RS 	0.096 -
GS and CS 	0.088
GSD, RSD
Secondary
-
0.31
Primary 	0.31
Transmission 	0.30
GSD Optional
Secondary 	0.075 -
Primary 	0.074
Transmission 	0.074
GSLDPR/GSLDTPR - 0.26
GSLDSU/GSLDTSU 	0.30
LS-1, LS-2 	0.018 	-
Source: Exhibit ZDJ-3, Document No. 1, Page 3 of 4.
III. 	EFFECTIVE DATE
ISSUE 31: 	What should be the effective date of the fuel adjustment factors and capacity cost
recovery factors for billing purposes?
Stipulation: 	Revised factors should become effective with the first billing cycle of January
2025.
ISSUE 32: 	Should the Commission approve revised tariffs reflecting the fuel adjustment
factors and capacity cost recovery factors determined to be appropriate in this
proceeding?
Stipulation: 	Yes. 	The 	Commission 	should 	approve 	revised 	tariffs 	reflecting 	the 	fuel
adjustment factors and capacity cost recovery factors determined to be reasonable
in this proceeding. The Commission should direct staff to verify that the revised
tariffs are consistent with the Commission’s decisions.
ISSUE 33: 	Should this docket be closed?
Stipulation: 	No, this is a continuing docket and should remain open.