Florida Public Service Commission native order document 09997-2024

FILED 11/22/2024
DOCUMENT NO. 09997-2024
FPSC - COMMISSION CLERK
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. PSC-2024-0481-FOF-EI
ISSUED: November 22, 2024
The following Commissioners participated in the disposition of this matter:
MIKE LA ROSA, Chairman
ARTGRAHAM
GARY F. CLARK
ANDREW GILES FAY
GABRIELLA P ASSIDOMO
FINAL ORDER APPROVING EXPENDITURES AND TRUE-UP AMOUNTS FOR FUEL
ADJUSTMENT FACTORS; GPIF TARGETS, RANGES, AND REWARDS; AND
PROJECTED EXPENDITURES AND TRUE-UP AMOUNTS FOR CAPACITY COST
RECOVERY FACTORS
APPEARANCES:
MATTHEW 	BERNIER and 	STEPHANIE CUELLO, 	ESQUIRES, 	106 East
College Avenue, 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, and 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 	and 	OCTAVIO 	SIMOES-PONCE,
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).

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI
PAGE 2
JON C. MOYLE, JR. and KAREN A. PUTNAL, ESQUIRES, Moyle Law Firm,
PA, The Perkins House, 118 North Gadsden Street, Tallahassee, Florida 32301
On behalf of the Florida Industrial Power Users Group (FIPUG).
ROBERT 	SCHEFFEL 	WRIGHT 	and 	JOHN 	T. 	LAVIA, 	III, 	ESQUIRES,
Gardner, 	Bist, 	Bowden, 	Dee, 	LaVia, 	Wright, 	Perry 	& 	Harper, 	PA, 	1300
Thomaswood Drive, Tallahassee, Florida 32308
On behalf of the Florida Retail Federation (FRF).
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 	HETRICK, 	ESQUIRE, 	General 	Counsel, 	Florida 	Public 	Service
Commission, 2540 Shumard Oak Boulevard, Tallahassee, Florida 32399-0850
Florida Public Service Commission General Counsel.
BY THE COMMISSION
BACKGROUND
As p art of the continuing fuel and purchased power adjustment and generating performance
incentive clause proceedings, an administrative hearing was held on November 5, 2024. 	We have
jurisdiction over this subject matter pursuant to the provisions of Chapter 366, Florida Statutes
(F.S.), including Sections 366.04, 366.05, and 366.06, F.S.
White Springs Agricultural Chemicals, Inc. d/b/a PCS Phosphate – White Springs and
Nucor Steel Florida, Inc., parties to this docket, were excused from this hearing. All of the issues
in this docket for Duke Energy Florida, LLC (DEF), Florida Public Utilities Company (FPUC),
and Tampa Electric Company (TECO) have been stipulated to by all of the parties. Likewise, all
of FPL’s issues have been stipulated to by all of the parties except Issues 2K-2N, as discussed
below.
DECISION
At the hearing, Exhibit Nos. 1-80 were admitted into evidence without objection and the
prefiled testimony of all witnesses listed on Page 5 of Prehearing Order, Order No. PSC-2024-
0465-PHO-EI, issued October 31, 2024, were admitted into evidence. 	We approved all of the

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI
PAGE 3
stipulations contained on Attachment A hereto. Upon approval of the Type 2 stipulations1 listed
in Attachment A, all issues were resolved for DEF, FPUC and TECO and those parties were
excused. Likewise, all of FPL’s issues, except Issues 2K-2N, were also resolved by our approval
of the Type 2 stipulations contained in Attachment A. 	The procedural matters associated with
FPL’s Issue Nos. 2K-2N were then taken up.
FPL Issue Nos. 2K through 2N
FPL Issue Nos. 2K through 2N2 concern the replacement power costs for FPL’s St. Lucie
Units 1 and 2 for May/June and July of 2024. All parties have agreed that these issues should be
deferred from this final hearing to a later date. 	However, the parties initially disagreed about
three additional procedural matters which have been raised by FPL. First, should the hearing be
deferred until a date certain, specifically until 2026? Second, should these issues be taken up in
this Fuel Clause docket, the 2025 FPL rate case, or spun off into a separate docket? 	Third,
should discovery on these issues be deferred until 2026?
After oral argument FPL, FRF, and FIPUG were able to reach agreement on these
procedural issues as follows: “Resolution of these issues, Numbers 2K-2N, should be deferred to
the Fuel Clause hearing in 2026, but discovery on Issue Nos. 2K-2N can begin on April 1, 2025,
provided it is limited to Issue Nos. 2K-2N.” OPC took no position on this language but agreed
that a Type 2 Stipulation was acceptable. 	Due to the fact that the prudence of plant operation
decisions and replacement fuel costs are traditionally litigated in the Fuel Clause we find that the
stipulation to do so here is appropriate. We are also persuaded that deferring the consideration of
these issues until 2026, given the extensive time it will take for FPL to prepare and litigate its
anticipated rate case, is appropriate. We further find that allowing discovery to start on April 1,
2025, provided that discovery is limited to Issue Nos. 2K-2N, is a reasonable compromise and is
approved. That being the case, we approve the Type 2 stipulation as proposed by the parties for
Issue Nos. 2K-2N.
All issues, testimony and exhibits having been stipulated to and all stipulations having
been approved by this Commission, the hearing was adjourned.
The new fuel adjustment and capacity factors shall become effective as set forth in the
stipulations. The new factors shall continue in effect until modified by us. We hereby approve
revised 	tariffs 	reflecting 	the 	fuel 	adjustment 	factors 	and 	capacity 	cost 	recovery 	factors
1 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.
2Issue 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?; 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?; 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?; 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?.

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI
PAGE 4
determined to be appropriate in this proceeding. We direct staff to verify that the revised tariffs
are consistent with our decision.
Based on the foregoing, it is
ORDERED by the Florida Public Service Commission that the findings set forth in the
body of this order, and Attachment A hereto, are hereby approved. It is further
ORDERED that Duke Energy Florida, LLC, Florida Public Utilities Company, Florida
Power & Light Company and Tampa Electric Company are hereby authorized to apply the fuel
cost recovery factors set forth herein during the period January 2025 through December 2025. It
is further
ORDERED that the estimated true-up amounts contained in the fuel cost recovery factors
approved herein are hereby authorized subject to final true-up and further subject to proof of the
reasonableness and prudence of the expenditures upon which the amounts are based. It is further
ORDERED that Duke Energy Florida, LLC, Florida Power & Light Company, and
Tampa Electric Company are hereby authorized to apply the capacity cost recovery factors set
forth herein during the period January 2025 through December 2025. It is further
ORDERED that the estimated true-up amounts contained in the capacity cost recovery
factors approved herein are hereby authorized subject to final true-up and further subject to proof
of the reasonableness and prudence of the expenditures upon which the amounts are based. It is
further
ORDERED that the revised tariffs reflecting the fuel adjustment factors and capacity cost
recovery factors determined to be appropriate in this proceeding are hereby approved and we
direct Commission staff to verify that the revised tariffs are consistent with our decision. 	It is
further
ORDERED that Issue Nos. 2K-2N shall be deferred to the 2026 Fuel Clause docket and
that discovery on those issues shall not begin until April 1, 2025. It is further
ORDERED that while the Fuel and Purchased Power Cost Recovery Clause with
Generating Performance Incentive Factor docket is assigned a separate docket number each year
for administrative convenience, it is a continuing docket and shall remain open.

ORDER NO. PSC-2024-048 l-FOF-EI
DOCKET NO. 20240001-EI
PAGES
By ORDER of the Florida Public Service Commission this 22nd day of November, 2024.
SBr
Commi
Florida Public Service Commission
2540 Shumard Oak Boulevard
Tallahassee, Florida 32399
(850) 413-6770
www.tloridapsc.com
Copies furnished: 	A copy of this document is
provided to the pa,ties of record at the time of
issuance and, if applicable, interested persons.
NOTICE OF FU RTHER 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.
Any party adversely affected by the Commission's final action in this matter may request:
1) reconsideration of the decision by filing a motion for reconsideration with the Office of
Commission Clerk, 2540 Shumard Oak Boulevard, Tallahassee. Florida 32399-0850, within
fifteen (15) days of the issuance of this order in the form prescribed by Rule 25-22.060, 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 Appeal in the case of a water and/or
wastewater utility by filing a notice of appeal with the Office of Commission Clerk, and filing a
copy of the notice of appeal and the filing fee with the appropriate court. 	This fil ing must be
completed within thirty (30) days after the issuance of this order, pursuant to Rule 9.110, Florida
Rules of Appellate Procedure. 	The notice of appeal must be in the fonn specified in Rule
9.900(a), Florida R ules of Appellate Procedure.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 1 of 23
PAGE 6
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 3 stipulations in this proceeding: 4
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).
3 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.
4 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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 2 of 23
PAGE 7
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?
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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 3 of 23
PAGE 8
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?
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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 4 of 23
PAGE 9
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: 	Yes. 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?
Stipulations:
DEF: 	Under-recovery 	of 	$19,202,150 	(collected 	through 	its 	2024 	Mid-Course
Correction as per Order No. PSC-2024-0171-PCO-EI).5
5Order 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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 5 of 23
PAGE 10
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).6
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).7
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.
TECO: 	Over-recovery of $28,431,329.
6Order 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.
7Order 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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 6 of 23
PAGE 11
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, LLC 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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 7 of 23
PAGE 12
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.
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).

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 8 of 23
PAGE 13
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
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 9 of 23
PAGE 14
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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 10 of 23
PAGE 15
TECO: 	January – May 2025, 3.078 cents per kWh.
June – December 2025, 3.386 cents per kWh.
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 11 of 23
PAGE 16
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).
FPL:
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/kW
h)
Fuel
Recovery
Loss
Multiplie
r
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

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 12 of 23
PAGE 17
Source: Schedule E1-E, (Exhibit AM-5, 2024 FCR Projections, Pages 7 of 174).
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).
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 13 of 23
PAGE 18
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
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
So urce: Schedule E1-E, (Exhibit AM-6, 2024 FCR Projections, Page 4 of 8).

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 14 of 23
PAGE 19
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).
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.

ORDER NO. PSC-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 15 of 23
PAGE 20
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 16 of 23
PAGE 21
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 17 of 23
PAGE 22
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 18 of 23
PAGE 23
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.

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 24 	Page 19 of 23
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.
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.

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 25 	Page 20 of 23
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?
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

ORDER NO. PSC-2024-0481-FOF-EI
DOCKET NO. 20240001-EI 	Attachment A
PAGE 26 	Page 21 of 23
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
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 22 of 23
PAGE 27
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-2024-0481-FOF-EI 	Attachment A
DOCKET NO. 20240001-EI 	Page 23 of 23
PAGE 28
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.