0001292814-25-003897.txt : 20251112 0001292814-25-003897.hdr.sgml : 20251112 20251112060254 ACCESSION NUMBER: 0001292814-25-003897 CONFORMED SUBMISSION TYPE: 6-K PUBLIC DOCUMENT COUNT: 15 CONFORMED PERIOD OF REPORT: 20250930 FILED AS OF DATE: 20251112 DATE AS OF CHANGE: 20251112 FILER: COMPANY DATA: COMPANY CONFORMED NAME: BRAZILIAN ELECTRIC POWER CO CENTRAL INDEX KEY: 0001439124 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] ORGANIZATION NAME: 01 Energy & Transportation EIN: 000000000 STATE OF INCORPORATION: D5 FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 6-K SEC ACT: 1934 Act SEC FILE NUMBER: 001-34129 FILM NUMBER: 251468155 BUSINESS ADDRESS: STREET 1: RUA DA QUITANDA, 196, 24TH FLOOR STREET 2: CENTRO CITY: RIO DE JANEIRO STATE: D5 ZIP: 20091-005 BUSINESS PHONE: 55 21 2514 5891 MAIL ADDRESS: STREET 1: RUA DA QUITANDA, 196, 24TH FLOOR STREET 2: CENTRO CITY: RIO DE JANEIRO STATE: D5 ZIP: 20091-005 6-K 1 ebrpr3q25_6k.htm 6-K

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

Report of Foreign Private Issuer
Pursuant to Rule 13a-16 or 15d-16 of the

Securities Exchange Act of 1934

For the month of November, 2025

Commission File Number 1-34129

CENTRAIS ELÉTRICAS BRASILEIRAS S.A. - ELETROBRÁS

(Exact name of registrant as specified in its charter)

BRAZILIAN ELECTRIC POWER COMPANY

(Translation of Registrant's name into English)

Rua da Quitanda, 196 – 24th floor,
Centro, CEP 20091-005,
Rio de Janeiro, RJ, Brazil

(Address of principal executive office)

Indicate by check mark whether the registrant files or will file annual reports under cover Form 20-F or Form 40-F.

Form 20-F ___X___ Form 40-F _______

Indicate by check mark whether the registrant by furnishing the information contained in this Form is also thereby furnishing the information to the Commission pursuant to Rule 12g3-2(b) under the Securities Exchange Act of 1934.

Yes _______ No___X____

TABLE OF CONTENTS
1. CONSOLIDATED RESULT \| IFRS AND REGULATORY	7
2. ADJUSTED CONSOLIDATED RESULT \| IFRS AND REGULATORY	9
3. ENERGY TRADING	13
4. INVESTMENTS AND EXPANSION PROJECTS	14
5. INDEBTEDNESS	16
6. COMPULSORY LOAN	17
7. CASH FLOW	18
8. FINANCIAL PERFORMANCE	19
8.1. Operational and Financial Results	19
8.2. Generation Segment	21
8.3. Transmission Segment	24
8.4. Operating Costs and Expenses - IFRS	25
8.5. Equity Holdings - IFRS	29
8.6. Financial Result - IFRS	30
8.7. Current and Deferred Taxes - IFRS	31
9. OPERATIONAL PERFORMANCE	32
9.1. Generation Segment	32
9.2. Transmission Segment	34
9.3. ESG	35
10. APPENDIX	36
10.1. Appendix 1 - Generation and Transmission Revenue IFRS	36
10.2. Appendix 2 - PMSO Breakdown	37
10.3. Appendix 3 - Financing and Loans Granted (Receivables)	38
10.4. Appendix 4 - Accounting Statements	39
10.5. Appendix 5 - IFRS vs. Regulatory Reconciliation	43

AXIA ENERGIA RELEASES 3^rd QUARTER 2025 RESULTS

Highlights:

Shareholder remuneration: R$ 4.3 billion in dividends, totaling R$ 8.3 billion distributed in fiscal year 2025, reaching approximately R$ 4.01 per Class A and Class B preferred share, and R$ 3.65 per common share and golden share.

In September and October, Management delivered significant and consistent results, notably with the signing of the sale of Eletronuclear, the divestment of the stake in EMAE, and the acquisition of Tijoá Energia, accelerating the Company’s streamlining process and reducing its risk profile. These developments, together with the strong results achieved in 3Q25, resilient 2026 prices, advances in energy trading, and improvements to our long-term energy model, generated allocable capital under our capital allocation methodology. This, in turn, enabled both the dividend proposal and participation in the transmission auction No. 4/2025. The capital allocation methodology underscores our commitment to financial discipline, shareholder value creation, and sustained investment capacity.

Transmission auction No. 4/2025: winning bid of lots 6A, 6B, 7A and 7B, with RAP of R$ 138.74 million and CAPEX projected by ANEEL of R$ 1.63 billion, attesting to AXIA Energia's competitiveness and efficiency.

Adjusted Regulatory Net Revenue: R$ 9,969 million in 3Q25, down 4.6% YoY, with higher transmission revenues partially offsetting the lower generation revenue related to the sale of the Amazonas thermal power plants and the additional sale of energy from the Tucuruí HPP, which occurred only in 3Q24.

Contribution margin from generation, ACL + MCP: The contribution margin from energy traded in the Free Contracting Environment (ACL) and settled in the Short Term Market (MCP) increased to R$ 86/MWh in 3Q25 from R$ 48/MWh in 3Q24, considering the resources available for allocation in both segments.

Energy trading: 813 clients served in 3Q25, up 16% YoY, with 723 in the ACL compared to 614 in 3Q24.

Adjusted Regulatory EBITDA excluding the variation in results from the Amazonas thermal plants sold in 2025: EBITDA reached R$ 6,419 million in 3Q25, up 3.4% YoY, driven by the 9.8% increase in transmission revenues along with the 10.1% drop in PMSO expenses, reflecting the Company's focus on continuously enhancing operational efficiency. These advances more than offset the 2.1% decrease in generation revenue and the 21.9% reduction in equity income, ensuring resilient EBITDA growth.

Adjusted IFRS Net Income: Totaled R$ 2,176 million, down 68.0% YoY, due to the recognition of a R$ 303 million regulatory remeasurement in 3Q25, compared to R$ 6,130 million in 3Q24, when the impact of the 2023 Periodic Tariff Review was recognized, with no equivalent effect in 2025.

Investments: R$ 2,701 million in 3Q25, up by 32% and 57% compared to 2Q25 and 3Q24, respectively. It is worth noting the 28% YoY increase in investments in reinforcements and improvements in the transmission segment, which reached R$ 1,061 million in 3Q25.

Still within the transmission segment, 230 large-scale projects are under implementation, representing an additional RAP of R$ 1.7 billion between 2025 and 2030 and a total estimated CAPEX of R$ 12.5 billion.

100% Renewable Portfolio: In October, we completed the sale of our last thermal power asset, the Santa Cruz TPP. With this transaction, AXIA Energia now holds a 100% renewable portfolio, in line with its Net Zero 2030 commitment.

Portfolio Management Oct/25: Agreement for the sale of stake in Eletronuclear to J&F for R$ 535 million, providing for the release of guarantees granted by AXIA Energia and the transfer of the “ADI debentures.” The buyer will assume full responsibility for the payment of these debentures, totaling R$ 2.4 billion, as established in the Settlement Agreement with the Federal Government.

Execution of the contract for the sale of AXIA Energia’s stake in Empresa Metropolitana de Águas e Energia S.A. (EMAE) to Companhia de Saneamento Básico do Estado de São Paulo (SABESP) for R$ 476.5 million, including the possibility of future earn-out payments.

Acquisition of the remaining 50.1% stake in Tijoá Energia, in October 2025, for R$ 247 million. The plant has an installed capacity of 808 MW and, in 2024, achieved annual revenue of R$ 320 million and EBITDA of R$ 136 million.

Financial management: net debt totaled R$ 42,577 million in 3Q25, up by R$ 2,451 million and R$ 3,680 million compared to 2Q25 and 3Q24, respectively. This increase was due to the higher gross debt and lower available cash, resulting from the R$ 4 billion dividend payment in August 2025, which consumed a portion of the R$ 5 billion in free cash generated during the period. The average debt maturity decreased by 3.9 months while the average cost rose to CDI + 0.64% p.a. from CDI + 0.59% p.a. in 3Q24.

Notably, Eletronorte raised R$ 2 billion through a debenture issuance in July 2025, with a final cost equivalent to CDI -0.56% p.a. after a swap transaction.

Compulsory Loan: the provision inventory was reduced by R$ 2.7 billion YoY and R$ 362 million sequentially, totaling R$ 11.7 billion in 3Q25. Agreements reached and favorable decisions led to a net reversal of R$ 300 million in the quarter.

MAIN OPERATIONAL AND FINANCIAL INDICATORS

Table 1 - Operating highlights

	3Q25	3Q24	∆%	2Q25	∆%
Generation and Trading
Installed Generation Capacity (MW)	44,368	44,191	0.4	44,368	0.0
Assured Capacity (aMW) (1)	21,655	21,912	-1.2	21,655	0.0
Net Generation (TWh)	24.5	26.5	-7.6	38.7	-36.6
Energy Sold ACR (TWh) (2)	26.7	31.3	-14.7	18.8	42.5
Energy Sold ACL (TWh) (3)	52.5	45.4	15.8	36.1	45.4
Energy Sold Quotas (TWh) (4)	15.4	25.9	-40.7	10.4	48.6
Average ACR Price (R$/MWh) (5)	268.70	298.96	-10.1	284.80	-5.7
Average ACL Price (R$/MWh)	156.07	156.13	0.0	152.07	2.6
Transmission
Transmission lines (km)	74,769	73,958	1.1	73,774	1.3
RAP (R$ mm) (6)	16,644	17,015	-2.2	17,209	-3.3

(1) Assured Capacity (AC) reflects: (a) Ordinance GM/MME 544/21, which established the revision of AC values for plants that had their concessions renewed due to the capitalization (Quota regime plants: Tucuruí, Itumbiara, Sobradinho, Mascarenhas de Moraes, and Curuá-Una), leading to a significant AC reduction, effective from 2023; (b) Ordinance GM/MME 709/22, which introduced an Ordinary Review of the AC for hydroelectric power plants effective from 2023, impacting several AXIA Energia plants; (c) exit of TPP Candiota III as of Jan/24 and of TPPs Mauá III, Aparecida, Anamã, Anori, Codajás, and Caapiranga as of May/25; (d) inclusion of Colíder HPP and exclusion of Mauá HPP as of June/25, following the uncrossing of asset holdings with Copel; (e) inclusion of newly consolidated SPEs: Teles Pires HPP (Oct/23), Baguari HPP (Oct/23), Retiro Baixo HPP (Nov/23), and Santo Antônio HPP (Nov/23); (f) inclusion of the expanding wind farms Casa Nova B and Coxilha Negra, with full AC in 2024; (g) figures do not yet reflect the completion of the sale of the Santa Cruz TPP, concluded in Oct/25, nor the consolidation of the Três Irmãos HPP, whose signing occurred in Oct/25 and is still pending completion.

(2) Does not include quotas.

(3) Includes contracts under Law 13.182/2015.

(4) The figures presented refer to the Assured Capacity of quotas in GWh.

(5) Excludes thermoelectric power plants.

(6) Approved RAP for the current regulatory cycle, considering the modules in operation at the end of each period—including those in operation at the start of the cycle, as well as new modules that entered commercial operation. Includes transmission contracts from AXIA Energia Holding, Chesf, CGT Eletrosul, Eletronorte, TMT, and VSB.

Table 2 - Financial highlights

	3Q25	3Q24	∆%	2Q25	∆%
Financial Indicators
Gross Revenue	11,725	12,960	-9.5	12,082	-3.0
Adjusted Gross Revenue	11,751	12,960	-9.3	12,191	-3.6
Net Operating Revenue	10,003	11,043	-9.4	10,199	-1.9
Adjusted Net Operating Revenue	10,029	11,043	-9.2	10,308	-2.7
Regulatory Net Operating Revenue	9,943	10,449	-4.8	9,701	2.5
EBITDA	-1,495	12,159	-112.3	1,259	-218.8
Adjusted EBITDA	5,890	11,964	-50.8	5,151	14.4
Regulatory EBITDA	-601	6,970	-108.6	5,820	-110.3
Adjusted Regulatory EBITDA	6,382	6,775	-5.8	5,501	16.0
EBITDA Margin (%)	-14.9	110.1	-125.1pp	12.3	-27.3pp
Adjusted EBITDA Margin (%)	58.7	108.3	-49.6pp	50.0	8.8pp
Net Income	-5,448	7,195	-175.7	-1,325	311.1
Adjusted Net Income	2,176	6,805	-68.0	1,469	48.1
Adjusted Gross Debt	72,005	68,774	4.7	71,042	1.4
Adjusted Net Debt (Adj Net Debt)	42,577	38,897	9.5	40,125	6.1
Adj Net Debt/Adjusted LTM EBITDA	2.1	1.6	33.9	1.5	38.1
Investments	2,701	1,720	57.0	2,043	32.2

HIGHLIGHTS OF CONSOLIDATED RESULTS

1. CONSOLIDATED RESULT | IFRS AND REGULATORY

Table 3 - Income statement IFRS (R$ mm)

	3Q25			3Q24		2Q25		9M25	9M24
	IFRS	Adjustment	Adjusted	Adjusted	% Y/Y	Adjusted	% Q/Q	Adjusted	Adjusted	% Y/Y
Generation	6,908	26	6,934	8,348	-16.9	6,960	-0.4	20,862	20,109	3.7
Transmission	4,646	0	4,646	4,566	1.7	5,079	-8.5	14,910	13,520	10.3
Others	171	0	171	46	n.m.	152	12.6	392	182	n.m.
Gross Revenue	11,725	26	11,751	12,960	-9.3	12,191	-3.6	36,164	33,811	7.0
(-) Deductions from Revenue	-1,723	0	-1,723	-1,918	-10.2	-1,883	-8.5	-5,413	-5,655	-4.3
Net Revenue	10,003	26	10,029	11,043	-9.2	10,308	-2.7	30,751	28,156	9.2
Energy resale, grid, fuel and construction	-4,179	0	-4,179	-4,014	4.1	-3,568	17.1	-11,609	-9,917	17.1
Personnel, Material, Services and Others	-1,623	114	-1,509	-1,692	-10.8	-1,403	7.6	-4,379	-4,744	-7.7
Operating provisions	-236	218	-18	-251	-92.7	-177	-89.7	-281	-834	-66.4
Results from asset sale	-7,071	7,071	0	0	0.0	0	0.0	0	0	0
Regulatory remeasurements - Transmission contracts	303	0	303	6,130	-95.1	0	0.0	-648	6,130	n.m.
Other income and expenses	43	-43	0	0	0.0	0	0.0	0	0	0.0
Results, before Equity holdings	-2,760	7,385	4,625	11,216	-58.8	5,160	-10.4	13,834	18,791	-26.4
Equity holdings	1,265	0	1,265	749	69.0	-10	n.m.	1,623	2,025	-19.8
EBITDA	-1,495	7,385	5,890	11,964	-50.8	5,151	14.4	15,457	20,816	-25.7
D&A	-1,156	0	-1,156	-990	16.7	-1,131	2.1	-3,399	-2,955	15.0
EBIT	-2,651	7,385	4,734	10,974	-56.9	4,019	17.8	12,058	17,861	-32.5
Financial Result	-2,571	186	-2,385	-2,225	7.2	-2,377	0.3	-8,081	-7,756	4.2
EBT	-5,222	7,571	2,349	8,749	-73.1	1,642	43.1	3,976	10,105	-60.6
Income Tax and Social Contribution (1)	-226	53	-173	-1,944	-91.1	-173	0.1	-411	-1,828	-77.5
Net Income	-5,448	7,624	2,176	6,805	-68.0	1,469	48.1	3,565	8,277	-56.9

(1) The adjusted value originally disclosed for the Income Tax and Social Contribution line in 3Q24, published on November 6, 2024, was -R$ 1,186 million. Subsequently, part of the deferred tax recognized in 4Q24, amounting to R$ 758 million, was identified as having its triggering event in 3Q24. Accordingly, a non-recurring adjustment was made between the two quarters, reallocating this amount from 4Q24 to 3Q24, with no impact on full-year 2024 results. As a result, in the 4Q24 disclosure, the adjusted value for 3Q24 was revised from -R$ 1,186 million to -R$ 1,944 million. The value presented for 3Q24 in this earnings release reflects the revised amount, as disclosed in the 4Q24 results on March 13, 2025.

Table 4 - Regulatory IS (R$ mm)

	3Q25			3Q24		2Q25		9M25	9M24
	Regulatory	Adjustment	Adjusted	Adjusted	% Y/Y	Adjusted	% Q/Q	Adjusted	Adjusted	% Y/Y
Generation	6,749	26	6,775	8,001	-15.3	6,945	-2.4	20,744	20,676	0.3
Transmission (1)	4,745	0	4,745	4,320	9.8	4,488	5.7	13,656	14,450	-5.5
Others	171	0	171	45	n.m.	152	12.6	392	179	n.m.
Gross Revenue	11,665	26	11,691	12,366	-5.5	11,585	0.9	34,791	35,305	-1.5
(-) Deductions from Revenue	-1,723	0	-1,723	-1,918	-10.2	-1,883	-8.5	-5,413	-5,655	-4.3
Net Revenue	9,943	26	9,969	10,449	-4.6	9,701	2.8	29,378	29,650	-0.9
Energy resale, grid, fuel and construction (1)	-2,764	0	-2,764	-2,988	-7.5	-2,478	11.5	-8,395	-7,579	10.8
Personnel, Material, Services and Others	-1,620	114	-1,505	-1,702	-11.5	-1,419	6.1	-4,398	-4,784	-8.1
Operating provisions	142	65	207	405	-49.0	-98	n.m.	31	-575	n.m.
Results from asset sale	-6,821	6,821	0	0	0.0	0	0.0	0	0	0
Regulatory remeasurements - Transmission contracts	0	0	0	0	0.0	0	0.0	0	0	0
Other income and expenses	43	-43	0	0	0.0	0	0.0	0	0	0.0
Results, before Equity holdings	-1,077	6,983	5,906	6,165	-4.2	5,706	3.5	16,617	16,712	-0.6
Equity holdings	476	0	476	610	-21.9	-205	n.m.	643	1,686	-61.9
EBITDA	-601	6,983	6,382	6,775	-5.8	5,501	16.0	17,260	18,398	-6.2
D&A	-1,589	0	-1,589	-1,490	6.6	-1,615	-1.6	-4,795	-4,419	8.5
EBIT	-2,190	6,983	4,793	5,285	-9.3	3,886	23.3	12,465	13,979	-10.8
Financial Result	-2,814	339	-2,475	-2,352	5.2	-2,398	3.2	-8,148	-8,167	-0.2
EBT	-5,003	7,322	2,318	2,934	-21.0	1,488	55.8	4,317	5,812	-25.7
Income Tax and Social Contribution (2)	-462	53	-409	-1,168	-65.0	-244	67.9	-754	-1,454	-48.1
Net Income	-5,465	7,375	1,909	1,766	8.1	1,244	53.4	3,563	4,358	-18.2

(1) The figures for 3Q24 presented in this disclosure differ in two lines from those originally published on November 6, 2024. Gross transmission revenue decreased by R$ 147 million, from R$ 4,467 to R$ 4,320 million, while the cost of network usage charges—recorded under “Energy resale, grid, fuel and construction”—also decreased by R$ 147 million, from R$ 3,135 million to R$ 2,988 million. As a result, the net effect on EBITDA and net income is nil. The change in both lines results from the review of accounting practices in 2025 related to the elimination of intercompany transactions between the Company’s generation and transmission segments, This adjustment reflects that network usage charges paid by certain generation plants are offset by revenues received by the transmission companies within the group. To ensure comparability between 2024 and 2025, the corresponding elimination values for 2024 were also revised.

(2) The adjusted value originally disclosed for the Income Tax and Social Contribution line in 3Q24, published on November 6, 2024, was -R$ 410 million. Subsequently, part of the deferred tax recognized in 4Q24, amounting to R$ 758 million, was identified as having its triggering event in 3Q24. Accordingly, a non-recurring adjustment was made between the two quarters, reallocating this amount from 4Q24 to 3Q24, with no impact on full-year 2024 results. As a result, in the 4Q24 disclosure, the adjusted value for 3Q24 was revised from -R$ 410 million to -R$ 1,168 million. The value presented for 3Q24 in this earnings release reflects the revised amount, as disclosed in the 4Q24 results on March 13, 2025.

2. ADJUSTED CONSOLIDATED RESULT | IFRS AND REGULATORY

Adjusted Regulatory Income Statement

This section presents the reconciliation between Regulatory and IFRS Income Statements, along with the adjustments related to non-recurring events in the Regulatory Income Statement.

A detailed reconciliation is also available in the “Regulatory and IFRS Income Statement Reconciliation” spreadsheet, accessible on the Company’s Investor Relations website, under Market Information > Historical Financial Information.

Table 5 - Regulatory IS x IFRS IS (R$ mm)

	3Q25 IFRS	Difference	3Q25 Regulatory	Non-recurring Adjustment	3Q25 Regulatory Adjusted	3Q24 Regulatory Adjusted	% Y/Y
Generation	6,908	-159	6,749	26	6,775	8,001	-15.3
Transmission	4,646	99	4,745	0	4,745	4,320	9.8
Others	171	0	171	0	171	45	n.m.
Gross Revenue	11,725	-60	11,665	26	11,691	12,366	-5.5
(-) Deductions from Revenue	-1,723	0	-1,723	0	-1,723	-1,918	-10.2
Net Revenue	10,003	-60	9,943	26	9,969	10,449	-4.6
Construction	-1,262	1,262	0	0	0	0	0.0
Energy resale	-1,714	0	-1,714	0	-1,714	-1,628	5.3
Grid	-1,010	153	-857	0	-857	-869	-1.4
Fuel	-193	0	-193	0	-193	-491	-60.6
Energy resale, grid, fuel and construction	-4,179	1,415	-2,764	0	-2,764	-2,988	-7.5
Personnel	-832	-4	-836	82	-754	-915	-17.6
Material	-63	0	-63	0	-63	-64	-1.6
Services	-548	0	-548	15	-533	-568	-6.2
Others	-180	8	-173	18	-155	-154	0.4
Personnel, Material, Services and Others	-1,623	4	-1,620	114	-1,505	-1,702	-11.5
Operating provisions	-236	378	142	65	207	405	-49.0
Results from asset sale	-7,071	249	-6,821	6,821	0	0	0.0
Regulatory remeasurements - Transmission contracts	303	-303	0	0	0	0	0.0
Other income and expenses	43	0	43	-43	0	0	0.0
Results, before Equity holdings	-2,760	1,683	-1,077	6,983	5,906	6,165	-4.2
Equity holdings	1,265	-788	476	0	476	610	-21.9
EBITDA	-1,495	894	-601	6,983	6,382	6,775	-5.8
D&A	-1,156	-433	-1,589	0	-1,589	-1,490	6.6
EBIT	-2,651	461	-2,190	6,983	4,793	5,285	-9.3
Financial Result	-2,571	-242	-2,814	339	-2,475	-2,352	5.2
EBT	-5,222	219	-5,003	7,322	2,318	2,934	-21.0
Income Tax and Social Contribution	-226	-236	-462	53	-409	-1,168	-65.0
Net Income, continued	-5,448	-17	-5,465	7,375	1,909	1,766	8.1

Non-recurring Adjustments

The following adjustments refer to events considered non-recurring:

▪

Generation Revenue: R$ 26 million, related to adjustments in the value of sale transactions from the thermal power plants.

▪

PMSO (Personnel): R$ 82 million, of which R$ 50 million was severance and R$ 32 million was VDPs.

▪

PMSO (Services): R$ 15 million, of which R$ 14 million refer to legal consulting services related to the contingency reduction strategy.

▪

PMSO (Other): R$ 18 million, related to commitments under the self-managed health plan, which was replaced by a plan managed by a specialized market operator.

▪

Operating Provisions: R$ 65 million, resulting from:

(a) R$ 266 million in provisions for litigation;

(b) -R$ 176 million in reversals of provisions for estimated losses on loans and financing;

(d) R$ 15 million in adjustments related to the compulsory loan share conversion process;

(e) -R$ 12 million in estimated losses on investments and non-recoverable assets (impairment)

▪

Asset Disposal: R$ 6,821 million, referring to non-cash impacts recognized in the P&L resulting from asset purchase and sale transactions during the quarter. These include signing the agreement for the sale of a stake in Eletronuclear (R$ 7,290 million), uncrossing assets with Copel (-R$ 483 million), signing the agreement for the sale of a stake in EMAE (R$ 25 million) and completing the sale of thermal power plants (-R$ 11 million).

▪

Other Revenues and Expenses: -R$ 43 million, fully adjusted as non-recurring, given the atypical nature of the items that make up this item.

▪

Financial Result: R$ 339 million, linked to the monetary restatement of compulsory loan and litigation.

▪

Income Tax and Social Contribution: R$ 53 million, related to a current tax expense recognized upon completion of the transaction involving the sale of the Mauá HPP.

Regulatory Result: Adjusted EBITDA

In 3Q25, adjusted regulatory EBITDA totaled R$ 6,382 million, down R$ 393 million YoY, reflecting:

(a) the drop in generation revenue due to the sale of the Amazonas thermal power plants and the additional energy sale from Tucuruí HPP which occurred only in 3Q24;

(b) lower reversals of provisions; and

These effects were partially offset by:

(a) higher transmission revenue;

(b) lower PMSO costs and expenses; and

Equity income was R$ 476 million in 3Q25, and does not include the net income from the stake in Eletronuclear, which was classified as asset held for sale following the signing of the divestment agreement with J&F.

It is worth noting that, excluding the results from the Amazonas thermal power plants, sold in May 2025, EBITDA went up R$ 214 million to R$ 6,419 million in 3Q25 from R$ 6,205 million in 3Q24.

Table 6 - Adjusted regulatory EBITDA, without thermal power plants (R$ mm)

	3Q25	Thermal Power Plants (TPP)	3Q25 Excluding TPP	3Q24	Thermal Power Plants (TPP)	3Q24 Excluding TPP
Generation	6,775	200	6,575	8,001	1,281	6,720
Transmission	4,745	0	4,745	4,320	0	4,320
Others	171	0	171	45	0	45
Gross Revenue	11,691	200	11,491	12,366	1,281	11,085
(-) Deductions from Revenue	-1,723	-21	-1,702	-1,918	-219	-1,698
Net Revenue	9,969	179	9,790	10,449	1,062	9,387
Energy resale, grid, fuel and construction	-2,764	-210	-2,555	-2,988	-833	-2,154
Personnel, Material, Services and Others	-1,505	-6	-1,499	-1,702	-35	-1,667
Operating provisions	207	0	207	405	376	29
Results, before Equity holdings	5,906	-37	5,942	6,165	570	5,595
Equity holdings	476	0	476	610	0	610
EBITDA	6,382	-37	6,419	6,775	570	6,205

Generation revenue was R$ 6,775 million in 3Q25, down R$ 1,225 million YoY. Recurring revenue fell 15.3% reflecting decreases of 12.3% in volume and 3.4% in average price. The reduction in both volume and price can be explained by:

(a) the sale of Amazonas thermal power plants, and

(b) the additional sale of energy from Tucuruí HPP in 3Q24, due to the renegotiation of hydrological risk, an event without a counterpart in 3Q25.

Excluding the revenue billed from energy sold by the thermal power plants, generation revenue was down by R$ 144 million, reaching R$ 6,575 million in 3Q25, reflecting an 8.5% drop in volume, partially offset by a 6.9% increase in average price. In 3Q25, revenue was positively impacted by higher energy settlements in the Short Term Market (MCP) amounting to R$ 1,755 million, compared to R$ 695 million in 3Q24. This increase reflected the combined increases of 38% in average price and 83% in volume.

Costs associated with generation reached R$ 2,555 million in 3Q25, up by R$ 400 million YoY, of which R$ 380 million relate to higher expenses with energy purchased for resale.

Transmission revenue increased by R$ 425 million YoY, reaching R$ 4,745 million in 3Q25, mainly reflecting a reduction in the negative component of the Adjustment Portion (PA).

Personnel, Materials, Services and Other (PMSO) expenses fell by R$ 168 million, totaling R$ 1,499 million in 3Q25. The decrease resulted from measures implemented by the Company to enhance operational efficiency.

Provisions under the regulatory view showed a reversal of R$ 207 million in 3Q25, compared to R$ 29 million in 3Q24. This variation reflects the R$ 170 million reversal in 3Q25 related to Amazonas Energia debts with AXIA Energia, following the release of judicial deposits made by the counterparty.

3Q25’s performance reflected positive effects from higher transmission revenue and lower PMSO and provision expenses, reflecting the Company’s continuous pursuit of operational efficiency and mitigation of contingencies. These improvements more than offset the lower contribution from the generation segment and from equity income, ensuring resilient EBITDA growth.

IFRS Result: Adjusted EBITDA and Net Income

Adjusted IFRS PMSO was R$ 1,509 million, down 10.8% YoY, reflecting savings related to efficiency gains. In 3Q25, the adjusted PMSO was impacted by the following effects:

(a) R$ 82 million related to Voluntary Dismissal Programs (VDPs) and severance costs;

(b) R$ 18 million related to commitments under the self-managed health plan, which was replaced by a plan managed by a specialized market operator;

Adjusted IFRS EBITDA reached R$ 5,890 million in 3Q25, down 50.8% YoY. This variation was mainly explained by the recognition of a R$ 303 million regulatory remeasurement in 3Q25, compared to R$ 6,130 million in 3Q24, when the impact of the 2023 Periodic Tariff Review was recognized, with no equivalent effect in 2025.

Adjusted IFRS Financial Result reached -R$ 2,385 million in 3Q25, compared to -R$ 2,225 million in 3Q24.

Adjusted Income Tax and Social Contribution tax expenses under IFRS reached R$ 173 million in 3Q25 compared to R$ 1,944 million in 3Q24, due to lower recognition of deferred tax expenses.

Thus, Adjusted IFRS Net income reached R$ 2,176 million, down 68.0% YoY.

3. ENERGY TRADING

AXIA Energia companies sold 94.7 TWh of energy in 3Q25, down 7.8% compared to the 102.6 TWh traded in 3Q24.

The volumes sold include energy from plants under the quota regime, renewed under Law 12,783/2013, as well as from plants operating under the ACL and ACR exploration regimes and consolidated Special Purpose Entities - SPEs: HPPs Teles Pires and Baguari (as of Oct/23), and Retiro Baixo and Santo Antônio (as of Nov/23).

Table 7 - Energy balance 3Q25 (aMW)

	2025		2026		2027

Resources (A)	16,905		16,984		17,833
Own resources (1) (2) (3) (4) (5)	14,214		15,533		16,702
Hydraulic	13,938		15,251		16,420
Wind	276		282		282
Energy Purchase	2,690		1,452		1,130
Limit =>	Lower	Higher	Lower	Higher	Lower	Higher
Sales (B) (6)	11,998	14,368	9,347	12,347	7,148	9,648
ACR - Except quotas	3,498		3,597		3,148
ACL - Bilateral Contracts + STM implemented (range) (6)	8,500	10,870	5,750	8,750	4,000	6,500
Average prices Contracts signed
Limit =>	Lower	Higher	Lower	Higher	Lower	Higher
Average Price of Sales Contracts (ACR and ACL - R$/MWh)	170	180	185	205	195	225
Balance (A - B)	4,907	2,537	7,637	4,637	10,684	8,184
Balance considering estimated hedge (9)	2,370	0	4,862	1,862	7,696	5,196
Uncontracted energy considering estimated hedge (9)	14%	0%	29%	11%	43%	29%

Contracts signed until 9/30/2025.

The energy balance reflects the SPEs consolidated into AXIA Energia: Santo Antônio HPP (as of 3Q22) and Baguari and Retiro Baixo HPPs (as of 4Q23) in terms of resources, sales, and average prices. Similarly, Teles Pires HPP, an SPE consolidated into Eletronorte (as of 4Q23), is also included.

The energy balance does not include Independent Power Producers (IPPs) contracts resulting from the Amazonas Distribuidora de-verticalization process, thermal plant availability contracts, or Assured Capacity Quotas, whether in terms of resources, requirements (sales), or average prices.

Own Resources include the decotization plants (new IPPs) and the New Grants—Sobradinho, Itumbiara, Tucuruí, Curuá-Una, and Mascarenhas de Moraes. For hydroelectric projects, the estimate of GFIS2 was used, representing Assured Capacity adjusted for Internal Losses, Losses in the Basic Grid, Availability, and portfolio-specific factors.

The revised Assured Capacity values, as outlined in Ordinance No. 709/GM/MME, of November 30, 2022, have been taken into account.

With the gradual phasing out of quota-based generation legacy contracts (decotization), plants currently operating under the quota regime are gradually granted new concessions under the IPP regime over a five-year period beginning in 2023. The Assured Capacity values were established in Ordinance GM/MME No. 544/21.

Considering the new concession grants from 2023 onward for the Sobradinho, Itumbiara, Tucuruí, Curuá-Una, and Mascarenhas de Moraes plants, whose Assured Capacity values were established in Ordinance GM/MME No. 544/21.

The balances include intercompany transactions, impacting both energy purchase and sales lines in the ACL, in the following amounts: approximately 900 aMW in 2025 and 200 aMW in 2026 and 2027.

Table 8 - Assured capacity quotas of hydroelectric power plants (aMW)

	2025	2026	2027
Assured Capacity Quotas	2,626	1,313	0

This excludes the Assured Capacity of Jaguari HPP (12.7 aMW), whose concession remains under AXIA Energia's provisional management.

Decotization occurs gradually over a five-year period beginning in 2023. The Assured Capacity values applied from 2023 onward are those established in Ordinance GM/MME No. 544/21.

The figures represent an estimate of uncontracted energy. The projected values for 2025, 2026 and 2027 is 81.8%. Worth noting that the average historical GSF from 2019 to 2024 is 82.7%. Source: CCEE, obtained from the CCEE website at the following link: CCEE Data and Analysis (in Portuguese only, select the MRE option in the panel). It is important to note that this is only an estimate, based on past events.

4. INVESTMENTS AND EXPANSION PROJECTS

Investments totaled R$ 2,701 million in 3Q25, with allocation as follows:

(a) R$ 1,203 million to transmission;

(b) R$ 677 million to Itaipu's HVDC project;

(d) R$ 282 million to equity holdings;

(e) R$ 181 million to infrastructure; and

(f) R$ 69 million to the environmental area.

It is worth highlighting the higher investments related to the revitalization of the Itaipu High Voltage Direct Current (HVDC) system, which transmits energy generated by the power plant to consumer centers in Brazil. The project results from a technical and financial cooperation agreement between AXIA Energia, which is responsible for execution, and Itaipu, which fully reimburses the investments, with funds released in advance of disbursements.

The amount invested in infrastructure was allocated as follows:

(a) 36% for IT;

(b) 28% for socio-environmental initiatives;

(d) 17% for equipment and vehicles.

In the socio-environmental area, key highlights included investments related to the maintenance of operating licenses for power plants and substations, as well as land compensation.

The breakdown of investments by the holding company and its main subsidiaries is available in the operational spreadsheet in the Results Center section of the Company’s Investor Relations website.

Table 9 - Investments (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Generation Corporate	289	534	-45.8	357	-19.1	813	1,768	-54.0
Implementation / Expansion	27	216	-87.7	45	-41.5	109	926	-88.3
Maintenance	263	318	-17.3	312	-15.8	705	842	-16.3
Transmission Corporate	1,203	966	24.6	1,199	0.3	3,057	2,265	35.0
Expansion	135	93	44.3	85	58.1	274	119	n.m.
Reinforcements and improvements	1,061	830	27.8	1,108	-4.3	2,765	2,039	35.6
Maintenance	8	42	-81.8	5	44.7	19	107	-82.6
Infrastructure	181	104	73.7	117	54.5	341	173	97.7
Environmental	69	109	-36.4	67	3.4	184	242	-24.1
SPEs	282	0	0.0	225	25.2	507	486	4.2
Generation - Contributions	0	0	0.0	0	0.0	0	478	n.m.
Generation - Acquisition	0	0	0.0	0	0.0	0	0	0.0
Transmission - Contributions	282	0	0.0	225	25.2	507	8	n.m.
Transmission - Acquisition	0	0	0.0	0	0.0	0	0	0.0
Investment for Special Obligation – Itaipu HVDC	677	7	n.m.	77	n.m.	836	199	n.m.
Total	2,701	1,720	57.0	2,043	32.2	5,739	5,132	11.8

Expansion Projects - Transmission

Large Scale Projects

▪

Projects: 230^[1], including the Itaipu HVDC System Revitalization project. Throughout 3Q25, the sample was reduced from 250 to 230 projects, due to 21 projects that were energized and the inclusion of 1 new authorization issued by the regulator.

▪

Estimated investment: R$ 6.21 billion, excluding the Itaipu HVDC System Revitalization project, as AXIA Energia is responsible solely for the execution, and therefore does not benefit from associated revenue while being fully reimbursed for the amount disbursed.

▪

Auctions: Investments of R$ 6.24 billion, mainly driven by the following SPEs: Nova Era Janapu, which was part of the sample since 2Q24, while Nova Era Catarina, Nova Era Ceará, Nova Era Integração and Nova Era Teresina were added in 3Q24^[2]. The lot acquired in Auction 01/2022, awarded to Eletronorte and concluded in August 2025 — 13 months ahead of schedule — was excluded in 3Q25.

▪

Additional associated RAP: R$ 1.7 billion between 2025-2030.

Small Scale Projects

▪

Projects: data from ONS's Improvement and Reinforcement Plan Management System (SGPMR).

▪

Works: 8,575 small-scale events under implementation or to be implemented, of which 8,088 were improvements and 487 were reinforcements.

Table 10 - Portfolio of ongoing transmission projects

	3Q25	3Q24	%	2Q25	%
Large Scale: Reinforcement and Improvement
Estimated Portfolio Investment (R$ bi) (2)	6.2	6.8	-8.9	7.0	-10.6
Additional RAP associated (R$ bi)	1.0	1.1	-8.9	1.1	-7.5
# of projects in the beggining of the period (1)	244	245	-0.4	235	3.8
(-) energized	-20	-5	n.m.	-9	n.m.
(+) new authorizations	1	1	0.0	18	-94.4
# of projects in the end of the period (1)	225	241	-6.6	244	-7.8
Large Scale: Expansion (Auctions in implementation) (3)
Estimated Portfolio Investment (R$ bi) (2)	6.2	6.4	-1.8	6.4	-1.8
Additional RAP associated (R$ bi)	0.7	0.7	6.5	0.7	3.2
# of projects in the beggining of the period (1)	6	1	n.m.	6	0.0
(-) energized	-1	0	0.0	0	0.0
(+) new authorizations	0	5	n.m.	0	0.0
# of projects in the end of the period	5	6	-16.7	6	-16.7
Small Scale (4)
# of projects in the end of the period	8,575	11,130	-23.0	9,194	-6.7
Improvement	8,088	10,491	-22.9	8,668	-6.7
Reinforcement	487	639	-23.8	526	-7.4

^[1] Referring to reinforcements, improvements and auction-related projects. Considers projects registered in ANEEL's Transmission Management System (SIGET). Projects are included when added to the system and excluded when they are either canceled or enter commercial operation. The 230 projects will add 2,306 km of transmission lines and 12,926 MVA in substations.

^[2] Each of the 5 SPEs created holds the contracts signed in last years' transmission auctions. SPE Nova Era Janapu holds contract no. 09/2023-ANEEL for the 4th lot of Auction 01-2023; SPE Nova Era Teresina holds contract no. 04/2024-ANEEL for the 1st lot of Auction 01-2024; SPE Nova Era Ceará holds contract no. 06/2024-ANEEL for the 3rd lot of Auction 01-2024; SPE Nova Era Integração holds contract no. 08/2024-ANEEL for the 5th lot of Auction 01-2024; and SPE Nova Era Catarina holds contract no. 12/2024-ANEEL for the 9th lot of Auction 01-2024.

5. INDEBTEDNESS

Net debt totaled R$ 42,577 million in 3Q25, up R$ 2,451 million sequentially and R$ 3,680 million YoY. As a result of liability management and a 425 bps increase in the Brazilian basic interest rate (Selic), the Company's average debt maturity was reduced by 3.9 months in 3Q25 when compared to 3Q24, while the total average cost increased to CDI + 0.64% p.a. in 3Q25 from CDI + 0.59% p.a. in 3Q24.

Table 11 - Net debt (R$ mm)

	09/30/2025	06/30/2025	09/30/2024
(+) Gross Debt, including derivatives	72,005	71,042	68,774
(+) Gross Debt	70,836	70,290	68,879
(+) Derivatives (currency hedge) Net	1,169	752	-105
(-) Cash and Cash Equivalents + Current Securities	28,256	29,387	28,378
(-) Restricted Cash for Loans and Financing	987	899	875
(-) Loans receivable	187	632	624
Net Debt	42,577	40,125	38,897
Adjusted Net Debt / Adjusted Regulatory EBITDA LTM	1.9x	1.8x	1.6x
Net Debt's Average Term (months)	55.5	56.5	59.4

Below are the gross debt maturity schedule and its breakdown by index, according to the index profile, as well as the respective spreads over each index, considering gross debt including derivatives. A more detailed breakdown is available in the operational spreadsheet in the Results Center on the Company’s Investor Relations website.

Chart 1 - Debt maturity schedule after hedge (R$ billion)

Table 12 - Debt breakdown, including hedge

Index	Average Cost	Total Balance (R$ million)	Share of Total (%)
CDI +	CDI + 1.12%	38,353	53.3
IPCA	IPCA + 5.97%	24,304	33.8
% of CDI	122% of CDI	4,546	6.3
TJLP	TJLP + 1.99%	3,031	4.2
Fixed Rate	5.72% per year	1,568	2.2
EUR	2.65% per year	204	0.3
Total		72,005	100.0

6. COMPULSORY LOAN

AXIA Energia has implemented measures to mitigate risks associated with legal proceedings related to compulsory loans on electricity^[1]. To address this, the Company has strengthened its legal defense strategy and pursued settlements with discounts and full resolution of lawsuits. As a result of the negotiations:

▪

The inventory of provisions was reduced by R$ 2.7 billion YoY and R$ 362 million sequentially, totaling R$ 11.7 billion in 3Q25, mainly due to the agreements signed;

▪

Net reversal of R$ 300 million due to agreements signed and favorable decisions in the quarter;

▪

R$ 186 million was the amount recorded in 3Q25 under financial expenses related to monetary restatements;

▪

With the signing of new agreements in 3Q25, R$ 21 million in guarantees previously deposited in court will be released upon approval, bringing the total released since 3Q22 to R$ 2.6 billion.

Since 3Q22, when negotiations began, the provision inventory related to compulsory loan fell by R$ 14.2 billion, reaching R$ 11.7 billion in 3Q25, even considering the accumulated R$ 2.9 billion monetary restatement in the period. The agreements also enabled the elimination of R$ 10.1 billion in legal risks considered "off balance", of which R$ 930 million was classified as possible and R$ 9.2 billion as remote.

Chart 2 - Total inventory of compulsory loan provisions 3Q25 x 3Q24 (R$ bn)

Chart 3 - Total inventory of compulsory loan provisions 3Q25 x 2Q25 (R$ bn)

^[1] Starting in 3Q25, the figures presented in this section fully encompass all procedural matters related to the topic, rather than only the book-entry credits, which represented approximately 99% of the total balance and had been the focus of this section in previous quarters. As a result, the figures disclosed herein may show slight variations compared to those reported in prior periods.

7. CASH FLOW

It is worth highlighting for 3Q25 the R$ 4 billion dividend payment in August 2025.

Table 13 - Cash flow (R$ mm)

	3Q25	3Q24	∆%
Adjusted Regulatory Result, before Equity Holdings	5,906	6,165	-4.2
EBITDA Adjustment *	-162	196	n.m.
Income Tax and Social Contribution	-154	-430	-64.1
Working Capital	773	569	35.9
Privatization Charges	0	0	n.m.
Dividends Received	350	115	n.m.
Operating Cash Flow	6,713	6,614	1.5
Investments **	-1,743	-1,911	-8.8
Free Cash Flow	4,970	4,704	5.7
Debt Service	-1,281	-1,379	-7.1
Litigation	-1,244	-1,141	9.1
Guarantees and Restricted Deposits	23	222	-89.8
Supplementary social security	-116	-86	35.8
Net Funding ***	-92	-1,878	-95.1
Receipt of Loans and Financial Charges	653	32	n.m.
Disposal of equity holdings	18	2,281	-99.2
Dividends	-4,022	47	n.m.
Free Net Cash	-1,092	2,802	n.m.
Change in Restricted Cash (short and long term)	-205	-492	-58.3
Change in Financial Investments (long-term)	-117	-16	n.m.
Net Cash	-1,414	2,294	n.m.

*Does not take into account the adjustment related to asset disposal in the net profit line.

**Excludes generation contributions.

***Net funding: debt raised, net of issuance costs.

FINANCIAL AND OPERATIONAL RESULTS ANALYSIS

8. FINANCIAL PERFORMANCE

8.1. Operational and Financial Results

The table below presents the results by segment for the AXIA Energia Group’s two main businesses—generation and transmission—considering revenue and direct costs. Other costs and expenses, results from equity holdings, financial results, and taxes are analyzed on a consolidated basis.

Table 14 - Income statement 3Q25 (R$ mm)

Income Statement	IFRS (a)	Adjustment (b)	Regulatory (c)=(a)+(b)	Non Recurring (d)	Adjusted Regulatory (e)=(c)+(d)	Generation (e.1)	Transmission (e.2)	Others (e.3)	Eliminations (e.4) (1)
Gross Revenue	11,725	-60	11,665	26	11,691	6,775	5,020	171	-276
(-) Deductions	-1,723	0	-1,723	0	-1,723	-889	-834	0	0
Net Revenue	10,003	-60	9,943	26	9,969	5,886	4,187	171	-276
Energy purchased for resale	-1,714	0	-1,714	0	-1,714	-1,714	0	0	0
Charges on use of the electricity grid	-1,010	153	-857	0	-857	-1,132	0	0	276
Fuel for electricity production (net of CCC)	-193	0	-193	0	-193	-193	0	0	0
Other Generation Costs (2)	-31	0	-31	0	-31	-31	0	0	0
Construction costs	-1,262	1,262	0	0	0	0	0	0	0
Regulatory remeasurements	303	-303	0	0	0	0	0	0	0
Contribution Margin	6,095	1,052	7,147	26	7,173	2,815	4,187	171	0
PMSO, excluded Other Generation Costs (2)	-1,592	4	-1,588	114	-1,474
Provisions	-236	378	142	65	207
Results from asset sale	-7,071	249	-6,821	6,821	0
Other income and expenses	43	0	43	-43	0
Results, before Equity holdings	-2,760	1,683	-1,077	6,983	5,906
Equity holdings	1,265	-788	476	0	476
EBITDA	-1,495	894	-601	6,983	6,382
D&A	-1,156	-433	-1,589	0	-1,589
EBIT	-2,651	461	-2,190	6,983	4,793
Financial Result	-2,571	-242	-2,814	339	-2,475
EBT	-5,222	219	-5,003	7,322	2,318
Income Tax and Social Contribution	-226	-236	-462	53	-409
Net Income	-5,448	-17	-5,465	7,375	1,909

(1) Eliminations: These refer to the portion of transmission system usage charges paid by AXIA Energia's generators to the Company's own transmission companies, which receive them in the form of RAP. For accounting consolidation purposes (Tables 4 and 5), these amounts are eliminated from both transmission revenue and generation usage charges. For management purposes, gross transmission revenue in 3Q25 is R$ 5,020 million, and including the accounting elimination of -R$ 276 million, this translates into accounting revenue of R$ 4,745 million. In the case of generation connection charges costs, for management purposes, the value in 3Q25 is -R$ 1,132 million, and including the accounting elimination of R$ 276 million, this translates into an accounting cost of -R$ 857 million.

(2) The "RHR Hedge Cost" and "Other Operating Costs" lines, related to the generation segment costs, make up the "Other PMSO Costs" line under the accounting view. For a better understanding of the contribution margin by segment, from a management perspective, both lines are allocated in the composition of the contribution margin from generation. In 3Q25, the adjusted regulatory PMSO under the accounting view totaled R$ 1,505 million, composed of R$ 19 million in RHR hedge costs and R$ 13 million in other generation operating costs, both allocated in the margin from generation, and R$ 1,474 million in other cost and expense components for personnel, materials, services and others. At the same time, in 3Q25, the adjusted IFRS PMSO from an accounting perspective totaled R$ 1,509 million, comprised of R$ 19 million in RRH hedging costs and R$ 13 million in other generation operating costs, both allocated to the margin from generation, and R$ 1,478 million in other cost and expense components related to personnel, materials, services, and others.

Table 15 - Income statement 3Q24 (R$ mm)

Income Statement	IFRS (a)	Adjustment (b)	Regulatory (c)=(a)+(b)	Non Recurring (d)	Adjusted Regulatory (e)=(c)+(d)	Generation (e.1)	Transmission (e.2)	Others (e.3)	Eliminations (e.4) (1)
Gross Revenue	12,960	-594	12,366	0	12,366	8,001	4,575	45	-255
(-) Deductions	-1,918	0	-1,918	0	-1,918	-1,205	-715	2	0
Net Revenue	11,043	-594	10,449	0	10,449	6,796	3,860	47	-255
Energy purchased for resale	-1,452	-176	-1,628	0	-1,628	-1,628	0	0	0
Charges on use of the electricity grid	-1,016	147	-869	0	-869	-1,123	0	0	255
Fuel for electricity production (net of CCC)	-491	0	-491	0	-491	-491	0	0	0
Other Generation Costs (2)	-100	0	-100	0	-100	-100	0	0	0
Construction costs	-1,055	1,055	0	0	0	0	0	0	0
Regulatory remeasurements	6,130	-6,130	0	0	0	0	0	0	0
Contribution Margin	13,059	-5,698	7,361	0	7,361	3,454	3,860	47	0
PMSO, excluded Other Generation Costs (2)	-1,905	-10	-1,915	313	-1,602
Provisions	229	656	885	-480	405
Results from asset sale	0	0	0	0	0
Other income and expenses	28	0	29	-29	0
Results, before Equity holdings	11,411	-5,051	6,360	-195	6,165
Equity holdings	749	-138	610	0	610
EBITDA	12,159	-5,189	6,970	-195	6,775
D&A	-990	-500	-1,490	0	-1,490
EBIT	11,169	-5,689	5,480	-195	5,285
Financial Result	-2,788	-126	-2,915	563	-2,352
EBT	8,381	-5,815	2,566	368	2,934
Income Tax and Social Contribution	-1,186	776	-410	-758	-1,168
Net Income	7,195	-5,039	2,156	-390	1,766

(1) Eliminations: These refer to the portion of transmission system usage charges paid by AXIA Energia's generators to the Company's own transmission companies, which receive them in the form of RAP. For accounting consolidation purposes (Tables 4 and 5), these amounts are eliminated from both transmission revenue and generation usage charges. For management purposes, gross transmission revenue in 3Q24 is R$ 4,575 million, and including the accounting elimination of -R$ 255 million, this translates into accounting revenue of R$ 4,320 million. In the case of generation connection charges costs, for management purposes, the value in 3Q24 is -R$ 1,123 million, and including the accounting elimination of R$ 255 million, this translates into an accounting cost of -R$ 869 million.

(2) The "RHR Hedge Cost" and "Other Operating Costs" lines, related to generation segment costs, make up the "Other PMSO Costs" line under the accounting view. For a better understanding of the contribution margin by segment, from a management perspective, both lines are allocated in the composition of the contribution margin from generation. In 3Q24, the adjusted regulatory PMSO under the accounting view totaled R$ 1,702 million, composed of R$ 91 million in RHR hedge costs and R$ 9 million in other generation operating costs, both allocated in the margin from generation, and R$ 1,602 million in other cost and expense components for personnel, materials, services and others. At the same time, in 3Q24, the adjusted IFRS PMSO from an accounting perspective totaled R$ 1,692 million, comprised of R$ 91 million in RRH hedging costs and R$ 9 million in other generation operating costs, both allocated to the margin from generation, and R$ 1,592 million in other cost and expense components related to personnel, materials, services, and others.

8.2. Generation Segment

Revenue by Contracting Environment

Recurring regulatory revenue was R$ 6,775 million in 3Q25, R$ 159 million lower than adjusted IFRS generation revenue. This difference reflected the accounting treatment of the portion of revenue from Amazonas Energia related to previously unpaid amounts, following a change in the assessment of receivables. Under IFRS, these amounts were recognized as revenue, while under regulatory accounting—where such recognition had already occurred—there was also a reversal of the provision recorded at that time. The difference, which had been recognized in previous comparison periods, had the same nature at that time.

Two effects on energy sales in the regulated market deserve highlight:

(a) the contractual extension and sale of additional energy in 3Q24, without a counterpart in 3Q25, related to the renegotiation of the hydrological risk of Tucuruí HPP, and

(b) the 84% reduction in revenue from the sale of thermal energy, which in 3Q25 included only the Santa Cruz TPP, whose sale was completed on October 9, 2025.

Regarding non-recurring effects in the quarter, a negative impact of R$ 26 million was recorded, stemming from adjustments to the value of thermal power plant sale transactions. The adjustment relates to obligations and rights with maturities extending beyond the closing of the transactions.

Table 16 - Generation revenue by contracting environment (R$ mm)

Revenue Generation	Volume (aMW) (a)			Price (R$/MWh) (b)			Regulatory Revenue (c) = (a) x (b)
Revenue Generation	3Q25	% Y/Y	% Q/Q	3Q25	% Y/Y	% Q/Q	3Q25	% Y/Y	% Q/Q
(+) Regulated Market	3,609	-40.1	-9.7	231	-24.5	-14.8	1,840	-54.7	-22.2
Existing	3,244	8.6	-1.0	220	4.0	0.7	1,576	13.0	0.7
M&As (1)	120	29.6	32.3	239	-19.9	-22.1	63	3.8	4.2
HPP Tucuruí Extension (2)	0	n.m.	0.0	0	0.0	0.0	0	n.m.	0.0
Thermal	246	-77.0	-61.0	369	-32.0	-31.3	200	-84.4	-72.9
(+) Free Market	7,435	3.9	-2.4	165	3.9	7.3	2,707	7.9	5.9
Existing	7,342	2.6	-3.6	165	3.7	7.1	2,669	6.4	4.4
M&As (1)	93	0.0	0.0	185	0.0	0.0	38	0.0	0.0
(+) O&M (Quotas)	2,279	-42.2	1.4	94	11.7	-9.3	474	-35.4	-7.1
(+) ST Market (CCEE)(3)	3,233	83.1	-19.2	246	37.9	41.9	1,755	152.4	15.9
(=) Revenue with energy sold	16,556	-12.3	-7.3	185	-3.4	4.1	6,775	-15.3	-2.5
(+) Other (4)	—	—	—	—	—	—	-26	n.m.	-76.7
(=) Total Revenue	—	—	—	—	—	—	6,749	-15.6	-1.3
Recurring	—	—	—	—	—	—	6,775	-15.3	-2.4
Non-recurring	—	—	—	—	—	—	-26	0.0	-76.1

Revenue Generation	Regulatory Revenue (c)			Accounting Adjustment (d) (5)			Accounting Revenue (e) = (c) + (d)
Revenue Generation	3Q25	3Q24	2Q25	3Q25	3Q24	2Q25	3Q25	3Q24	3Q25x3Q24	2Q25	3Q25x2Q25
Regulated Market	1,840	4,065	2,365	159	347	15	1,998	4,412	-54.7%	2,381	-16.1
Free Market	2,707	2,508	2,557	0	0	0	2,707	2,508	7.9%	2,557	5.9
O&M (Quotas)	474	734	510	0	0	0	474	734	-35.4%	510	-7.1
Short-term market (3)	1,755	695	1,514	0	0	0	1,755	695	152.4%	1,514	15.9
Energy Sales	6,775	8,002	6,946	159	347	15	6,934	8,349	-16.9%	6,962	-0.4
Others (4)	-26	-1	-111	0	0	0	-26	-1	n.m.	-111	-76.7
Total Revenue	6,749	8,001	6,836	159	347	15	6,908	8,348	-17.2%	6,851	0.8
Recurring	6,775	8,001	6,945	159	347	15	6,934	8,348	-16.9%	6,960	-0.4
Non-recurring	-26	0	-109	0	0	0	-26	0	0.0%	-109	-76.1

(1) M&A: Includes revenue from assets in which AXIA Energia’s ownership interest has changed over the past 12 months.

(2) Energy sales related to the 12th and 13th Existing Energy Auctions (LEN) of the Tucuruí HPP, resulting from the extension of the concession term through the signing of a contract in the Regulated Contracting Environment (ACR), following the renegotiation of hydrological risk for electricity generation, as per ANEEL Ruling No. 1,395, dated May 20, 2019. The revenues refer to the period from July 12, 2024, to August 30, 2024. This event, which affected only 3Q24—with no equivalent effect in 3Q25—generated a sold volume of 1,872 MWm, recognized revenue of R$ 1,327 million, and an average price of R$ 321/MWh.

(3) Short-term market: the Brazilian electric energy trading chamber (CCEE).

(4) Main effect: recognition of a negative amount of R$ 26 million, related to adjustments in the value of thermal power plant sale transactions. This effect refers to obligations and rights with maturities extending beyond the completion of the transactions and is treated as a non-recurring adjustment to gross revenue in the period.

(5) The differences between IFRS and regulatory revenues in 2Q25, 3Q24 and 3Q25 refer to energy sold and unpaid for by Amazonas Energia, which was not recognized as revenue under IFRS accounting, but recorded under regulatory accounting, where it was fully provisioned.

Regulatory Margin from Generation

The contribution margin from generation reflects the value added by this segment’s results, considering energy trading and directly related costs, and excluding Personnel, Materials, Services, and Other expenses.

The contribution of generation to the results decreased to R$ 2,815 million in 3Q25 from R$ 3,454 million in 3Q24, which is mainly explained by the sale of the Amazonas thermal power plants in May 2025 and the lower volume of available energy due to the GSF (Generation Scaling Factor), which fell to 64.9% in 3Q25 from 79.1% in 3Q24. In unit terms, the margin by volume of available energy (energy resource) decreased to R$ 91/MWh in 3Q25 from R$ 96/MWh in 3Q24.

It is worth noting that, when excluding the thermal power plant results (Table 18), the unit contribution margin rose to R$ 93/MWh in 3Q25 from R$ 86/MWh in 3Q24, while energy resources fell to 13,819 MWm from 15,368 MWm, reflecting the drop in the GSF mentioned above.

Table 17 - Generation - adjusted contribution margin, regulatory (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Gross Revenue	6,775	8,001	-15.3	6,945	-2.4	20,744	20,676	0.3
Taxes	-616	-911	-32.4	-704	-12.5	-2,067	-2,407	-14.1
Sector charges	-274	-294	-7.0	-380	-28.0	-968	-958	1.0
Net Revenue	5,886	6,796	-13.4	5,861	0.4	17,709	17,311	2.3
Energy purchased for resale	-1,714	-1,628	5.3	-1,447	18.4	-4,905	-3,513	39.6
Charges on use of the electricity grid (1)	-1,132	-1,123	0.8	-1,082	4.7	-3,337	-3,257	2.4
Fuel for electricity production (net of CCC (2))	-193	-491	-60.6	-222	-13.0	-975	-1,461	-33.2
Other Generation Costs	-31	-100	-68.5	-38	-17.1	-106	-133	-20.4
GSF Insurance (3)	-19	-91	-79.3	-17	11.7	-52	-112	-53.5
Others (4)	-13	-9	40.1	-21	-40.1	-54	-21	n.m.
Contribution Margin	2,815	3,454	-18.5	3,072	-8.4	8,386	8,947	-6.3
Resources (MWm) (5)	14,065	16,230	-13.3	15,786	-10.9	16,228	17,378	-6.6
Unit Margin (R$/MWh)	91	96	-6.0	89	1.7	79	78	0.7

Table 18 - Generation, ex thermal power plants - adjusted contribution margin, regulatory (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Gross Revenue	6,575	6,720	-2.1	6,205	6.0	18,512	16,943	9.3
Taxes	-594	-692	-14.0	-655	-9.2	-1,928	-1,807	6.7
Sector charges	-274	-294	-7.0	-380	-28.0	-968	-933	3.7
Net Revenue	5,707	5,734	-0.5	5,170	10.4	15,616	14,203	10.0
Energy purchased for resale	-1,703	-1,628	4.6	-1,300	31.0	-4,430	-3,064	44.6
Charges on use of the electricity grid (1)	-1,125	-1,075	4.7	-995	13.1	-3,112	-3,156	-1.4
Fuel for electricity production (net of CCC (2))	0	0	0.0	0	0.0	0	0	0.0
Other Generation Costs	-31	-100	-68.5	-38	-17.1	-106	-133	-20.4
GSF Insurance (3)	-19	-91	-79.3	-17	11.7	-52	-112	-53.5
Others (4)	-13	-9	40.1	-21	-40.1	-54	-21	153.4
Contribution Margin	2,847	2,931	-2.9	2,836	0.4	7,968	7,849	1.5
Resources (MWm) (5)	13,819	15,368	-10.1	15,310	-9.7	15,755	16,690	-5.6
Unit Margin (R$/MWh)	93	86	8.0	85	10.0	77	72	7.9

(1) Does not consider the accounting elimination effect of charges paid to the Company's own transmission segment.

(2) CCC: Conta de Consumo de Combustíveis, or Fuel Consumption Account, is responsible for management of payments

made by distribution and transmission companies to subsidize the costs of generators serving Isolated Systems.

(3) RHR: Renegotiation of Hydrological Risk

(4) Others: association contributions (CCEE and ONS) and other costs.

(5) Includes own resources and structural purchases, taking into account contracts with a supply duration longer than 12 months.

Table 19 - Generation - ajusted contribution margin, regulatory - by contracting environment (R$ mm)

	3Q25					3Q24		2Q25
	Total (a)=(b)+(c) +(d)+(e)	Thermal (b)	Quota (c)	ACR (d)	ACL + MCP (e)	ACL + MCP	% Y/Y	ACL + MCP	% Q/Q
Gross Revenue	6,749	174	474	1,640	4,462	3,202	39.3	4,051	10.1
(-) Adjustment	26	26	0	0	0	0	0.0	0	0.0
Adjusted Gross Revenue	6,775	200	474	1,640	4,462	3,202	39.3	4,051	10.1
(-) Taxes	-616	-21	-43	-148	-403	-330	22.4	-429	-5.9
(-) Sector Charges	-274	0	-40	-71	-163	-125	30.6	-234	-30.5
(-) Energy purchased for resale	-1,714	-11	0	0	-1,703	-1,628	4.6	-1,300	31.0
(-) Charges on use of the electricity grid (1)	-1,132	-7	-201	-297	-628	-415	51.2	-595	5.4
(-) Fuel for electricity production (2)	-193	-193	0	0	0	0	0.0	0	0.0
(-) Other Generation Costs	-31	0	-1	-22	-9	-4	99.5	-14	-37.9
GSF Insurance (3)	-19	0	0	-19	0	0	0.0	0	0.0
Others (4)	-13	0	-1	-3	-9	-4	99.5	-14	-37.9
Contribution Margin (f)	2,815	-32	189	1,102	1,556	701	n.m.	1,478	5.3

	Own Resources (MWm)				12,999	15,203	-14.5	14,820	-12.3
	(-) Quotas				-2,279	-3,474	-34.4	-2,248	1.4
	(-) ACR (includes thermal plants)				-3,609	-6,194	-41.7	-3,993	-9.6
	(+) Structural Purchases				1,066	1,028	3.8	966	10.4
	Resources (MWm) (5)				8,177	6,562	24.6	9,545	-14.3
	Resources (MWh thousand) (4) (g)				18,055	14,490	24.6	20,845	-13.4

	R$/MWh (f)/(g)				86	48	78.3	71	21.5

(1) Does not consider the accounting elimination effect of charges paid to the Company's own transmission segment.

(2) Net of CCC: Conta de Consumo de Combustíveis, or Fuel Consumption Account, is responsible for management of payments

made by distribution and transmission companies to subsidize the costs of generators serving Isolated Systems.

(3) RHR: Renegotiation of Hydrological Risk

(4) Others: association contributions (CCEE and ONS) and other costs.

(5) Includes own resources and structural purchases, considering contracts with a supply term longer than 12 months.

The contribution margin of energy traded in the Free Contracting Market and settled in the Short Term Market increased to R$ 86/MWh in 3Q25 from R$ 48/MWh in 3Q24, considering the resources available for allocation in both environments.

Available resources increased due to the combined effect of volume released by the gradual phasing out of legacy contracts (decotization) and absence, this year, of the additional sale related to the Tucuruí HPP contract extension. These factors more than offset the lower GSF, which fell to 64.9% in 3Q25 from 79.1% in 3Q24.

The contribution in financial volume increased to R$ 1,556 million in 3Q25 from R$ 701 million in 3Q24, with higher revenue more than offsetting the increased expenses related to energy purchases, as a result of the energy trading strategy in the quarter.

8.3. Transmission Segment

Regulatory Margin from Transmission

Net transmission revenue comprises gross revenue and its respective deductions and, for management purposes, represents the contribution margin of this segment.

Gross transmission revenue is based on the Allowed Annual Revenue (RAP) and the Adjustment Portion (PA) approved by ANEEL for the current tariff cycle, 2025/2026 (from July 1, 2025, to June 30, 2026). It is worth noting that the PA of the current tariff cycle is a contractual mechanism established by the regulator to compensate for any deficit or surplus between the revenue billed and the RAP approved in the previous cycle.

In addition, gross revenue includes:

(a) taxes and charges that are not part of the RAP (gross-up);

(b) discounts for unavailability;

(d) pass-through items, which are offset in the following cycle through the PA.

Accounting eliminations related to transmission system usage charges paid by AXIA Energia’s generation companies to the Group’s own transmission subsidiaries are not considered. Deductions include taxes (PIS/COFINS, ICMS, and ISS) and sector charges (CDE, PROINFA, TFSEE, R&D, and RGR).

Net regulatory transmission revenue was R$ 4,187 million, up 8.5% YoY, mainly reflecting the lower PA in the current tariff cycle, primarily explained by:

(a) the repositioning of RBSE's financial component;

(b) the review of resources linked to the 2023 Periodic Tariff Review (RTP); and

Further details and explanations are available in the "Modeling Support - Transmission" spreadsheet, located in the Results Center on the Company's Investor Relations website, including an analysis of the transmission revenue and a breakdown of the Adjustment Portion (PA).

Table 20 - Transmission - adjusted contribution margin, regulatory (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
RAP (1)	4,134	4,246	-2.6	4,246	-2.6	12,626	13,033	-3.1
PA (1)	-117	-382	-69.5	-382	-69.5	-881	-524	68.2
Approved RAP and Adjustment Portion	4,018	3,864	4.0	3,864	4.0	11,745	12,509	-6.1
Taxes and Sector Charges (2)	685	551	24.3	585	17.0	1,858	1,739	6.8
Unavailability Discount (3)	-51	-60	-15.3	-64	-21.5	-181	-184	-1.5
RAP Addition: new facilities	9	4	n.m.	40	-77.1	80	57	41.1
Pass through (4)	176	71	n.m.	157	11.9	476	416	14.5
Other mismatches (5)	184	146	25.9	179	2.8	499	565	-11.6
Gross Revenue (6)	5,020	4,575	9.7	4,760	5.5	14,477	15,102	-4.1
Tributes	-479	-423	13.1	-457	4.8	-1,341	-1,373	-2.3
Sector Charges (7)	-355	-292	21.8	-332	7.0	-1,025	-918	11.7
Net Revenue	4,187	3,860	8.5	3,972	5.4	12,111	12,810	-5.5

(1) RAP and PA: considers 1/4 of the amounts approved for the tariff cycle in effect during the quarter, and proportional amounts accumulated throughout the year.

(2) Considers (a) PIS/COFINS and (b) CDE/Proinfa. Both are pass-through costs, and AXIA Energia collects these amounts from consumers.

(3) Discount associated with Variable Portion (PV), suspension of Base Payment (PB)

due to unavailability, and pending items in Release Terms (TL).

(4) Items for which transmission companies act only as collection agents, and which will be deducted in PA in the following tariff cycle.

This involves differences between the approved RAP and billing by ONS related to cost-sharing of advances, as well

as the receipt of CDE Fund resources (via CCEE) for amounts not collected due to discounts applied on tariffs.

(5) Other mismatches in relation to the approved RAP for the current tariff cycle, such as (a) mismatch

between Transmission and Distribution Annual Adjustments, (b) complementary AVCs associated with the termination of

Transmission System Usage Agreements (CUST) by generators, etc.

(6) Does not consider the accounting elimination effect of charges paid to the Company's own transmission segment.

Eliminations: transactions that occur between companies of the same group, i.e., AXIA Energia companies.

These refer to transmission system usage charges paid by AXIA Energia generation companies to AXIA Energia transmission companies,

which receive them in the form of RAP. For consolidation purposes, these amounts are eliminated from

transmission revenue and generation usage cost.

(7) Sector Charges includes: RGR, R&D, TFSEE, CDE, and Proinfa.

8.4. Operating Costs and Expenses - IFRS

Table 21 - Operating costs and expenses (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Energy purchased for resale	1,714	1,452	18.0	1,356	26.5	4,630	2,986	55.0
Charges on use of the electricity grid	1,010	1,016	-0.6	955	5.8	2,961	2,986	-0.9
Fuel for electricity production	193	491	-60.6	222	-13.0	975	1,461	-33.2
Construction	1,262	1,055	19.7	1,036	21.9	3,043	2,483	22.6
Personnel, Material, Services and Others	1,623	2,005	-19.0	1,631	-0.5	4,912	5,261	-6.6
Depreciation and Amortization	1,156	990	16.7	1,131	2.1	3,399	2,955	15.0
Operating provisions	236	-229	n.m.	133	77.1	495	-160	n.m.
Result from asset sale	7,071	0	n.m.	105	n.m.	7,176	115	n.m.
Regulatory remeasurements	-303	-6,130	-95.1	3,433	n.m.	4,082	-6,130	n.m.
Costs and expenses	13,961	650	n.m.	10,002	39.6	31,674	11,958	n.m.
*Non-recurring events*
(-) Non-recurring PMSO events	-114	-313	-63.6	-228	-50.0	-534	-516	3.3
(-) Non-recurring provisions	-218	480	n.m.	43	n.m.	-215	994	n.m.
(-) Result from asset sale	-7,071	0	n.m.	-105	n.m.	-7,176	-115	n.m.
(-) Regulatory remeasurements	0	0	0.0	-3,433	n.m.	-3,433	0	0.0
Adjusted Costs and Expenses	6,559	817	n.m.	6,279	4.5	20,316	12,320	64.9

Energy purchased for resale, charges on the use of electricity grid, fuel for electricity production, and construction costs comprise the generation and transmission margins. The explanation of the remaining lines, including PMSO (Personnel, Materials, Services, and Other), is provided below.

Personnel, Material, Services and Others

▪

Personnel: adjusted balance of R$ 750 million in 3Q25, down 17% YoY, with the main effects being:

▪

R$ 152 million in savings driven by the Voluntary Dismissal Plans (VDPs), broken down as follows:

(a) R$ 118 million from workforce reduction,

(b) R$ 64 million reflecting the capitalization of personnel costs, more aligned with the increased level of investments, and

(c) R$ 34 million from efficiency gains driven by team restructuring, new hiring models, and increased process centralization.

These effects were partially offset by new hires, which increased expenses by R$ 37 million.

▪

Non-recurring effects: R$ 82 million, being:

(a) R$ 32 million with VDPs,

(b) R$ 29 million related to FGTS fine linked to terminations, and

▪

Material: adjusted balance of R$ 63 million in 3Q25, in line with the R$ 64 million recorded in 3Q24.

▪

There were no non-recurring effects in the quarter.

▪

Services: adjusted balance of R$ 533 million in 3Q25, down R$ 36 million YoY, driven by optimization and savings with travel, insurance, and consulting services.

▪

Non-recurring effects: R$ 15 million, being R$ 14 million related to success fee paid to legal defense as part of the contingency reduction strategy.

▪

Outros: adjusted balance of R$ 163 million in 3Q25, up R$ 6 million YoY.

▪

Non-recurring effects: R$ 18 million associated with commitments under the self-managed health plan, which was replaced by a plan managed by a specialized market operator.

For more details on PMSO, including a breakdown by company and by nature of other costs and expenses, please refer to Appendix 2 - PMSO Breakdown.

Table 22 - Detailed IFRS PMSO (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Personnel	800	902	-11.3	899	-11.0	2,555	2,771	-7.8
VDP	32	2	n.m.	98	-67.5	226	45	n.m.
Material	63	64	-1	41.9	51	157.2	147	7
Services	548	569	-3.6	456	20.1	1,442	1,464	-1.6
Others	180	468	-61.5	136	32.4	533	833	-36.0
other generation costs	31	100	-68.5	38	-17.1	106	133	-20.4
other expenses	149	368	-59.6	98	51.5	427	700	-39.0
PMSO (a)	1,623	2,005	-19.0	1,631	-0.5	4,912	5,261	-6.6
Personnel	-50	0	0.0	-115	-56.8	-218	0	0.0
VDP	-32	-2	n.m.	-98	-67.5	-226	-45	n.m.
Material	0	0	0.0	0	0.0	0	0	0.0
Services	-15	0	0	-15	-1.6	-72	-42.2	70
Others	-18	-311	-94.4	0	0.0	-18	-429	-95.9
other generation costs	0	0	0.0	0	0.0	0	0	0.0
other expenses	-18	-311	-94.4	0	0.0	-18	-429	-95.9
Non recurring (b)	-114	-313	-63.6	-228	-50.0	-534	-516	3.3
Personnel	750	902	-16.9	784	-4.3	2,336	2,771	-15.7
VDP	0	0	0.0	0	0.0	0	0	0.0
Material	63	64	-1.5	42	51.3	157	147	6.6
Services	533	569	-6.3	441	20.9	1,370	1,422	-3.7
Others	163	157	3.9	136	19.5	516	404	27.6
other generation costs	31	100	-68.5	38	-17.1	106	133	-20.4
other expenses	131	57	n.m.	98	33.6	410	271	51.2
PMSO adjusted (c) = (a) + (b)	1,509	1,692	-10.8	1,403	7.6	4,379	4,744	-7.7
PMSO excluding TPP * (c.1)	1,503	1,657	-9.3	1,374	9.4	4,307	4,641	-7.2
expenses	1,471	1,558	-5.5	1,336	10.2	4,201	4,508	-6.8
costs: generation segment **	31	100	-68.5	38	-17.1	106	133	-20.4
Thermal Power Plants (c.2)	6	35	-81.6	29	-78.3	72	103	-29.8

* TPP: Thermal Power Plants. PMSO of thermal plants sold to Âmbar.For 2Q25, considers amounts for the Santa Cruz Thermal Power Plant for the full quarter.

For the other plants, whose sale was completed on May 15, 2025, amounts are considered up to that date.

** Other operating costs, related to generation operations: GSF insurance, association contributions, and other items.

Regulatory Remeasurement and Asset Disposal Result

▪

Regulatory Remeasurement - Transmission Contracts: Revenue of R$ 303 million in 3Q25, reflecting adjustments in the flow of RAP receivables from transmission concession contracts, resulting from the annual readjustment process for the 2025/2026 cycle, which began in July 2025.

▪

Asset disposal result: R$ 7,071 million expense in 3Q25, mainly reflecting non-cash adjustments due to negotiations concluded during the period, notably:

▪

-R$ 7,290 million: Sale of the entire stake in Eletronuclear to J&F;

▪

+R$ 234 million: Asset uncrossing with Copel, with the acquisition of the Colíder HPP in exchange for a stake in the Jayme Canet Junior HPP (Mauá) and in the Mata de Santa Genebra transmission plant;

▪

-R$ 25 million: Sale of the entire stake in EMAE to Sabesp;

▪

+R$ 11 million: Completion of the sale of the Amazonas thermal plants to Âmbar Energia.

Operating Provisions

Table 23 - Operating provisions - IFRS (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Operating Provisions / Reversals
Provision/Reversal for Litigation	-419	418	n.m.	22	n.m.	-505	646	n.m.
Estimated losses on investments	12	11	1.3	21	-45.9	45	-18	n.m.
Measurement at fair value of assets held for sale	0	-30	n.m.	0	0.0	0	137	n.m.
Provision for the Implementation of Lawsuits - Compulsory Loan	-15	3	n.m.	-20	-23.5	-10	-47	-79.3
ECL - Loans and financing	176	-6	n.m.	-10	n.m.	166	-10	n.m.
ECL - Consumers and resellers	-35	-59	-40.3	-79	-55.1	-133	-235	-43.2
ECL - Other credits	175	-10	n.m.	-26	n.m.	142	-125	n.m.
Onerous contracts	29	52	-44.1	30	-0.7	88	136	-35.3
Results of actuarial reports	-95	-128	-26.0	-92	3.4	-279	-384	-27.2
Other *	-63	-23	n.m.	20	n.m.	-10	60	n.m.
Operating Provisions / Reversals	-236	229	n.m.	-133	77.1	-495	160	n.m.
*Non-recurring items / Adjustments*	218	-480	n.m.	-43	n.m.	215	-994	n.m.
Provision for Litigation	419	-418	n.m.	-22	n.m.	505	-646	n.m.
Measurement at fair value of assets held for sale	0	0	0.0	0	0.0	0	-293	n.m.
Estimated losses on investments	-12	-11	1.3	-21	-45.9	-45	18	n.m.
Provision for the Implementation of Lawsuits - Compulsory Loan	15	-3	n.m.	20	-23.5	10	47	-79.3
ECL - Loans and financing	-176	6	n.m.	10	n.m.	-166	10	n.m.
Onerous contracts	-29	-52	-44.1	-30	-0.7	-88	-136	-35.3
Impairment	0	0	n.m.	0	0.0	0	6	n.m.
Restitution RGR	0	0	0.0	0	0.0	0	0	0.0
Adjusted Provisions/Reversals	-18	-251	-92.7	-177	-89.7	-281	-834	-66.4

Positive values in the table above indicate reversal of provision.

* Primarily Includes impairment and RGR refunds.

▪

Provision for litigation: provision of R$ 419 million in 3Q25 compared to a reversal of R$ 418 million in 3Q24. The R$ 837 million variation was explained by the recording of provisions in civil, tax, labor, regulatory, environmental, land, and other proceedings, partially offset by the reversal of provisions in compulsory loan proceedings.

▪

Compulsory Loan: Contributed a net reversal of R$ 300 million in 3Q25, compared to the net reversal of R$ 374 million in 3Q24, reflecting agreements signed and favorable decisions. It is worth noting that, unlike other provisions, the monetary restatement related to the compulsory loan provision was recognized under financial results.

▪

Other events: Contributed a provision of R$ 566 million in 3Q25, compared to a reversal of R$ 324 million in 3Q24, an R$ 890 million variation in expenses in the period, mainly explained by:

(a) provisions recognized in 3Q25 related to cases of various natures, including civil, labor, and regulatory matters; and

(b) monetary restatement, which contributed an expense of R$ 153 million in 3Q25, compared to R$ 270 million in 3Q24.

▪

Fair value measurement of asset available for sale: no recognitions in 3Q25, after a R$ 30 million provision was recorded in 3Q24.

▪

Share conversion process – Compulsory Loan: R$ 15 million provision in 3Q25, compared to R$ 3 million reversal in 3Q24. This result reflects the mark-to-market effect on the average price of the Company’s class B preferred shares over the past 12 months, related to amounts recorded in the balance sheet and linked to those shares.

▪

Expected Credit Losses (ECL) - Loans and Financings: the R$ 176 million reversal included R$ 140 million related to provisions for guarantees granted by AXIA Energia in connection with loans contracted by Amazonas Energia.

▪

Expected Credit Losses (ECL) - Other Receivables: R$ 175 million reversal in 3Q25 compared to a R$ 10 million provision in 3Q24. In 3Q25, R$ 170 million in debts owed by Amazonas Energia to AXIA Energia were reversed following the release of judicial deposits previously made by the counterparty.

▪

Onerous Contracts: R$ 29 million reversal in 3Q25 compared to a R$ 52 million reversal in 3Q24, reflecting changes in the value of contracts in the period.

▪

Results of actuarial reports: R$ 95 million provision in 3Q25 compared to a R$ 128 million provision in 3Q24 associated with interest expenses and current service costs, as outlined in the 2024 reports, due to a reduction in the underlying liability base.

8.5. Equity Holdings - IFRS

The main highlights of equity income were as follows:

▪

Eletronuclear: 3Q25 income was not recognized following the signing of the agreement for the sale of the company’s stake.

▪

Transnorte Energia (TNE): The increase in 3Q25 results reflected the positive effect of the regulatory remeasurement arising from the agreement between ANEEL and TNE to pursue the economic and financial rebalancing of the concession. The agreement set a maximum RAP value of R$ 592 million (as of July 2025) and extended the concession term from 17 to 27 years. Under the IFRS accounting perspective, this led to a review that increased the value of the contractual asset, resulting in a positive impact from the regulatory remeasurement.

▪

Equatorial Maranhão: Recognition of both 3Q25 and 2Q25 results.

Table 24 - Equity holdings (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Highlights Affiliates (a)	395	620	-36.3	-45	-972.7	626	1,620	-61.3
Eletronuclear (1)	0	237	n.m.	-147	n.m.	-84	540	-115.5
ISA Energia	191	231	-17.4	25	673.3	350	649	-46.1
Equatorial Maranhão	149	71	109.7	0	n.m.	149	149	0.0
Other Affiliates	55	81	-32.2	78	-29.3	211	282	-25.2
Highlights SPEs (b) (2)	751	37	n.m.	-148	-608.6	651	204	218.7
IE Madeira	55	11	398.5	31	75.7	170	128	32.9
Belo Monte Transmissora de Energia S.A. - BMTE	95	50	90.6	27	253.9	178	157	13.5
Transnorte Energia (TNE)	649	62	949.3	-128	-609.3	572	97	490.9
Chapecoense	59	47	26.0	55	7.3	157	129	22.2
ESBR Jirau	57	14	308.9	22	161.4	118	55	115.4
IE Garanhuns	15	5	191.3	23	-37.9	53	45	17.2
Norte Energia	-179	-152	17.9	-179	0.2	-598	-406	47.3
Other Holdings (c) (3)	119	92	29.7	67	77.9	230	279	-17.5
Total Equity Holdings (a) + (b) + (c)	1,265	749	69.0	-126	n.m.	1,507	2,103	-28.4
Non-recurring events
(-) Regulatory remeasurements, ISA Energia	0	0	0.0	116	n.m.	116	0	0.0
Adjusted Equity Holding	1,265	749	69.0	-10	n.m.	1,623	2,103	-22.8

(1) 3Q25 income was not recognized following the signing of the agreement for the sale of the company’s stake.

(2) SPE: special purpose entities.

(3) Includes movements from amounts recognized in the balance sheet of affiliated companies measured at fair value/cost.

8.6. Financial Result - IFRS

Table 25 - Financial result (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Financial Income	1,272	815	56.0	1,069	19.0	3,414	2,181	56.5
Interest income, fines, commissions and fees	38	45	-16.1	-13	n.m.	61	117	-47.5
Income from financial investments	1,228	835	47.1	1,101	11.5	3,387	1,955	73.2
Late payment surcharge on electricity	16	18	-9.0	36	-54.4	85	96	-12.3
Other financial income	68	-24	n.m.	24	n.m.	121	178	-32.0
(-) Taxes on financial income	-79	-59	32.9	-79	-1.0	-240	-165	45.4
Financial Expenses	-2,269	-2,583	-12.2	-2,380	-4.7	-7,112	-7,551	-5.8
Debt Charges	-1,444	-1,437	0.5	-1,528	-5.5	-4,613	-4,561	1.1
Loans, financing and suppliers	-1,439	-1,306	10.2	-1,459	-1.3	-4,402	-4,162	5.8
Leasing	-5	-131	-96.3	-70	-93.0	-211	-399	-47.2
CDE obligation charges (1)	-665	-622	7.0	-661	0.6	-1,988	-1,844	7.8
River basin revitalization charges (1)	-80	-85	-5.6	-79	2.1	-237	-253	-6.1
Financial discount for early payment - ENBpar	0	0	0.0	0	0.0	0	0	0.0
Other financial expenses	-79	-440	-82.1	-111	-29.3	-274	-893	-69.3
Net Financial Items	-1,575	-1,020	54.4	-1,244	26.6	-4,921	-3,328	47.9
Monetary changes	-196	0	n.m.	-264	-25.8	-744	-536	38.7
Compulsory Loan	-186	-214	-13.0	-178	4.9	-539	-593	-9.1
Others	-9	215	n.m.	-86	-89.0	-205	57	n.m.
Exchange rate variations	6	25	-77.3	-12	n.m.	-1	27	n.m.
Change in fair value of hedged debt net of derivative	-1,056	-729	44.8	-587	79.8	-2,609	-1,292	n.m.
Monetary updates - CDE (1)	-270	-236	14.5	-316	-14.5	-1,318	-1,096	20.2
Monetary updates - river basins (1)	-42	-43	-2.0	-52	-19.6	-207	-196	5.5
Change in derivative financial instrument not linked to debt protection	-17	-38	-55.5	-14	22.0	-41	-234	-82.5
Financial Results	-2,571	-2,788	-7.8	-2,555	0.6	-8,620	-8,698	-0.9
*Adjustments*
Monetary restatement - Compulsory Loan	186	214	-13.0	178	4.9	539	593	-9.1
Write-off of judicial deposits due to the conciliation project	0	100	n.m.	0	0.0	0	100	n.m.
Adjustment of the correction rate for judicial deposits	0	249	n.m.	0	0.0	0	249	n.m.
Adjusted Financial Result	-2,385	-2,225	7.2	-2,377	0.3	-8,081	-7,756	4.2

(1) These obligations were established by Law 14,182/21 (Privatization of Eletrobras, now AXIA Energia) as a condition for obtaining new concession grants for power generation for an additional 30 years. The charges were calculated based on data published in CNPE Resolution 015/2021, considering (a) the present value of the obligation; (b) the future payment flow; and (c) the payment term.

The main variations this quarter were:

▪

Financial Income: went up to R$ 1,272 million in 3Q25 from R$ 815 million in 3Q24, mainly due to the higher CDI rate in the period — 14.9% in 3Q25 versus 10.4% in 3Q24 — combined with a 6% increase in average cash.

▪

Debt charges: R$ 1,444 million expense in 3Q25, in line with 3Q24. Interest expenses on loans and financing increased, mainly due to the higher Selic rate in the period, combined with a 3% rise in the average level of gross debt. Part of this increase was offset by a reduction in leasing charges due to the termination of power purchase agreements—treated as leases—for thermal plants located in the state of Amazonas in May 2025.

▪

Monetary restatements: R$ 196 million expense in 3Q25, compared to zero in 3Q24. This line is comprised by the monetary restatements of two main components:

▪

Lawsuit update for compulsory loans: R$ 186 million expense in 3Q25 from R$ 214 million in 3Q24, reflecting the reduction in the provision inventory, which offset the higher Selic rate.

▪

Other lines: R$ 9 million expense in 3Q25 compared to a R$ 215 million revenue in 3Q24, mainly due to events that occurred in 2024 with no corresponding effects in 2025, such as the reduction in interest income on dividends due related to the reclassification to Other Revenues, the recognition of monetary restatement revenue, and the write-off of judicial deposits.

▪

Other financial expenses: R$ 79 million in 3Q25, compared to R$ 440 million in 3Q24. The reduction was mainly explained by the write-off of judicial deposits of R$ 371 million in 3Q24, with no corresponding entry in 3Q25.

8.7. Current and Deferred Taxes - IFRS

There were no events worth highlighting in the tax line in 3Q25.

▪

Non-recurring effects: R$ 53 million related to current tax expense recognized upon completion of the transaction involving the sale of the Mauá HPP.

Table 26 - Income tax and social contribution (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Current income tax and social contribution	-425	-229	85.7	-254	67.5	-757	-723	4.8
Deferred income tax and social contribution	198	(957)	n.m.	1356	-85.4	1,569	435	n.m.
Income tax and social contribution total	-226	-1,186	-80.9	1102	n.m.	811	-288	n.m.
Adjustments
Constitution of deferred taxes on tax losses - Holding	0	0	0.0	0	0	0	-1,074	n.m.
Reversal of Deferred Tax on Tax Loss with the Sale of Candiota	0	0	0.0	0	0	0	292	n.m.
Constitution/Reversal of Deferred Tax on Tax Loss (1)	0	0	0.0	0	0	0	-782	n.m.
Deferred Tax Adjustment on Regulatory Remeasurement (2)	0	-758	n.m.	-882	n.m.	-882	-758	16.4
Deferred Tax Adjustment on Eletronorte's tax rate	0	0	0.00	-393	n.m.	-393	0	0.0
Current income tax on assets sold	53	0	0.00	0	0.00	53	0	0.0
Adjusted income tax and social contribution	-173	-1,944	-91.1	-173	0.1	-411	-1,828	-77.5

(1) AXIA Energia and CGT Eletrosul in 2Q24. At the Holding level, R$1,074 million in tax credits were recognized, stemming from tax loss carryforwards accumulated by AXIA Energia, following a reassessment of taxable income due to the merger with Furnas. At CGT Eletrosul, R$292.4 million were reversed, based on a revised expectation regarding the completion of the operations required to utilize the tax credit generated by the sale of the Candiota thermal power plant.

(2) Deferred Tax recognized in 2Q25 relative to the Regulatory Remeasurement, due to changes in the payment schedule of the RBSE financial component for contracts extended under Law 12,783/2013, as approved by ANEEL’s Board at its 20th Ordinary Public Meeting held on June 10, 2025, affecting the 2025–26 to 2027–28 cycles.

9. OPERATIONAL PERFORMANCE

9.1. Generation Segment

Generation Assets

The Company had 82 plants, including 47 hydroelectric, 33 wind, 1 thermal and 1 solar in 3Q25, considering corporate ventures, shared ownership and stakes via SPEs. Compared to 2Q25, the decrease of six assets was primarily due to the transfer of ownership of thermal power plants held by Eletronorte. Additionally, the period reflected the acquisition of the Colíder HPP and the transfer of the Gov. Jayme Canet HPP from CGT Eletrosul.

Portfolio installed capacity reached 44,368 MW in 3Q25, with 99% generated from clean sources with low greenhouse gas emissions, representing 17% of Brazil's total installed capacity.

Table 27 - Generation assets

Source	Installed Capacity (MW)	Assured Capacity (aMW)	Accumulated Generated Energy (GWh)
Hydro (47 plants)	43,073	21,028	106,338
Thermal (1 plants)	500	401	1,336
Wind Power (33 plants)	794	226	1,415
Solar (1 plant)	0.93	0.00	0.73
Total (82 plants)	44,368	21,655	109,090

Total energy generated by AXIA Energia fell by 7.6% YoY in 3Q25.

Chart 4 - AXIA Energia - net energy generation (GWh)

System Data – Installed Capacity and Generation

Brazil's installed capacity was 258,111.84 MW in 3Q25.

Chart 5 - Brazil’s installed capacity - by source

Source: ANEEL's Generation Information System (SIGA)

Chart 6 - Generated energy SIN - national interconnected system (GWh)

Source: Operating Results 01/01 to 9/30/2025 from the National Operator of the Electric System (ONS)

System Data – Energy Market

Table 28 - PLD

		3Q25	3Q24	∆%	2Q25	∆%
Market	GSF (%)	64.92	79.10	-14.2 p.p.	95.64	-30.7 p.p.
	PLD SE (R$/MWh)	252.43	169.67	48.8	216.45	16.6
	PLD S (R$/MWh)	252.98	169.72	49.1	224.26	12.8
	PLD NE (R$/MWh)	239.96	142.72	68.1	154.07	55.8
	PLD N (R$/MWh)	250.98	172.55	45.5	154.59	62.4

Chart 7 - GSF (%)

Month	2021	2022	2023	2024	2025
September	52%	71%	83%	73%	63%

Chart 8 - Historical average of affluent natural energy (ENA) - SIN (%)

During the dry season, 3Q25 recorded ENAs below the historical average, with recovery observed only in the Southern submarket in September.

Chart 9 - Energy stored in reservoirs (EAR) - SIN (%)

The Brazilian Interconnected System (SIN) ended the quarter with the level of energy stored in reservoirs at 55%, more than 6% higher than in the same period last year. The highlight was the Northern submarket at 82.4%, 7% above the highest level of the last five years.

9.2. Transmission Segment

The Company ended 3Q25 with 74.8 thousand km of transmission lines, compared to 74.0 thousand km in 3Q24. There were also 412 substations, being 296 owned and 116 operated by third parties.

Table 29 - Transmission lines (km)

Company	Own(1)	In Partnership (2)	Total
Chesf	22,191	1,832	24,023
Eletronorte	10,988	2,013	13,001
CGT Eletrosul	12,182	5	12,187
AXIA Energia	22,129	3,429	25,558
Total	67,490	7,279	74,769

(1) Includes TMT (100%) and VSB (100%).

(2) Partnerships consider extensions proportional to the capital invested by AXIA Energia Companies in the venture.

9.3. ESG

Table 30 - ESG KPIs 3Q25

Pillar	KPI	3Q24	3Q25	Change
Planet	Accumulated GHG Emissions for the year (1)	2,605,049	1,252,389	-52%
Planet	(Scopes 1, 2 and 3) (tCO2e)	2,605,049	1,252,389	-52%
People	Accident Frequency Rate - own Employees (with time off)	0.54	0.49	-9%
	Women in the Workforce (%)	21%	25%	4 p.p.
	Leadership positions held by women (%) (2)	26%	25%	-1 p.p.
Governance	Complaints answered on time (%)	100.0%	98.0%	-2 p.p.

The values presented are preliminary and not assured, and may be adjusted based on data collection, verification and updating processes.

(1) The reduction in emissions is primarily due to the removal of coal-fired thermoelectric generation from the Company’s energy matrix.

(2) Reduction was due to departures connected to the VDPs.

(3) The percentage of complaints handled remains within the parameters established by the target.

10. APPENDIX

10.1. Appendix 1 - Generation and Transmission Revenue IFRS

Generation revenue comprises:

(a) revenue from supply to non-end consumers — distributors, traders, and generators — under contracts in the Regulated Contracting Environment (ACR) and the Free Contracting Environment (ACL);

(b) revenue from supply to end consumers — industrial and commercial clients — under contracts exclusively in the ACL;

(d) revenue from operation and maintenance, representing remuneration for energy sold under the quota regime.

Table 31 - Generation operating revenue (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Power supply to non-end consumers	4,235	6,224	-32.0	4,374	-3.2	13,951	13,632	2.3
Power supply to end consumers	422	695	-39.3	433	-2.6	1,349	2,248	-40.0
CCEE	1,777	695	n.m.	1,534	15.8	3,923	1,911	n.m.
O&M revenue	474	734	-35.4	509	-6.9	1,503	2,319	-35.2
Generation Revenues	6,908	8,348	-17.2	6,851	0.8	20,727	20,109	3.1
*Non-recurring items - Adjustments*	26	0	0.0	109	-76.1	135	0	0.0
Adjusted Generation Revenue	6,934	8,348	-16.9	6,960	-0.4	20,862	20,109	3.7

Transmission revenue comprises:

(a) operation and maintenance (O&M) revenue, related to the operation and maintenance of assets;

(b) construction revenue, linked to investments made (appropriated and allocated) in ongoing projects; and

(c) contractual (financial) revenue, associated with the application of inflation indices to the asset balances of each concession contract.

Table 32 - Transmission operating revenue (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Revenue from Operation & Maintenance (O&M)	2,096	1,906	10.0	2,065	1.5	6,177	5,863	5.4
Construction Revenue	1,182	1,044	13.2	1,063	11.2	2,991	2,351	27.2
Contractual Revenue - Transmission	1,367	1,616	-15.4	1,951	-29.9	5,742	5,306	8.2
Transmission Revenues	4,646	4,566	1.7	5,079	-8.5	14,910	13,520	10.3
*Non-recurring items - Adjustments*	0	0	0.0	0	0.0	0	0	0.0
Adjusted Transmission Operating Revenue	4,646	4,566	1.7	5,079	-8.5	14,910	13,520	10.3

10.2. Appendix 2 - PMSO Breakdown

Table 33 - PMSO 3Q25 (R$ mm)

PMSO	3Q25
(R$ million)	AXIA Energia Holding	Chesf	Eletronorte	CGT Eletrosul	Total	Elimination	Consolidated IFRS
Personnel	357	199	165	78	800	0	800
Voluntary Dismissal Plan (PDV) - Provision	18	5	7	1	32	0	32
Material	26	17	13	8	63	0	63
Services	315	101	100	33	548	0	548
Other	97	11	50	26	184	-3	180
PMSO	813	333	336	146	1,627	-3	1,623
*Non-recurring events*
Personnel: VDP	-18	-5	-7	-1	-32	0	-32
Personnel: Termination Costs	-20	-8	-17	-4	-50	0	-50
Services: Success fee related to legal consulting	-13	-1	0	0	-14	0	-14
Services: Other expenses	-1	0	0	0	-1	0	-1
Other: Expenses related to healthcare	-7	-4	-5	-2	-18	0	-18
Other: Judicial convictions	0	0	0	0	0	0	0
Other: Write-off of court deposits	0	0	0	0	0	0	0
Adjusted PMSO	754	314	306	138	1,513	-3	1,509

Table 34 - PMSO 3Q24 (R$ mm)

PMSO	3Q24
(R$ million)	AXIA Energia Holding	Chesf	Eletronorte	CGT Eletrosul	Total	Elimination	Consolidated IFRS
Personnel	349	226	208	81	864	38	902
Voluntary Dismissal Plan (PDV) - Provision	0	3	-2	0	2	0	2
Material	13	13	27	5	59	6	64
Services	242	112	121	39	514	54	569
Other	340	51	96	3	491	-22	468
PMSO	945	405	451	129	1,929	76	2,005
*Non-recurring events*
Personnel: PDV, PDC	0	-3	2	0	-2	0	-2
Personnel: Retroactive profit Sharing (PLR)	0	0	0	0	0	0	0
Services: Commissions related to compulsory loans	0	0	0	0	0	0	0
Other: Judicial convictions	-90	0	0	0	-90	0	-90
Other: Write-off of court deposits	-216	0	0	-5	-221		-221
Adjusted PMSO	638	401	453	124	1,616	76	1,692

Table 35 - Other costs and expenses (R$ mm)

	3Q25	3Q24	%	2Q25	%	9M25	9M24	%
Convictions, losses and legal costs	60	57	4.8	5	n.m.	136	218	-37.8
GSF	19	92	-79.6	17	11.7	52	116	-55.1
Insurance	24	39	-37.5	24	-0.1	71	86	-16.9
Equity Holding	28	10	n.m.	18	56.0	55	43	29.0
Donations and contributions	16	17	-2.4	29	-43.4	66	81	-18.0
Rent	23	21	8.7	19	25.5	65	43	50.1
Recovery of expenses	-61	-24	n.m.	-12	n.m.	-85	-70	21.2
Taxes	23	-1	n.m.	17	35.4	85	36	n.m.
Others	48	257	-81.4	20	n.m.	88	280	-68.6
Total	180	468	-61.5	136	32.4	533	833	-36.0

10.3. Appendix 3 - Financing and Loans Granted (Receivables)

Chart 10 - Receivables (R$ billion)

Does not include ECL of R$ 3,989 million and current liabilities.

10.4. Appendix 4 - Accounting Statements

Table 36 - Balance sheet (R$ thousand)

	PARENT COMPANY		CONSOLIDATED
	09/30/2025	12/31/2024	09/30/2025	12/31/2024
ASSETS
CURRENT
Cash and cash equivalents	6,094,879	16,387,945	18,501,361	26,572,522
Restricted cash	291,512	449,865	633,628	508,734
Securities	2,659,286	6,421,621	9,754,362	8,951,838
Clients	1,631,063	1,686,293	5,424,445	5,911,477
Transmission contract assets	4,770,067	4,634,940	10,437,925	10,539,570
Financing, loans and debentures	154,280	971,555	12,035	475,459
Remuneration for equity holdings	834,923	2,286,078	612,283	721,683
Taxes and Contributions	1,475,741	1,734,020	2,252,359	2,831,414
Income tax and social contribution	0	0	0	0
Right to compensation	726,346	865,299	755,287	893,254
Warehouse	64,663	50,576	389,921	441,471
Derivative financial instruments	0	500,998	14,521	692,660
Others	1,160,175	729,718	1,871,101	1,408,919
	19,862,935	36,718,908	50,659,228	59,949,001
Assets held for sale	1,714,953	1,353,723	1,714,953	4,502,102
	21,577,888	38,072,631	52,374,181	64,451,103
NON-CURRENT
LONG-TERM ASSETS
Restricted cash	1,571,968	1,430,650	3,154,083	3,170,749
Equity Holdings Income	181,049	181,049	0	0
Right to compensation	175,127	692,126	184,770	720,081
Financing, loans and debentures	1,091,319	1,894,322	174,489	163,140
Clients	142,506	171,017	533,852	602,411
Securities	440,401	421,933	556,422	433,341
Taxes and Contributions	2,357,835	2,356,369	2,743,790	2,715,445
Deferred income tax and social contribution	0	0	5,819,907	5,673,011
Bonds and deposits linked	4,058,212	3,693,298	5,630,275	5,190,344
Transmission contractual assets	18,751,225	21,223,812	53,241,622	56,848,086
Derivative financial instruments	336,887	1,269,677	675,939	1,544,095
Others	1,544,215	2,000,734	916,853	1,645,570
	30,650,744	35,334,987	73,632,002	78,706,273
INVESTMENTS
Equity Income	106,916,968	112,300,525	23,316,774	30,727,405
Held at fair value	1,039,837	839,546	1,039,837	861,234
Other Investments	19,387	19,387	97,988	97,987
	107,976,192	113,159,458	24,454,599	31,686,626
FIXED ASSETS	7,793,047	6,137,175	39,091,851	36,854,055
INTANGIBLE	20,487,718	20,779,526	76,949,814	78,173,273
	166,907,701	175,411,146	214,128,266	225,420,227
TOTAL ASSETS	188,485,589	213,483,777	266,502,447	289,871,330
	PARENT COMPANY		CONSOLIDATED
LIABILITIES AND SHAREHOLDERS' EQUITY	9/30/2025	12/31/2024	9/30/2025	12/31/2024
CURRENT LIABILITIES
Loans, financing and debentures	6,983,721	8,329,966	11,210,908	12,809,872
Compulsory loans - Agreements	919,573	1,105,534	919,573	1,105,534
Compulsory loans	1,223,269	1,326,925	1,223,269	1,326,925
Suppliers	1,347,599	1,145,660	2,785,590	2,756,329
Taxes and Contributions	192,487	378,569	912,729	1,146,169

Income tax and social contribution	0	0	0	0
Onerous contracts	0	0	122,446	62,711
Shareholder remuneration	40,975	2,486,778	43,889	2,490,668
Personnel obligations	437,231	483,779	924,361	1,065,114
Reimbursement Obligations	0	0	61,141	55,517
Post-employment benefits	954	993	303,525	289,840
Provision for litigation	719,478	1,719,453	802,073	1,791,088
Sector charges	66,655	105,352	824,847	820,067
Obligations under Law 14,182/2021	1,021,349	814,819	3,660,074	2,916,199
RGR Returns	645,715	492,276	645,715	492,276
Leasing	35,260	8,429	73,821	26,861
Derivative financial instruments	955,644	824,125	1,615,340	1,175,652
Others	169,284	458,746	1,178,740	1,105,094
	14,759,194	19,681,404	27,308,041	31,435,916
Liabilities associated with assets held for sale	0	0	0	194,454
	14,759,194	19,681,404	27,308,041	31,630,370
NON-CURRENT
Loans, financing and debentures	36,111,757	40,926,187	59,625,045	62,810,702
Shareholder remuneration	0	0	585	0
Suppliers	0	0	9,481	7,959
Provision for litigation	14,448,899	15,658,437	20,714,103	21,583,395
Post-employment benefits	411,672	418,586	3,390,699	3,416,381
Obligations under Law 14,182/2021	11,131,450	11,111,765	39,103,575	39,105,924
RGR Returns	109,993	439,974	109,993	439,974
Onerous contracts	0	0	474,039	621,725
Reimbursement Obligations	0	0	22,004	15,286
Leasing	105,820	79,994	419,823	155,722
Concessions payable - Use of public assets	38,164	38,175	559,738	543,867
Advances for future capital increases	120,226	108,938	120,226	108,938
Derivative financial instruments	230,088	2,283	230,088	2,283
Sector charges	517,209	744,833	753,080	942,348
Taxes and Contributions	91,486	103,682	244,381	372,488
Deferred income tax and social contribution	793,701	1,566,835	2,973,385	4,287,021
Others	326,043	739,459	1,103,759	1,827,171
	64,436,508	71,939,148	129,854,004	136,241,184
SHAREHOLDERS' EQUITY
Share capital	70,135,201	70,099,826	70,135,201	70,099,826
Share issue costs	-108,186	-108,186	-108,186	-108,186
Capital Reserves and Granted Equity Instruments	13,920,382	13,910,768	13,920,382	13,910,768
Treasury shares	-2,252,578	-2,223,011	-2,252,578	-2,223,011
Profit reserves	39,905,041	43,905,041	39,905,041	43,905,041
Proposed additional dividend	0	1,535,196	0	1,535,196
Accumulated profit	-7,117,905	0	-7,117,905	0
Accumulated other comprehensive income	-5,192,068	-5,256,409	-5,192,068	-5,256,409
Amounts recognized in other comprehensive income classified as held for sale	0	0	0	0
Controlling shareholders	109,289,887	121,863,225	109,289,887	121,863,225
Non-controlling shareholders	0	0	50,515	136,551
TOTAL SHAREHOLDERS' EQUITY	109,289,887	121,863,225	109,340,402	121,999,776
TOTAL LIABILITIES AND SHAREHOLDERS' EQUITY	188,485,589	213,483,777	266,502,447	289,871,330

Table 37 - Income statement (R$ thousand)

	PARENT COMPANY		CONSOLIDATED
	09/30/2025	09/30/2024	09/30/2025	09/30/2024
CONTINUING OPERATIONS
Net operating revenue	10,419,618	2,647,184	30,615,636	28,156,480
Operating costs	-6,704,223	-1,757,956	-16,843,658	-14,929,256
GROSS PROFIT	3,715,395	889,228	13,771,978	13,227,224
Operating expenses	-8,198,186	-668,903	-10,748,491	-3,158,383
Regulatory Remeasurements - Transmission Contracts	-1,762,645	2,229,490	-4,081,630	6,129,771
OPERATING RESULT BEFORE FINANCIAL RESULT	-6,245,436	2,449,815	-1,058,143	16,198,612
FINANCIAL RESULT	-4,585,068	-3,200,964	-8,620,094	-8,697,910
Income from interest, fines, commissions and fees	217,517	726,656	61,324	116,872
Income from financial investments	1,697,593	872,896	3,386,869	1,955,055
Late payment surcharge on electricity	5,256	850	84,594	96,498
Other financial income	111,254	117,498	121,026	177,927
(–) Taxes on financial income	-129,056	-116,611	-240,038	-165,097
Financial Income	1,902,564	1,601,289	3,413,775	2,181,255
Debt charges	-2,825,256	-2,423,204	-4,612,608	-4,561,343
CDE obligation charges	-571,797	-178,795	-1,988,233	-1,844,288
River basin revitalization charges	-62,878	-22,317	-237,431	-252,910
Other financial expenses	-166,494	-693,039	-274,208	-892,893
Financial expenses	-3,626,425	-3,317,355	-7,112,480	-7,551,434
Monetary updates – CDE	-379,124	-67,801	-1,318,278	-1,096,405
Monetary updates – river basins	-54,010	-11,212	-207,268	-196,420
Monetary reliefs	-478,224	-458,765	-744,231	-536,390
Exchange rate variations	-9,580	61,018	-1,352	27,116
Change in fair value of hedged debt net of derivative	-1,940,269	-1,008,138	-2,609,482	-1,292,131
Change in derivative financial instrument not linked to debt protection	0	0	-40,778	-233,501
Financial items, net	-2,861,207	-1,484,898	-4,921,389	-3,327,731
PROFIT BEFORE EQUITY HOLDINGS	-10,830,504	-751,149	-9,678,237	7,500,702
Equity income	2,775,475	8,915,489	1,506,539	2,024,711
Other income and expenses	90,485	31,730	233,615	31,058
OPERATING PROFIT BEFORE TAX	-7,964,544	8,196,070	-7,938,083	9,556,471
Current income tax and social contribution	0	0	-757,481	-722,921
Deferred income tax and social contribution	837,428	1,074,204	1,568,725	434,937
NET INCOME FOR CONTINUING OPERATIONS	-7,127,116	9,270,274	-7,126,839	9,268,487
Portion attributable to controlling	-7,127,116	9,270,274	-7,127,116	9,270,274
Portion attributable to non-controlling	0	0	277	-1,787
NET INCOME (LOSS) FOR DISCONTINUED OPERATIONS	0	0	0	0
Portion attributable to controlling	0	0	0	0
Portion attributable to non-controlling	0	0	0	0
NET INCOME FOR THE YEAR	-7,127,116	9,270,274	-7,126,839	9,268,487
Portion attributable to controlling	-7,127,116	9,270,274	-7,127,116	9,270,274
Portion attributable to non-controlling	0	0	277	-1,787
EARNINGS PER SHARE
Earnings per share - basic (ON)	-3.13	4.07	0.00	0.00
Earnings per share - basic (PN)	-3.45	4.48	0.00	0.00
Earnings per share - diluted (ON)	-3.11	4.02	0.00	0.00
Earnings per share - diluted (PN)	-3.42	4.43	0.00	0.00

Table 38 - Cash flow statement (R$ thousand)

	PARENT COMPANY		CONSOLIDATED
	09/30/2025	09/30/2024	09/30/2025	09/30/2024
OPERATING ACTIVITIES
Profit for the year before income tax and social contribution	-7,964,544	8,196,070	-7,938,083	9,556,471
Adjustments to reconcile profit with cash generated by operations:
Depreciation and amortization	691,116	173,057	3,399,225	2,954,830
Net exchange and monetary variations	920,938	476,760	2,271,129	1,802,099
Result of acquisitions and divestments	7,250,655	115,483	7,176,177	115,483
Financial charges	3,037,738	1,024,763	5,985,230	4,586,614
Equity income	-2,775,475	-8,915,489	-1,506,539	-2,024,711
Other income and expenses	-90,485	-42,069	-233,615	-41,397
Transmission revenues	-5,556,575	-1,661,502	-14,910,112	-13,519,941
Construction cost - transmission	1,145,205	338,486	3,043,066	2,482,964
Regulatory Remeasurements - Transmission Contracts	1,762,645	-2,229,490	4,081,630	-6,129,771
Operating provisions (reversals)	-490,624	-747,377	495,482	-159,797
Write-offs of PP&E and Intangible Assets	7,959	0	-99,395	0
Result of hedged debt and derivatives	1,940,269	1,008,138	2,650,260	1,525,632
Other	179,040	770,791	284,995	809,676
	8,022,406	-9,688,449	12,637,533	-7,598,319
(Additions)/decreases in operating assets
Clients	26,843	34,109	447,900	-150,160
Right to compensation	766,112	707,625	783,438	738,843
Others	154,262	-170,940	-570,057	-349,681
	947,217	570,794	661,281	239,002
Additions/(decreases) in operating liabilities
Suppliers	158,799	143,356	-69,778	-962,956
Advances	0	0	0	0
Personnel obligations	-41,380	28,888	-135,585	-569,684
Sector charges	-282,132	624,297	-217,924	548,650
Others	-597,980	135,276	-402,791	-560,716
	-762,693	931,817	-826,078	-1,544,706
Payment of financial charges	-2,889,934	-3,290,688	-4,534,868	-5,070,249
Receipt of RAP revenue	6,131,390	1,779,777	14,536,591	14,828,290
Receipt of Financial Charges from Subsidiaries	0	0	0	0
Receipt of remuneration from investments in equity holdings	2,211,921	2,985,443	877,130	1,059,198
Payment of litigation	-2,738,570	-2,240,605	-3,118,773	-2,544,691
Bonds and linked deposits	-418,444	-103,399	-389,759	-183,164
Payment of income tax and social contribution	-21,156	-70,366	-328,098	-1,509,790
Supplementary pension payments	-17,140	-16,583	-282,610	-313,365
Net cash provided by operating activities of discontinued operations	0	0	0	0
Net cash provided by (used in) operating activities	2,500,453	-946,189	11,294,266	6,918,677
FINANCING ACTIVITIES
Loans and financing obtained and debentures obtained	0	13,237,820	3,330,000	21,152,463
Payment of loans and financing and debentures - principal	-6,622,713	-9,920,297	-9,254,732	-12,851,588
Payment of remuneration to shareholders	-7,981,613	-1,287,242	-7,982,004	-1,176,190
Payment to dissenting shareholders - incorporation of shares	0	0	0	0
Share buybacks	-36,728	-68,399	-36,728	-68,399
Payment of CDE obligations and revitalization of basins - principal	-725,774	0	-2,575,565	-1,974,963
Lease payments - principal	-25,444	-33,914	-39,360	-48,167
Derivatives Payment	-462,570	0	-546,001	0
Others	-203,775	0	-203,777	0
Net cash (used in) financing activities	-16,058,617	1,927,968	-17,308,167	5,033,156
INVESTMENT ACTIVITIES
Grant of advance for future capital increase	0	-8,051	0	-8,051
Receipt of loans and financing	795,946	805,687	445,644	8,848
Receipt of financial charges	359,454	752,803	209,590	56,359
Acquisition of fixed assets	-335,909	-92,911	-1,281,112	-1,870,635

Acquisition of intangible assets	-117,042	-67,912	-274,879	-202,874
Restricted cash	17,035	-149,912	-108,228	-708,150
Financial (withdrawals)/contributions (securities)	3,919,935	862,776	-429,693	-786,853
Receipt of charges (securities)	301,813	183,697	413,724	402,521
Debentures Acquisition	0	0	0	0
Transmission infrastructure - contractual asset	-1,145,205	-338,486	-3,043,066	-2,482,964
Capital acquisition/contribution of equity holdings	-720,752	-176,643	-873,311	-176,644
Disposal of equity holdings	189,823	2,449,160	2,884,072	2,449,160
Net cash in the incorporation of subsidiaries	0	1,018,193	0	0
Net cash in the acquisition of control of investees	0	0	0	0
Others	0	0	0	-305
Net cash provided by investment activities of discontinued operations	0	0	0	0
Net cash provided by (used in) investing activities	3,265,098	5,238,401	-2,057,259	-3,319,588
Increase (decrease) in cash and cash equivalents	-10,293,066	6,220,180	-8,071,160	8,632,245
Cash and cash equivalents at the beginning of the period	16,387,945	5,698,457	26,572,522	13,046,371
Cash and cash equivalents at the end of the period	6,094,879	11,918,637	18,501,361	21,678,616
	-10,293,066	6,220,180	-8,071,161	8,632,245

10.5. Appendix 5 - IFRS vs. Regulatory Reconciliation

Table 39 - Reconciliation IFRS vs. regulatory (R$ thousand)

	CVM Result IFRS	Regulatory Result	∆	CVM Result IFRS	Regulatory Result	∆
	09/30/2025			09/30/2024
OPERATING REVENUES
Generation
Power supply for distribution companies	13,951,211	13,833,218	117,993	13,631,687	14,198,185	-566,498
Power supply for end consumers	1,349,467	1,349,467	0	2,247,830	2,247,830	0
CCEE revenue (short term market)	3,923,394	3,923,394	0	1,910,559	1,910,559	0
Operation and maintenance (O&M) revenue	1,502,653	1,502,653	0	2,319,252	2,319,252	0
Transmission
Operation and maintenance revenue	6,177,346	0	6,177,346	5,862,771	0	5,862,771
Construction revenue	2,990,824	0	2,990,824	2,350,714	0	2,350,714
Contract revenue – Transmission	5,741,942	0	5,741,942	5,306,457	0	5,306,457
Transmission System Availability (Rap)	0	13,655,618	-13,655,618	0	14,449,745	-14,449,745
Other income	391,871	391,872	0	182,057	179,332	2,725
Deductions
(-) Sector charges	-1,994,085	-1,994,084	-1	-1,876,645	-1,876,994	349
(-) ICMS	-224,986	-224,986	0	-701,758	-701,758	0
(-) PASEP e COFINS	-3,190,461	-3,190,461	0	-3,073,862	-3,073,861	-1
(-) Other Deductions	-3,540	-3,540	0	-2,582	-2,233	-349
Net Operating Revenue	30,615,636	29,243,150	1,372,486	28,156,480	29,650,057	-1,493,577
OPERATING COSTS
Personnel, Material and Services	-1,954,915	-1,954,837	-78	-2,106,272	-2,105,285	-987
Energy purchased for resale	-4,629,606	-4,904,602	274,996	-2,986,397	-3,513,004	526,607
Charges for use of the electricity grid	-2,960,926	-2,514,835	-446,092	-2,986,393	-2,605,112	-381,281
Fuel for electricity production	-975,346	-975,346	0	-1,460,855	-1,460,855	0
Construction	-3,043,066	0	-3,043,066	-2,482,964	0	-2,482,964
Depreciation	-1,443,360	-2,836,739	1,393,379	-1,291,734	-2,738,039	1,446,305

Amortization	-1,695,641	-1,701,363	5,722	-1,463,207	-1,477,292	14,085
Operating provisions/reversals	0	0	0	0	0	0
Other costs	-140,798	-126,124	-14,674	-151,434	-151,624	190
Operating costs	-16,843,658	-15,013,844	-1,829,814	-14,929,256	-14,051,211	-878,045
GROSS PROFIT	13,771,978	14,229,306	-457,328	13,227,224	15,598,846	-2,371,622
OPERATING EXPENSES
Personnel, Material and Services	-2,198,635	-2,209,709	11,074	-2,276,163	-2,313,516	37,353
Voluntary Dismissal Program	-225,624	-225,624	0	-45,137	-45,137	0
Remuneration and compensation	0	0	0	0	0	0
Depreciation	-155,718	-150,481	-5,237	-145,106	-143,715	-1,391
Amortization	-104,506	-106,589	2,083	-54,783	-59,729	4,946
Donations and contributions	-51,729	-51,729	0	-74,362	-74,365	3
Operating provisions/reversals	-495,482	227,776	-723,258	159,797	418,901	-259,104
Result from asset sales	-7,176,177	-6,317,107	-859,070	-115,483	-115,483	0
Other expenses	-340,620	-363,256	22,636	-607,146	-610,221	3,075
OPERATING EXPENSES	-10,748,491	-9,196,719	-1,551,772	-3,158,383	-2,943,265	-215,118
Regulatory Remeasurements - Transmission Contracts	-4,081,630	0	-4,081,630	6,129,771	0	6,129,771
OPERATING RESULT BEFORE FINANCIAL RESULT	-1,058,143	5,032,587	-6,090,730	16,198,612	12,655,581	3,543,031
FINANCIAL RESULT	-8,620,094	-9,097,414	477,320	-8,697,910	-9,108,649	410,739
PROFIT BEFORE EQUITY HOLDINGS	-9,678,237	-4,064,827	-5,613,410	7,500,702	3,546,932	3,953,770
Equity income	1,506,539	642,891	863,648	2,024,711	1,685,874	338,837
Other income and expenses	233,615	233,615	0	31,058	31,159	-101
OPERATING PROFIT BEFORE TAX	-7,938,083	-3,188,321	-4,749,762	9,556,471	5,263,965	4,292,506
Current income tax and social contribution	-757,481	-757,481	0	-722,921	-722,921	0
Deferred income tax and social contribution	1,568,725	-135,889	1,704,614	434,937	808,817	-373,880
NET INCOME FOR CONTINUING OPERATIONS	-7,126,839	-4,081,691	-3,045,148	9,268,487	5,349,861	3,918,626
Portion attributable to controlling	-7,127,116	-4,081,968	-3,045,148	9,270,274	5,352,733	3,917,541
Portion attributable to controlling	277	277	0	-1,787	-2,872	1,085
NET INCOME (LOSS) FOR DISCONTINUED OPERATIONS	0	0	0	0	0	0
Portion attributable to controlling	0	0	0	0	0	0
Portion attributable to controlling	0	0	0	0	0	0
NET INCOME FOR THE YEAR	-7,126,839	-4,081,691	-3,045,148	9,268,487	5,349,861	3,918,626
Portion attributable to controlling	-7,127,116	-4,081,968	-3,045,148	9,270,274	5,352,733	3,917,541
Portion attributable to controlling	277	277	0	-1,787	-2,872	1,085

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: November 5, 2025

CENTRAIS ELÉTRICAS BRASILEIRAS S.A. - ELETROBRÁS

By:	/S/ Eduardo Haiama
	Eduardo Haiama Vice-President of Finance and Investor Relations

FORWARD-LOOKING STATEMENTS

This document may contain estimates and projections that are not statements of past events but reflect our management’s beliefs and expectations and may constitute forward-looking statements under Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities and Exchange Act of 1934, as amended. The words “believes”, “may”, “can”, “estimates”, “continues”, “anticipates”, “intends”, “expects”, and similar expressions are intended to identify estimates that necessarily involve known and unknown risks and uncertainties. Known risks and uncertainties include, but are not limited to: general economic, regulatory, political, and business conditions in Brazil and abroad; fluctuations in interest rates, inflation, and the value of the Brazilian Real; changes in consumer electricity usage patterns and volumes; competitive conditions; our level of indebtedness; the possibility of receiving payments related to our receivables; changes in rainfall and water levels in reservoirs used to operate our hydroelectric plants; our financing and capital investment plans; existing and future government regulations; and other risks described in our annual report and other documents filed with the CVM and SEC. Estimates and projections refer only to the date they were expressed, and we do not assume any obligation to update any of these estimates or projections due to new information or future events. Future results of the Company’s operations and initiatives may differ from current expectations, and investors should not rely solely on the information contained herein. This material contains calculations that may not reflect precise results due to rounding.

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