6-K 1 elppr3q25_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 1-14668

COMPANHIA PARANAENSE DE ENERGIA

(Exact name of registrant as specified in its charter)

Energy Company of Paraná

(Translation of Registrant's name into English)

José Izidoro Biazetto, 158
81200-240 Curitiba, Paraná
Federative Republic of Brazil
+55 (41) 3331-4011

(Address of principal executive offices)

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____

| Summary |

1. Consolidated Results | 2
1.1 Ebitda | 2
1.2 Operating Revenue | 3
1.3 Operating costs and expenses | 3
1.4 Equity Income Result | 4
1.5 Financial Results | 4
1.6 Consolidated Net Profit | 4
1.7 Debt and Leverage | 5
2. Investment | 7
3.1 Economic and Financial Performance | 8
3.1.1 IFRS effect on the Transmission segment | 9
3.2 Operational Performance | 10
3.2.1 Generation | 10
3.2.2 Energy sold | 10
3.2.3 Transmission | 11
RBSE | 11

4. Copel Distribution | 12
4.1 Economic and Financial Performance | 12
4.2 Operational Performance | 13
4.2.1 Grid Market (TUSD) | 13
4.2.2 Captive Market | 13
4.2.3 Operational data | 13
5. Copel Commercialization | 15
5.1 Economic and Financial Performance | 15
5.2 Operational Performance | 16
6. ESG performance | 17
6.1 ESG in Copel’s Strategy | 17
6.2 Recent highlights | 17
6.3 Indicators | 18
6.4 Ratings, Rankings and Indexes | 18
7. Other highlights from the period | 19
List of Exhibits | 21

| 1. Consolidated Results |

The consolidated result is made up of Copel Holding, Copel Geração e Transmissão (GenCo), Copel Distribuição (DisCo), Copel Comercialização (TradeCo) and other equity holdings[2]. The following analyses refer to the third quarter of 2025 (3Q25) compared to the same period in 2024 (3Q24) and, where applicable, to the accumulated periods of the first nine months of 2024 and 2025 (9M24 and 9M25, respectively).

1.1 Ebitda

Copel's Recurring Ebitda² amounted to R$ 1,337.4 million in 3Q25, 7.8% higher than the R$ 1,240.3 million recorded in 3Q24. This result reflects the company's ability to consistently generate value, supported by the strength of its assets and the efficient execution of its operational and commercial strategy. GenCo and TradeCo accounted for approximately 53.4% of this result, while DisCo accounted for 48.7%³.

Highlights in 3Q25 include:

(i) |  | GenCo's Ebitda grew 11.0% (+R$ 71.3 million) compared to 3Q24, totaling R$ 721.1 million, especially due to the increase in revenue from electricity grid availability, explained mainly by the incorporation of the transmission company Mata de Santa Genebra S.A. - MSG and by the increase in supply revenue driven by the positive effects of hydroelectric generation utilization in modulation with high volatility of the hourly Difference Settlement Price - PLD in the South submarket. This result was partially offset by the higher generation deviation, resulting from the increase in curtailment, which rose from 23.4% in 3Q24 to 34.4% in 3Q25. More details in section 3.1;

(ii) |  | DisCo' Ebitda, which increased by 7.2% (+R$ 43.6 million) compared to 3Q24 1.7% increase in the billed grid market and the Annual Tariff Adjustment - RTA of June 2025, with an average increase of 6.4% in the Distribution System Usage Tariffs - TUSD. More details in section 4.1;

(iii) |  | the increase of R$ 18.7 million in Elejor's Ebitda compared to 3Q24, with the effect of higher energy sold for bilateral contracts and average energy balance prices 17.0% higher between the periods.

This result was partially offset by the decrease of R$ 10.0 million in TradeCo's Ebitda, basically due to the lower sales margin, of R$ 7.3 million, and the Ebitda from discontinued operations, of R$ 20.2 million, recorded at Copel (Holding) in 3Q24 and absent in 3Q25.

The non-recurring items considered in the calculation of Recurring Ebitda are shown in the following table:

|  |  |  |  |  | R$ million
| 3T25 | 3T24 | Δ% | 2025 | 2024 | Δ%
EBITIDA | 1,358.7 | 1,526.7 | -11.0 | 4,678.0 | 4,230.8 | 10.6
(-/+) Fair value in the purchase and sale of energy | 42.9 | (17.9) | — | (25.0) | 26.0 | —
(-/+) Provision/Reversal of POS indemnity | — | 18.4 | — | 21.0 | 18.4 | 14.1
(-/+) Partial disposal of assets/assets swap | (35.4) | (264.4) | (86.6) | (345.7) | (264.4) | 30.7
(-/+) Ebitda Discontinued Operations Compagas and UEGA | — | 20.2 | — | — | 58.6 | —
(-/+) Equity equivalence | (37.3) | (63.2) | (40.9) | (202.0) | (225.4) | (10.4)
(-/+) NRV | (36.9) | (17.2) | 114.7 | (72.7) | (49.5) | 46.9
(-/+) Difference Corporate/Regulatory Transfer Revenue | 45.4 | 37.7 | 20.4 | 121.9 | 57.6 | 111.6
Recurring Ebitda | 1,337.4 | 1,240.3 | 7.8 | 4,175.5 | 3,852.1 | 8.4

Consolidated Recurring Ebitda

*Includes Ebitda from discontinued operations, Copel (Holding), Copel Serviços, Elejor and eliminations and reclassifications between group companies.

[1]

1 Copel Serviços, Elejor and other stakes in generation assets.

2 Excluding non-recurring items, mark-to-market - MTM at TradeCo, new replacement value for the adjustment to present value of the indemnifiable asset (VNR) at DisCo, equity equivalence and IFRS effects on transmission contract assets.

3 Copel (Holding), Copel Serviços and Elejor accounted for -2.1% of recurring Ebitda. 1

2

1.2 Operating Revenue

Recurring Net Operating Revenue, considering the effects of IFRS on the energy transmission segment, totaled R$ 6,810.5 million in 3Q25, an increase of 18.7% compared to the R$ 5,739.7 million recorded in 3Q24. This result mainly reflects the increase:

| (i) | R$ 424.73 million (+101.0%) in the result of sectorial financial assets and liabilities (CVA), because of the adherence of tariff coverage in relation to costs with Parcel A, especially with energy purchased for resale and the return of PIS/COFINS to DisCo consumers in the period;

| (ii) | R$ 406.9 million (+48.8%) in electricity supply revenue, with the following highlights: i. an increase of R$ 273.8 million in supply revenue, due to a 25.0% growth in the volume of energy sold for TradeCo's bilateral contracts and higher energy sales in the Free Contracting Environment - ACL in Elejor's portfolio; ii. an increase of R$ 120.7 million in Copel DIS revenue due to higher energy sales in the short-term market (MCP) and in the Surplus and Deficit Compensation Mechanism (MSCD); and iv. an increase of R$ 12.3 million in Copel GeT, resulting from better results in transactions carried out in the short-term market in 3Q25 compared to 3Q24, especially with the modulation of the hydroelectric generation portfolio in view of the behavior of the PLD in the South submarket during the period. This result was partially offset by the increase in generation deviation (+58.7%) in wind farms;

| (iii) | R$ 256.3 million (+39.9%) in construction revenue, mainly due to the enhancement in the volume of works related to DisCo's investment program (see topic 2), which includes investments aimed at improving and modernizing infrastructure and upgrading customer service; with no effect on the result given that the amount recorded in costs and expenses is equal;

| (iv) | R$ 100.2 million (+5.9%) in electricity grid availability, mainly explained by the incorporation of the transmission company Mata de Santa Genebra S.A. - MSG and an average increase of 2.2% in the RAP of transmission companies with 100% participation by Copel GeT for the 2025/2026 cycle, ex-MSG.

1.3 Operating costs and expenses

In 3Q25, recurring operating costs and expenses totaled R$ 5,849.6 million, an increase of 20.2% compared to R$ 4,867.9 million recorded in 3Q24. The cost of electricity purchased for resale represents 52.7% of total costs incurred in the quarter, followed by construction costs with a 15.4% share, PMSO with 12.3%, sector charges with 11.7%, and others with a 7.9% share.

The main variations in the period are:

| (i) | an increase of R$ 737.6 million (+27.3%) in electricity purchased for resale mainly due to: i. the increase of R$ 434.7 million in the purchase of energy from DisCo, with emphasis on the higher volume from the distributed generation system (+R$ 219.1 million) and the acquisition of energy from the Energy Trading Chamber (CCEE) (+R$ 191.6 million) and ii. an increase of R$ 331.7 million (+33.2%) at TradeCo due to the acquisition of electricity in bilateral contracts;

| (ii) | an increase of R$ 256.3 million (+25.0%) in construction costs, mainly due to DisCo investment program, with no effect on results given the matching of the amount recorded in construction revenue.

| (iii) | an increase of R$ 17.2 million in provisions and reversals due mainly to the increase of R$ 18.5 million in DisCo expected credit losses (ECL), as a result of reversals related t defaults in 3Q24, which were non-recurring in this quarter.

This result was partially offset by a 4.1% reduction (-R$ 30.6 million) in recurring manageable costs (PMSO), mainly due to an 18.4% (-R$ 47.9 million) reduction in personnel costs, influenced mainly by the departure of 209 employees, mostly through the Voluntary Dismissal Program (PDV) completed in 2024.

3

The graph below shows manageable costs compared between quarters and accumulated in the year:

|  |  |  |  |  | R$ million |
Recurring Manageable Costs | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
Staff and administrators | 212.6 | 260.5 | (18.4) | 683.2 | 839.2 | (18.6) |
Social security and assistance plans | 57.9 | 63.3 | (8.5) | 176.9 | 199.0 | (11.1) |
Material | 19.1 | 22.1 | (13.6) | 64.0 | 62.2 | 2.9 |
Third-party services | 287.4 | 274.6 | 4.7 | 848.4 | 772.7 | 9.8 |
Other operating costs and expense * | 141.7 | 128.8 | 10.0 | 358.8 | 331.6 | 8.2 |
TOTAL | 718.7 | 749.3 | (4.1) | 2,131.3 | 2,204.7 | (3.3) |
*Excludes the effects of the following non-recurring items: Personnel - Reversal/provision for Voluntary Dismissal Program; and Others - disposal of assets/assets swap |

Neutralizing the effects of provisions related to performance bonuses (PPD), profit sharing (PLR), long-term incentives (ILP) and PDV, there was a reduction of R$ 23.6 million (-11.2%) in personnel and management costs in the quarterly comparison, due to a reduction in headcount compared to the previous period, partially offset by the pro rata provision between October and December of the collective bargaining agreement - ACT 2024, which includes a salary readjustment by the National Consumer Price Index - INPC, of 4.09%, considering 12 months until September/2024.

|  |  |  |  |  | R$ million |
Personnel costs | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
Staff and administrators | 212.6 | 260.5 | (18.4) | 683.2 | 839.2 | (18.6) |
(-/+) Profit sharing, PPD and ILP | (25.5) | (49.8) | (48.8) | (110.0) | (156.5) | (29.7) |
TOTAL | 187.1 | 210.7 | (11.2) | 573.2 | 682.7 | (16.0) |

Evolution of the workforce

1.4 Equity Income Result

The equity income from jointly controlled companies and other affiliates of Copel in 3Q25 decreased by 40.9% compared to the same period last year (R$ 37.3 million, compared to R$ 63.2 million in 3Q24). The decrease is mainly due to the consolidation of 100% of Mata de Santa Genebra S.A. - MSG, as of June 1, 2025, with a reduction of the contract assets of the jointly owned subsidiaries in the transmission segment caused by higher inflation in the period (IPCA 0.63% compared to 1.41% in 1Q24).

1.5 Financial Results

The financial result was a negative R$ 442.5 million in 3Q25 compared to a negative R$ 222.4 million in 3Q24, an increase of R$ 220.1 million (38.7%). This variation is mainly due to the increase in expenses with charges and monetary variation of R$ 236.7 million (+41.4%), due to the increase in debt and the CDI (Copel's main debt indexer) in a higher interest rate environment. These effects were partially offset by an increase of R$ 20.0 million in fair value adjustments on debentures due to swaps.

|  |  |  |  |  | R$ million |
Financial Results | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
Financial Income | 352.60 | 331.20 | 6.50 | 1,025.50 | 857.20 | 19.60 |
Financial Expenses | (795.10) | (553.60) | 43.60 | (2,316.50) | (1,637.50) | 41.50 |
Total Financial Result | (442.50) | (222.40) | 99.00 | (1,291.00) | (780.30) | 65.40 |

1.6 Consolidated Net Profit

Copel recorded reported net income of R$ 364.2 million in 3Q25, compared to R$ 737.4 million in 3Q24, a decrease of 50.6%, mainly due to (i) the lower financial result presented above (-R$ 220.1 million); and (ii) the decline in income from associates (-R$ 25.9 million), mainly due to the consolidation of MSG. This result was partially offset by the decrease in taxes (-R$ 23.0 million), mainly due to the declaration of Interest on Equity in Q324 and lower financial results.

The main adjustments to net income in 3Q25 were:

Excluding non-recurring effects and non-cash items (VNR, MTM, IFRS in broadcasters and net income from discontinued operations), recurring net income decreased 36.5% compared to 3Q24, totaling R$ 374.8 million. This was substantially influenced by (i) a R$ 220.1 million reduction in financial income; (ii) a R$ 58,2 million increase in taxes; and (iii) a R$ 25.9 million decrease in equity income. This result was partially offset by a R$ 97.1 million increase in recurring Ebitda.

4

1.7 Debt and Leverage

Copel's total consolidated debt as of september 30, 2025, was R$ 21,091.7 million, an increase of 18.8% in relation to the amount of R$17,753.8 million recorded on December 31, 2024.

The following table and graphs show the indebtedness of Copel and its subsidiaries in 1Q25:

Debt per Subsidiary

R$ million |
R$ mil | GenCo² | DisCo | Others3 | Total |
Total Debt 1 | 11,646.9 | 9,235.2 | 209.6 | 21,091.7 |
Availability | 2,205.6 | 1,516.9 | 808.4 | 4,530.9 |
Adjusted Net Debt | 9,441.3 | 7,718.3 | (598.8) | 16,560.8 |
Leverage |  |  |  | 2.8x4 |
Duration (years) | 3.1 | 3.3 | 3.8 | 3.4 |
1 Considers the effect of WAP on debentures. 2 Considered Copel Geração e Transmissão S.A. (parent company). 3 Includes Copel Serviços, wind farms (Brisa Potiguar, Cutia, Jandaíra, Vilas, Aventura, and SRMN) and transmission companies (Costa Oeste and Marumbi). 4 Excludes the effect of the acquisition of 70% of the HPP Baixo Iguaçu. |

On September 30, 2025, consolidated leverage reached 3.0x, reflecting net debt of R$ 16,560.8 million — an increase of 0.4x compared to the end of 2024. Despite the increase, the indicator remains within the parameters defined by the optimal capital structure. The increase is mainly attributed to the completion of the acquisition of 70% of the Baixo Iguaçu Hydroelectric Plant, with a cash outflow of R$ 1.1 billion, as part of the asset divestment process, which Copel finalized on October 22, 2025. Excluding the effects of this transaction, leverage at the end of the period was 2.8x.

Adjusted Net Debt/Recurring EBITDA

*does not consider equity in earning, considers discontinued operations and excludes impairment effects, Voluntary Dismissal Program, MTM, GSF renegotiation, and gains on the disposal of assets / assets swap

The average cost of debt at nominal rates on September 30, 2025, is 13.22% (11.96% on December 31, 2024), which is equivalent to 88.73% of the CDI (98.46% of the CDI on December 31, 2024).

Debt Composition and Indexation

5

Amortization - R$ million

Average term: 4.9 years

6

| 2. Investments |

In 3Q25, the investment program amounted to R$ 981.4 million, 85.6% of which was made by DisCo and 14.4% by GenCo and Copel (Holding).

|  |  |  | R$ million
Subsidiary / SPE | Realized
3Q25 | 3Q24 | 9M25 | 9M24
DisCo | 840.0 | 509.6 | 2,317.7 | 1,653.8
GenCo | 140.5 | 54.5 | 313.7 | 127.7
Generation¹ | 75.5 | 22.9 | 121.7 | 48.2
Hydroelectric | 20.1 | 8.9 | 40.8 | 28.3
Wind | 55.4 | 14.0 | 80.9 | 19.9
Transmission | 54.8 | 16.6 | 168.4 | 53.9
Improvements/Reinforcement² | 50.4 | 16.5 | 158.7 | 53.1
Other Investments | 4.4 | 0.1 | 9.7 | 0.8
Other GenCo Projects3 | 10.2 | 15.0 | 23.6 | 25.6
Copel (Holding) | 0.6 | 0.4 | 1.8 | 1.5
TradeCo | 0.1 | 0.1 | 0.6 | 0.4
Copel Serviços and other equities4 | 0.2 | 0.0 | 1.1 | 40.6
Total | 981.4 | 564.6 | 2,634.9 | 1,824.0
1 Includes acquisition of R$ 196.6 million from the consolidation of Mauá HPP and MSG
2 Includes Facility Modernization Plan - PMI.
3 Includes modernization of COGT (Generation and Transmission Operations Center), modernization of GPS Parigot de Souza HPP and Marumbi and Uirapuru SPEs
4 Includes an innovation plan in the energy sector aligned with the investment thesis, Copel's innovation programs, and ESG practices

Of the amount realized by Copel’s DisCo in the quarter, 97.0% was earmarked for investments in electrical assets and 3.0% in non-electrical assets and other investments. The funds were allocated mainly within the scope of the Paraná Trifásico and Rede Elétrica Inteligente projects, with the aim of modernizing, automating and renewing the distribution grid with standardized technologies to meet the needs of automation equipment. Among the benefits of the projects are the reinforcement of rural grid to reduce disconnections and ensure support for the growth of agribusiness in the state of Paraná, a reduction in costs with O&M and commercial services and improved control of the indicators of Equivalent Duration of Interruption per Consumer Unit - DEC and Equivalent Frequency of Interruption per Consumer Unit - FEC. The program is made up of pillar projects:

| • | Paraná Trifásico (Paraná Three-Phase): covers the construction of approximately 25,000 km of new grids by 2025 and represents the improvement and renewal of rural distribution grids in the company's concession area, with the implementation of a three-phase grid and the creation of redundancy in the main rural branches. By the end of September 2025, 24,510 km of network had been completed.

| • | Rede Elétrica Inteligente (Smart Grid): aims to implement a private communication network with standardized technology to serve all the distribution network's automation equipment and advanced metering infrastructure. By late September 2025, 1,801,508 smart meters had already been installed. During phases 1, 2, 3, 4 and 4.1 of the program, we achieved advances for our operation, with a reduction in man-hours and km traveled, fewer non-technical losses, improvement quality and a reduction in compensation for breaches of quality performance limits.

The investments made at GenCo are mainly aimed at reinforcements and improvements to the transmission lines, as well as enhancing the performance of wind assets. These two segments accounted for 35.9% and 39.4% of the total invested in the period, respectively.

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| 3. Copel Geração e Transmissão (GenCo) (Consolidated Result) |

3.1 Economic and Financial Performance

GenCo reported recurring Ebitda[4] of R$ 721.1 million, an increase 11.0% or R$ 71.3 million over the R$ 649.8 million recorded in 3Q24.

This result mainly reflects:

| (i) | higher revenue from grid availability, of R$ 119.4 million, mainly due the incorporation of the Mata de Santa Genebra S.A. - MSG transmission company and an average increase of 2.2% in the RAP of transmission companies wholly owned by Copel GeT for the 2025/2026 cycle, ex-MSG;

| (ii) | the decrease of R$ 33.3 million in the cost of PMSO;

| (iii) | the increase of R$ 23.1 million, resulting from the positive effects on transactions carried out in the short-term market, especially the modulation of the hydroelectric generation portfolio in the face of the behavior of the PLD in the South submarket in the period;

| (iv) | the reduction of R$ 17.9 million in charges for the use of the electricity grid, due to the increased participation of the locational signal in the calculation of TUST;

| (v) | the increase of R$ 10.1 million, due to higher energy sales for bilateral contracts (4,009 GWh, compared to 3,307 GWh in 3Q24);

| (vi) | the increase of R$ 7.1 million in revenue from Energy Purchase Contracts in the Regulated Environment - CCEAR, essentially due to the start of supply from Jandaíra and consolidation of the HPP Mauá;

| (vii) | the decrease of R$ 6.4 million in provisions and reversals, mainly reflecting lower provisions for civil litigation and expected credit losses.

The positive effects mentioned above were partially offset by the:

| (i) | the increase in the cost of electricity purchased for resale of R$ 113.6 million, resulting from the combination of lower GSF (64.9% in 3Q25 versus 79.2% in 3Q24) and higher PLD (R$ 253.06/MWh in 3Q25, versus R$ 171.21/MWh in 3Q24);

| (ii) | greater deviation in generation, of R$ 39.1 million (+58.7%), resulting from the increase in curtailment, which rose from 23.4% in 3Q24 to 34.4% in 3Q25.

|  |  |  |  |  | R$ million |
Recurring Ebitda | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
Ebitda | 746.7 | 930.4 | (19.7) | 2,681.7 | 2,466.2 | 8.7 |
(-/+) Partial disposal of assets / assets swap | (35.4) | (264.4) | (86.6) | (345.8) | (264.4) | 30.8 |
(-/+) POS indemnity reversal/provision | — | 4.1 | — | 8.6 | 4.1 | 109.8 |
(-/+) Recurrent Ebitda from discontinued operations UEGA | — | — | — | — | (27.4) | — |
(-/+) Equity equivalence | (35.6) | (58.0) | (38.6) | (200.9) | (222.5) | (9.7) |
(-/+) Corporate/Regulatory Tra Revenue Difference (See item 3.1.1) | 45.4 | 37.7 | 20.4 | 121.9 | 57.6 | 111.6 |
Recurring Ebitda | 721.1 | 649.8 | 11.0 | 2,265.5 | 2,013.6 | 12.5 |

PMSO expenses (manageable costs), excluding non-recurring items, provisions, and reversals, decreased by R$ 33.3 million (-13.8%), mainly explained by: (i) a reduction in Staff and management costs of R$ 18.2 million, influenced by the departure of 58 employees, mostly under the Voluntary Dismissal Program (PDV) in 2024 and 2025; (ii) lower costs with Third-party services (-R$ 10.3 million), mainly related to maintenance of facilities and specialized services in wind assets, given the change in O&M supplier from full-scope to full-service; (iii) a decrease of R$ 5.1 million in Other operating costs and expenses, mainly due to the reduction in costs related to financial compensation for the use of water resources, given the lower generation in the period. This result was partially offset by higher costs with the acquisition of; (iv) Materials (+R$ 2.5 million), essentially intended for wind assets.

|  |  |  |  |  | R$ million |
Recurrent Manageable Costs* | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
Staff and management | 65.4 | 83.6 | (21.8) | 213.7 | 274.3 | (22.1) |
Social security and assistance plans | 16.9 | 19.2 | (12.0) | 52.4 | 60.6 | (13.5) |
Material | 8.5 | 6.0 | 41.7 | 24.6 | 14.6 | 68.5 |
Third-party services | 58.2 | 68.5 | (15.0) | 191.6 | 202.0 | (5.1) |
Other operating costs and expenses* | 60.2 | 65.3 | (7.8) | 34.9 | 160.9 | (78.3) |
TOTAL | 209.2 | 242.6 | (13.8) | 517.2 | 712.4 | (27.4) |
*Excludes the effects of the following non-recurring items: Personnel - Reversal/provision for Voluntary Dismissal Program; and Others - disposal of assets/assets swap |

Neutralizing the effects of the provisions relating to the PDV, PPD and PLR, there was a 18.3% reduction in personnel and administration costs compared to 3Q24, reflecting the already mentioned reduction in the workforce between the periods, partially offset by the pro rata provision, between October and December, for the 2024 Collective Bargaining Agreement, with a salary adjustment of 4.09% (INPC accumulated over 12 months up to September/2024).

[4] Excluding non-recurring items and IFRS effects on transmission contract assets.

8

|  |  |  |  |  | R$ million |
Personnel costs | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
Staff and administrators | 65.4 | 83.6 | (21.8) | 213.7 | 274.3 | (22.1) |
(-/+) Profit sharing, PPD and ILP | (9.5) | (15.2) | (37.5) | (32.8) | (45.4) | (27.8) |
TOTAL | 55.9 | 68.4 | (18.3) | 180.9 | 228.9 | (21.0) |

Recurring Net Income reached R$ 237.0 million in 3Q25, down 7.9% compared to 3Q24. This result mainly reflects the combination of the following effects: i. negative variation in financial results (-R$ 269.1 million in 3Q25, compared to -R$ 133.9 million in 3Q24), explained by the higher amount of debt and higher CDI (3.6% in 3Q25, compared to 2.6% in 3Q24); ii. lower income tax and social contribution expenses of R$ 46.7 million, mainly due to the payment of interest on equity capital (JCP) to Copel (Holding) in Q325; iii. higher EBITDA of R$ 71.4 million, due to the points presented above; iv. a reduction in depreciation of R$ 19.1 million, due to the renewal of concessions and the sale of assets; and v. a decrease of R$ 22.4 million in equity equivalence, mainly due to the consolidation of Mata de Santa Genebra - MSG into the portfolio, which ceased to contribute R$ 25.4 million to equivalence.

​In the year to date, GenCo recorded Recurring Ebitda of R$ 2,265.5 million, an increase of 12.5% over the same period last year.

|  |  |  |  |  | R$ million |
Main Indicators | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
Net Operating Revenue (R$ million) | 1,252.30 | 1,096.90 | 14.20 | 3,653.20 | 3,311.30 | 10.30 |
Operating Costs and Expenses (R$ million) | (727.60) | (430.10) | 69.20 | (1,713.50) | (1,693.20) | 1.20 |
Operating Result (R$ million) | 291.20 | 590.90 | (50.70) | 1,378.00 | 1,393.40 | (1.10) |
Net Profit (R$ million) | 249.30 | 416.30 | (40.10) | 1,030.90 | 1,057.60 | (2.50) |
Recurring Net Profit (R$ million) | 237.00 | 257.40 | (7.90) | 888.90 | 942.20 | (7.70) |
Ebitda (R$ million) | 746.70 | 930.40 | (19.70) | 2,681.70 | 2,466.20 | 8.70 |
Recurring EBITDA (R$ million) | 721.10 | 649.80 | 11.00 | 2,265.50 | 2,013.60 | 12.50 |
Operating Margin | 0.23 | 0.54 | (56.80) | 0.38 | 0.42 | (10.40) |
Net Margin | 0.20 | 0.26 | (20.30) | 0.24 | 0.27 | (11.00) |
Ebitda Margin | 0.60 | 0.85 | (29.70) | 0.73 | 0.75 | (1.40) |
Ajusted Ebitda Margin | 0.58 | 0.59 | (2.80) | 0.62 | 0.61 | 2.00 |
Investment Program (R$ million) | 140.50 | 54.50 | 157.80 | 313.70 | 127.70 | 145.70 |

3.1.1 IFRS effect on the Transmission segment

For the calculation, an adjustment was made considering the effects of the application of ICPC 01 / IFRIC 12 on the corporate statements in the transmission segment:

|  |  |  |  |  | R$ million |
IFRS effect in the Transmission segment | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
(A) Corporate revenue1 | 321.3 | 206.9 | 55.2 | 797.8 | 715.1 | 11.6 |
O&M revenue and effective interest | 318.8 | 204.3 | 56.0 | 789.1 | 708.2 | 11.4 |
Construction revenue and margin | 54.5 | 19.0 | 186.8 | 165.7 | 48.9 | 238.9 |
Cost of construction | (52.1) | (16.4) | 217.8 | (156.9) | (41.9) | 274.2 |
(B) Regulatory revenue1 | 366.6 | 244.6 | 49.9 | 919.7 | 772.7 | 19.0 |
(B-A) Regulatory/Societal TRA Revenue/Difference | 45.4 | 37.7 | 20.4 | 121.9 | 57.6 | 111.6 |
(+/-) Effects on Equity of transmission companies2 | 11.3 | (24.5) | — | (78.7) | (107.2) | (26.5) |
IFRS effect in Transmission business | 56.7 | 13.2 | 330.5 | 43.2 | (49.6) | — |
1 N et of taxes and charges. 2 D ifference between corporate and regulatory profit of jointly owned subsidiaries in the transmission segment, proportional to Gen Co's stake in the projects. |

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3.2 Operational Performance

With a presence in 10 states, GenCo operates a diversified park of hydroelectric and wind power plants, totaling 6,227.0 MW of installed capacity and 2,696.2 average MW of physical guarantee. In the Transmission segment, Copel has a total grid of 9,684 km of transmission lines and 53 basic grid substations, considering its holdings.

For more information on generation and transmission operational data, see Annex IV.

3.2.1 Generation

Copel's generation park is made up of 100% renewable operating sources.

GenCo's hydro generation was 34.2% lower in 3Q25 (4,406 GWh against 6,700 GWh in 3Q24), due to a less favorable hydrological scenario and divestment in small hydroelectric plants and the HPP Colíder. At the wind farms, generation was 15.3% lower in 3Q25 (922 GWh compared to 1,089 GWh in 3Q24), despite the increase in curtailment in 3Q25 (34.4% compared to 23.5% in 3Q24) and the unavailability of some machines. In the year to date, total generation from the Company's portfolio was 22.4% lower (15,908 GWh in 9M25, compared to 20,499 GWh in 9M24).

3.2.2 Energy sold

In the 3rd quarter of 2025, GenCo recorded 3,662 GWh of electricity sold from hydroelectric sources, an increase of 1.1%, mainly due to higher sales under bilateral contracts. This was partially offset by an increase in the amount of energy purchased on the short-term market (MCP). The energy sold does not consider the generation allocated to the Energy Reallocation Mechanism (MRE), which fell by 52.9% in the quarter (1,671 GWh compared to 3,545 GWh in 3Q24), reflecting the hydrological conditions in the period.

For wind farms, the total electricity sold was 1,195 GWh, an increase of 7.4%, mainly due to the increase in sales under bilateral contracts and energy sold in the regulated environment (CCEARs), as a result of the start of supply from the Jandaíra Complex[5].

[5] Jandaíra I, II, III and IV wind farms (30° LEN - CCEAR 2025 - 2044).

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Consolidated Sales (GWh)

GSF and PLD

Source: CCEE

Source: CCEE

3.2.3 Transmission

Copel has more than 9,600 km of transmission lines in eight Brazilian states, including its own assets and those in partnership with other companies. In addition to building, maintaining and operating its own extensive energy transmission network, Copel provides services for projects run by other concessionaires. The Transmission projects are listed in Annex IV, including the projects of GenCo, SPEs Costa Oeste, Marumbi, Uirapuru Transmissora and MSG (100% GenCo), as well as the 6 SPEs in which Genco has a stake.

RBSE

Below is a description of the flow of the portion of the Revenue relating to the Basic Network of the Existing System - RBSE[6] for the next few cycles. It is important to note that the data may be altered in the future due to tariff revision processes and/or revision of the parameters used to compose these revenues by the regulatory body. The figures below include the revision in the methodology for calculating the financial component, established by Aneel’s homologation resolution (REH) 3,467/2025, with a negative impact of R$ 115.1 million, and have been adjusted annually by the IPCA, according to Aneel’s homologation resolution 3,481/2025.

Note:

Economic component: future values based on the 2025-2026 cycle (according to REH 3,481/2025)

Financial component: values published in REH 3.467/2025. .

RAP values up to the 2027-2028 cycle projected based on the values in REH 3,467/2025.

[6] This refers to concession contract 060/2001, which represents 36.6% of GenCo's annual permitted revenue (APR) for transmission and proportional stakes.

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| 4. Copel Distribuição (DisCo) |

4.1 Economic and Financial Performance

DisCo's reported recurring Ebitda of R$650.9 million in 3Q25, up 7.2% (R$43.6 million) compared to 3Q24, mainly due to 1.7% growth in the billed grid market and the June 2025 Annual Tariff Adjustment (RTA) in June 2025, with an average increase of 6.4% in Distribution System Usage Tariffs (TUSD). The following also contributed to the result:

(i) the increase of R$ 120.7 million in Copel DisCo's supply revenue, mainly due to the improved results from settlements at the CCEE;

(ii) a R$ 424.7 million increase in revenue from sectoral assets and liabilities, mainly due to the constitution of amounts to be offset (active CVA) in the 2025-2026 cycle, driven by higher electricity costs and the effects of the June 2025 tariff adjustment; and

(iii) a R$ 10.1 million reduction in PMSO, due to the departure of 145 employees, mostly under the 2024 and 2025 PDV, partially offset by increased costs with third-party services.

These results were partially offset:

(i) a reduction of R$ 29.8 million in revenues from electricity supply (R$ - 18.4 million) and availability of the electricity grid (-R$ 11.4 million), resulting from Mini and Micro Distributed Generation (MMGD) and the migration from captive to free;

(ii) by an increase of 434.4 million due to the higher volume of energy from the MMGD compensation system and an increase in the cost of electricity purchased for resale due to higher market prices;

(iii) by a decrease of R$ 18.8 million in other operating revenues, reflecting, above all, the reduction in amounts received from infrastructure sharing rentals;

(iv) by the increase of R$ 26.7 million in provisions and reversals due to the increase of R$ 18.5 million in Estimated Losses on Doubtful Accounts - PECLD, mainly related to the default of the low voltage group and the increase of R$ 8.2 million in litigation, especially due to legal proceedings; and

(v) an increase of R$ 6.8 million in other operating costs and expenses.

For the year to date, recurring Ebitda reached R$ 1,913.1 million, an increase of 6.9%.

|  |  |  |  |  | R$ million |
Recurring Ebitda | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
EBITDA | 687.8 | 611.1 | 12.6 | 1,973.6 | 1,826.3 | 8.1 % |
(-/+) Reversão/Provisão indenização PDV | — | 13.3 | (100.0) | 12.2 | 13.3 | (8.3) % |
(-/+) VNR | (36.9) | (17.2) | 114.5 | (72.7) | (49.5) | 46.9 % |
Ebitda Recorrente | 650.9 | 607.3 | 7.2 | 1,913.1 | 1,790.2 | 6.9 % |

Manageable costs (PMSO), excluding provisions and reversals, decreased by R$ 10.1 million (-2.2%) compared to 3Q24, due to the effect of the reduction, mainly because: i. of R$ 40.3 million (-32.0%) in personnel, management, pension, and welfare costs; and ii. of R$ 5.2 million (-33.1%) in material expenses, mainly due to inventory reorganization and control and a reduction in fuel, parts, and equipment costs for the Company's fleet.

These effects were partially offset by an increase of (i) R$ 28.6 million (+15.2%) in third-party service costs, due to higher contracting volumes and demand, especially for electrical system maintenance services, including costs for cleaning the right-of-way (+R$ 33.1 million), partially offset by the reduction in facility maintenance services (-R$ 6.1 million) and (ii) R$ 6.8 million (+12.3%) in other operating costs and expenses, mainly due to the increase of R$ 5.2 million in losses on the decommissioning of assets associated with the investment program.

In the year to date, recurring manageable costs fell by 1.3%, mainly due to lower personnel and material costs, partially offset by higher third-party service costs and other costs and expenses, especially losses on the decommissioning of assets.

|  |  |  |  | R$ million |
Manageable Costs | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆%
Personnel and management | 115.8 | 166.3 | (30.4) | 400 | 514.6 | (22.3)
Private pension and healthcare plans | 38.1 | 41.2 | (7.5) | 115.5 | 129.2 | (10.6)
Materials | 10.3 | 15.4 | (33.1) | 38.3 | 46 | (16.7)
Third party services | 216.4 | 187.8 | 15.2 | 617.9 | 519.1 | 19.0
Other operating costs and expenses¹ | 61.8 | 55.1 | 12.2 | 154.7 | 136.2 | 13.6
TOTAL | 442.4 | 465.8 | (5.0) | 1,326.4 | 1,345.1 | (1.4)
1 Considers losses on the de decommissioning of assets in the amount of R$ 40.3 million in 3Q 2025.

Excluding the effects of the PDV, PPD and PLR provisions, the personnel costs line fell by 16.0%, mainly reflecting lower remuneration, charges, and expenses related to pension and welfare plans, as a result of the reduction in the number of employees, mainly through the Voluntary Dismissal Program, as already mentioned, partially offset by the pro rata provision, between October and December, of the 2024 Collective Bargaining Agreement, with a 4.09% salary adjustment (INPC accumulated over 12 months until September 2024).

|  |  |  |  | R$ million
Personnel costs | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆%
Staff and administrators | 115.8 | 166.3 | (30.4) | 400 | 514.6 | (22.3)
(-/+) Profit sharing, PPD and ILP | (14.8) | (32.7) | (54.7) | (72.1) | (106.4) | (32.2)
(-/+) Provision/Reversal of POS indemnity | — | (13.3) | — | (12.2) | (13.3) | (8.3)
TOTAL | 101.0 | 120.3 | (16.0) | 316 | 395 | (20.0)

In 3Q25, the following also stand out:

| • | an increase of R$ 26.8 million in depreciation and amortization, due to the larger asset base resulting from the investment program carried out in the last 12 months;

| • | a R$ 76.9 million reduction in financial results, mainly due to increased monetary variation and debt charges, as a result of funding raised until 2025, the main index for Copel's debts, offset by increased income from financial investments and interest on taxes to be offset; and

| • | the decrease of R$ 19.9 million in income tax and social contribution, mainly due to lower financial results and higher depreciation, which reduced the tax base.

Copel DisCo's recurring net income in 3Q25 was R$ 201.0 million (16.7% lower than in 3Q24), impacted mainly by increased depreciation and amortization and lower financial income, as highlighted above.

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Below are DisCo's main indicators:

|  |  |  |  |  | R$ million
Main Indicators | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆%
Net Operating Revenue (R$ million) | 5,125.2 | 4,352.4 | 17.8 | 13,986.1 | 12,556.1 | 11.4
Operating Costs and Expenses (R$ million) | (4,616.8) | (3,893.8) | 18.6 | (12,532.4) | (11,163.7) | 12.3
Operating Result (R$ million) | 328.4 | 355.5 | (7.6) | 824.2 | 974.6 | (15.4)
Net Profit (R$ million) | 225.3 | 243.8 | (7.6) | 610.7 | 693.6 | (12.0)
Recurring net profit (R$ million) | 201.0 | 241.3 | (16.7) | 525.5 | 640.6 | (18.0)
Ebitda (R$ million) | 687.8 | 611.1 | 12.6 | 1,973.6 | 1,826.3 | 8.1
Recurrent Ebitda (R$ million) | 650.9 | 607.3 | 7.2 | 1,913.1 | 1,790.2 | 6.9
Operating Margin | 6.5% | 8.2 % | (20.7) | 5.9 % | 7.8 % | (24.4)
Net Margin | 4.4% | 5.6 % | (21.4) | 4.4 % | 5.5 % | (20.0)
Ebitda margin | 13.4% | 14.0 % | (4.3) | 14.1 % | 14.5 % | (2.8)
Adjusted Ebitda margin without NRV | 12.8% | 14.0 % | (8.6) | 13.7 % | 14.3 % | (4.2)
Investment Program (R$ million) | 840.0 | 509.6 | 64.8 | 2,317.7 | 1,653.8 | 40.1

4.2 Operational Performance

4.2.1 Grid Market (TUSD)

In the third quarter of 2025, electricity consumption in DisCo grid market grew 1.7% compared to the same period last year. This increase is mainly due to lower temperatures, which boosted residential consumption for heating, and greater economic activity, which favored the performance of the commercial and industrial segments in the area served by Copel. The billed grid market, which deducts part of the energy compensated by Mini and Micro Distributed Generation (MMGD), also increased by 1.7%.

4.2.2 Captive Market

The captive market saw a 5.6% decrease in electricity consumption in 3Q25 compared to the same period last year and a 6.0% drop in the year to date. The captive market billed, which considers MMGD's offset energy, fell by 6.3% in Q3 2025 and 2.3% in the year to date. This decline is mainly explained by the advance of MMGD, except for energy from Distributed Generation (DG) II and III modalities, which is compensated, and by the migration of consumers to the Free Contracting Environment (ACL), which has been directly impacting demand in the captive market.

4.2.3 Operational data

DisCo has a concession valid until July 7, 2045, whose service quality criteria (Equivalent Interruption Duration per Consumer Unit - DEC and Equivalent Interruption Frequency per Consumer Unit - FEC) are defined by ANEEL.

Despite the severe weather events in the state of Paraná in recent months, the company has acted in a timely manner to re-establish the power supply and prevent vegetation on the grid, which has contributed to maintaining the quality-of-service indices within the regulatory limits.

For DEC, the result for the last 12 months in September 2025 was 7.46 hours, while for FEC, the result for the same period was 4.90 interruptions, both within the established regulatory limit.

Losses - Distribution losses can be defined as the difference between the electricity acquired by distributors and that billed to their consumers and are segmented as Technical and Non-Technical. Technical losses are inherent to the activity of electricity distribution and non-technical losses are mainly due to theft (clandestine connection, direct detour from the grid), fraud (meter tampering or detour), and reading, measuring or billing errors. At the end of September 2025, Technical Losses for the last 12 months were 2,299 GWh, compared to 2,260 GWh for the same period last year, and Non-Technical Losses were 630 GWh, compared to 830 GWh for the same period last year. Total losses over the last 12 months amounted to 2,895 GWh.

GWh - 12 Months | Sep-21 | Sep-22 | Sep-23 | Sep-24 | Sep-25
Injected Energy | 34,374 | 35,216 | 35,781 | 39,056 | 39,610
Distribution Losses | 2,651 | 2,651 | 2,743 | 3,090 | 2,895
Technical Losses | 1,989 | 2,038 | 2,070 | 2,260 | 2,292
Non-Technical Losses | 662 | 614 | 673 | 830 | 603
* As established by the result of CP 09/2024 (DSP No. 1,220/2025)

Non-technical losses, calculated as the difference between total losses and technical losses, are largely associated with the concessionaire's management and the socio-economic characteristics of the concession areas. To this end, Copel maintains a Program to Combat Non-Technical Losses, through the following actions, among others:

| • | use of smart meter alarms to improve the performance of selected targets;

| • | improving actions to combat irregular procedures, improving the performance of targeted inspections;

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| • | investments aimed at providing and/or acquiring inspection equipment;

| • | preparation and execution of specific training and refresher courses related to commercial losses;

| • | carrying out inspections on both medium and low voltage;

| • | educational notices in the press and messages on electricity bills;

| • | joint operations with the Police and the Public Prosecutor's Office;

| • | the opening of police investigation in regions where a significant number of irregular procedures have been found.

The tariff transfer of efficient levels of losses is provided for in the concession contracts and these losses are included in energy purchase costs up to the regulatory limit stipulated by Aneel. DisCo has remained within the regulatory limits in recent tariff processes and in September 2025, total losses were 0.84% below the regulatory limit, influenced by the revision of targets resulting from the effects of CP 09/24.

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| 5. Copel Comercialização (TradeCo) |

5.1 Economic and Financial Performance

Copel’s TradeCo reported negative recurring EBITDA of R$ 6.8 million in 3Q25, a significant drop from R$ 3.3 million in 3Q24, mainly reflecting the reduction in the sales margin of approximately R$ 7.3 million, due in particular to legacy contracts of sale of energy from intermittent sources, as well as the increase in manageable costs, as shown below.

The main adjustment in the quarter was the fair value of energy purchase and sale contracts (mark-to-market), calculated as the difference between the contracted price and the future market price estimated by the Company, which was negative at R$ 42.9 million in 3Q25 compared to a positive R$ 17.9 million in 3Q24, mainly influenced by the increase in the SE-NE (Southeast - Northeast) submarket spread in mark-to-market for the period, added to the change in the profile of the base contracts, the reduction in the long-term NTN-B discount rate, and the reduction in the Northeast submarket spread.

|  |  |  |  | R$ million |
Recurring Ebitda | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
Ebitda | (49.7) | 21.0 | (337.3) | 57.7 | 42.6 | 35.4 |
(-/+) Provision/Reversal of Voluntary Dismissal Program (PDV) | — | 0.2 | — | — |  | — |
(-/+) Fair value on the purchase and sale of energy | 42.9 | (17.9) | (340) | (25.0) | 26.0 | (196.0) |
Recurring Ebitda | (6.8) | 3.3 | (307,8) | 32.7 | 68.6 | (52.3) |

Manageable costs, excluding non-recurring items, provisions, and reversals, increased by 39.1% in 3Q25, mainly influenced by an increase of approximately R$ 1.9 million in Personnel and Management expenses, due to the ongoing restructuring process of the trading company, in addition to R$ 1.8 million in Other Operating Costs and Expenses, due to costs with compulsory association contributions, renewable energy certification, and software rental, partially offset by a 60.8% reduction in third-party service costs compared to the same period in 2024, mainly due to the termination of software development contracts.

|  |  |  |  | R$ thousand |
Recurring Manageable Costs* | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆% |
Staff and management | 5,504.0 | 3,423.0 | 60.8 | 14,336.0 | 10,983.0 | 30,5 |
Social security and assistance plans | 429.0 | 429.0 | — | 1,302.0 | 1,321.0 | (1.6) |
Material | 113.0 | 14.0 | 720.7 | 221.0 | 48.0 | 360.3 |
Third-party services | 724.0 | 1,847.0 | (60.8) | 2,730.0 | 4,253.0 | (35.8) |
Other costs and expenses operating | 2,738.0 | 953.0 | 187.3 | 6,530.0 | 3,516.0 | 85.6 |
TOTAL | 9,508.0 | 6,665.0 | 42.7 | 25,119 | 20,121 | 24.8 |
*Excludes effects of non-recurring item Personnel - Reversal/provision Voluntary Dismissal Program |

Personal accounts and administrators, excluding the effects of PDV, PLR, and PPD, recorded a 42.1% increase in 3Q25, mainly due to the aforementioned restructuring process of the marketing company.

|  |  |  |  | R$ thousand
Recurring Personnel Costs | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆%
Staff and administrators | 5,504 | 3,591 | 53.3 | 14,340 | 11,152 | 28.6
(-/+) Profit sharing PLR, PPD and ILP | (1,770.0) | (797.0) | 122.0 | (3,952.0) | (2,074.0) | 90.6
TOTAL | 3,734 | 2,625 | 42.2 | 10,384 | 8,910 | 16.5

TradeCo reported a recurring net loss of R$ 43.0 million in Q3 2025, compared to a net profit of R$ 14.5 million in Q3 2024, mainly due to: (i) the operating performance already reported; (ii) a R$ 1.4 million decline in financial results (a 14.0% reduction compared to 3Q24), mainly due to lower income from financial investments.

For the year to date, the recurring net loss was R$ 17.8 million, 133.7% lower than in the same period of 2024, also due to the lower sales margin (-200%).

|  |  |  |  |  | R$ million
Main Indicators | 3Q25 | 3Q24 | ∆% | 9M25 | 9M24 | ∆%
Net Operating Revenue (R$ million) | 1,122.4 | 901.4 | 24.5 | 3,209.8 | 2,590.4 | 23.9
Operating Costs and Expenses (R$ million) | (1,172.6) | (880.9) | 33.1 | (3,153.6) | (2,549.1) | 23.7
Operating Result (R$ million) | (41.0) | 31.1 | (231.8) | 85.1 | 71.2 | 19.5
Net Profit (R$ million) | (27.0) | 20.5 | (232.1) | 56.0 | 47.2 | 18.5
Recurring Net Profit (R$ million) | (43.0) | 14.5 | (396.2) | (17.8) | 52.7 | (133.7)
Ebitda (R$ million) | (49.7) | 21.0 | (337.3) | 54.9 | 42.6 | 28.9
Recurrent Ebitda (R$ million) | (6.8) | 3.1 | (321.3) | 29.9 | 68.6 | (56.4)
Operating Margin | — | — | — | — | — | (3.6)
Net Margin | — | — | — | — | — | (4.4)
Ebitda Margin | — | — | — | — | — | 4.0
Investment Program (R$ million) | 0.1 | 0.1 | — | 0.6 | 0.4 | 50.0

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5.2 Operational Performance

In 3Q25, energy sales grew 25.0% compared to the same period in 2024, mainly due to the effect of increased sales to traders in bilateral contracts (+38.1%). The following chart shows the evolution of the Company in terms of GWh sold, demonstrating growth of 14.8% over the last four years.

Following the company's commercial strategy guidelines, sales in 3Q25 for the five-year horizon increased by 96.2% compared to the previous quarter, a period in which there was a jump from 219.9 to 431.4 MWm. For the 2025-2029 period, there was a 19.7% decrease, mainly due to a reduction in energy sales to free consumers.

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| 6. ESG performance |

6.1 ESG in Copel’s Strategy

Copel incorporates ESG (Environmental, Social, and Governance) principles into its corporate strategy, basing its actions on material issues identified through stakeholder consultation and within the guidelines established by its Sustainability Policy. Integrity is a cross-cutting value that guides all of the company's practices, reinforcing its commitment to ethics, transparency, and compliance. This approach is complemented by voluntary commitments aligned with the Global Compact Principles and the UN Sustainable Development Goals (2030 Agenda).

Priority SDGs by Copel

Copel’s ESG strategy aims to promote a broad and systemic sustainability culture. Rooted in stakeholder engagement, material topics guide programs and initiatives that generate shared value, minimize risks, and enhance opportunities.

On the environmental front, decarbonization, climate adaptation and resilience, biodiversity, and eco-efficiency are key drivers of projects and initiatives—such as the carbon neutrality plan, under which the company commits to achieving carbon neutrality for its direct emissions by 2030. Copel invests in 100% renewable energy, researches alternative sources, and reduces greenhouse gas emissions, reinforcing its commitment to combating climate change.

In the social dimension, the “people” pillar is central, with a focus on employee health and safety, human rights, and diversity. Copel promotes a healthy work environment, with a goal of zero fatal accidents, acting fairly and inclusively with employees and stakeholders, while also strengthening community engagement.

In terms of governance, Copel adopts a structured and transparent approach, highlighted by its Integrity Program, which is based on the Code of Conduct and aligned with the principles of the UN Global Compact. The program develops actions aimed at risk prevention, fostering an ethical culture, and ensuring continuous employee engagement. The company also maintains robust risk management and internal controls, ensuring compliance with laws and regulations and strengthening governance at all organizational levels.

Copel’s ESG performance is continuously monitored through indicators and external assessments, such as the B3 Corporate Sustainability Index (ISE B3), S&P Global’s CSA, and CDP.

In this way, Copel integrates ESG into its corporate strategy in a cross-cutting manner, committed to sustainable development, value creation for society, and the strengthening of corporate governance.

6.2 Recent highlights

| • | Copel mediates panel at Brazil's largest event on GHG emissions: In August 2025, Copel was invited to mediate a panel at Brazil's largest event on climate change, promoted by the GHG Protocol program, which released the results of the 2024/25 corporate GHG emissions inventories. The invitation recognizes the company's track record in sustainable actions, such as the Carbon Neutrality Plan by 2030. As the founder of the GHG Protocol in Brazil, Copel reaffirms its prominent role in energy transition and sustainability.

| • | Volunteering and Recognition: In celebration of National Volunteering Day (August 28), the Tricopel project, which operates under the umbrella of the EletriCidadania corporate program, was featured in an article produced by the UB Play newspaper (affiliated with TV Cultura). The program allows employees to dedicate up to 8 hours of their workday every two months to social and environmental actions of interest to the community.

| • | Launch of the New Supplier Code of Conduct: Copel launched its Supplier Code of Conduct, a document that establishes clear guidelines for the operations of its suppliers. The Code focuses on ethics, sustainability, and corporate responsibility, presenting guidelines on topics such as integrity, social and environmental responsibility, risk prevention, and respect for human rights.

| • | Pura Energia Partner Award 2025: On August 27, Copel held a ceremony to recognize the winners of the Pura Energia Partner Award 2025. This event, which falls under the Governance and Social Responsibility pillar, recognizes partners for their actions in line with the Company's values and purposes. The initiative reinforces Copel's commitment to establishing ethical and sustainable partnerships.

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6.3 Indicators

Regarding the scope 1 GHG indicator (tCO2), the data refers to direct greenhouse gas emissions from Copel's operations (fleet, soil change and fugitive emissions), calculated every six months. The 2025 data will be audited later by a third party.

Environmental Indicator | Carried
2023 | 2024 | Δ% | 1Q25 | 2Q25 | 3Q25 | Δ%
Renewable sources (% Installed capacity) | 94.1 | 94.1 | — | 100.00 | 100.00 | 100.00 | —
Renewable sources (% Energy generated) | 99.9 | 99.97 | 0.1 | 100.00 | 100.00 | 100.00 | —
GHG Emission scope 1 (tCO2)¹ | 81,690.3 | 17,318.0 | (78.8) | — | 4,937.7 | — | —
GHG Emission scope 2 (tCO2)² | 148,798.7 | 229.169,5 | 54.0 | — | 169,117.0 | — | —
¹Scope 1 refers to direct emissions of greenhouse gases from Copel's operations (fleet, soil change and fugitive emissions), calculated every six months. The 2025 data will be verified later by a third party.
²Scope 2 refers to indirect greenhouse gas emissions from Copel's operations (consumption and loss of electricity) - GHG emissions are carried out every six months.

Social Indicator | Carried
2023 | 2024 | Δ% | 1Q25 | 2Q25 | 3Q25 | Δ%
Women at Copel (% Copel employees) | 21.7 | 21.9 | 0.9 | 22.3 | 22.1 | 22.5 | 1.8
Women at Copel (% Contractors) | 11.7 | 14.0 | 19.7 | 16.0 | 16.6 | 14.5 | (12.7)
Frequency of occupational accidents - TF (% Company employees) | 1.4 | 2.0 | 42.9 | 1.6 | 1.3 | 0.8 | (38.5)
Frequency of occupational accidents - TF (% Contractors) | 4.9 | 3.9 | (20.4) | 4.2 | 3.0 | 2.9 | (3.3)
TFIFR: Frequency rate of occupational accidents with leave of absence. This rate (occurrences per one million hours/men) represents exposure to risk, number of contractors involved in accidents with leave of absence or fatalities in the period considered.
ABNT – NBR 14280: 2001

Governance Indicator | Carried
2023 | 2024 | Δ% | 1Q25 | 2Q25 | 3Q25 | Δ%
Women in leadership positions (%) | 21.8 | 22.1 | 1.4 | 22.6 | 20.3 | 22.2 | 9.4
Women in the Board of Directors (%) | 11.1 | 11.1 | — | 11.1 | 11.1 | 11.1 | —
Independent Board Members (%) | 88.8 | 88.8 | — | 88.8 | 88.8 | 88.8 | —
Reports solved through the Whistleblowing Channel (%) | 82.7 | 82.0 | (0.8) | 51.0 | 66.0 | 95.0 | 43.9
*The indicator considers the completion of investigations in the period analyzed/year, the Company analyzes 100% of the complaints received.

6.4 Ratings, Rankings and Indexes

Index |  |  |  |  |  |
Ranking | 82.47% Ranking 19th | CSA Score 70 | B | Yes | Medium Risk | AA
Reference Year | 2025 | 2024 | 2024 | 2024 | 2023 | 2025

18

| 7. Other highlights from the period |

7. Other highlights from the period

Migration to the [B]³'s Novo Mercado segment

On August 22, 2025, the Extraordinary General Meeting (EGM) approved the unification of shares and admission to the [B]³'s Novo Mercado, subject to: (a) obtaining the consent of creditors whose respective financial instruments provide for early maturity of the debts of the Company or its subsidiaries as a result of the approval of the matters of the EGM (“Waivers”); (b) convening a special meeting of preferred shareholders; and (c) submitting the request for Migration to the Novo Mercado to B3, with the effective admission of the Company's shares to trading on the Novo Mercado.

Of the conditions established, the following have already been met: (i) obtaining the waivers on November 4, 2025, and (ii) approval by B3 of the request for migration to the Novo Mercado, conditional on the disclosure of documentation dealing with the operationalization of the conversion of the company's preferred shares on November 5, 2025.

We highlight that on November 10, 2025, the mandatory conversion of all class B preferred shares (PNB) into class A preferred shares (PNA) was carried out.

The migration will only take effect after approval at the Special Meeting of Preferred Shareholders (AGESP), scheduled for November 17, 2025, to ratify the conversion of preferred shares into common shares.

For more information on this matter, please refer to Material Facts 08/25, 09/25, and 12/25.

Copel recognized as Latin America's Most Honored Company in international ranking

On August 26, 2025, the Company was named Latin America's Most Honored Company, ranking second in the Electric and Other Utilities sector in the annual Latin America Executive Team survey conducted by Extel, a global leader in performance evaluations for the capital markets. For the second consecutive year, Copel is in the top 3 in the sector, with its leadership and programs serving as outstanding references: Board of Directors, CEO, CFO, Head and IR team, ESG, and Investor Day programs. The distinction highlights Copel's commitment to value creation, governance, and stakeholders.

Copel is the largest company in Paraná and the fifth largest in the South

On September 17, the ranking of the 500 largest companies in the South – Grandes & Líderes 2025 (Great & Leaders 2025) was released by Grupo Amanhã and PricewaterhouseCoopers (PwC) Brazil, consolidating Copel as the largest company in Paraná and the fifth largest in the South Region. This recognition highlights Copel's commitment to investments that generate greater reliability and availability of energy throughout the state. Since 2019, Copel has led the ranking of the 100 largest companies in Paraná and is among the five largest in the South.

Paraná Trifásico receives national recognition from the MME

The 1st Brazilian Mining and Energy Congress (CBME 2025), in preparation for CP30, took place on September 22 and 23, 2025. Paraná Trifásico, the largest rural electricity grid modernization program in Brazil, was highlighted in the area of rural electricity distribution infrastructure. This recognition demonstrates Copel's commitment to investing in a more powerful and stable power grid. By the end of this year, more than 25,000 km of three-phase networks will have been implemented throughout the state.

Copel wins award for best Energy Transmission Company in Brazil

On October 1, 2025, the Company was voted the best energy transmission company in Brazil at the 1st ONS Quality in Operation Awards, organized by the National Electric System Operator (ONS). The award recognizes the concessionaires that achieved the best performance percentages in 2024 in terms of the availability of equipment in the power transmission network that makes up the National Interconnected System (SIN).

This recognition highlights Copel's commitment to maintaining high availability rates for power transmission equipment through investment in technology for the execution of improvement and reinforcement works on its facilities.

Copel Innovation Challenge 2025 awards winning groups

On October 14, 2025, Copel announced the winners of the Copel Innovation Challenge 2025. The highlights were: a platform for reverse auctioning ICMS credits, an AI-based solution to reduce unproductive services by Copel DIS field teams, and a predictive system using AI and smart grid data to forecast failures in electrical assets. The challenge is part of Copel Beyond, a movement that has been driving the Company's digital and cultural transformation.

Closing of the Divestment in the Baixo Iguaçu Hydroelectric Plant

On October 22, 2025, the Company completed the divestment of the Baixo Iguaçu Hydroelectric Plant, whose equity value totaled R$ 1,683.3 million, after fulfilling all conditions precedent and obtaining approvals from the competent authorities. The divestment highlights Copel's agility and efficiency in recycling assets and minority interests. For more information, see Material Fact 10/25.

Copel receives award for accounting quality and transparency

On October 24, 2025, the Company received the 2024 Transparency Trophy for the ninth time, awarded by the National Association of Finance, Administration, and Accounting Executives (ANEFAC) in recognition of its financial and accounting balance sheet..

Divestment in Distributed Generation

On October 30, 2025, the Company formalized with Thopen Energia the divestment of four photovoltaic solar plants with 22 MWp in operation. The transaction, valued at R$ 78 million, encompasses Distributed Generation (DG) assets and reinforces its commitment to continuously optimize its portfolio with sustainable value creation.

19

Disclaimer

Information contained in this document may include forward-looking statements and reflects management's current perception and outlook on the evolution of the macroeconomic environment, industry conditions, the Company's performance and financial results. Any statements, expectations, capabilities, plans and assumptions contained in this document that do not describe historical facts, such as information regarding the declaration of payment of dividends, the future direction of operations, the implementation of relevant operational and financial strategies, the investment program, factors or trends affecting the financial condition, liquidity or results of operations are forward-looking statements of significance under the U.S. Private Securities Litigation Reform Act of 1995 and involve various risks and uncertainties. There can be no assurance that such results will occur. The statements are based on various factors and expectations, including economic and market conditions, industry competitiveness and operational factors. Any changes in such expectations and factors could cause actual results to differ materially from current expectations.

Investor Relations

ri@copel.com

Phone: (41) 3331-4011

20

| EXHIBIT I - CONSOLIDATED RESULTS > INCOME STATEMENT

|  |  |  |  |  | R$ '000 |
Income Statement | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ% |
OPERATING REVENUES | 6,811,177 | 5,735,608 | 18.8 | 18,928,417 | 16,631,872 | 13.8 |
Electricity sales to final customers | 1,878,258 | 1,970,334 | -4.7 | 5,982,373 | 6,255,268 | -4.4 |
Electricity sales to distributors | 1,241,556 | 834657 | 48.8 | 3,357,229 | 2,301,493 | 45.9 |
Use of the main distribution and transmission grid | 1,752,729 | 1,660,092 | 5.6 | 5,212,408 | 5,133,304 | 1.5 |
Construction revenue | 952,822 | 661,016 | 44.1 | 2,435,282 | 1,908,985 | 27.6 |
Fair value of assets from the indemnity for the concession | 36,909 | 17,190 | 114.7 | 72,651 | 49,467 | 46.9 |
Result of Sectorial financial assets and liabilities | 845,437 | 420,709 | 101.0 | 1,408,164 | 566,185 | 148.7 |
Other operating revenues | 103,466 | 171,610 | -39.7 | 460,310 | 417,170 | 10.3 |
OPERATING COSTS AND EXPENSES | -5,866,333 | -4,640,519 | 26.4 | -15,545,166 | -13,715,653 | 13.3 |
Electricity purchased for resale | -3,083,439 | -2,327,982 | 32.5 | -7,899,201 | -6,314,383 | 25.1 |
Charge of the main distribution and transmission grid | -687,026 | -714,064 | -3.8 | -2,080,127 | -2,222,422 | -6.4 |
Personnel and management | -212,592 | -278,929 | -23.8 | -704,166 | -857,625 | -17.9 |
Pension and healthcare plans | -57,932 | -63,291 | -8.5 | -176,884 | -198,988 | -11.1 |
Materials and supplies | -19,122 | -22,093 | -13.4 | -64,036 | -62,236 | 2.9 |
Materials and supplies for power eletricity | — | — | — | — | -936 | — |
Third-party services | -287,408 | -274,613 | 4.7 | -848,418 | -772,679 | 9.8 |
Depreciation and amortization | -376,524 | -368,414 | 2.2 | -1,092,755 | -1,089,197 | 0.3 |
Provisions and reversals | -85,565 | -68,379 | 25.1 | -240,010 | -227,955 | 5.3 |
Construction cost | -950,376 | -658,392 | 44.3 | -2,426,558 | -1,902,041 | 27.6 |
Other cost and expenses | -106,349 | 135,638 | -178.4 | -13,011 | -67,191 | -80.6 |
EQUITY IN EARNINGS OF SUBSIDIARIES | 37,329 | 63,210 | -40.9 | 202,001 | 225,398 | -10.4 |
PROFIT BEFORE FINANCIAL RESULTS AND TAXES | 982,173 | 1,158,299 | -15.2 | 3,585,252 | 3,141,617 | 14.1 |
FINANCIAL RESULTS | -442,561 | -222,378 | 99.0 | -1,290,947 | -780,237 | 65.5 |
Financial income | 352,570 | 331,192 | 6.5 | 1,025,522 | 857,229 | 19.6 |
Financial expenses | -795,131 | -553,570 | 43.6 | -2,316,469 | -1,637,466 | 41.5 |
OPERATIONAL EXPENSES/ INCOME | 539,612 | 935,921 | -42.3 | 2,294,305 | 2,361,380 | -2.8 |
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -175,437 | -198,541 | -11.6 | -691,899 | -628,745 | 10.0 |
Income tax and social contribution on profit | -72,813 | -65,713 | 10.8 | -225,118 | -208,150 | 8.2 |
Deferred income tax and social contribution on profit | -102,624 | -132,828 | -22.7 | -466,781 | -420,595 | 11.0 |
NET INCOME continuing operations | 364,175 | 737,380 | -50.6 | 1,602,406 | 1,732,635 | -7.5 |
NET INCOME discontinued operations | 18,898 | 479,709 | -96.1 | 18,898 | 491,571 | -96.2 |
NET INCOME | 383,073 | 1,217,089 | -68.5 | 1,621,304 | 2,224,206 | -27.1 |
Attributed to the controlling company's shareholders - continuing operations | 365,324 | 744,556 | -50.9 | 1,602,972 | 1,759,435 | -8.9 |
Attributed to the controlling company's shareholders - discontinued operations | 18,898 | 475,104 | — | 18,898 | 463,690 | -95.9 |
Attributed to non-controlling shareholders - continuing operations | -1,149 | -7,142 | -83.9 | -566 | -15,458 | -96.3 |
Attributed to non-controlling shareholders - discontinued operations | — | 4,571 | — | — | 16,539 | -100.0 |
EBITDA continued operations | 1,358,697 | 1,526,713 | -11.0 | 4,678,007 | 4,230,814 | 10.6 |

22

| EXHIBIT I - CONSOLIDATED RESULTS > BALANCE SHEET

R$ '000 |  | R$ '000
Assets | Sep-25 | Dec-24 | Δ% |  | Liabilities | Sep-25 | Dec-24 | Δ%
CURRENT | 13,140,211 | 13,041,808 | 0.8 |  | CURRENT | 9,161,089 | 10,342,380 | (11.4)
Cash and cash equivalents | 3,815,007 | 4,161,939 | (8.3) |  | Payroll, social charges and accruals | 266,081 | 411,102 | (35.3)
Bonds and securities | 155,621 | 623 | 24,879.3 |  | Suppliers | 3,008,055 | 2,324,423 | 29.4
Collaterals and escrow accounts | 9 | 9 | — |  | Income tax and social contribution payable | 58,969 | 83,482 | (29.4)
Customers | 4,280,345 | 3,962,702 | 8.0 |  | Other taxes due | 327,463 | 302,345 | 8.3
Dividends receivable | 80,520 | 82,278 | (2.1) |  | Loans and financing | 214,337 | 1,231,205 | (82.6)
Sectorial financial assets | 101,272.0 | — | — |  | Debentures | 1,943,347 | 2,025,110 | (4.0)
Account receivable related to concession | 12,454 | 10,609 | 17.4 |  | Minimum compulsory dividend payable | 4,869 | 3,878 | 25.6
Contract Assets | 406,223 | 283,896 | 43.1 |  | Post employment benefits | 112,988 | 95,383 | 18.5
Fair value in energy purchase and sale operations | 257,470 | 217,350 | 18.5 |  | Customer charges due | 100,913 | 44,825 | 125.1
Other current receivables | 1,058,206 | 949,674 | 11.4 |  | Research and development and energy efficiency | 100,650 | 179,149 | (43.8)
Inventories | 164,913 | 136,324 | 21.0 |  | Accounts Payable related to concession | 142,527 | 113,092 | 26.0
Income tax and social contribution | 361,936 | 296,128 | 22.2 |  | Net sectorial financial liabilities | 1,343,870 | 935,322 | 43.7
Other current recoverable taxes | 576,238 | 994,618 | (42.1) |  | Lease liability | 61,491 | 57,502 | 6.9
Prepaid expenses | 58,203 | 63,211 | (7.9) |  | Fair value in energy purchase and sale operations | 259,232 | 214,955 | 20.6
Related parties | — | 621 | (100.0) |  | Other accounts payable | 987,947 | 1,199,195 | (17.6)
Assets held for sale | 1,811,794 | 1,881,826 | (3.7) |  | Provision for allocation of Pis and Cofins credits | 59,640 | 580,000 | —
NON-CURRENT | 48,908,206 | 44,342,348 | 10.3 |  | Liabilities associated with assets held for sale | 168,710 | 541,412 | (68.8)
Long Term Assets | 19,347,248 | 15,315,121 | 26.3 |  | NON-CURRENT | 26,939,661 | 21,404,841 | 25.9
Bonds and securities | 688,675 | 529,085 | 30.2 |  | Social and labor obligations | 2,169 | 457 | 374.6
Other temporary investments | 31,327 | 30,603 | 2.4 |  | Suppliers | 130,938 | 142,380 | (8.0)
Customers | 143,422 | 116,180 | 23.4 |  | Deferred income tax and social contribution | 2,053,413 | 1,895,459 | 8.3
Judicial deposits | 373,897 | 394,364 | (5.2) |  | Other taxes due | 253,381 | 291,195 | (13.0)
Sectoral financial assets | 303,816 | — | — |  | Loans and financing | 3,196,297 | 3,387,589 | (5.6)
Account receivable related to concession | 4,051,462 | 3,497,351 | 15.8 |  | Debentures | 15,574,106 | 10,602,255 | 46.9
Contract Assets | 10,296,319 | 6,927,010 | 48.6 |  | Post employment benefits | 1,068,935 | 1,063,326 | 0.5
Fair value in energy purchase and sale operations | 561,453 | 479,938 | 17.0 |  | Research and development and energy efficiency | 285,639 | 241,294 | 18.4
Other non-current receivables | 745,396 | 681,846 | 9.3 |  | Accounts Payable related to concession | 973,291 | 992,252 | (1.9)
Income tax and social contribution | 103,115 | 164,043 | (37.1) |  | Net sectorial financial liabilities | — | 142,488 | —
Deferred income tax and social contribution | 880,813 | 1,174,175 | (25.0) |  | Lease liability | 245,884 | 271,004 | (9.3)
Other non-current recoverable taxes | 1,167,468 | 1,320,526 | (11.6) |  | Fair value in energy purchase and sale operations | 223,222 | 170,837 | 30.7
Advance expenses | 85 | — | — |  | Other accounts payable | 249,142 | 247,021 | 0.9
Investments | 2,926,176 | 3,577,937 | (18.2) |  | Provision for allocation of Pis and Cofins credits | 709,120 | 1,000,588 | (29.1)
Property, plant and equipment, net | 8,229,048 | 8,516,697 | (3.4) |  | Provisions for litigation | 1,974,124 | 956,696 | 106.3
Intangible assets | 18,128,024 | 16,623,610 | 9.0 |  | EQUITY | 25,947,667 | 25,636,935 | 1.2
Right to use an asset | 277,710 | 308,983 | (10.1) |  | Attributed to controlling shareholders | 25,986,034 | 25,674,718 | 1.2
TOTAL | 62,048,417 | 57,384,156 | 8.1 |  | Share capital | 12,821,758 | 12,821,758 | —
|  |  |  |  | Capital reserves | 12,116 | 5,595 | 116.6
|  |  |  |  | Equity valuation adjustments | 482,585 | 517,408 | (6.7)
|  |  |  |  | Treasury shares | (117,194) | (50,044) | 134.2
|  |  |  |  | Legal reserves | 1,766,110 | 1,766,110 | —
|  |  |  |  | Tax incentive reserve | 4,009 | — | —
|  |  |  |  | Retained earnings | 9,363,687 | 9,363,866 | —
|  |  |  |  | Proposed additional dividend | — | 1,250,025 | (100.0)
|  |  |  |  | Accrued earnings | 1,652,963 | — | —
|  |  |  |  | Attributable to non-controlling interest | (38,367) | (37,783) | 1.5
|  |  |  |  | TOTAL | 62,048,417 | 57,384,156 | 8.1

23

| EXHIBIT I - CONSOLIDATED RESULTS > CASH FLOW

CASH FLOWS FROM OPERATIONAL ACTIVITIES
|  | R$'000
| 09/30/25 | 09/30/24
Net income from continuing operations | 1,602.406 | 1,732.635
Adjustments to reconcile net income for the period with cash generation from operating activities: | 3,241.563 | 3,799.845
Unrealized monetary and exchange variation and debt charges - net | 2,045,940 | 1,511,124
Interest - bonus from the grant of concession agreements under the quota system | -94,742 | -88,600
Remuneration of transmission concession contracts | -563,403 | -597,298
Income tax and social contribution | 225,118 | 208,150
Deferred income tax and social contribution | 466,781 | 420,595
Equity in earnings of investees | -202,001 | -225,398
Appropriation of post-employment benefits obligations | 172,717 | 192,662
Creation for research and development and energy efficiency programs | 148,920 | 132,771
Recognition of fair value of assets from the indemnity for the concession | -72,651 | -49,467
Sectorial financial assets and liabilities result | -1,551,696 | -623,896
Depreciation and amortization | 1,092,755 | 1,089,197
Provision from the voluntary dismissal program | 20,979 | 18,388
Long-term incentives | 10,416 | 976
Net operating estimated losses, provisions and reversals | 240,010 | 227,955
Realization of added value in business combinations | -1,348 | -539
Fair value in energy purchase and sale operations | -24,973 | 26,009
Fair value adjustment of debt instruments and hedges (swaps) | 16,779 | —
Loss on disposal of accounts receivable related to concession | 2,093 | 3,193
Loss on disposal of contract assets | 7,289 | 11,963
Loss on disposal of property, plant and equipment | 4,551 | 16,084
Loss on disposal of intangible assets | 75,985 | 62,406
Result of write-offs of use rights of assets and liabilities of leases - net | — | -4,631
Assets disposal results | -356,278 | -264,434
Others | -24,084 | —
Decrease (increase) in assets | 700.833 | 674.876
Trade accounts receivable | 353,483 | 583,818
Dividends and interest on own capital received | 164,241 | 158,889
Judicial deposits | 46,386 | 6,133
Sectorial financial assets | 502,571 | 124,699
Other receivables | -78,927 | -39,671
Inventories | -28,589 | 27,493
Income tax and social contribution recoverable | -178,513 | -162,094
Other taxes recoverable | -85,411 | -33,493
Prepaid expenses | 4,971 | 8,517
Related parties | 621 | 585
Increase (decrease) in liabilities | 162,968 | -507,704
Payroll, social charges and accruals | -49,089 | -334,900
Related parties | — | —
Suppliers | 398,007 | 110,944
Other taxes | 827,585 | 654,962
Post-employment benefits | -149,503 | -164,689
Sectorial charges due | 56,088 | 7,188
Research and development and energy efficiency | -199,080 | -235,389
Payable related to the concession | -84,955 | -82,483
Other accounts payable | -373,593 | -191,986
Provisions for legal claims | -262,492 | -271,351
CASH GENERATED BY OPERATING ACTIVITIES | 4,105.364 | 3,967.017
Income tax and social contribution paid | -249,631 | -257,299
Loans and financing - interest due and paid | -359,006 | -386,404
Debentures - interest due and paid | -963,399 | -658,810
Charges for lease liabilities paid | -24,081 | -23,957
Charges on loans granted/obtained from related parties |  | —
NET CASH GENERATED BY OPERATING ACTIVITIES FROM CONTINUING OPERATIONS | 2,509,247 | 2,640,547
NET CASH GENERATED BY OPERATING ACTIVITIES FROM DISCONTINUED OPERATIONS | — | 3,620
NET CASH GENERATED FROM OPERATING ACTIVITIES | 2,509,247 | 2,644,167
CASH FLOWS FROM INVESTMENT ACTIVITIES |  |
Financial investments | -88,352 | -39,727
Loans and financing granted to related parties | — | —
Receipt of loans and financing granted to related parties | — | —
Additions to contract assets | -2,210.701 | -1,652.051
Acquisitions of subsidiaries - effect on cash | -108,137 | -82,954
Acquisitions in investments | — | 10,357
Sale of investments | -26.319 | -9,923
Additions in investments | 294 | 37,129
Capital reduction of investees | — | —
Additions to property, plant and equipment | -190,433 | —
Sale of property, plant and equipment | -1,060.804 | —
Additions to intangible assets | 914,795 | 2,066
NET CASH USED BY INVESTMENT ACTIVITIES FROM CONTINUING OPERATIONS | -2,769.657 | -1,735.103
NET CASH USED BY INVESTMENT ACTIVITIES FROM DISCONTINUED OPERATIONS | — | 608.713
NET CASH USED FROM INVESTING ACTIVITIES | -2,769.657 | -1,126.390
CASH FLOWS FROM FINANCING ACTIVITIES |  |
Issue of loans and financing | — | 2,474
Issue of debentures | 5,000,000 | 2,320,000
Transaction costs in the issuing of debentures | -66,366 | -55,612
Payments of principal - loans and financing | -1,202,171 | -196,430
Payments of principal - debentures | -2,448,147 | -1,061,675
Amortization of principal of lease liabilities | -49,859 | -54,364
Buyback of own shares | -70,040 | —
Dividends and interest on own capital paid | -1,249,037 | -586,257
NET CASH GENERATED (USED) BY FINANCING ACTIVITIES FROM CONTINUING OPERATIONS | -85,620 | 368,136
NET CASH GENERATED (USED) BY FINANCING ACTIVITIES FROM DISCONTINUED OPERATIONS | — | -9,656
NET CASH GENERATED (USED) FROM FINANCING ACTIVITIES | -85.620 | 358.480
TOTAL EFFECTS ON CASH AND CASH EQUIVALENTS | -346,030 | 1,876,257
Cash and cash equivalents at the beginning of the period | 4,161,939 | 5,634,623
Cash and cash equivalents at the end of the period | 3,815,007 | 7,580,218
Change in cash and cash equivalents from discontinued operations | 902 | -69,338
CHANGE IN CASH AND CASH EQUIVALENTS | -346,030 | 1,876,257

24

| EXHIBIT I - CONSOLIDATED RESULTS > ADJUSTED EBITDA AND FINANCIAL RESULT

|  |  |  |  |  | R$'000
RECURRING EBITDA | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
EBITDA | 1,359 | 1,527 | -11.0 | 4,678 | 4,231 | 10.6
(-/+) Fair value in the purchase and sale of energy | 43 | -18 | -339.7 | -25 | 26 | -196.2
(-/+) Provision (reversal) Incentive Dismissal Program | — | 18 | -100.0 | 21 | 18 | 14.1
(-/+) Assets disposal /swap | -35 | -264 | -86.6 | -346 | -264 | 30.7
(-/+) Ebitda from discontinued Op. Compagas and UEGA | — | 20 | -100.0 | — | 59 | -100.0
(-/+) Equity Income | -37 | -63 | -41.0 | -202 | -225 | -10.4
(-/+)NRV | -37 | -17 | 114.5 | -73 | -50 | 46.9
(+/-)Difference in Revenue from Corporate/Regulatory Transfer (see item 3.1.1) | 45 | 38 | 20.4 | 122 | 58 | 111.6
RECURRING EBITDA | 1,337 | 1,240 | 7.8 | 4,176 | 3,852 | 8.4
|  |  |  |  |  | R$'000
| 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
Financial Revenues | 352,570 | 330,431 | 6.7 | 1,025,522 | 857,230 | 19.6
Income from investments held for trading | 176,485 | 205,967 | -14.3 | 520,551 | 537,453 | -3.1
Late fees on electricity bills | 83,284 | 85,594 | -2.7 | 246,843 | 188,771 | 30.8
Interest on taxes to be compensated | 37,409 | 40,253 | -7.1 | 120,716 | 58,695 | 105.7
Monetary restatement and adjustment to present value of accounts payable related to concession | 4,450 | 3 | 148,233.3 | 38,802 | 17,838 | 117.5
Income and monetary restatement of judicial deposits | 11,099 | 10,467 | 6.0 | 32,926 | 26,725 | 23.2
Income from sectorial assets and liabilities | 16,280 | 5,281 | 208.3 | 32,222 | 40,795 | -21.0
Adjust the fair value of debentures | 20,033 | — | — | 20,033 | — | —
(-) Pis/Pasep and Cofins on revenues | -14,714 | -13,772 | 6.8 | -43,507 | -34,963 | 24.4
Other financial revenues | 18,244 | -3,362 | -642.7 | 56,936 | 21,916 | 159.8
Financial Expenses | -795,131 | -553,570 | 43.6 | -2,316,469 | -1,637,466 | 41.5
Monetary variation, foreign exchange and debt service charges | -655,907 | -419,198 | 56.5 | -1,869,617 | -1,251,890 | 49.3
Monetary variation and adjustment to present value of accounts payable related to concession | -33,792 | -35,722 | -5.4 | -121,537 | -107,907 | 12.6
Income from sectorial assets and liabilities (NE nº 8) | — | — | — | -77,774 | -33,027 | 135.5
Monetary variation of litigation | -24,784 | -39,642 | -37.5 | -57,080 | -70,988 | -19.6
Uptade of provision for allocation of Pis and Cofins credits | -6,852 | -21,656 | -68.4 | -52,717 | -26,385 | 99.8
Swap effect on debentures | -36,812 | — | — | -36,812 | — | —
Interest on lease liabilities | -8,055 | -5,097 | 58.0 | -25,009 | -19,877 | 25.8
Interest on tax installments | -7,097 | -6,647 | 6.8 | -20,269 | -21,110 | -4.0
Interest on R&D and PEE | -6,600 | -5,608 | 17.7 | -18,209 | -16,723 | 8.9
Pis/ Pasep and Cofins taxes over interest on equity | -10,175 | — | — | -10,231 | -27,812 | -63.2
Other financial expenses | -5,057 | -20,000 | -74.7 | -27,214 | -61,747 | -55.9
Financial income (expenses) | -442,561 | -223,139 | 98.3 | -1,290,947 | -780,236 | 65.5

25

| EXHIBIT I - CONSOLIDATED RESULTS > EQUITY IN EARNINGS OF SUBSIDIARIES AND INDICATORS

|  |  |  |  |  | R$'000
Variation in Equity in earnings of subsidiaries | 3T25 | 3T24 | Δ% | 9M25 | 9M24 | Δ%
Joint Ventures | 30,157 | 57,344 | (47.4) | 183,786 | 211,365 | (13.0)
Voltalia São Miguel do Gostoso I Participações S.A. | (283) | 3,656 | (107.7) | (4,384) | (1,189) | 268.7
Caiuá Transmissora de Energia S.A. | 3,128 | 2,700 | 15.9 | 12,333 | 9,113 | 35.3
Integração Maranhense Transmissora de Energia S.A. | 4,903 | 4,600 | 6.6 | 16,422 | 14,364 | 14.3
Matrinchã Transmissora de Energia (TP NORTE) S.A. | 24,234 | 18,007 | 34.6 | 72,894 | 65,354 | 11.5
Guaraciaba Transmissora de Energia (TP SUL) S.A. | 9,455 | 12,664 | (25.3) | 31,753 | 35,199 | (9.8)
Paranaíba Transmissora de Energia S.A. | 7,645 | 6,096 | 25.4 | 24,751 | 21,490 | 15.2
Mata de Santa Genebra Transmissão S.A. | — | 2,387 | (100.0) | 23,057 | 36,764 | (37.3)
Cantareira Transmissora de Energia S.A. | (19,068) | 7,181 | (365.5) | 6,552 | 30,138 | (78.3)
Solar Paraná | 143 | 53 | 169.8 | 408 | 132 | 209.1
Associates | 7,172 | 5,866 | 22.3 | 18,215 | 14,033 | 29.8
Dona Francisca Energética S.A. | 1,865 | 1,480 | 26.0 | 5,035 | 4,002 | 25.8
Foz do Chopim Energética Ltda. | 5,307 | 4,386 | 21.0 | 13,180 | 10,033 | 31.4
Carbocampel S.A. | — | — | — | — | (2) | —
TOTAL | 37,329 | 63,210 | (40.9) | 202,001 | 225,398 | (10.4)

|  |  |  |  |  |  | R$'000
Main Indicators -Associates Sep-25 |  |  |  |  | Dona Francisca |  | Foz do Chopim
Total assets |  |  |  |  | 172,252 |  | 43,080
Shareholder’s equity¹ |  |  |  |  | 161,667 |  | 40,845
Net operating revenue |  |  |  |  | 49,952 |  | 50,555
Net Income |  |  |  |  | 21,866 |  | 36,845
Participation in the enterprise - % |  |  |  |  | 23.03 |  | 35.77
Investment book value |  |  |  |  | 37,232 |  | 14,610
|  |  |  |  |  |  | R$ mil
Main Indicators -Joint ventures Sep-25 | Voltalia | Caiuá | Integração Maranhense | Matrinchã | Guaraciaba | Paranaíba | Cantareira
Total assets | 228,486 | 351,435 | 631,606 | 3,350,123 | 1,713,159 | 2,023,603 | 1,821,827
Shareholder’s equity¹ | 228,246 | 259,145 | 417,415 | 2,366,505 | 1,151,609 | 1,173,194 | 804,184
Net operating revenue | — | 27,041 | 41,493 | 187,894 | 105,088 | 171,935 | 50,951
Net Income | (9,576) | 22,894 | 28,389 | 105,988 | 45,373 | 90,684 | 9,469
Participation in the enterprise - % | 49.0 | 49.0 | 49.0 | 49.0 | 49.0 | 24.5 | 49.0
Investment book value | 111,841 | 126,981 | 204,533 | 1,159,587 | 564,288 | 287,433 | 394,050
Note: Income from Transmitters according to adjustments for the application of CPC 47 / IFRS 15 in the Corporate Statements.

26

| EXHIBIT I - CONSOLIDATED RESULTS > SHARE CAPITAL

Share Capital - As of September 30, 2025
|  |  |  |  |  |  |  |  | mil ações
Shareholders | ON | % | PNA | % | PNB | % | Especial* | TOTAL | %
State of Paraná | 358,563 | 27.6 % | — | — | 116,081 | 6.9 % | <1 | 474,644 | 15.9 %
BNDESPAR | 131,162 | 10.1 % | — | — | 524,646 | 31.2 % | — | 655,808 | 22.0 %
Free Floating | 801,852 | 61.7 % | 1,075 | 34.4 % | 1,030,306 | 61.4 % | — | 1,833,233 | 61.5 %
B3 | 788,628 | 60.6 % | 1,075 | 34.4 % | 939,927 | 56.0 % | — | 1,729,630 | 58.0 %
NYSE | 13,016 | 1.0 % | — | — | 88,753 | 5.3 % | — | 101,769 | 3.4 %
LATIBEX | 208 | — % | — | — | 1,626 | 0.1 % | — | 1,834 | 0.1 %
Other | 2,946 | 0.2 % | 2,053 | 66 | 949 | 0.1 % | — | 5,948 | 0.2 %
Treasury shares | 5,825 | 0.4 % | — | — % | 7,353 | 0.4 % | — | 13,178 | 0.4 %
TOTAL | 1,300,348 | 100 % | 3,128 | 100 % | 1,679,335 | 100 % | <1 | 2,982,811 | 100 %
* State of Paraná has a special class preferred share with veto power as established in the Statute.

27

| EXHIBIT II- RESULT BY SUBSIDIARY > COPEL GET (CONSOLIDATED)

|  |  |  |  |  | R$ '000
Income Statement | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
OPERATING REVENUES | 1,252,299 | 1,096,920 | 14.2 | 3,653,229 | 3,311,337 | 10.3
Electricity sales to distributors | 878,430 | 866,090 | 1.4 | 2,678,548 | 2,528,738 | 5.9
Use of the main transmission grid | 316,159 | 204,312 | 54.7 | 781,932 | 708,172 | 10.4
Construction revenue | 54,530 | 19,013 | — | 165,671 | 48,887 | —
Other operating revenues | 3,180 | 7,505 | -57.6 | 27,078 | 25,540 | 6.0
OPERATING COSTS AND EXPENSES | -727,611 | -430,080 | 69.2 | -1,713,548 | -1,693,164 | 1.2
Electricity purchased for resale | -179,725 | -66,075 | — | -290,395 | -111,715 | —
Charges of main distribution and transmission grid | -125,444 | -143,403 | -12.5 | -386,559 | -438,291 | -11.8
Personnel and management | -65,370 | -87,689 | -25.5 | -222,269 | -278,444 | -20.2
Pension and healthcare plans | -16,887 | -19,172 | -11.9 | -52,369 | -60,603 | -13.6
Materials and supplies | -8,550 | -6,030 | 41.8 | -24,628 | -14,557 | 69.2
Materials and supplies for power eletricity | — | — | — | — | -936 | —
Third-party services | -58,239 | -68,491 | -15.0 | -191,576 | -202,014 | -5.2
Depreciation and amortization | -186,411 | -205,511 | -9.3 | -541,112 | -625,566 | -13.5
Provisions and reversals | -10,073 | -16,480 | -38.9 | -16,842 | -22,618 | -25.5
Construction cost | -52,084 | -16,390 | — | -156,947 | -41,944 | —
Other cost and expenses | -24,828 | 199,161 | — | 169,149 | 103,524 | 63.4
EQUITY IN EARNINGS OF SUBSIDIARIES | 35,603 | 58,021 | -38.6 | 200,940 | 222,454 | -9.7
PROFIT BEFORE FINANCIAL RESULTS AND TAXES | 560,291 | 724,861 | -22.7 | 2,140,621 | 1,840,627 | 16.3
FINANCIAL RESULTS | -269,049 | -133,918 | — | -762,640 | -447,250 | 70.5
Financial income | 109,843 | 106,711 | 2.9 | 335,363 | 275,770 | 21.6
Financial expenses | -378,892 | -240,629 | 57.5 | -1,098,003 | -723,020 | 51.9
OPERATIONAL EXPENSES/ INCOME | 291,242 | 590,943 | -50.7 | 1,377,981 | 1,393,377 | -1.1
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -60,816 | -186,599 | -67.4 | -365,997 | -317,381 | 15.3
Income tax and social contribution on profit | -69,124 | -60,379 | 14.5 | -199,814 | -174,792 | 14.3
Deferred income tax and social contribution on profit | 8,308 | -126,220 | — | -166,183 | -142,589 | 16.5
NET INCOME continuing operations | 230,426 | 404,344 | -43.0 | 1,011,984 | 1,075,996 | -5.9
NET INCOME discontinued operations | 18,898.00 | 12,004 | 57.4 | 18,898.00 | -18,377 | —
NET INCOME | 249,324 | 416,348 | -40.1 | 1,030,882 | 1,057,619 | -2.5
Attributed to shareholders of the parent company - continuing operations | 230,426 | 404,344 | -43.0 | 1,011,984 | 1,084,352 | -6.7
Attributed to the controlling company's shareholders - discontinued operations | 18,898 | 12,004 | 57.4 | 18,898 | -11,586 | —
Attributed to non-controlling shareholders | — | — | — | — | -15,147 | —
EBITDA continuing operations | 746,702 | 930,372 | -19.7 | 2,681,733 | 2,466,193 | 8.7

28

| EXHIBIT II- RESULT BY SUBSIDIARY > COPEL DIS

| R$ '000
Income Statement | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
OPERATING REVENUES | 5,125,167 | 4,352,365 | 17.8 | 13,986,100 | 12,556,067 | 11.4
Electricity sales to final customers | 1,463,734 | 1,482,084 | -1.2 | 4,770,004 | 4,835,789 | -1.4
Electricity sales to distributors | 183,393 | 62,717 | 192.4 | 284,740 | 83,935 | 239.2
Use of the main distribution grid | 1,556,804 | 1,568,245 | -0.7 | 4,782,283 | 4,774,303 | 0.2
Construction revenue | 898,292 | 642,002 | 39.9 | 2,269,611 | 1,860,097 | 22.0
Fair value of assets from the indemnity for the concession | 36,909 | 17,190 | 114.7 | 72,651 | 49,467 | 46.9
Sectorial assets and liabilities result | 845,436 | 420,709 | 101.0 | 1,408,163 | 566,185 | 148.7
Other operating revenues | 140,598 | 159,418 | -11.8 | 398,648 | 386,291 | 3.2
OPERATING COSTS AND EXPENSES | -4,616,770 | -3,893,834 | 18.6 | -12,532,390 | -11,163,695 | 12.3
Electricity purchased for resale | -2,344,772 | -1,910,333 | 22.7 | -6,170,339 | -5,222,496 | 18.1
Charges of main transmission grid | -678,247 | -676,178 | 0.3 | -2,024,457 | -2,113,943 | -4.2
Personnel and management | -115,838 | -166,337 | -30.4 | -399,998 | -514,552 | -22.3
Pension and healthcare plans | -38,056 | -41,217 | -7.7 | -115,521 | -129,216 | -10.6
Materials and supplies | -10,255 | -15,409 | -33.4 | -38,275 | -46,026 | -16.8
Third-party services | -216,410 | -187,818 | 15.2 | -617,866 | -519,102 | 19.0
Depreciation and amortization | -179,433 | -152,595 | 17.6 | -519,851 | -433,938 | 19.8
Provisions and reversals | -73,628 | -46,880 | 57.1 | -221,736 | -188,090 | 17.9
Construction cost | -898,292 | -642,002 | 39.9 | -2,269,611 | -1,860,097 | 22.0
Other cost and expenses | -61,840 | -55,064 | 12.3 | -154,736 | -136,235 | 13.6
PROFIT BEFORE FINANCIAL RESULTS AND TAXES | 508,397 | 458,531 | 10.9 | 1,453,710 | 1,392,372 | 4.4
FINANCIAL RESULTS | -179,976 | -103,031 | 74.7 | -569,070 | -381,617 | 49.1
Financial income | 194,454 | 162,905 | 19.4 | 519,387 | 367,811 | 41.2
Financial expenses | -374,430 | -265,936 | 40.8 | -1,088,457 | -749,428 | 45.2
OPERATIONAL EXPENSES/ INCOME | 328,421 | 355,500 | -7.6 | 884,640 | 1,010,755 | -12.5
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -103,077 | -111,695 | -7.7 | -273,909 | -317,165 | -13.6
Income tax and social contribution on profit | — | — | — | — | — | —
Deferred income tax and social contribution on profit | -103,077 | -111,695 | -7.7 | -273,909 | -317,165 | -13.6
NET INCOME (LOSS) | 225,344 | 243,805 | -7.6 | 610,731 | 693,590 | -11.9
EBITDA | 687,830 | 611,127 | 12.6 | 1,973,561 | 1,826,310 | 8.1

29

| EXHIBIT II- RESULT BY SUBSIDIARY > COPEL DIS

|  |  |  | R$'000
OPERATING REVENUE | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
Electricity sales to final customers | 1,922,785 | 1,816,194 | 5.9 | 5,642,216.0 | 5,831,298.0 | -3.2
Residential | 998,892 | 866,777 | 15.2 | 2,894,590.0 | 2,736,461.0 | 5.8
Industrial | 145,126 | 173,431 | -16.3 | 410,976.0 | 527,212.0 | -22.0
Commercial, service and other activities | 432,224 | 416,827 | 3.7 | 1,297,038.0 | 1,371,374.0 | -5.4
Rural | 194,216 | 183,580 | 5.8 | 601,792.0 | 615,340.0 | -2.2
Public Sector | 70,992 | 63,484 | 11.8 | 211,974.0 | 212,449.0 | -0.2
Street lightining | 57,045 | 50,113 | 13.8 | 148,366.0 | 141,632.0 | 4.8
Public Service | 24,290 | 61,982 | -60.8 | 77,480.0 | 226,830.0 | -65.8
Donations and subsidies | 383,554 | 283,646 | 35.2 | 1,123,505.0 | 826,980.0 | 35.9
Electricity sales to distributors | 190,495 | 65,329 | 191.6 | 295,980.0 | 88,072.0 | 236.1
Bilateral contracts | 2,665 | 4,068 | -34.5 | 7,796.0 | 16,471.0 | -52.7
Electricity Trading Chamber - CCEE | 187,830 | 61,261 | 206.6 | 288,184.0 | 71,601.0 | 302.5
Use of the main distribution grid | 3,205,443 | 2,920,059 | 9.8 | 9,426,178.0 | 8,874,798.0 | 6.2
Residential | 1,081,623 | 957,338 | 13.0 | 3,224,929.0 | 2,962,998.0 | 8.8
Industrial | 343,882 | 338,325 | 1.6 | 984,752.0 | 965,024.0 | 2.0
Commercial, service and other activities | 538,163 | 521,217 | 3.3 | 1,656,918.0 | 1,644,790.0 | 0.7
Rural | 214,916 | 208,072 | 3.3 | 683,492.0 | 679,621.0 | 0.6
Public Sector | 79,145 | 75,184 | 5.3 | 247,429.0 | 241,233.0 | 2.6
Street lightining | 54,012 | 52,129 | 3.6 | 153,884.0 | 152,137.0 | 1.1
Public Service | 35,356 | 57,505 | -38.5 | 107,352.0 | 194,389.0 | -44.8
Free Market | 819,984 | 666,994 | 22.9 | 2,246,691.0 | 1,912,089.0 | 17.5
Dealers and generators | 38,362 | 43,295 | -11.4 | 120,731.0 | 122,517.0 | -1.5
Construction Revenue | 898,292 | 642,002 | 39.9 | 2,269,611.0 | 1,860,097.0 | 22.0
Fair value of assets from the indemnity for the concession | 36,909 | 17,190 | 114.7 | 72,651.0 | 49,467.0 | 46.9
Sectorial assets and liabilities result | 931,610 | 463,591 | 101.0 | 1,551,695.0 | 623,895.0 | 148.7
Other operating income | 154,932 | 175,668 | -11.8 | 439,287.0 | 425,665.0 | 3.2
Leases and rentals | 143,565 | 162,847 | -11.8 | 416,627.0 | 404,046.0 | 3.1
Income from the provision of services | 1,723 | 1,942 | -11.3 | 3,355.0 | 3,696.0 | -9.2
Other income | 9,644 | 10,879 | -11.4 | 19,305.0 | 17,923.0 | 7.7
RECEITA OPERACIONAL BRUTA | 7,724,020 | 6,383,679 | 21.0 | 20,821,123.0 | 18,580,272.0 | 12.1
(-) Tributos e deduções | -2,598,851 | -2,031,314 | 27.9 | -6,835,022.0 | -6,024,205.0 | 13.5
(-) PIS/PASEP e COFINS | -540,173 | -453,255 | 19.2 | -1,460,826.0 | -1,315,394.0 | 11.1
(-) ICMS | -851,647 | -794,979 | 7.1 | -2,554,192.0 | -2,436,437.0 | 4.8
(-) Encargos Setoriais | -1,207,029 | -783,080 | 54.1 | -2,819,999.0 | -2,272,374.0 | 24.1
(-) ISS | -2 | — | — | -5.0 | — | —
NET OPERATING REVENUES | 5,125,169 | 4,352,365 | 17.8 | 13,986,101.0 | 12,556,067.0 | 11.4

30

| EXHIBIT II- RESULT BY SUBSIDIARY > COPEL COM (MERCADO LIVRE)

|  |  |  | R$ '000
Income Statement | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
OPERATING REVENUES | 1,122,386 | 901,385 | 24.5 | 3,209,841.0 | 2,590,380.0 | 23.9
Electricity sales to final customers | 414,694 | 488,576 | -15.1 | 1,212,945.0 | 1,420,544.0 | -14.6
Electricity sales to distributors | 750,140 | 410,894 | 82.6 | 1,969,890.0 | 1,167,170.0 | 68.8
Other operating revenues | -42,448 | 1,915 | — | 27,006.0 | 2,666.0 | 913.1
OPERATING COSTS AND EXPENSES | -1,172,599 | -880,878 | 33.1 | -3,153,561.0 | -2,549,093.0 | 23.7
Electricity purchased for resale | -1,162,277 | -871,755 | 33.3 | -3,125,498.0 | -2,523,054.0 | 23.9
Personnel and management | -5,504 | -3,591 | 53.3 | -14,340.0 | -11,152.0 | 28.6
Pension and healthcare plans | -429 | -429 | — | -1,302.0 | -1,321.0 | -1.4
Materials and supplies | -113 | -14 | 720.7 | -221.0 | -48.0 | 360.3
Third-party services | -724 | -1,847 | -60.8 | -2,730.0 | -4,253.0 | -35.8
Depreciation and amortization | -500 | -443 | 12.9 | -1,387.0 | -1,313.0 | 5.7
Provisions and reversals | -314 | -1,847 | -83.0 | -1,552.0 | -4,436.0 | -65.0
Other cost and expenses | -2,738 | -953 | 187.3 | -6,530.0 | -3,516.0 | 85.7
EQUITY IN EARNINGS OF SUBSIDIARIES | — | — | 0.0 | 0.0 | 0.0 | 0.0
PROFIT BEFORE FINANCIAL RESULTS AND TAXES | -50,213 | 20,508 | — | 56,280.0 | 41,287.0 | 36.3
FINANCIAL RESULTS | 9,190 | 10,626 | -13.5 | 28,800.0 | 29,924.0 | -3.8
Financial income | 9,322 | 10,731 | -13.1 | 29,213.0 | 30,166.0 | -3.2
Financial expenses | -132 | -105 | 25.8 | -414.0 | -242.0 | 71.0
OPERATIONAL EXPENSES/ INCOME | -41,023 | 31,134 | — | 85,080.0 | 71,211.0 | 19.5
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | 13,985 | -10,667 | — | -29,106.0 | -23,980.0 | 21.4
Income tax and social contribution on profit | -963 | -4,893 | -80.3 | -21,069.0 | -32,723.0 | -35.6
Deferred income tax and social contribution on profit | 14,948 | -5,774 | — | -8,036.0 | 8,743.0 | —
NET INCOME (LOSS) | -27,037 | 20,467 | — | 55,974.0 | 47,231.0 | 18.5
EBITDA | -49,713 | 20,951 | — | 54,893.0 | 42,600.0 | 28.9

31

| EXHIBIT II- RESULT BY SUBSIDIARY > INCOME STATEMENT FOR THE QUARTER BY COMPANY

|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Income Statement 3Q25 | GET | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Pequenos ativos mantidos para venda | MSG | C. Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Elimin. e Reclassif. | Consolidado
Geração | Transmissão
NET OPERATING INCOME | 590,479 | 273,419 | 5,125,167 | — | 34,901 | — | 2,411 | 155,644 | 149,661 | 8,185 | — | 83,684 | 23,152 | 1,122,386 | — | -757,912 | 6,811,177
Electricity sales to final customers | — | — | 1,463,734 | — | — | — | — | — | — | — | — | — | — | 414,694 | — | -170 | 1,878,258
Electricity sales to distributors | 580,339 | — | 183,393 | — | 34,814 | — | — | 155,644 | 149,661 | 8,185 | — | — | — | 750,140 | — | -620,620 | 1,241,556
Use of the main distribution and transmission grid (TUSD/ TUST) | — | 218,364 | 1,556,804 | — | — | — | — | — | — | — | — | 82,677 | 17,776 | — | — | -122,892 | 1,752,729
Construction revenue | — | 48,247 | 898,292 | — | — | — | — | — | — | — | — | 915 | 5,368 | — | — | — | 952,822
Fair value of assets from the indemnity for the concession | — | — | 36,909 | — | — | — | — | — | — | — | — | — | — | — | — | — | 36,909
Sectoral assets and liabilities result | — | — | 845,437 | — | — | — | — | — | — | — | — | — | — | — | — | — | 845,437
Other operating revenues | 10,140 | 6,808 | 140,598 | — | 87 | — | 2,411 | — | — | — | — | 92 | 8 | -42,448 | — | -14,230 | 103,466
OPERATING COSTS AND EXPENSES | -342,550 | -111,403 | -4,616,769 | — | -22,708 | — | -2,490 | -171,994 | -104,602 | -6,294 | — | -9,704 | -6,731 | -1,172,599 | -52,832 | 754,343 | -5,866,333
Energy purchased for resale | -122,727 | — | -2,344,772 | — | -27 | — | — | -41,511 | -28,990 | -1,238 | — | — | — | -1,162,276 | — | 618,102 | -3,083,439
Charges of the main distribution and transmission grid | -71,028 | — | -678,247 | — | -6,245 | — | — | -18,175 | -37,203 | -360 | — | — | — | — | — | 124,232 | -687,026
Personnel and management | -32,443 | -28,419 | -115,838 | — | -1,250 | — | -95 | -2,430 | -974 | -86 | — | -882 | -136 | -5,504 | -24,535 | — | -212,592
Private pension and health plans | -8,780 | -7,525 | -38,056 | — | -41 | — | -18 | -331 | -144 | -11 | — | -76 | -20 | -429 | -2,501 | — | -57,932
Materials and supplies | -1,256 | -1,218 | -10,254 | — | -83 | — | -9 | -5,466 | -523 | -45 | — | -14 | -33 | -113 | -109 | — | -19,122
Third-party services | -21,732 | -13,381 | -216,410 | — | -3,752 | — | -1,378 | -23,038 | -5,474 | -973 | — | -5,843 | -1,668 | -723 | -7,560 | 14,524 | -287,408
Depreciation and amortization | -83,232 | -4,820 | -179,433 | — | -8,157 | — | -968 | -69,573 | -19,307 | -2,850 | — | -77 | -10 | -500 | -1,055 | -6,542 | -376,524
Provisions and reversals | -5,102 | -4,208 | -73,628 | — | — | — | — | -116 | -23 | -571 | — | -163 | -3 | -315 | -4,231 | 2,795 | -85,565
Construction cost | — | -46,034 | -898,292 | — | — | — | — | — | — | — | — | -1,425 | -4,625 | — | — | — | -950,376
Other operating costs and expenses | 3,750 | -5,798 | -61,839 | — | -3,153 | — | -22 | -11,354 | -11,964 | -160 | — | -1,224 | -236 | -2,739 | -12,841 | 1,232 | -106,349
EQUITY IN EARNINGS OF SUBSIDIARIES | 889 | 84,928 | — | — | — | — | — | -20,435 | — | — | — | — | — | — | 428,744 | -456,797 | 37,329
EARNINGS BEFORE INCOME TAXES | 248,818 | 246,944 | 508,398 | — | 12,193 | — | -79 | -36,785 | 45,059 | 1,891 | — | 73,980 | 16,421 | -50,213 | 375,912 | -460,366 | 982,173
FINANCIAL RESULTS | -139,302 | -110,707 | -179,977 | — | -17,987 | — | -1,636 | 2,934 | 3,314 | 2,451 | 676 | -30,813 | 2,397 | 9,189 | 16,900 | — | -442,561
Financial income | 22,067 | 15,463 | 194,454 | — | 7,538 | — | 1,454 | 50,033 | 5,666 | 2,460 | — | 11,270 | 2,883 | 9,321 | 29,962 | -1 | 352,570
Financial expenses | -161,369 | -126,170 | -374,431 | — | -25,525 | — | -3,090 | -47,099 | -2,352 | -9 | 676 | -42,083 | -486 | -132 | -13,062 | 1 | -795,131
OPERATIONAL EXPENSES / INCOME | 109,516 | 136,237 | 328,421 | — | -5,794 | — | -1,715 | -33,851 | 48,373 | 4,342 | 676 | 43,167 | 18,818 | -41,024 | 392,812 | -460,366 | 539,612
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -593 | -14,732 | -103,077 | — | 1,962 | — | — | -22,253 | -16,269 | -1,093 | — | -14,712 | 6,708 | 13,986 | -27,488 | 2,124 | -175,437
NET INCOME FROM CONTINUING OPERATIONS | 108,923 | 121,505 | 225,344 | — | -3,832 | — | -1,715 | -56,104 | 32,104 | 3,249 | 676 | 28,455 | 25,526 | -27,038 | 365,324 | -458,242 | 364,175
NET INCOME FROM DISCONTINUED OPERATIONS | 18,898 | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | 18,898
NET INCOME | 127,821 | 121,505 | 225,344 | — | -3,832 | — | -1,715 | -56,104 | 32,104 | 3,249 | 676 | 28,455 | 25,526 | -27,038 | 365,324 | -458,242 | 383,073
Attributed to shareholders of the parent company - continuing operations | 109,477 | 120,951 | 225,344 | — | -2,683 | — | -1,716 | -56,092 | 32,103 | 3,248 | 670 | 28,454 | 25,526 | -27,036 | 384,220 | -477,137 | 365,329
Attributed to shareholders of the parent company - discontinued operations | 18,898 | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | 18,898
Attributed to non-controlling shareholders - continuing operations | — | — | — | — | 1,428 | — | — | — | — | — | — | — | — | — | — | — | 1,428
Attributed to non-controlling shareholders - discontinued operations | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
EBITDA continuing operations | 332,050 | 251,764 | 687,831 | — | 20,350 | — | 889 | 32,788 | 64,366 | 4,741 | — | 74,057 | 16,431 | -49,713 | 376,967 | -453,824 | 1,358,697

32

Income Statement 3Q24 | GET | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Pequenos ativos mantidos pra venda | MSG | C. Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Elimin. e Reclassif. | Consolidado |  |
Geração | Transmissão |  |
NET OPERATING INCOME | 528,893 | 211,441 | 4,352,365 | 155,965 | 19,880 | — | 2,920 | 182,149 | 156,887 | 9,425 | — | — | 21,098 | 901,383 | — | -806,798 | 5,735,608 |  |
Electricity sales to final customers | — | — | 1,482,084 | — | — | — | — | — | — | — |  |  | — | 488,575 | — | -325 | 1,970,334 |  |
Electricity sales to distributors | 517,630 | — | 62,717 | — | 19,760 | — | — | 182,150 | 156,884 | 9,425 |  |  | — | 410,894 | — | -524,803 | 834,657 |  |
Use of the main distribution and transmission grid (TUSD/ TUST) | — | 187,755 | 1,568,245 | — | — | — | — | — | — | — |  |  | 18,665 | — | — | -114,573 | 1,660,092 |  |
Construction revenue | — | 16,588 | 642,002 | 3,287 | — | — | — | — | — | — |  |  | 2,426 | — | — | -3,287 | 661,016 |  |
Fair value of assets from the indemnity for the concession | — | — | 17,190 | — | — | — | — | — | — | — |  |  | — | — | — | — | 17,190 |  |
Distribution of piped gas | — | — | — | 152,678 | — | — | — | — | — | — |  |  | — | — | — | -152,678 | — |  |
Sectoral assets and liabilities result | — | — | 420,709 | — | — | — | — | — | — | — |  |  | — | — | — | — | 420,709 |  |
Other operating revenues | 11,263 | 7,098 | 159,418 | — | 120 | — | 2,920 | -1 | 3 | — |  |  | 7 | 1,914 | — | -11,132 | 171,610 |  |
OPERATING COSTS AND EXPENSES | -187,540 | -6,451 | -3,893,834 | -140,556 | -26,214 | — | -2,072 | -160,633 | -71,122 | -5,796 | — | — | -4,457 | -880,878 | -62,277 | 801,310 | -4,640,519 |  |
Energy purchased for resale | -37,649 | — | -1,910,333 | — | -2,871 | — | — | -19,446 | -7,404 | -1,572 | — | — | — | -871,755 | — | 523,048 | -2,327,982 |  |
Charges of the main distribution and transmission grid | -89,832 | — | -676,178 | — | -6,104 | — | — | -17,327 | -38,231 | -345 | — | — | — | — | — | 113,953 | -714,064 |  |
Personnel and management | -47,883 | -35,249 | -166,338 | -7,703 | -1,547 | — | -39 | -3,726 | -525 | -140 | — | — | -166 | -3,591 | -19,724 | 7,702 | -278,929 |  |
Private pension and health plans | -10,666 | -7,796 | -41,217 | -1,003 | -40 | — | -6 | -581 | -82 | -22 | — | — | -26 | -429 | -2,426 | 1,003 | -63,291 |  |
Materials | -2,931 | -1,969 | -15,409 | -449 | -138 | — | — | -724 | -346 | -21 | — | — | -31 | -14 | -502 | 441 | -22,093 |  |
Raw material and supplies - energy production | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — |  |
Natural gas and supplies for gas business | — | — | — | -113,280 | — | — | — | — | — | — | — | — | — | — | — | 113,280 | — |  |
Third-party services | -24,009 | -12,365 | -187,818 | -1,166 | -4,684 | — | -972 | -31,746 | -9,371 | -688 | — | — | -1,182 | -1,847 | -11,753 | 12,988 | -274,613 |  |
Depreciation and amortization | -89,870 | -4,403 | -152,595 | -4,752 | -7,972 | — | -1,053 | -69,143 | -31,885 | -2,847 | — | — | -11 | -443 | -843 | -2,597 | -368,414 |  |
Provisions and reversals | -10,873 | -5,082 | -46,881 | -5,019 | — | — | — | -285 | — | — | — | — | -356 | -1,847 | -20,182 | 22,145 | -68,379 |  |
Construction cost | — | -13,987 | -642,002 | -3,287 | — | — | — | — | — | — | — | — | -2,403 | — | — | 3,287 | -658,392 |  |
Other operating costs and expenses | 126,173 | 74,400 | -55,063 | -3,897 | -2,858 | — | -2 | -17,655 | 16,722 | -161 | — | — | -282 | -952 | -6,847 | 6,060 | 135,638 |  |
EQUITY IN EARNINGS OF SUBSIDIARIES | 53,839 | 70,463 | — | — | — | — | — | 5,422 | — | — | — | — | — | — | 673,175 | -739,689 | 63,210 |  |
EARNINGS BEFORE INCOME TAXES | 395,192 | 275,453 | 458,531 | 15,409 | -6,334 | — | 848 | 26,938 | 85,765 | 3,629 | — | — | 16,641 | 20,505 | 610,898 | -745,177 | 1,158,299 |  |
FINANCIAL RESULTS | -76,970 | -50,400 | -103,031 | -5,518 | -29,724 | — | -1,043 | -14,328 | 5,391 | 1,151 | — | — | 1,238 | 10,626 | 34,711 | 5,519 | -222,378 |  |
Financial income | 35,847 | 21,724 | 162,905 | 4,279 | 4,628 | — | 1,230 | 40,722 | 5,526 | 1,151 | — | — | 1,741 | 10,731 | 47,308 | -6,600 | 331,192 |  |
Financial expenses | -112,817 | -72,124 | -265,936 | -9,797 | -34,352 | — | -2,273 | -55,050 | -135 | — | — | — | -503 | -105 | -12,597 | 12,119 | -553,570 |  |
OPERATIONAL EXPENSES / INCOME | 318,222 | 225,053 | 355,500 | 9,891 | -36,058 | — | -195 | 12,610 | 91,156 | 4,780 | — | — | 17,879 | 31,131 | 645,609 | -739,658 | 935,921 |  |
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -83,874 | -55,059 | -111,695 | -3,698 | 12,252 | — | -780 | -17,222 | -30,987 | -686 | — | — | -1,169 | -10,667 | 98,947 | 6,097 | -198,541 |  |
NET INCOME continuing operations | 234,348 | 169,994 | 243,805 | 6,193 | -23,806 | — | -975 | -4,612 | 60,169 | 4,094 | — | — | 16,710 | 20,464 | 744,556 | -733,561 | 737,380 |  |
NET INCOME discontinued operations | 12,004 | — | — | — | — | — | — | — | — | — | — | — | — | — | 475,104 | -7,399 | 479,709 |  |
NET INCOME | 246,352 | 169,994 | 243,805 | 6,193 | -23,806 | — | -975 | -4,612 | 60,169 | 4,094 | — | — | 16,710 | 20,464 | 1,219,660 | -740,960 | 1,217,089 |  |
Attributed to shareholders of the parent company - continuing operations | 234,348 | 169,994 | 243,805 | — | -16,902 | — | -975 | -4,612 | 60,169 | 4,094 | — | — | 16,710 | 20,464 | 1,340,046 | -918,243 | 744,556 |  |
Attributed to the controlling company's shareholders - discontinued operations | 12,004 | — | — | 3,158 | — | — | — | — | — | — | — | — | — | — | -120,386 | 592,332 | 475,104 |  |
Attributed to non-controlling shareholders - continuing operations | — | — | — | — | -6,904 | — | — | — | — | — | — | — | — | — | — | -238 | -7,142 |  |
Attributed to non-controlling shareholders - discontinued operations | — | — | — | 3,035 | — | — | — | — | — | — | — | — | — | — | — | 1,536 | 4,571 |  |
EBITDA continuing operations | 485,062 | 279,856 | 611,126 | 20,161 | 1,638 | — | 1,901 | 96,081 | 117,650 | 6,476 | — | — | 16,652 | 20,948 | 611,741 | -742,580 | 1,526,713 |  |

33

| ANEXO II - RESULTADO POR SUBSIDIÁRIA > DRE POR EMPRESA ACUMULADO

|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Income Statement 9M25 | GET | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Small Assets | MSG | C. Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Elimin. e Reclassif. | Consolidated
Geração | Transmissão
NET OPERATING INCOME | 1,679,414 | 790,448 | 13,986,101 | — | 113,051 | — | 8,542 | 573,088 | 447,026 | 27,996 | 27,740 | 114,752 | 70,764 | 3,209,841 | — | -2,120,346 | 18,928,417
Electricity sales to final customers | — | — | 4,770,004 | — | — | — | — | — | — | — | — | — | — | 1,212,945 | — | -576 | 5,982,373
Electricity sales to distributors | 1,644,065 | — | 284,740 | — | 112,846 | — | — | 564,749 | 447,026 | 27,996 | 27,740 | — | — | 1,969,890 | — | -1,721,823 | 3,357,229
Use of the main distribution and transmission grid (TUSD/ TUST) | — | 620,982 | 4,782,283 | — | — | — | — | — | — | — | — | 113,575 | 54,521 | — | — | -358,953 | 5,212,408
Construction revenue | — | 148,395 | 2,269,611 | — | — | — | — | — | — | — | — | 1,055 | 16,221 | — | — | — | 2,435,282
Fair value of assets from the indemnity for the concession | — | — | 72,651 | — | — | — | — | — | — | — | — | — | — | — | — | — | 72,651
Sectoral assets and liabilities result | — | — | 1,408,164 | — | — | — | — | — | — | — | — | — | — | — | — | — | 1,408,164
Other operating revenues | 35,349 | 21,071 | 398,648 | — | 205 | — | 8,542 | 8,339 | — | — | — | 122 | 22 | 27,006 | — | -38,994 | 460,310
OPERATING COSTS AND EXPENSES | -521,745 | -470,763 | -12,532,390 | — | -70,449 | — | -7,474 | -454,409 | -272,652 | -15,978 | -7,461 | -14,130 | -19,958 | -3,153,561 | -111,405 | 2,107,209 | -15,545,166
Energy purchased for resale | -213,165 | — | -6,170,339 | — | -91 | — | — | -60,717 | -46,253 | -2,098 | -515 | — | — | -3,125,498 | — | 1,719,475 | -7,899,201
Charges of the main distribution and transmission grid | -225,800 | — | -2,024,457 | — | -18,544 | — | — | -52,760 | -112,814 | -1,056 | -2,186 | — | — | — | — | 357,491 | -2,080,126
Personnel and management | -117,326 | -92,035 | -399,998 | — | -4,013 | — | -316 | -8,070 | -2,474 | -292 | — | -1,650 | -422 | -14,340 | -63,230 | — | -704,166
Private pension and health plans | -28,125 | -22,444 | -115,521 | — | -119 | — | -60 | -1,167 | -366 | -42 | — | -161 | -64 | -1,302 | -7,513 | — | -176,884
Materials and supplies | -6,450 | -4,529 | -38,275 | — | -347 | — | -8 | -12,203 | -1,398 | -55 | — | 43 | -37 | -222 | -556 | — | -64,037
Materials and supplies for power eletricity | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Third-party services | -65,579 | -38,876 | -617,866 | — | -12,812 | — | -3,857 | -89,847 | -19,726 | -2,860 | -1 | -7,956 | -4,555 | -2,730 | -21,774 | 40,021 | -848,418
Depreciation and amortization | -231,156 | -13,535 | -519,851 | — | -24,442 | — | -2,919 | -208,600 | -57,902 | -8,551 | -4,513 | -103 | -24 | -1,387 | -3,044 | -16,728 | -1,092,755
Provisions and reversals | -6,627 | -9,869 | -221,736 | — | — | — | -250 | -1,297 | -23 | -572 | 100 | -255 | -36 | -1,552 | -943 | 3,050 | -240,010
Construction cost | — | -140,466 | -2,269,611 | — | — | — | — | — | — | — | — | -2,342 | -14,139 | — | — | — | -2,426,558
Other operating costs and expenses | 372,483 | -149,009 | -154,736 | — | -10,081 | — | -64 | -19,748 | -31,696 | -452 | -346 | -1,706 | -681 | -6,530 | -14,345 | 3,900 | -13,011
EQUITY IN EARNINGS OF SUBSIDIARIES | 157,992 | 281,295 | — | — | — | — | — | 12,975 | — | — | — | — | — | — | 1,676,396 | -1,926,657 | 202,001
EARNINGS BEFORE INCOME TAXES | 1,315,661 | 600,980 | 1,453,711 | — | 42,602 | — | 1,068 | 131,654 | 174,374 | 12,018 | 20,279 | 100,622 | 50,806 | 56,280 | 1,564,991 | -1,939,794 | 3,585,252
FINANCIAL RESULTS | -393,633 | -289,627 | -569,071 | — | -45,360 | — | -4,253 | -58,611 | 6,926 | 6,245 | 115 | -40,979 | 6,923 | 28,799 | 61,579 | — | -1,290,947
Financial income | 94,105 | 65,383 | 519,387 | — | 48,953 | — | 4,090 | 132,780 | 14,665 | 6,254 | — | 13,764 | 8,411 | 29,213 | 88,522 | -5 | 1,025,522
Financial expenses | -487,738 | -355,010 | -1,088,458 | — | -94,313 | — | -8,343 | -191,391 | -7,739 | -9 | 115 | -54,743 | -1,488 | -414 | -26,943 | 5 | -2,316,469
OPERATIONAL EXPENSES / INCOME | 922,028 | 311,353 | 884,640 | — | -2,758 | — | -3,185 | 73,043 | 181,300 | 18,263 | 20,394 | 59,643 | 57,729 | 85,079 | 1,626,570 | -1,939,794 | 2,294,305
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -213,016 | -8,380 | -273,909 | — | 881 | — | -168 | -60,717 | -60,856 | -3,004 | -824 | -20,276 | -5,376 | -29,105 | -23,598 | 6,449 | -691,899
NET INCOME | 709,012 | 302,973 | 610,731 | — | -1,877 | — | -3,353 | 12,326 | 120,444 | 15,259 | 19,570 | 39,367 | 52,353 | 55,974 | 1,602,972 | -1,933,345 | 1,602,406
Attributed to shareholders of the parent company - continuing operations | 690,114 | 302,973 | 610,731 | — | -1,314 | — | -3,353 | 12,326 | 120,444 | 15,259 | 19,570 | 39,367 | 52,353 | 55,974 | 1,584,074 | -1,914,447 | 1,584,071
Attributed to shareholders of the parent company - descontinued operations | 18,898 | — | — | — | — | — | — | — | — | — | — | — | — | — | 18,898 | -18,898 | 18,898
Attributed to non-controlling shareholders - continuing operations | — | — | — | — | -563 |  | — | — | — | — | — | — | — | — | — | — | -563
EBITDA continuing operations | 1,546,817 | 614,515 | 1,973,562 | — | 67,044 | — | 3,987 | 340,254 | 232,276 | 20,569 | 24,792 | 100,725 | 50,830 | 57,667 | 1,568,035 | -1,923,066 | 4,678,007

34

Income Statement 9M24 | GET | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | C. Oeste, Marumbi, Uirapuru | Small Assets | MSG | Mercado Livre | Holding | Elimination | Consolidated
Geração | Transmissão
NET OPERATING INCOME | 1,588,303 | 724,766 | 12,556,067 | 562,129 | 67,212 | — | 3,093 | 542,593 | 416,916 | 26,594 | — | — | 59,742 | 2,590,380 | — | -2,505,923 | 16,631,872
Electricity sales to final customers | — | — | 4,835,789 | — | — | — | — | — | — | — | — | — | — | 1,420,544 | — | -1,065 | 6,255,268
Electricity sales to distributors | 1,547,071 | — | 83,935 | — | 66,834 | — | — | 538,443 | 416,908 | 26,594 | — | — | — | 1,167,170 | — | -1,545,462 | 2,301,493
Use of the main distribution and transmission grid (TUSD/ TUST) | — | 656,585 | 4,774,303 | — | — | — | — | — | — | — | — | — | 58,828 | — | — | -356,412 | 5,133,304
Construction revenue | — | 47,995 | 1,860,097 | 13,618 | — | — | — | — | — | — | — | — | 893 | — | — | -13,618 | 1,908,985
Fair value of assets from the indemnity for the concession | — | — | 49,467 | — | — | — | — | — | — | — | — | — | — | — | — | — | 49,467
Distribution of piped gas | — | — | — | 548,511 | — | — | — | — | — | — | — | — | — | — | — | -548,511 | —
Sectoral assets and liabilities result | — | — | 566,185 | — | — | — | — | — | — | — | — | — | — | — | — | — | 566,185
Other operating revenues | 41,232 | 20,186 | 386,291 | — | 378 | — | 3,093 | 4,150 | 8 | — | — | — | 21 | 2,666 | — | -40,855 | 417,170
OPERATING COSTS AND EXPENSES | -806,253 | -173,188 | -11,163,695 | -503,516 | -71,378 | -44,679 | -4,340 | -455,323 | -260,488 | -14,964 | — | — | -7,342 | -2,549,093 | -166,560 | 2,505,166 | -13,715,653
Energy purchased for resale | -53,356 | — | -5,222,496 | — | -2,928 | — | — | -47,088 | -9,559 | -1,991 | — | — | — | -2,523,054 | — | 1,546,089 | -6,314,383
Charges of the main distribution and transmission grid | -275,413 | — | -2,113,943 | — | -18,726 | -18,392 | — | -49,679 | -119,233 | -1,033 | — | — | — | — | — | 373,997 | -2,222,422
Personnel and management | -152,031 | -112,000 | -514,553 | -33,621 | -4,255 | -3,124 | -128 | -11,765 | -1,661 | -447 | — | — | -540 | -11,152 | -49,092 | 36,744 | -857,625
Private pension and health plans | -33,753 | -24,664 | -129,216 | -4,083 | -124 | -364 | -21 | -1,783 | -253 | -68 | — | — | -83 | -1,321 | -7,702 | 4,447 | -198,988
Materials | -6,794 | -3,818 | -46,026 | -416 | -239 | -18 | -16 | -2,596 | -1,182 | -87 | — | — | -72 | -48 | -1,350 | 426 | -62,236
Raw material and supplies - energy production | -936 | — | — | — | — | -944 | — | — | — | — | — | — | — | — | — | 944 | -936
Natural gas and supplies for gas business | — | — | — | -397,554 | — | — | — | — | — | — | — | — | — | — | — | 397,554 | —
Third-party services | -67,174 | -37,982 | -519,102 | -10,650 | -12,598 | -9,842 | -2,533 | -96,707 | -27,186 | -2,263 | — | — | -4,588 | -4,253 | -35,198 | 57,397 | -772,679
Depreciation and amortization | -280,055 | -12,450 | -433,938 | -27,146 | -24,232 | -10,316 | -1,729 | -206,666 | -95,773 | -8,540 | — | — | -33 | -1,313 | -2,420 | 15,414 | -1,089,197
Provisions and reversals | -16,938 | -10,202 | -188,091 | -7,541 | — | -176 | — | -445 | -7 | -38 | — | — | -293 | -4,436 | -49,357 | 49,569 | -227,955
Construction cost | — | -41,077 | -1,860,097 | -13,618 | — | — | — | — | — | — | — | — | -867 | — | — | 13,618 | -1,902,041
Other operating costs and expenses | 80,197 | 69,005 | -136,233 | -8,887 | -8,276 | -1,503 | 87 | -38,594 | -5,634 | -497 | — | — | -866 | -3,516 | -21,441 | 8,967 | -67,191
EQUITY IN EARNINGS OF SUBSIDIARIES | 83,246 | 269,437 | — | — | — | — | — | -10,003 | — | — | — | — | — | — | 1,825,750 | -1,943,032 | 225,398
EARNINGS BEFORE INCOME TAXES | 865,296 | 821,015 | 1,392,372 | 58,613 | -4,166 | -44,679 | -1,247 | 77,267 | 156,428 | 11,630 | — | — | 52,400 | 41,287 | 1,659,190 | -1,943,789 | 3,141,617
FINANCIAL RESULTS | -231,737 | -161,521 | -381,617 | -10,607 | -73,886 | -4,372 | -487 | -82,874 | 22,036 | 3,156 | — | — | 5,061 | 29,924 | 95,876 | 10,811 | -780,237
Financial income | 88,115 | 54,876 | 367,811 | 29,114 | 29,394 | 1,068 | 2,063 | 101,948 | 22,474 | 3,111 | — | — | 6,617 | 30,166 | 157,457 | -36,985 | 857,229
Financial expenses | -319,852 | -216,397 | -749,428 | -39,721 | -103,280 | -5,440 | -2,550 | -184,822 | -438 | 45 | — | — | -1,556 | -242 | -61,581 | 47,796 | -1,637,466
OPERATIONAL EXPENSES / INCOME | 633,559 | 659,494 | 1,010,755 | 48,006 | -78,052 | -49,051 | -1,734 | -5,607 | 178,464 | 14,786 | — | — | 57,461 | 71,211 | 1,755,066 | -1,932,978 | 2,361,380
INCOME TAX AND SOCIAL CONTRIBUTION ON PROFIT | -122,134 | -86,568 | -317,165 | -17,301 | 26,532 | — | -1,117 | -47,565 | -60,653 | -1,890 | — | — | -4,079 | -23,980 | 4,369 | 22,806 | -628,745
NET INCOME continuing operations | 511,425 | 572,926 | 693,590 | 30,705 | -51,520 | -49,051 | -2,851 | -53,172 | 117,811 | 12,896 | — | — | 53,382 | 47,231 | 1,759,435 | -1,910,172 | 1,732,635
NET INCOME discontinued operations | -11,586 | — | — | — | — | — | — | — | — | — | — | — | — | — | 463,690 | 39,467 | 491,571
NET INCOME | 499,839 | 572,926 | 693,590 | 30,705 | -51,520 | -49,051 | -2,851 | -53,172 | 117,811 | 12,896 | — | — | 53,382 | 47,231 | 2,223,125 | -1,870,705 | 2,224,206
Attributed to shareholders of the parent company - continuing operations | 511,425 | 572,926 | 693,590 | — | -36,579 | — | -2,851 | -53,172 | 117,811 | 12,896 | — | — | 53,382 | 47,231 | 1,747,850 | -1,905,074 | 1,759,435
Attributed to the controlling company's shareholders - discontinued operations | -11,586 | — | — | 15,660 | — | -39,829 | — | — | — | — | — | — | — | — | 475,275 | 24,171 | 463,690
Attributed to non-controlling shareholders - continuing operations | — | — | — | — | -14,941 | — | — | — | — | — | — | — | — | — | — | -517 | -15,458
Attributed to non-controlling shareholders - discontinued operations | — | — | — | 15,045 | — | -9,222 | — | — | — | — | — | — | — | — | — | 10,715 | 16,539
EBITDA continuing operations | 1,145,351 | 833,465 | 1,826,310 | 85,759 | 20,066 | -34,363 | 482 | 283,933 | 252,201 | 20,170 | — | — | 52,433 | 42,600 | 1,661,610 | -1,959,203 | 4,230,814

35

| EXHIBIT II- RESULT BY SUBSIDIARY > ASSETS BY COMPANY

|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Assets - Sep-2025 | Geração e Transmissão | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Small Assets | MSG | Costa Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Elimin. e Reclassif. | Consolidado
CURRENT | 3,155 | 6,537 | — | 122 | — | 125 | 1,183 | 154 | 71 | — | 331 | 90 | 898 | 2,699 | -2,226 | 13,140
Cash and cash equivalents | 343 | 1,514 | — | 90 | — | 36 | 1,013 | 75 | 66 | — | 61 | 59 | 183 | 376 | — | 3,815
Bonds and securities | — | — | — | 1 | — | 1 | — | — | — | — | 154 | — | — | — | — | 156
Collaterals and escrow accounts | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Customers | 378 | 3,473 | — | 14 | — | 1 | 97 | 64 | 4 | — | 40 | 9 | 434 | — | -233 | 4,280
Dividends receivable | 132 | — | — | — | — | — | 33 | — | — | — | — | — | — | 1,870 | -1,954 | 81
Sectorial financial assets | — | 101,272 | — | — | — | — | — | — | — | — | — | — | — | — | — | 101,272
Account receivable related to concession | 12 | — | — | — | — | — | — | — | — | — | — | — | — | — | — | 12
Contract Assets | 314 | — | — | — | — | — | — | — | — | — | 73 | 19 | — | — | — | 406
Fair value in the purchase and sale of energy | — | — | — | — | — | — | — | — | — | — | — | — | 257 | — | — | 257
Other current receivables | 143 | 566 | — | 3 | — | — | 3 | 13 | — | — | 1 | 1 | 1 | 333 | -6 | 1,058
Inventories | 34 | 129 | — | 2 | — | — | — | — | — | — | — | — | — | — | — | 165
Income tax and social contribution | 47 | 144 | — | 8 | — | 2 | 33 | — | 1 | — | 1 | 2 | 22 | 102 | — | 362
Other current recoverable taxes | 12 | 563 | — | — | — | — | — | 1 | — | — | — | — | — | — | — | 576
Prepaid expenses | 8 | 41 | — | 4 | — | — | 2 | 1 | — | — | — | — | — | 1 | — | 58
Related parties | 13 | 7 | — | — | — | — | 3 | — | — | — | — | — | — | 10 | -33 | —
Assets held for sale | 1,718 | — | — | — | — | 86 | — | — | — | — | — | — | — | 7 | — | 1,812
NON-CURRENT | 24,168 | 18,508 | — | 603 | — | 23 | 7,494 | 2,226 | 176 | — | 3,199 | 523 | 601 | 23,608 | -32,221 | 48,908
Long Term Assets | 6,575 | 7,628 | — | 133 | — | 20 | 659 | 55 | — | — | 3,198 | 523 | 591 | 312 | -346 | 19,347
Bonds and securities | 185 | 3 | — | — | — | — | 365 | 19 | — | — | 112 | 4 | — | — | — | 689
Other temporary investments | — | — | — | — | — | 20 | — | — | — | — | — | — | — | 11 | — | 31
Customers | — | 143 | — | — | — | — | — | — | — | — | — | — | — | — | — | 143
Judicial deposits | 47 | 182 | — | — | — | — | 5 | — | — | — | — | — | 17 | 122 | — | 374
Sectoral financial assets | — | 304 | — | — | — | — | — | — | — | — | — | — | — | — | — | 304
Account receivable related to concession | 911 | 3,141 | — | — | — | — | — | — | — | — | — | — | — | — | — | 4,051
Contract Assets | 4,712 | 2,037 | — | — | — | — | — | — | — | — | 3,079 | 519 | — | — | -51 | 10,296
Fair value in the purchase and sale of energy | — | — | — | — | — | — | — | — | — | — | — | — | 561 | — | — | 561
Other non-current receivables | 623 | 82 | — | 7 | — | — | — | 34 | — | — | — | — | — | — | — | 745
Income tax and social contribution | 2 | 64 | — | — | — | — | — | — | — | — | 6 | — | 12 | 19 | — | 103
Deferred income tax and social contribution | — | 644 | — | 120 | — | — | — | — | — | — | — | — | — | 116 | — | 881
Other non-current recoverable taxes | 94 | 1,029 | — | — | — | — | — | 1 | — | — | — | — | — | 43 | — | 1,167
Prepaid expenses | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Related parties | — | — | — | 6 | — | — | 288 | — | — | — | — | — | — | — | -294 | —
Investments | 10,487 | — | — | — | — | — | 2,463 | — | — | — | — | — | — | 23,272 | -33,297 | 2,926
Property, plant and equipment, net | 3,129 | — | — | 305 | — | 1 | 4,315 | 299 | 172 | — | — | 1 | 1 | 6 | — | 8,229
Intangible assets | 3,900 | 10,738 | — | 165 | — | 2 | 12 | 1,872 | 4 | — | — | — | 5 | 10 | 1,421 | 18,128
Right to use an asset | 78 | 141 | — | — | — | — | 45 | — | — | — | 1 | — | 4 | 8 | — | 278
TOTAL | 27,323 | 25,044 | — | 725 | — | 148 | 8,678 | 2,380 | 247 | — | 3,530 | 613 | 1,499 | 26,307 | -34,448 | 62,048

36

| EXHIBIT II- RESULT BY SUBSIDIARY > ASSETS BY COMPANY

|  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Assets - Sep-2024 | Geração e Transmissão | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Costa Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Elimin. e Reclassif. | Consolidado
CURRENT | 3,478,566 | 6,769,769 | — | 124,996 | — | 48,889 | 1,119,406 | 146,365 | 60,415 | 106,590 | 916,049 | 3,264,843 | -2,994,084 | 13,041,808
Cash and cash equivalents | 511,790 | 1,734,522 | — | 97,082 | — | 42,389 | 976,988 | 61,545 | 55,027 | 77,510 | 324,750 | 280,340 | -13 | 4,161,939
Bonds and securities | — | — | — | — | — | 528 | — | — | — | — | — | 95 | — | 624
Collaterals and escrow accounts | — | 9 | — | — | — | — | — | — | — | — | — | — | — | 9
Customers | 379,135 | 3,267,284 | — | 10,752 | — | 3,795 | 94,192 | 76,636 | 4,118 | 8,750 | 348,795 | — | -230,755 | 3,962,702
Dividends receivable | 153,322 | — | — | — | — | — | 8,393 | — | — | — | — | 2,644,431 | -2,723,868 | 82,278
Sectorial financial assets | — | — | — | — | — | — | — | — | — | — | — | — | — | 10,609
Account receivable related to concession | 10,609 | — | — | — | — | — | — | — | — | 18,050 | — | — | — | 283,896
Contract Assets | 265,846 | — | — | — | — | — | — | — | — | — | 217,350 | — | — | 217,350
Other current receivables | 90,679 | 541,676 | — | 3,210 | — | 74 | 4,084 | 6,595 | — | 549 | 8,561 | 301,929 | -7,680 | 949,674
Inventories | 39,204 | 95,620 | — | 1,299 | — | — | — | — | — | 201 | — | — | — | 136,324
Income tax and social contribution | 108,582 | 101,406 | — | 10,831 | — | 2,035 | 25,086 | 134 | 907 | 1,409 | 13,387 | 32,349 | — | 296,128
Other current recoverable taxes | 10,626 | 979,880 | — | — | — | — | 80 | 1,035 | 8 | — | 2,990 | — | — | 994,618
Prepaid expenses | 9,288 | 42,066 | — | 1,822 | — | 68 | 7,913 | 420 | 355 | 122 | 216 | 944 | — | 63,211
Related parties | 17,664 | 7,306 | — | — | — | — | 2,670 | — | — | — | — | 4,754 | -31,773 | 621
Assets classified as held for sale | 1,881,821 | — | — | — | — | — | — | — | — | — | — | — | 5 | 1,881,826
NON-CURRENT | 22,800,216 | 16,797,534 | — | 623,724 | — | 100,266 | 7,961,804 | 2,279,634 | 184,758 | 508,080 | 531,035 | 23,164,333 | -30,609,036 | 44,342,348
Long Term Assets | 6,186,586 | 6,847,655 | — | 132,366 | — | 15,084 | 747,629 | 54,415 | — | 507,812 | 520,497 | 708,857 | -405,709 | 15,315,121
Bonds and securities | 149,368 | 3,159 | — | — | — | — | 353,799 | 17,941 | — | 4,815 | — | — | — | 529,085
Other temporary investments | — | — | — | — | — | 14,709 | — | — | — | — | — | 15,894 | — | 30,603
Customers | — | 116,180 | — | — | — | — | — | — | — | — | — | — | — | 116,180
Judicial deposits | 49,775 | 190,181 | — | — | — | 72 | 484 | — | — | 242 | 16,933 | 136,677 | — | 394,364
Sectoral financial assets | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Account receivable related to concession | 886,620 | 2,610,731 | — | — | — | — | — | — | — | — | — | — | — | 3,497,351
Contract Assets | 4,729,547 | 1,701,448 | — | — | — | — | — | — | — | 502,754 | — | — | -6,739 | 6,927,010
Other non-current receivables | 276,590 | 65,322 | — | — | — | — | — | — | — | — | 479,938 | — | — | 479,938
Income tax and social contribution | 1,819 | 59,940 | — | 6,954 | — | — | — | 34,860 | — | — | — | 298,120 | — | 681,846
Deferred income tax and social contribution | — | 918,078 | — | — | — | — | — | — | — | — | 22,780 | 79,504 | — | 164,043
Other non-current recoverable taxes | 92,867 | 1,182,616 | — | 119,561 | — | — | — | — | — | — | — | 136,536 | — | 1,174,175
Prepaid expenses | — | — | — | — | — | 303 | 224 | 1,614 | — | — | 776 | 42,126 | — | 1,320,526
Related parties | — | — | — | 5,851 | — | — | 393,122 | — | — | — | — | — | -398,970 | —
Investments | 10,104,390 | 442 | — | — | — | — | 2,698,723 | — | — | — | — | 22,431,868 | -31,657,485 | 3,577,937
Property, plant and equipment, net | 3,160,968 | — | — | 317,388 | — | 80,590 | 4,462,642 | 306,000 | 180,931 | 229 | 702 | 7,248 | — | 8,516,697
Intangible assets | 3,260,920 | 9,788,358 | — | 173,337 | — | 901 | 8,809 | 1,918,982 | 3,827 | 39 | 5,731 | 8,546 | 1,454,158 | 16,623,610
Right to use an asset | 87,352 | 161,079 | — | 633 | — | 3,691 | 44,001 | 237 | — | — | 4,174 | 7,815 | — | 308,983
TOTAL | 26,278,782 | 23,567,303 | — | 748,720 | — | 149,155 | 9,081,210 | 2,425,999 | 245,173 | 614,670 | 1,447,083 | 26,429,176 | -33,603,120 | 57,384,156

37

| EXHIBIT II- RESULT BY SUBSIDIARY > LIABILITIES BY COMPANY

|  |  |  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Liabilities - Sep-25 | Geração e Transmissão | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Small Assets | MSG | Costa Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Eliminations | Consolidated
CURRENT | 3,184 | 6,021 | — | 117 | — | 18 | 903 | 106 | 3 | — | 139 | 31 | 834 | 36 | -2,230 | 9,161
Social charges and accruals | 79 | 163 | — | 1 | — | — | — | — | — | — | — | — | 5 | 18 | — | 266
Associated companies and parent company | 7 | 16 | — | — | — | — | 9 | 1 | — | — | 1 | — | — | 2 | -37 | —
Suppliers | 305 | 2,377 | — | 7 | — | 9 | 74 | 30 | 2 | — | 6 | 2 | 429 | 5 | -239 | 3,008
Income Tax and Social Contribution payable | — | — | — | — | — | — | 12 | 44 | 1 | — | — | 2 | — | — | — | 59
Other taxes | 27 | 277 | — | 1 | — | — | 8 | 3 | — | — | 3 | — | 7 | — | — | 327
Loans and financing | 79 | 3 | — | — | — | — | 128 | — | — | — | — | 5 | — | — | — | 214
Debentures | 832 | 923 | — | — | — | 4 | 59 | — | — | — | 125 | — | — | — | — | 1,943
Dividends payable | 1,395 | 357 | — | — | — | — | 64 | — | — | — | — | 20 | 118 | 5 | -1,954 | 5
Post employment benefits | 30 | 79 | — | — | — | — | — | — | — | — | — | — | — | 5 | — | 113
Customer charges due | 11 | 89 | — | — | — | — | — | — | — | — | — | — | — | — | — | 101
Research and development and energy efficiency | 3 | 86 | — | — | — | — | — | 8 | — | — | 1 | 1 | — | — | — | 101
Payables related to concession | 25 | — | — | 105 | — | — | — | 12 | — | — | — | — | — | — | — | 143
Sectorial financial liabilities | — | 1,344 | — | — | — | — | — | — | — | — | — | — | — | — | — | 1,344
Other accounts payable | 12 | 47 | — | — | — | — | 1 | — | — | — | — | — | — | 1 | — | 61
Fair value in energy purchase and sale operations | — | — | — | — | — | — | — | — | — | — | — | — | 259 | — | — | 259
Other bills to pay | 215 | 199 | — | 2 | — | — | 548 | 7 | — | — | 1 | — | 15 | 1 | — | 988
PIS and Cofins to be refunded to consumers | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Provision for allocation of Pis and Cofins credits | — | 60 | — | — | — | — | — | — | — | — | — | — | — | — | — | 60
Provisions for litigation | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Liabilities associated with assets held for sale | 165 | — | — | — | — | 4 | — | — | — | — | — | — | — | — | — | 169
NON-CURRENT | 9,571 | 10,869 | — | 736 | — | 70 | 2,833 | 78 | 4 | — | 1,988 | 36 | 341 | 285 | 128 | 26,940
Social accruals | — | — | — | — | — | — | — | — | — | — | — | — | — | 2 | — | 2
Associated companies and parent company | — | — | — | — | — | — | 285 | — | — | — | — | — | — | 6 | -291 | —
Suppliers | 131 | — | — | — | — | — | — | — | — | — | — | — | — | — | — | 131
Deferred income tax and social contribution | 1,496 | — | — | 1 | — | — | 40 | 8 | 2 | — | 239 | 20 | 110 | — | 138 | 2,053
Tax liabilities | — | 253 | — | — | — | — | — | — | — | — | — | — | — | — | — | 253
Loans and financing | 463 | 750 | — | — | — | — | 1,972 | — | — | — | — | 12 | — | — | — | 3,196
Debentures | 5,917 | 7,531 | — | — | — | 70 | 332 | — | — | — | 1,723 | — | — | — | — | 15,574
Post-employment benefits | 308 | 722 | — | — | — | — | — | — | — | — | — | — | 2 | 37 | — | 1,069
Research and development and energy efficiency | — | 278 | — | — | — | — | — | 3 | — | — | 4 | — | — | — | — | 286
Payables related to the concession | 176 | — | — | 731 | — | — | — | 66 | — | — | — | — | — | — | — | 973
Sectorial financial liabilities | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Lease liability | 74 | 109 | — | — | — | — | 49 | — | — | — | — | — | 5 | 8 | — | 246
Other payables | — | — | — | — | — | — | — | — | — | — | — | — | 223 | — | — | 223
Fair value in energy purchase and sale operations | 60 | 34 | — | — | — | — | 153 | — | — | — | 1 | — | — | 90 | -90 | 249
PIS/Cofins to be refunded to consumers | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Provision for allocation of PIS and COFINS | — | 709 | — | — | — | — | — | — | — | — | — | — | — | — | — | 709
Provisions for litigation | 947 | 483 | — | 3 | — | — | 2 | — | 2 | — | 20 | 4 | — | 142 | 371 | 1,974
EQUITY | 14,569 | 8,154 | — | -128 | — | 60 | 4,942 | 2,196 | 241 | — | 1,404 | 546 | 324 | 25,986 | -32,346 | 25,948
Attributable to controlling shareholders | 14,569 | 8,154 | — | -128 | — | 60 | 4,942 | 2,196 | 241 | — | 1,404 | 546 | 324 | 25,986 | -32,308 | 25,986
Capital | 6,843 | 5,372 | — | 36 | — | 79 | 4,878 | 2,010 | 224 | — | 1,135 | 275 | 237 | 12,822 | -21,088 | 12,822
Advance for Future Capital Increase | — | — | — | — | — | — | 26 | — | — | — | — | 1 | — | — | -27 | —
Capital reserves | — | 1 | — | — | — | — | — | — | — | — | — | — | 1 | 12 | -2 | 12
Asset valuation adjustments | 502 | — | — | 2 | — | — | — | — | — | — | — | — | — | 483 | -504 | 483
Treasury shares | — | — | — | — | — | — | — | — | — | — | — | — | — | -117 | — | -117
Legal Reserves | 1,028 | 392 | — | — | — | — | 53 | 66 | 1 | — | 22 | 32 | 30 | 1,766 | -1,624 | 1,766
Profit retention reserve | 5,240 | 1,778 | — | — | — | — | 321 | — | — | — | 161 | 187 | — | 9,364 | -7,686 | 9,364
Tax incentive reserve | 4 | — | — | — | — | — | — | — | — | — | — | — | — | 4 | -4 | 4
Additional proposed dividends | — | — | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Accumulated profit | 952 | 611 | — | -166 | — | -19 | -336 | 120 | 15 | — | 85 | 52 | 56 | 1,653 | -1,372 | 1,653
Attributable to noncontrolling interests | — | — | — | — | — | — | — | — | — | — | — | — | — | — | -38 | -38
TOTAL | 27,323 | 25,044 | — | 725 | — | 148 | 8,678 | 2,380 | 247 | — | 3,530 | 613 | 1,499 | 26,307 | -34,448 | 62,048

38

| EXHIBIT II- RESULT BY SUBSIDIARY > LIABILITIES BY COMPANY

|  |  |  |  |  |  |  |  |  |  |  |  |  | R$'000
Liabilities - Sep-24 | Geração e Transmissão | Distribuição | Compagas | Elejor | UEG Araucária | Serviços | Parques Eólicos | FDA | Bela Vista | Costa Oeste, Marumbi, Uirapuru | Mercado Livre | Holding | Eliminations | Consolidated
CURRENT | 5,107,929 | 5,979,105 | — | 114,110 | — | 11,151 | 655,490 | 153,431 | 5,495 | 29,976 | 878,302 | 404,699 | -2,997,302 | 10,342,381
Social charges and accruals | 119,712 | 265,757 | — | 381 | — | — | — | — | — | — | 4,447 | 20,805 | — | 411,102
Associated companies and parent company | 10,810 | 11,482 | — | — | — | 160 | 9,617 | 520 | 141 | 162 | 368 | 1,690 | -34,954 | —
Suppliers | 319,382 | 1,792,275 | — | 3,857 | — | 9,345 | 56,148 | 21,547 | 718 | 5,323 | 350,946 | 3,362 | -238,481 | 2,324,423
Income Tax and Social Contribution payable | — | — | — | — | — | 457 | 9,548 | 72,506 | 368 | 602 | — | — | — | 83,482
Other taxes | 24,925 | 252,462 | — | 736 | — | -24 | 7,382 | 5,255 | 177 | 362 | 10,462 | 614 | — | 302,346
Loans and financing | 1,097,232 | 2,971 | — | — | — | — | 126,082 | — | — | 4,921 | — | — | — | 1,231,205
Debentures | 1,056,707 | 908,720 | — | — | — | 1,192 | 58,491 | — | — | — | — | — | — | 2,025,110
Dividends payable | 1,699,433 | 663,654 | — | — | — | — | 21,710 | 36,982 | 3,688 | 17,527 | 280,873 | 3,881 | -2,723,868 | 3,878
Post employment benefits | 24,557 | 66,352 | — | — | — | — | — | — | — | — | 126 | 4,348 | — | 95,383
Customer charges due | 19,940 | 23,598 | — | — | — | — | — | 855 | — | 432 | — | — | — | 44,825
Research and development and energy efficiency | 13,567 | 161,074 | — | 104 | — | — | — | 3,827 | — | 577 | — | — | — | 179,149
Payables related to concession | 4,686 | — | — | 106,333 | — | — | — | 2,073 | — | — | — | — | — | 113,092
Sectorial financial liabilities | — | 935,322 | — | — | — | — | — | — | — | — | — | — | — | 935,322
Other accounts payable | 13,697 | 41,959 | — | 284 | — | 21 | 571 | 186 | — | — | 180 | 604 | — | 57,502
Fair value in the purchase and sale of energy | — | — | — | — | — | — | — | — | — | — | 214,955 | — | — | 214,955
Other bills to pay | 161,869 | 273,479 | — | 2,415 | — | — | 365,940 | 9,682 | 403 | 69 | 15,945 | 369,395 | — | 1,199,195
PIS and Cofins to be refunded to consumers | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Provision for allocation of PIS and Cofins credits | — | 580,000 | — | — | — | — | — | — | — | — | — | — | — | 580,000
Provisions for litigation | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Assets held for sale | 541,412 | — | — | — | — | — | — | — | — | — | — | — | — | 541,412
NON-CURRENT | 6,931,439 | 9,922,614 | — | 760,550 | — | 74,736 | 3,145,692 | 86,163 | 3,221 | 38,654 | 280,154 | 349,758 | -188,137 | 21,404,840
Social obligations | — | 30 | — | — | — | — | — | — | — | — | — | 427 | — | 457
Associated companies and parent company | — | — | — | — | — | — | 389,891 | — | — | — | — | 5,851 | -395,742 | —
Suppliers | 142,376 | — | — | — | — | — | — | — | — | — | — | — | — | 142,380
Deferred income tax and social contribution | 1,445,182 | — | — | 1,222 | — | 802 | 33,343 | 10,513 | 1,679 | 18,752 | 102,398 | — | 281,567 | 1,895,459
Tax liabilities | — | 291,195 | — | — | — | — | — | — | — | — | — | — | — | 291,195
Loans and financing | 566,724 | 750,733 | — | — | — | — | 2,054,424 | — | — | 15,708 | — | — | — | 3,387,589
Debentures | 3,892,598 | 6,205,483 | — | — | — | 69,701 | 434,474 | — | — | — | — | — | — | 10,602,255
Post-employment benefits | 304,420 | 718,933 | — | — | — | — | — | — | — | — | 2,342 | 37,631 | — | 1,063,326
Research and development and energy efficiency | — | 234,277 | — | — | — | — | — | 6,488 | — | 529 | — | — | — | 241,294
Payables related to the concession | 167,478 | — | — | 755,649 | — | — | — | 69,125 | — | — | — | — | — | 992,252
Sectorial financial liabilities | — | 142,488 | — | — | — | — | — | — | — | — | — | — | — | 142,488
Lease liability | 80,058 | 127,277 | — | 393 | — | 3,861 | 47,308 | 36 | — | — | 4,311 | 7,761 | — | 271,004
Other payables | — | — | — | — | — | — | — | — | — | — | 170,837 | — | — | 170,837
Fair value in the purchase and sale of energy | 53,364 | 6,275 | — | — | — | 369 | 184,203 | — | — | — | — | 90,966 | -88,156 | 247,021
PIS/Cofins to be refunded to consumers | — | — | — | — | — | — | — | — | — | — | — | — | — | —
Provision for allocation of PIS and Cofins credits | — | 1,000,588 | — | — | — | — | — | — | — | — | — | — | — | 1,000,588
Provisions for litigation | 279,240 | 445,335 | — | 3,285 | — | — | 2,049 | — | 1,542 | 3,664 | 265 | 207,123 | 14,194 | 956,696
EQUITY | 14,239,413 | 7,665,584 | — | -125,940 | — | 63,269 | 5,280,029 | 2,186,403 | 236,457 | 546,040 | 288,629 | 25,674,718 | -30,417,679 | 25,636,934
Attributable to controlling shareholders | 14,239,413 | 7,665,584 | — | -125,940 | — | 63,269 | 5,280,029 | 2,186,403 | 236,457 | 546,040 | 288,629 | 25,674,718 | -30,379,896 | 25,674,717
Capital | 6,242,757 | 5,372,206 | — | 35,503 | — | 78,785 | 5,186,230 | 2,009,509 | 223,913 | 275,161 | 237,210 | 12,821,758 | -19,661,293 | 12,821,758
Advance for Future Capital Increase | 600,000 | — | — | — | — | — | 3,000 | — | — | — | — | — | -603,000 | —
Capital reserves | — | 166 | — | — | — | — | — | — | — | — | — | 5,595 | -166 | 5,595
Equity valuation adjustments | 537,346 | -420 | — | 2,372 | — | 148 | — | — | — | — | -137 | 517,408 | -539,309 | 517,408
Treasury shares | — | — | — | — | — | — | — | — | — | — | — | -50,044 | — | -50,044
Legal Reserves | 1,027,643 | 391,901 | — | — | — | — | 53,090 | 65,950 | 1,479 | 31,639 | 30,275 | 1,766,110 | -1,601,979 | 1,766,110
Profit retention reserve | 5,239,801 | 1,778,071 | — | — | — | — | 343,425 | — | — | 186,658 | — | 9,363,866 | -7,547,951 | 9,363,866
Additional proposed dividends | 591,866 | 123,660 | — | — | — | — | 41,574 | 110,945 | 11,064 | 52,581 | 21,279 | 1,250,025 | -952,968 | 1,250,025
Accumulated profit | — | — | — | -163,815 | — | -15,664 | -347,290 | — | — | — | — | — | 526,769 | —
Attributable to noncontrolling interests | — | — | — | — | — | — | — | — | — | — | — | — | -37,783 | -37,783
TOTAL | 26,278,782 | 23,567,303 | — | 748,720 | — | 149,155 | 9,081,210 | 2,425,999 | 245,173 | 614,670 | 1,447,083 | 26,429,176 | -33,603,120 | 57,384,156

39

| EXHIBIT III - ENERGY MARKET> DISTRIBUTION AND TOTAL MARKET

Copel’s Total Market |  | Number of Customers / Agreements |  | Energy Sold (GWh)
| set/25 | set/24 | ∆% |  | 3Q25 | 3Q24 | ∆% |  | 9M25 | 9M24 | ∆%
Copel DIS |  | 5,250,727 | 5,159,535 | 1.8 |  | 6,110 | 6,141 | -0.5 |  | 18,125 | 17,286 | 4.9
Captive Market |  | 5,250,309 | 5,159,261 | 1.8 |  | 4,625 | 4,898 | -5.6 |  | 15,051 | 16,010 | -6.0
Concessionaries and Licensees |  | 2 | 2 | — |  | 8 | 18 | -55.6 |  | 27 | 67 | -59.0
CCEE (Assigments MCSD EN) |  | 416 | 272 | 52.9 |  | 556 | 532 | 4.5 |  | 1,138 | 602 | 89.3
CCEE (MVE) |  | — | — | — |  | — | — | — |  | — | — | —
CCEE (MCP) 2 |  | — | — | — |  | 921 | 693 | 32.9 |  | 1,909 | 608 | —
Copel GeT |  | 425 | 523 | -18.7 |  | 3,662 | 3,621 | 1.1 |  | 12,090 | 12,317 | -1.8
CCEAR (Copel DIS) |  | 5 | 4 | 25.0 |  | 51 | 30 | 70.0 |  | 116 | 94 | 23.1
CCEAR (other concessionaries) |  | 101 | 119 | -15.1 |  | 459 | 581 | -21.0 |  | 1,604 | 1,736 | -7.6
Bilateral Agreements (Copel Mercado Livre) |  | 312 | 396 | -21.2 |  | 2,961 | 2,951 | 0.3 |  | 10,087 | 10,014 | 0.7
Bilateral Agreements 1 |  | 7 | 4 | 75.0 |  | 648 | 40 | 1,520.0 |  | 756 | 132 | 472.9
CCEE (MCP) 2 |  | — | — | — |  | -457 | 19 | — |  | -473 | 341 | —
Wind Farms Complex |  | 703 | 660 | 6.5 |  | 1,195 | 1,113 | 7.4 |  | 3,623 | 3,288 | 10.2
CCEAR (Copel DIS) |  | 19 | 15 | 26.7 |  | 35 | 31 | 12.9 |  | 100 | 96 | 4.2
CCEAR (other concessionaries) |  | 654 | 580 | 12.8 |  | 687 | 657 | 4.6 |  | 1,997 | 1,852 | 7.8
CER |  | 10 | 10 | — |  | 230 | 230 | — |  | 683 | 694 | -1.6
Bilateral Agreements (Copel Mercado Livre) |  | 5 | 22 | -77.3 |  | 159 | 137 | 16.1 |  | 406 | 316 | 28.5
Bilateral Agreements |  | 15 | 33 | -54.5 |  | 241 | 179 | 34.6 |  | 477 | 419 | 13.8
CCEE (MCP) 2 |  | — | — | — |  | -157 | -121 | — |  | -40 | -89 | —
Copel Mercado Livre |  | 1,758 | 1,602 | 9.7 |  | 7,270 | 5,814 | 25.0 |  | 20,528 | 17,383 | 18.1
Free Customers |  | 1,457 | 1,413 | 3.1 |  | 2,519 | 2,753 | -8.5 |  | 7,264 | 7,982 | -9.0
CCEAR (other concessionaries) |  | 29 | — | — |  | 95 | — | — |  | 197 | — | —
Bilateral Agreements (Group Companies) |  | 37 | 12 | 208.3 |  | 852 | 321 | 165.4 |  | 1,508 | 604 | 149.7
Bilateral Agreements |  | 235 | 177 | 32.8 |  | 3,746 | 2,713 | 38.1 |  | 11,440 | 8,673 | 31.9
CCEE (MCP) 2 |  | — | — | — |  | 58 | 27 | — |  | 119 | 124 | -4.0
Total Copel |  | 5,253,613 | 5,162,320 | 1.8 |  | 18,237 | 16,689 | 9.3 |  | 54,367 | 50,274 | 8.1
Eliminations (operations with Group companies) |  |  |  |  |  | 4,058 | 3,470 | 16.9 |  | 12,216 | 11,124 | 9.8
Total Consolidated Copel |  |  |  |  |  | 14,179 | 13,219 | 7.3 |  | 42,151 | 39,150 | 7.7
Note: Not considering the energy from MRE (Energy Relocation Mechanism). ¹ Includes Short Term Sales Agreements and CBR ² Negative values mean that there were more purchases than sales. CCEE: Electric Power Trade Chamber / CCEAR: Energy Purchase Agreements in the Regulated Market / MCP: Short Term Market / CER: Agreements Reserve Energy / MCSD EN - Mechanism for Compensation of Surpluses and Deficits of New Energy / MVE - MVE - Sale of energy to the free market through the Surplus Selling Mechanism.

Copel’s Dis Market |  | Number of Customers |  | Consumed Energy (GWh)
| set/25 | set/24 | ∆% |  | 3Q25 | 3Q24 | ∆% |  | 9M25 | 9M24 | ∆%
Residential |  | 4,371,253 | 4,274,234 | 2.3 |  | 2,366 | 2,275 | 4.0 |  | 7,552 | 7,376 | 2.4
Industrial |  | 68,395 | 68,991 | (0.9) |  | 3,293 | 3,244 | 1.5 |  | 9,728 | 9,496 | 2.4
Captive |  | 65,822 | 67,319 | (2.2) |  | 314 | 430 | (27.0) |  | 980 | 1,315 | (25.5)
Free |  | 2,573 | 1,672 | 53.9 |  | 2,979 | 2,814 | 5.9 |  | 8,748 | 8,180 | 6.9
Commercial |  | 451,413 | 446,640 | 1.1 |  | 1,727 | 1,690 | 2.2 |  | 5,528 | 5,498 | 0.5
Captive |  | 448,000 | 444,466 | 0.8 |  | 992 | 1,074 | (7.6) |  | 3,315 | 3,587 | (7.6)
Free |  | 3,413 | 2,174 | 57.0 |  | 735 | 616 | 19.2 |  | 2,213 | 1,911 | 15.8
Rural |  | 308,614 | 317,110 | (2.7) |  | 593 | 615 | (3.6) |  | 2,018 | 2,056 | (1.8)
Captive |  | 308,447 | 317,008 | (2.7) |  | 529 | 565 | (6.2) |  | 1,814 | 1,902 | (4.6)
Free |  | 167 | 102 | 63.7 |  | 64 | 51 | 25.4 |  | 204 | 154 | 32.6
Others |  | 57,608 | 56,442 | 2.1 |  | 598 | 610 | (2.0) |  | 1,876 | 1,905 | (1.5)
Captive |  | 56,787 | 56,234 | 1.0 |  | 424 | 556 | (23.7) |  | 1,389 | 1,829 | (24.1)
Free |  | 821 | 208 | 294.7 |  | 174 | 54 | — |  | 487 | 76 | —
Total Captive Market |  | 5,250,309 | 5,159,261 | 1.8 |  | 4,625 | 4,898 | (5.6) |  | 15,050 | 16,010 | (6.0)
Total Free Market |  | 6,974 | 4,156 | 67.8 |  | 3,951 | 3,535 | 11.8 |  | 11,652 | 10,321 | 12.9
Supply to Concessionaries |  | 7 | 7 | — |  | 258 | 253 | 1.9 |  | 769 | 752 | 2.2
Total Grid Market |  | 5,257,290 | 5,163,424 | 1.8 |  | 8,834 | 8,687 | 1.7 |  | 27,471 | 27,083 | 1.4
Micro and Mini Distributed Energy Generation |  | 502,341 | 383,261 | 31.1 |  | (769) | (581) | 32.3 |  | (2,437) | (1,859) | 31.1
Offset Energy from Distributed Generation II and III |  |  |  |  |  | 276 | 93 | 196.4 |  | 799 | 215 | 271.1
Total Billed Market |  |  |  |  |  | 8,341 | 8,199 | 1.7 |  | 25,833 | 25,439 | 1.5

40

| EXHIBIT III - ENERGY MARKET> TARIFFS

Supply Tariff (R$/MWh) | 2025 | Product Class* | Validity*
Amount Average MW | Price (R$)¹
Copel Geração e Transmissão |  |  |  |  |
Auction CCEAR 2011 - 2040 ( HPP Mauá) | 192 | 315.71 | SP100/SP92 | 01.07.2020 | 31.12.2040
Auction - CCEAR 2024 - 2053 (SHP Bela Vista) | 15 | 274.80 |  | 01.01.2024 | 12.31.2053
Copel Distribuição |  |  |  |  |
Concession holders in the State of Paraná | 24 | 305.74 |  |  |
Total / Tariff Weighted Average Supply | 231 | 312.02 |  |  |
Contains PIS and COFINS. Net of ICMS. |  |  |  |  |
*GSF renegotiation |  |  |  |  |
Purchase Tariff - Copel Distribuição (R$/MWh) | Amount | Sep/25 | Sep/24 | Δ% |
Average MW |
Itaipu 1 | 481.1 | 225.84 | 245.89 | -8.2 % |
Auction – CCEAR 2010 – H30 | 69.1 | 329.88 | 313.22 | 5.3 % |
Auction – CCEAR 2010 - T15 2 | — | — | 353.86 | -100.0 % |
Auction – CCEAR 2011 - H30 | 57.0 | 340.11 | 322.93 | 5.3 % |
Auction – CCEAR 2011 - T15 2 | 53.7 | 284.49 | 307.74 | -7.6 % |
Auction – CCEAR 2012 - T15 2 | 107.5 | 331.37 | 293.65 | 12.8 % |
Auction – CCEAR 2016 - T20 ² | 26.6 | 206.19 | 229.47 | -10.1 % |
Angra | 96.8 | 315.90 | 347.53 | -9.1 % |
CCGF 3 | 361.7 | 201.50 | 179.84 | 12.0 % |
Santo Antônio | 136.1 | 211.07 | 200.41 | 5.3 % |
Jirau | 226.5 | 185.71 | 176.33 | 5.3 % |
Others Auctions 4 | 755.7 | 290.69 | 311.04 | -6.5 % |
Total / Average Purchuse Tariff | 2,371.8 | 253.46 | 252.95 | 0.2 % |
Contains PIS and COFINS |
1 Furnas transport charge not included. |
2 Average auction price restated according as bilateral payment to vendors. It does not include |
3 Contract of quotas of assured power of those HPPs which concessions were extended pursuant |
4 Products average price, does not include PROINFA. |
*The table has been updated for all periods as new calculation methodology for average prices, a result of the 4th phase of the Public Hearing 78/2011 Aneel approved on 03.28.2016. |
Retail Tariff - Copel Distribuição (R$/MWh) |  | Sep/25 | Sep/24 | Δ% |
Industrial |  | 536.91 | 551.30 | -2.6 % |
Residential |  | 535.80 | 527.34 | 1.6 % |
Commercial |  | 572.13 | 583.06 | -1.9 % |
Rural |  | 556.17 | 575.85 | -3.4 % |
Other |  | 615.52 | 590.55 | 4.2 % |
Retail Tariff supply average tariff |  | 592.40 | 615.21 | -3.7 % |
Demand average tariff (R$/kW) |  | 33.45 | 40.02 | -16.4 % |
Does not consider tariff flags, Pis/Pasep and net of ICMS. |  |  |  |  |

41

| EXHIBIT III - ENERGY MARKET> ELECTRICITY PURCHASED AND CHARGES

|  |  |  |  |  | R$'000
Electricity Purchased for Resale | 3Q25 | 3Q24 | Δ% | 9M25 | 9M24 | Δ%
Purchase of energy in the regulated party - CCEAR | 1,080,404 | 1,077,768 | 0.2 | 2,952,919 | 3,009,783 | -1.9
Itaipu Binacional | 243,028 | 252,548 | -3.8 | 742,033 | 707,070 | 4.9
Câmara de Comercialização de Energia - CCEE | 465,591 | 277,655 | 67.7 | 851,223 | 450,261 | 89.1
Micro and mini generators and customer repurchase | 609,491 | 390,409 | 56.1 | 1,709,902 | 1,200,327 | 42.5
Proinfa | 107,232 | 84,278 | 27.2 | 320,561 | 252,990 | 26.7
Bilateral Agreements | 829,468 | 478,001 | 73.5 | 2,004,286 | 1,267,164 | 58.2
Fair value in the purchase and sale of energy | — | -17,872 | — | — | 26,009 | —
(-) PIS/Pasep and Cofins | -251,775 | -214,805 | 17.2 | -681,723 | -599,221 | 13.8
TOTAL | 3,083,439 | 2,327,982 | 32.5 | 7,899,201 | 6,314,383 | 25.1
|  |  |  |  |  | R$'000
Charges of the main distribution and transmission grid | 3Q25 | 3Q24 | Δ% | 2025 | 2024 | Δ%
Itaipu transportation charges | 51,113 | 43,439 | 17.7 | 135,344 | 153,025 | -11.6
System Service Charges - ESS | 628 | 39,171 | -98.4 | 7,194 | 61,629 | -88.3
System usage charges | 613,239 | 586,044 | 4.6 | 1,838,063 | 1,914,412 | -4.0
Charge reserve energy - EER | 100,233 | 115,845 | -13.5 | 336,847 | 337,581 | -0.2
Grid Use charges - Provisions | 482 | 10,852 | — | 538 | 10,900 | -95
(-) PIS / Pasep and Cofins taxes on charges for use of power grid | -78,664 | -81,293 | -3.2 | -237,855 | -255,128 | -6.8
TOTAL | 687,031 | 714,058 | -3.8 | 2,080,131 | 2,222,419 | -6.4

42

| EXHIBIT III - ENERGY MARKET> ENERGY BALANCE

|  |  |  |  |  | (average MW)
Energy Balance - Copel GET - Sep-25 | 2025 | 2026 | 2027 | 2028 | 2029 | 2030
Own Resources GeT | 1,956 | 1,890 | 1,901 | 1,920 | 1,928 | 1,928
GeT (1) | 1,359 | 1,291 | 1,291 | 1,291 | 1,291 | 1,291
GPS (CCGF) (2) | 73 | 73 | 73 | 73 | 73 | 73
Bela Vista + FDA | 524 | 526 | 537 | 556 | 564 | 564
Own Resources SPP and Wind Farm (3) | 544 | 544 | 544 | 544 | 544 | 544
Purchases | 220 | 75 | 50 | — | — | —
TOTAL OWN RESOURCES + SOLD | 2,720 | 2,509 | 2,495 | 2,464 | 2,472 | 2,472
TOTAL SOLD | 2,407 | 2,114 | 1,847 | 1,586 | 1,262 | 961
Sales (Regulated) | 737 | 706 | 706 | 706 | 706 | 706
Sales (Regulated) % | 27% | 28% | 28% | 29% | 29% | 29%
Sales (Free Market) | 1,670 | 1,408 | 1,141 | 880 | 556 | 255
Sales (Free Market) % | 62% | 57% | 46% | 36% | 23% | 10%
Total Available | 312 | 395 | 647 | 878 | 1,210 | 1,511
Total Available (%) | 11% | 15% | 26% | 35% | 48% | 61%
Avarege price of energy sold (R$))(4) | 175.18 | 189.99 | 190.70 | 198.93 | 209.97 | 227.61
Reference: September/25
(1) Includes Mauá 100% from June25 and GPS 30% (ex-CCGF). Does not include Baixo Iguaçu, Elejor and Foz do Chopim.
(2) GPS 70% (quota regime).
(3) Does not include Voltália Wind Complex.
(4) Average gross energy price (with PIS/COFINS and without ICMS). The GPS CCGF RAG is not considered in the calculation of average prices.

SALES (average MW)

Comments: 1- Excluding losses and internal consumption. 2- Considering the GFs of wind SPEs constant for all periods. 3- Considering the Sales of wind SPEs constant for all periods. 4- Considering energy purchases in each period. 5 - Prices updated according to the contractual readjustment index, from the reference dates until September/2025. 6 - The GPS CCGF RAG is not considered in the calculation of average prices. 7 - Average gross energy prices (with PIS/COFINS and without ICMS) 8- Considers the physical guarantee of the plants on September 30,2025.

43

| avarage prices of energy sold |
| 2025 |  | 2026 |  | 2027 |  | 2028 |  | 2029 |  | 2030 |
| $167.52 |  | $185.69 |  | $187.19 |  | $198.77 |  | $217.54 |  | $260.69 |
| *Includes hydroelectric plants, CCGF (GPS Plant), SPE FDA and SPE Bela Vista. |

| avarage prices of energy sold |
| 2025 |  | 2026 |  | 2027 |  | 2028 |  | 2029 |  | 2030 |
| $219.89 |  | $220.19 |  | $216.71 |  | $215.49 |  | $214.33 |  | $213.30 |
| Comments: |  |  |  |  |  |  |  |  |  |  |
| 1- Excluding losses and internal consumption. |
| 2- Considering the GFs of wind SPEs constant for all periods. |
| 3- Considering the Sales of wind SPEs constant for all periods. |
| 4- Considering energy purchases in each period. |
| 5 - Prices updated according to the contractual readjustment index, from the reference dates until September/2025. |
| 6 - The GPS CCGF RAG is not considered in the calculation of average prices. |
| 7 - Average gross energy prices (with PIS/COFINS and without ICMS) |
| 8- Considers the physical guarantee of the plants on September 30,2025. |

44

| EXHIBIT III - ENERGY MARKET> WIND POWER PRICES

Wind Farms - Sold | Auction ¹ | Price (R$) ² | Certification | Amount MW average/year | Start of Supply | End of Supply
São Bento Energia, Invest. e Part. S.A. |  |  |  |  |  |
GE Boa Vista S.A. | 2º LFA (26/08/2010) | 326.41 | P50 | 5.70 | 01.01.2013 | 31.12.2032
GE Farol S.A. | 316.90 | P50 | 9.10
GE Olho D’Água S.A. | 316.90 | P50 | 14.90
GE São Bento do Norte S.A. | 316.90 | P50 | 14.00
Copel Brisa Potiguar S.A. |  |  |  |  |  |
Nova Asa Branca I Energias Renováveis S.A. | 2º LFA (26/08/2010) | 320.28 | P50 | 13.20 | 01.01.2013 | 31.12.2032
Nova Asa Branca II Energias Renováveis S.A. | 320.28 | P50 | 12.80
Nova Asa Branca III Energias Renováveis S.A. | 320.28 | P50 | 12.50
Nova Eurus IV Energias Renováveis S.A. | 320.28 | P50 | 13.70
Santa Maria Energias Renováveis S.A. | 4º LER (18/08/2011) | 225.72 | P50 | 15.70 | 01.07.2014 | 30.06.2034
Santa Helena Energias Renováveis S.A. | 225.72 | P50 | 16.00
Ventos de Santo Uriel S.A. | 223.97 | P50 | 9.00
Cutia |  |  |  |  |  |
UEE Cutia S.A. | 6º LER (31/10/2014) | 265.51 | P90 | 9.60 | 01.10.2017 | 30.09.2037
UEE Esperança do Nordeste S.A. | 265.51 | P90 | 9.10
UEE Guajiru S.A. | 265.51 | P90 | 8.30
UEE Jangada S.A. | 265.51 | P90 | 10.30
UEE Maria Helena S.A. | 265.51 | P90 | 12.00
UEE Paraíso dos Ventos do Nordeste S.A. | 265.51 | P90 | 10.60
UEE Potiguar S.A. | 265.51 | P90 | 11.30
Bento Miguel |  |  |  |  |  |
CGE São Bento do Norte I S.A. | 20ª LEN (28/11/2014) | 251.49 | P90 | 9.70 | 01.01.2019 | 31.12.2038
CGE São Bento do Norte II S.A. | 251.49 | P90 | 10.00
CGE São Bento do Norte III S.A. | 251.49 | P90 | 9.60
CGE São Miguel I S.A. | 251.49 | P90 | 8.70
CGE São Miguel II S.A. | 251.49 | P90 | 8.40
CGE São Miguel III S.A. | 251.49 | P90 | 8.40
Vilas |  |  |  |  |  |
Vila Ceará I (Antiga Vila Paraíba IV) | 28ª LEN (31/08/2018) | 135.23 | P90 | 8.20 | 01.01.2024 | 31.12.2043
Vila Maranhão I | 135.23 | P90 | 8.30
Vila Maranhão II | 135.23 | P90 | 8.30
Vila Maranhão III (Antiga Vila Paraíba III) | 135.23 | P90 | 8.20
Vila Mato Grosso (Antiga Vila Alagoas III) | 29ª LEN (28/06/2019) | 112.80 | P90 | 3.30 | 01.01.2023 | 31.12.2042
Jandaira |  |  |  |  |  |
Jandaira I | 30ª LEN (18/10/2019) | 137.95 | P90 | 1.60 | 01.01.2025 | 31.12.2044
Jandaira II | 137.95 | P90 | 4.10
Jandaira III | 137.95 | P90 | 4.40
Jandaira IV | 137.95 | P90 | 4.30
Aventura |  |  |  |  |  |
Aventura II | 26º LEN (20/12/2017) | 145.83 | P90 | 11.70 | 01.01.2023 | 31.12.2042
Aventura III | 145.83 | P90 | 12.80
Aventura IV | 145.83 | P90 | 14.10
Aventura V | 145.83 | P90 | 15.00
Santa Rosa & Mundo Novo |  |  |  |  |  |
Santa Rosa & Mundo Novo I | 26º LEN (20/12/2017) | 148.84 | P90 | 16.50 | 01.01.2023 | 31.12.2042
Santa Rosa & Mundo Novo II | 148.84 | P90 | 17.00
Santa Rosa & Mundo Novo III | 148.84 | P90 | 18.00
Santa Rosa & Mundo Novo IV | 148.84 | P90 | 7.50
Santa Rosa & Mundo Novo V | 148.84 | P90 | 8.10
Voltália3 |  |  |  |  |  |
Caranaúbas | 04ª LER (18/08/2011) | 218.94 | — | 13.10 | 01.07.2014 | 30.06.2034
Reduto | 218.94 | — | 13.90
Santo Cristo | 218.94 | — | 14.80
São João | 218.94 | — | 14.30
¹LFA - Alternative Sources Auction/LER - Reserve Energy Auction/LEN - New Energy Auction. |  |  |
²Price updated by IPCA until Sep/24 (Reference Oct/24). Source: CCEE |  |  |
3Values presented refer to 100% of the Complex. Copel has a 49% stake in the project. |  |  |

45

| EXHIBIT III - ENERGY MARKET> ENERGY FLOW

|  |  |  |  |  |  |  |  |  |  |  | GWh
Energy Flow | COPEL DIS | COPEL GET + FDA + BELA VISTA | EÓLICAS | COPEL COM | ELIMINAÇÕES | CONSOLIDADO
3Q25 | 3Q24 | 3Q25 | 3Q24 | 3Q25 | 3Q24 | 3Q25 | 3Q24 | 3Q25 | 3Q24 | 3Q25 | 3Q24
Own Generation | — | — | 4,406 | 6,700 | 922 | 1089 | — | — | — | — | 5,328 | 7,789
Purchased energy | 5,858 | 6,375 | 927 | 466 | 89 | 7 | 7,270 | 5,814 | 4,058 | 3,470 | 10,086 | 9,192
Copel Comercialização | — | — | 763 | 321 | 89 | — | — | — | 852 | 321 | — | —
Companies of the group | 86 | 60 | — | — | — | — | 3,120 | 3,089 | 3,206 | 3,149 | — | —
Itaipu | 1,120 | 1,146 | — | — | — | — | — | 0 | — | — | 1,120 | 1,146
Auction – CCEAR | 3,315 | 3,898 | — | — | — | — | — | 0 | — | — | 3,315 | 3,898
CCEE (MCP) | 0 | 6 | — | — | — | — | — | 0 | — | — | 0 | 6
Angra | 214 | 215 | — | — | — | — | — | — | — | — | 214 | 215
CCGF | 770 | 933 | — | — | — | — | — | — | — | — | 770 | 933
Proinfa | 93 | 104 | — | — | — | — | — | — | — | — | 93 | 104
Other (1) | 260 | 13 | 164 | — | — | 7 | 4,116 | 2,725 | — | — | 4,540 | 2,745
Elejor | — | — | — | — | — | — | — | 0 | — | — | — | 0
Dona Francisca | — | — | 0 | 34 | — | — | 34 | — | — | — | 34 | 34
MRE Receipt | — | — | 0 | 111 | — | — | — | — | — | — | 0 | 111
Avaiable | 5,858 | 6,375 | 5,333 | 7,166 | 1,011 | 1096 | 7,270 | 5,814 | 4,058 | 3,470 | 15,414 | 16,981
Captive Market | 4,625 | 4,898 | — | — | — | — | — | — | — | — | 4,625 | 4,898
Concessionaires (2) | 8 | 18 | — | — | — | — | — | — | — | — | 8 | 18
CCEE concessionaire supply (3) | — | — | 42 | 40 | — | — | — | — | — | — | 42 | 40
CCEE (MCSD EN Assignments) (4) | 556 | 532 | — | — | — | — | — | — | — | — | 556 | 532
CCEE (MVE) (5) | — | — | — | — | — | — | — | — | — | — | — | —
CCEE (MCP) (6) | 921 | 699 | -457 | 19 | -157 | -121 | 58 | 27 | — | — | 365 | 624
Free Customers | — | — | — | — | — | — | 2,519 | 2,753 | — | — | 2,519 | 2,753
Bilateral Agreements | — | — | 606 | — | 241 | 179 | 3,746 | 2,713 | — | — | 4,593 | 2,892
Auction CCEAR (7) | — | — | 459 | 581 | 687 | 657 | 95 | — | — | — | 1,241 | 1238
MRE assignment (8) | — | — | 1,671 | 3,545 | — | — | — | — | — | — | 1,671 | 3,545
CER (9) | — | — | — | — | 230 | 230 | — | — | — | — | 230 | 230
Copel Comercialização | — | — | 2,961 | 2,952 | 159 | 137 | — | — | 3,120 | 3,089 | — | —
Companies of the group | — | — | 51 | 29 | 35 | 31 | 852 | 321 | 938 | 381 | — | —
Losses and Differences (10) | -252 | 228 | — | — | -184 | -17 | — | — | — | — | -436 | 211
(1) Others: Includes MCSD EM Assignments of Copel Distribuição (purchase).
(2) Energy supply to concessionaires and licensees with their own market below 500GWh/year.
(3) Supply of energy to CCEE's agent distributor, through a Regulated Bilateral Contract Agreement - CBR
(4) Assignments MCSD EN - Contractual assignments to other distributors through the New Energy Surplus and Deficit Compensation Mechanism.
(5) CCEE (MVE): Financial settlement of energy surpluses from the distributor to the free market through the Surplus Sale Mechanism.
(6) CCEE (MCP): Electric Energy Commercialization Chamber (Spot Market).
(7) CCEAR: Energy Trading Agreement in the Regulated Environment.
(8) MRE: Energy Reallocation Mechanism.
(9) CER: Reserve Energy Contract.
(10) Considers the effects of Mini and Micro Distributed Generation (MMGD).

46

| EXHIBIT III - ENERGY MARKET> ENERGY FLOW

|  |  |  |  |  |  |  |  |  |  |  | GWh
Energy Flow | COPEL DIS | COPEL GET + FDA + BELA VISTA | EÓLICAS | COPEL COM | ELIMINAÇÕES | CONSOLIDADO
9M25 | 9M24 | 9M25 | 9M24 | 9M25 | 9M24 | 9M25 | 9M24 | 9M25 | 9M24 | 9M25 | 9M24
Own Generation | — | — | 13,435 | 18,087 | 2,473 | 2,412 | — | — | — |  | 15,908 | 20,499
Purchased energy | 17,496 | 18,232 | 2,381 | 729 | 387 | 201 | 20,539 | 17,383 | 12,213 | 11,118 | 28,590 | 25,427
Copel Comercialização | — | — | 1,120 | 414 | 387 | 190 | — | — | 1,507 | 604 | — | —
Companies of the group | 214 | 184 | — | — | — | — | 10,492 | 10,330 | 10,706 | 10,514 | — | —
Itaipu | 3,323 | 3,414 | — | — | — | — | — | — | — | — | 3,323 | 3,414
Auction – CCEAR | 9,889 | 10,480 | — | — | — | — | — | — | — | — | 9,889 | 10,480
CCEE (MCP) | — | 245 | — | — | — | — | 11 | — | — | — | 11 | 245
Angra | 634 | 641 | — | — | — | — | — | — | — | — | 634 | 641
CCGF | 2,388 | 2,914 | — | — | — | — | — | — | — | — | 2,388 | 2,914
Proinfa | 275 | 315 | — | — | — | — | — | — | — | — | 275 | 315
Other (1) | 773 | 39 | 229 | — | — | 11 | 9,969 | 7,053 | — | — | 10,971 | 7,103
Elejor | — | — | — | — | 0 | 0 | — | — | — | — | — | 0
Dona Francisca | — | — | 33 | 100 | 0 | 0 | 67 | — | — | — | 100 | 100
MRE Receipt | — | — | 999 | 215 | 0 | 0 | — | — | — | — | 999 | 215
Avaiable | 17,496 | 18,232 | 15,816 | 18,816 | 2,860 | 2613 | 20,539 | 17,383 | 12,216 | 11,118 | 44,495 | 45,926
Captive Market | 15,050 | 16,010 | — | — | — | — | — | — | — | — | 15,050 | 16,010
Concessionaires (2) | 27 | 67 | — | — | — | — | — | — | — | — | 27 | 67
CCEE concessionaire supply (3) | — | — | 134 | 128 | — | — | — | — | — | — | 134 | 128
CCEE (MCSD EN Assignments) (4) | 1,139 | 602 | — | — | — | — | — | — | — | — | 1139 | 602
CCEE (MVE) (5) | — | — | — | — | — | — | — | — | — | — | — | —
CCEE (MCP) (6) | 1,909 | 853 | (472) | 341 | (40) | (89) | 130 | 124 | — | — | 1527 | 1,229
Free Customers | — | — | — | — | — | — | 7,264 | 7,982 | — | — | 7,264 | 7,982
Bilateral Agreements | — | — | 622 | 4 | 477 | 419 | 11,440 | 8,673 | — | — | 12,539 | 9,096
Auction CCEAR (7) | — | — | 1,604 | 1,736 | 1,997 | 1,852 | 197 | — | — | — | 3,798 | 3588
MRE assignment (8) | — | — | 3,726 | 6,499 | — | — | — | — | — | — | 3,726 | 6,499
CER (9) | — | — | — | — | 683 | 694 | — | — | — | — | 683 | 694
Copel Comercialização | — | — | 10,087 | 10,015 | 406 | 315 | — | — | 10,493 | 10,330 | — | —
Companies of the group | — | — | 115 | 93 | 100 | 92 | 1,508 | 604 | 1,723 | 788 | 0 | 1
Losses and Differences (10) | (629) | 700 | — | — | (763) | (670) | — | — | — | — | -1392 | 30
(1) Others: Energy purchased by Copel Comercialização. Includes MCSD EM Assignments of Copel Distribuição (purchase).
(2) Energy supply to concessionaires and licensees with their own market below 500GWh/year.
(3) Supply of energy to CCEE's agent distributor, through a Regulated Bilateral Contract Agreement - CBR.
(4) Assignments MCSD EN - Contractual assignments to other distributors through the New Energy Surplus and Deficit Compensation Mechanism.
(5) CCEE (MVE): Financial settlement of energy surpluses from the distributor to the free market through the Surplus Sale Mechanism.
(6) CCEE (MCP): Electric Energy Commercialization Chamber (Spot Market).
(7) CCEAR: Energy Trading Agreement in the Regulated Environment.
(8) MRE: Energy Reallocation Mechanism.
(9) CER: Reserve Energy Contract.
(10) Considers the effects of Mini and Micro Distributed Generation (MMGD).

47

| EXHIBIT III - ENERGY MARKET> ENERGY FLOW

ENERGY FLOW CONSOLIDATED 3Q25 | ENERGY FLOW CONSOLIDATED 3Q25 |
|  |  |  |  |  |  |  |  |  | GWh |  |  |  |  |  |  |  |  |  |  |  |  | GWh |
| Own Generation |  |  |  |  |  | Captive Market |  |  |  | Own Generation |  |  |  |  |  | Captive Market |
| 5,328 | 34.6% |  |  |  |  |  | 4,625 |  | 30.0% |  |  |  | 15,908 | 35.8% |  |  |  |  |  | 15,050 |  | 33.8% |
|  |  |  |  |  |  |  | Concessionaires2 |  |  |  |  |  |  |  |  |  |  | Concessionaires2 |
|  |  |  |  |  |  |  | 8 |  | —% |  |  |  |  |  |  |  |  |  |  | 27.00 |  | 0.1% |
|  |  |  |  |  |  |  | Electricity sales to distributor CCEE3 |  |  |  |  |  |  |  |  |  | Electricity sales to distributor CCEE3 |
|  |  |  |  |  |  |  | 42 |  | 0.3% |  |  |  |  |  |  |  |  |  |  | 134.00 |  | 0,3% |
|  |  |  |  |  |  |  | Assignment MCSD EN4 |  |  |  |  |  |  |  |  |  |  | Assignment MCSD EN4 |
|  |  |  |  |  |  |  | 556 |  | 3.6% |  |  |  |  |  |  |  |  |  |  | 1,139.00 |  | 2.6% |
|  |  |  |  | Total Available Power |  |  |  |  |  |  |  |  |  |  |  |  | Total Available Power |  |  |  |  |  |
|  |  |  |  | 15,414 |  |  | CCEE (MVE) |  |  |  |  |  |  |  | 44,495 |  |  | CCEE (MVE) |
|  |  |  |  |  |  |  | 0 |  | 0.0% |  |  |  |  |  |  |  |  |  |  | 0.00 |  | 0% |
|  |  |  |  |  |  |  | Free Customers |  |  |  |  |  |  |  |  |  |  | Free Customers |
| Purchased energy |  |  |  |  |  | 2,519 |  | 16.3% |  |  |  | Purchased energy |  |  |  |  |  | 7,264.00 |  | 16.3% |
| 10086 | 65.4 % |  |  |  |  |  |  |  |  |  |  |  | 28,590.000 | 64.30% |  |  |  |  |  |  |  |  |
| CCEAR: | 3,315 |  |  |  |  |  | Supplied Energy |  |  |  | CCEAR: | 9,889 |  |  |  |  |  | Supplied Energy |
| Itaipu: | 1,120 |  |  |  |  |  | 8,100 | 52.5 % |  |  |  |  | Itaipu: | 3,323 |  |  |  |  |  | 22,273.00 | 50.1 % |  |
| Dona Francisca: | 34 |  |  |  |  |  | Contratos Bilaterais | 4,593 |  |  |  | Dona Francisca: | 100 |  |  |  |  |  | Contratos Bilaterais | 12,539 |
| CCEE (MCP): | 0 |  |  |  |  |  |  | CCEAR: | 1,241 |  |  |  | CCEE (MCP): | 11 |  |  |  |  |  |  | CCEAR: | 3,798 |
| Angra: | 214 |  |  |  |  |  |  | CER: | 230 |  |  |  | Angra: | 634 |  |  |  |  |  |  | CER: | 683 |
| CCGF: | 770 |  |  |  |  |  | CCEE (MCP): | 365 |  |  |  | CCGF: | 2,388 |  |  |  |  |  | CCEE (MCP): | 1,527 |
| MRE: | 0 |  |  |  |  |  |  | MRE: | 1,671 |  |  |  | MRE: | 999 |  |  |  |  |  |  | MRE: | 3,726 |
| Elejor: | 0 |  |  |  |  |  |  |  |  |  |  |  | Elejor: | 0 |  |  |  |  |  |  |  |  |
| Proinfa: | 93 |  |  |  |  |  | Losses and Differences |  |  |  | Proinfa: | 275 |  |  |  |  |  | Losses and Differences |
| Outros1: | 4,540 |  |  |  |  |  | -436 |  | -2.8% |  |  |  | Outros1: | 10,971 |  |  |  |  |  | -1,392 |  | -3.1% |
| Notes: |  |  |  |  |  |  |
| CCEAR: Energy Purchase Agreements in the Regulated Market.
| CER: Reserve Energy Agreements.
| CCEE (MCP): Electric Power Trade Chamber (Short-term market).
| MRE: Energy Reallocation Mechanism.
| CG: Center of gravity of the Submarket (difference between billed and energy received from CG).
| ¹ Other: Energy purchased by Copel Comercialização and Copel Distribuição
| 2 Electricity sales to concessionaries and licensees with own market of less than 500GWh/year
| 3 Eletricity sales to the agent distributor of CCEE through a Regulated Bilateral Contract - CBR
| 4 Assignments MCSD EN - Contractual assignments to other distributors through the Mechanism for Compensation of Surpluses and Deficits (MCSD)
| 5 Considers the effect of Distributed Mini and Microgeneration (MMGD)
| 6 Considers losses and the volume of energy not delivered, referring to availability contracts, which provide for subsequent reimbursement.

48

| EXHIBIT IV - OPERATIONAL DATA > INDICATORS SUMMARY

MANAGEMENT |  |  |  |  |  |
Copel Staff List | 2020 | 2021 | 2022 | 2023 | 2024 | Sep-25
Geração e Transmissão | 1,533 | 1,523 | 1,487 | 1,477 | 1,091 | 1,046
Distribuição | 4,641 | 4,430 | 4,257 | 4,203 | 3,199 | 3,092
Telecomunicações | 355 | — | — | — | — | —
Holding | 96 | 169 | 84 | 83 | 60 | 54
Comercialização | 42 | 44 | 47 | 41 | 39 | 47
Serviços | — | — | 217 | — | — | —
TOTAL | 6,667 | 6,166 | 6,092 | 5,804 | 4,389 | 4,239
Cotrolated Staff List | 2020 | 2021 | 2022 | 2023 | 2024 | Sep-25
Elejor | 7 | 7 | 7 | 7 | 7 | 11
GENERATION |  |  |  |  |  |
Copel GET | Amount | Installed Capacity (MW) | Assured Power (Average MW)
Hydroelectric | 7 |  | 4,833.3 |  | 1,990.3 |
Wind | 42 |  | 1,127.9 |  | 560.9 |
Copel GET (Interest) |  | Proportional installed capacity (MW) | Proporcional Assured Power (Average MW)
Hydroelectric | 1 |  | 10.4 |  | 7.3 |
Total Copel GET |  |  | 5,971.6 |  | 2,558.5 |
Other Interest Copel |  | Proportional installed capacity (MW) | Proporcional Assured Power (Average MW)
Hydroelectric | 5 |  | 201.3 |  | 109.7 |
Wind | 4 |  | 53.2 |  | 28.0 |
Solar | 1 |  | 1.1 |  | — |
Total Other Interest | 10 |  | 255.6 |  | 137.7 |
TOTAL Copel Group |  |  | 6,227.2 |  | 2,696.2 |
TRANSMISSION |  |  |  |  |  |
Copel GeT | Amount |  | APR (R$ million)
Transmission Lines (km) |  | 4,591 |  | 1,423.9
Substation (amount) |  | 46 |
Interest | Amount |  | Proporcional APR (R$ million)
Transmission Lines (km) |  | 5,093 |  | 387.4
Substation (amount) |  | 7 |
TOTAL | TL | 9,684 |  | 1,811.3
Substation | 53 |
DISTRIBUTION |  |  |  |  |  |
Distribution lines (km) | 217,385 |  | Captive customers | 5,250,309 |
Substations | 406 |  | Customers by distribution employee | 1,622 |
Installed power substations (MVA) | 12,574 | DEC (in hundredths of an hour and minute) | 7.46 |
Municipalities served | 395 | FEC (number of outages) | 4.90 |
Locations served | 1,068 |  |  |  |  |
MERCADO LIVRE |  |  |  |  |  |
Number of contracts | 1,758 |  |  |  |  |
Energy sold (GWh) | 7,270 |  |  |  |  |

49

| EXHIBIT IV - OPERATIONAL DATA > GENERATION

COPEL GET |  |  |  |
| Installed Capacity (MW) | Assured Power (Average MW) | Generation 3Q25 (GWh)* | Concession Expires
Hydroelectric Power Plants | 4,833.3 | 1,990.3 | 12,682.3 |
Large hydroelectric power plant (HPP) | 4,797.0 | 1,965.8 | 12,562.9 |
Gov. Bento Munhoz da Rocha Netto (Foz do Areia - FDA) | 1,676.0 | 567.6 | 3,286.5 | 20.11.2054
Gov. Ney Aminthas de B. Braga (Segredo) | 1,260.0 | 552.8 | 3,901.4 | 21.11.2054
Gov. José Richa (Salto Caxias) | 1,240.0 | 553.3 | 3,882.8 | 21.11.2054
Gov. Parigot de Souza (GPS) (1) | 260.0 | 103.6 | 678.2 | 06.01.2053
- Regime de Cotas (70%) | 182.0 | 72.5 | 474.7
- Copel GeT(30%) | 78.0 | 31.1 | 203.5
HPP Gov. Jayme Canet Junior (Mauá) (2) | 361.0 | 188.5 | 814.0 | 28.06.2049
Small hydroelectric power station (SHP) | 36.3 | 24.5 | 119.4 |
Bela Vista | 29.8 | 18.6 | 83.5 | 08.03.2041
Derivação do Rio Jordão ** | 6.5 | 5.9 | 35.9 | 21.06.2032
Wind Power Plants | 1,127.9 | 560.9 | 2,474.1 |
São Bento Energia, Invest. e Part. S.A. | 94.0 | 38.1 | 170.1 |
GE Boa Vista S.A. | 14.0 | 5.2 | 21.2 | 28.04.2046
GE Farol S.A. | 20.0 | 8.8 | 36.8 | 20.04.2046
GE Olho D’Água S.A. | 30.0 | 12.8 | 58.3 | 01.06.2046
GE São Bento do Norte S.A. | 30.0 | 11.3 | 53.8 | 19.05.2046
Copel Brisa Potiguar S.A. | 183.6 | 89.4 | 347.4 |
Nova Asa Branca I Energias Renováveis S.A. | 27.0 | 12.1 | 49.3 | 25.04.2046
Nova Asa Branca II Energias Renováveis S.A. | 27.0 | 11.9 | 48.5 | 31.05.2046
Nova Asa Branca III Energias Renováveis S.A. | 27.0 | 12.3 | 41.8 | 31.05.2046
Nova Eurus IV Energias Renováveis S.A. | 27.0 | 12.4 | 48.7 | 27.04.2046
Santa Maria Energias Renováveis S.A. | 29.7 | 15.7 | 57.7 | 08.05.2047
Santa Helena Energias Renováveis S.A. | 29.7 | 16.0 | 68.3 | 09.04.2047
Ventos de Santo Uriel S.A. | 16.2 | 9.0 | 33.1 | 09.04.2047
Cutia | 180.6 | 71.4 | 316.9 |
UEE Cutia S.A. | 23.1 | 9.6 | 46.3 | 05.01.2042
UEE Esperança do Nordeste S.A. | 27.3 | 9.1 | 42.8 | 11.05.2050
UEE Guajiru S.A. | 21.0 | 8.3 | 33.4 | 05.01.2042
UEE Jangada S.A. | 27.3 | 10.3 | 55.0 | 05.01.2042
UEE Maria Helena S.A. | 27.3 | 12.0 | 51.6 | 05.01.2042
UEE Paraíso dos Ventos do Nordeste S.A. | 27.3 | 10.6 | 42.5 | 11.05.2050
UEE Potiguar S.A. | 27.3 | 11.5 | 45.3 | 11.05.2050
Bento Miguel | 132.3 | 58.7 | 235.9 |
CGE São Bento do Norte I S.A. | 23.1 | 10.1 | 44.3 | 04.08.2050
CGE São Bento do Norte II S.A. | 23.1 | 10.8 | 49.3 | 04.08.2050
CGE São Bento do Norte III S.A. | 23.1 | 10.2 | 40.9 | 04.08.2050
CGE São Miguel I S.A. | 21.0 | 9.3 | 36.9 | 04.08.2050
CGE São Miguel II S.A. | 21.0 | 9.1 | 32.0 | 04.08.2050
CGE São Miguel III S.A. | 21.0 | 9.2 | 32.5 | 04.08.2050
Vilas | 186.9 | 98.6 | 399.0 |
Vila Ceará I (Antiga Vila Paraíba IV) | 32.0 | 17.8 | 69.7 | 14.01.2054
Vila Maranhão I | 32.0 | 17.8 | 70.0 | 11.01.2054
Vila Maranhão II | 32.0 | 17.8 | 70.1 | 14.01.2054
Vila Maranhão III (Antiga Vila Paraíba III) | 32.0 | 16.6 | 69.4 | 14.01.2054
Vila Mato Grosso (Antiga Vila Alagoas III) | 58.9 | 28.6 | 119.8 | 06.12.2054
Jandaira | 90.1 | 46.9 | 199.6 |
Jandaira I | 10.4 | 5.6 | 26.3 | 02.04.2055
Jandaira II | 24.3 | 12.3 | 55.4 | 02.04.2055
Jandaira III | 27.7 | 14.8 | 56.2 | 02.04.2055
Jandaira IV | 27.7 | 14.2 | 61.7 | 02.04.2055
Aventura | 105.0 | 65.0 | 304.0 |
Aventura II | 21.0 | 13.1 | 62.2 | 06.05.2053
Aventura III | 25.2 | 15.5 | 72.5 | 06.11.2053
Aventura IV | 29.4 | 18.5 | 85.2 | 06.05.2053
Aventura V | 29.4 | 17.9 | 84.1 | 06.05.2053
Santa Rosa e Mundo Novo | 155.4 | 92.8 | 501.2 |
Santa Rosa e Mundo Novo I | 33.6 | 17.3 | 91.2 | 06.04.2053
Santa Rosa e Mundo Novo II | 29.4 | 17.2 | 105.4 | 06.04.2053
Santa Rosa e Mundo Novo III | 33.6 | 21.5 | 117.1 | 06.04.2053
Santa Rosa e Mundo Novo IV | 33.6 | 21.0 | 115.4 | 06.01.2053
Santa Rosa e Mundo Novo V | 25.2 | 15.8 | 72.1 | 06.01.2053
TOTAL | 5,961.2 | 2,551.2 | 15,156.4 |
(1) The Annual Generation Revenue (RAG), totaling R$176.6 million, was updated by ANEEL’s Homologatory Resolution No. 3,506, dated July 22, 2025. A PIS/Cofins rate of 9.25% applies to this amount. However, it is important to note that, as established by ANEEL regulations, the RAG already includes the pass-through of these federal taxes to the beneficiary distribution companies. (2) Power plants exempted from concession, are only registered with ANEEL. * Considers internal consumption of generators and generation in commercial operation. ** Plant do not participate in the MRE.

50

| EXHIBIT IV - OPERATIONAL DATA > GENERATION

INTEREST |  |  |  |  |  |
Enterprise | Partners | Installed Capacity (MW) | Assured Power ¹ (Average MW) | Proportional installed capacity (MW) | Proporcional Assured Power (Average MW) | Concession Expires
Hydroelectric Power Plants |  | 400.6 | 225.9 | 211.7 | 117.2 |
Large hydroelectric power plant (HPP) |  | 365.4 | 200.6 | 197.1 | 106.4 |
HPP Santa Clara (Elejor) | COPEL - 70% Paineira Participações - 30% | 120.2 | 66.0 | 84.2 | 46.2 | 10.05.2040
HPP Fundão (Elejor) | COPEL - 70% Paineira Participações - 30% | 120.2 | 62.1 | 84.1 | 43.5 | 06.11.2040
HPP Dona Francisca (DFESA) | COPEL - 23,03% Gerdau - 53,94% Celesc - 23,03% | 125.0 | 72.5 | 28.8 | 16.7 | 09.21.2037
Small hydroelectric power station (SHP) |  | 29.1 | 20.4 | 10.4 | 7.3 |
SHP Arturo Andreoli 5 (Foz do Chopim) | COPEL GeT - 35,77% Silea Participações - 64,23% | 29.1 | 20.4 | 10.4 | 7.3 | 07.07.2034
Hydroelectric Generating Centers (CGH) |  | 6.1 | 4.9 | 4.2 | 3.5 |
CGH Santa Clara I (Elejor) | COPEL - 70% Paineira Participações - 30% | 3.6 | 2.8 | 2.5 | 2.0 | (2)
CGH Fundão I (Elejor) | COPEL - 70% Paineira Participações - 30% | 2.5 | 2.1 | 1.7 | 1.5 | (2)
Wind Power Plants |  | 108.5 | 57.1 | 53.2 | 28.0 |
Voltalia - São Miguel do Gostoso (4 parques) | COPEL- 49% Voltalia- 51% | 108.5 | 57.1 | 53.2 | 28.0 | (3)
Solar |  | 2.3 | — | 1.1 | — |
Solar Paraná 4 | COPEL - 49% Sistechne Participações Societárias Ltda. - 51% | 2.3 | — | 1.1 | — | 09.15.2046
TOTAL |  | 511.4 | 283.0 | 1,391.9 | 145.2 |
¹ Assured power updated by Ordinance No. 709/2022 of: HPP Mauá, Santa Clara, Fundão and Dona Francisca.
² Elejor requested the reclassification of its Small Hydroelectric Power Plants - (SHPs) Fundão I and Santa Clara I to Hydroelectric Generating Centers (CGHs), as amended by Art. 8 of Law 9074/1995. This was formalized through ANEEL Authorizing Resolutions 14,744 and 14,745 of 06/20/2023, with the plants exempted from concession, having only registration with ANEEL.
³ The Concession Expires of the wind farm concessions are respectively: Carnaúbas (04.09.2047), Reduto (04.16.2047), Santo Cristo (04.18.2047), São João (03.26.2047).
⁴ Holding of 6 SCPs operating in the field of distributed generation (photovoltaic plants): Pharma Solar II, Pharma Solar III, Pharma Solar IV, in commercial operation, e Bandeirantes Solar I, Bandeirantes Solar II e Bandeirantes Solar III, in pre-operational.
⁵ Extension of Grant according to REH 3.242/2023.

51

| EXHIBIT IV - OPERATIONAL DATA > TRANSMISSION

Subsidiary / SPC | Contract | Enterprise | UF | TL |  | APR ¹ (R$ milhões) | Adjustment installment (R$ millions) | Concession Expiration
Extension (km)2 | Substation | MVA
Copel GeT | 060/2001 | Several | SP/PR | 2,129 | 35 | 13,015 | 663.6 | 01.11.1900 | 01.01.2043
Copel GeT | 075/2001 | TL Bateias - Jaguariaiva | PR | 137 | — | — | 18.2 | -0.5 | 08.17.2031
Copel GeT | 006/2008 | TL Bateias - Pilarzinho | PR | 32 | — | — | 3.1 | 0.1 | 03.17.2038
Copel GeT | 027/2009 | TL Foz - Cascavel Oeste | PR | 117 | — | — | 16.9 | -0.5 | 11.19.2039
Copel GeT | 010/2010 | TL Araraquara II — Taubaté | SP | 334 | — | — | 47.7 | -1.3 | 06.10.2040
Copel GeT | 015/2010 | SE Cerquilho III | SP | — | 1 | 300 | 7.7 | -0.4 | 06.10.2040
Copel GeT | 022/2012 | TL Foz do Chopim - Salto Osório LT Londrina - Figueira | PR | 102 | — | — | 8.5 | -0.3 | 08.27.2042
Copel GeT | 002/2013 | TL Assis — Paraguaçu Paulista II | SP | 83 | 1 | 150 | 12.3 | -2.3 | 02.25.2043
Copel GeT | 005/2014 | TL Bateias - Curitiba Norte | PR | 31 | 1 | 300 | 14.0 | -0.8 | 01.29.2044
Copel GeT | 021/2014 | TL Foz do Chopim - Realeza | PR | 52 | 1 | 300 | 16.2 | 1.6 | 05.09.2044
Copel GeT | 022/2014 | TL Assis – Londrina | SP/PR | 122 | — | — | 28.1 | -1.1 | 05.09.2044
Copel GeT | 006/16 | Lot E: TL Baixo Iguaçu - Realeza; TL Uberaba - Curitiba Centro; TL Curitiba Leste - Blumenau; SE Medianeira; SE Curitiba Centro; SE Andirá leste; Other Sections | PR | 255 | 4 | 900 | 169.4 | -5.2 | 07.04.2046
Costa Oeste Copel Get - 100% | 001/2012 | TL Cascavel Norte - Cascavel Oeste TL Cascavel Norte - Umuarama Sul SE Umuarama Sul | PR | 159 | 1 | 300 | 20.7 | -0.6 | 12.01.2042
Marumbi Copel GeT - 100% | 008/2012 | TL Curitiba - Curitiba Leste | PR | 29 | 1 | 672 | 29.9 | -1 | 10.05.2042
Uirapuru Transmissora Copel GeT - 100% | 002/2005 | TL Ivaiporã - Londrina | PR | 122 | — | — | 28.9 | -1 | 04.03.2035
Mata de Santa Genebra³ Copel GeT - 100% | 001/14 | TL Araraquara II - Bateias | SP/PR | 887 | 1 | 3,600 | 338.7 | -10.7 | 05.14.2044
Subtotal Copel GeT |  |  |  | 4,591 | 46 | 19,537 | 1423.9 | -11.7 |
Caiuá Transmissora Copel GeT - 49% Elecnor - 51% | 007/2012 | TL Guaíra - Umuarama Sul TL Cascavel Norte - Cascavel Oeste SE Santa Quitéria / SE Cascavel Norte | PR | 142 | 2 | 700 | 17.9 | -0.3 | 10.05.2042
Integração Maranhense Copel GeT - 49% Elecnor - 51% | 011/2012 | TL Açailandia - Miranda II | MA | 365 | 0 | 0 | 27.0 | -0.9 | 10.05.2042
Matrinchã Copel GeT - 49% State Grid - 51% | 012/2012 | TL Paranaíta - Ribeirãozinho | MT | 2,033 | 4 | 800 | 146.2 | -4.7 | 10.05.2042
Guaraciaba Copel GeT - 49% State Grid - 51% | 013/2012 | TL Ribeirãozinho - Marimbondo | GO/MG | 930 | 1 | — | 75.5 | -2.7 | 10.05.2042
Paranaíba Copel GeT - 24,5% Furnas - 24,5% State Grid - 51% | 007/2012 | TL Barreiras II - Pirapora II | GO/MG | 967 | — | — | 50.2 | -1.8 | 02.05.2043
Cantareira Copel GeT - 49% Elecnor - 51% | 19/2014 | TL Estreito - Fernão Dias | MG/SP | 656 | 0 | 0 | 70.6 | -2.4 | 05.09.2044
Subtotal SPCs 4 |  |  |  | 5,093 | 7 | 1,500 | 387.4 | -12.80 |
Total |  |  |  | 9,684 | 53 | 21,037 | 1,811.3 | -24.50 |
1 Proportional to Copel's interest in the project. Values referring to the 2025/2026 cycle, effective from July 1, 2025, according to REH 3.481/2025. RAP values consider Active RAP, which is the portion of RAP referring to assets in operation at the beginning of the tariff cycle. ² Considers double circuit sections (circuits that share the same transmission tower). ³ Transmission line in the process of consolidation, according to Material Fact 03/25. 4 Equity Income.

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| EXHIBIT IV - OPERATIONAL DATA > DISTRIBUTION

OPERATIONAL DATA |  |  |  |  |
Number of Consumers | Locations served | Cities served | Voltage | Number of Substations | MVA | Km of lines
5,257,290 | 1,068 | 395 | 13,8 kV | — | — | 115,533
34,5 kV | 237 | 1,815 | 93,667
69 kV | 36 | 2,519 | 755
88 kV | 0 | 5 | —
138 kV | 133 | 8,235 | 7,430
|  |  |  | 406 | 12,574 | 217,385
Consumer-to-employee ratio DIS | 2020 | 2021 | 2022 | 2023 | 2024 | set/25
Captive Consumers | 4,835,852 | 4,926,608 | 5,011,555 | 5,098,006 | 5,184,322 | 5,250,309
Copel Dis employees | 4,641 | 4,430 | 4,257 | 4,257 | 3,199 | 3,092
Consum/Emp | 1,042 | 1,112 | 1,177 | 1,198 | 1,621 | 1,698
QUALITY OF SUPPLY |  |  |  |  |
| Year | DEC ¹ (hours) | FEC ² (outages) |  |  |
| 2020 | 7.83 | 5.61 |  |  |
| 2021 | 7.47 | 5.09 |  |  |
| 2022 | 7.96 | 5.10 |  |  |
| 2023 | 7.97 | 5.41 |  |  |
| 2024 | 7.92 | 5.36 |  |  |
| Sep-25 | 7.46 | 4.90 |  |  |
¹ DEC measured in hours and hundredths of an hour ² FEC expressed in number of interruptions and hundredths of a number of interruptions year to date * Values of the last 12 months |  |  |
Period | Technical Loss | Non-Technical Loss | Total loss
Regulatory (1) | Real (2) | Regulatory (3) | Calculated (4) | Regulatory (5) | Total (6)
Sep-21 | 5.79 % | 5.91 % | 4.47 % | 4.48 % | 7.71 % | 7.71 %
Sep-22 | 5.79 % | 5.73 % | 4.47 % | 4.22 % | 7.63 % | 7.53 %
Sep-23 | 5.79 % | 5.85 % | 4.47 % | 4.71 % | 7.57 % | 7.67 %
Sep-24 | 5.79 % | 5.68 % | 4.47 % | 5.33 % | 7.57 % | 7.91 %
Sep-25 | 5.79 % | 5.75 % | 5.29 % | 3.41 % | 8.15 % | 7.31 %
(1) Percentage established in the tariff review;
(2) Technical loss calculated and reported monthly to Aneel;
(3) Percentage established in the tariff review;
(4) Difference between reported total losses and technical losses calculated as a percentage established in the review and the total injected energy, also reported monthly to Aneel;
(5) (Regulatory percentage of PNT x informed BT Market + technical losses calculated as a percentage established in the review and the total energy injected) / Injected energy;
(6) Total loss on injected energy.
NOTE: In the calculation of the distributor's total losses, energy losses inherent to the electric power system (technical losses), commercial losses (mainly due to fraud, theft) and differences related to the shift in the billing schedule and the effects of the portion of mini and micro generation distributed in the Company's network

53

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 12, 2025

COMPANHIA PARANAENSE DE ENERGIA – COPEL
By: | /S/ Daniel Pimentel Slaviero |
| Daniel Pimentel Slaviero Chief Executive Officer |

FORWARD-LOOKING STATEMENTS

This press release may contain forward-looking statements. These statements are statements that are not historical facts, and are based on management's current view and estimates of future economic circumstances, industry conditions, company performance and financial results. The words "anticipates", "believes", "estimates", "expects", "plans" and similar expressions, as they relate to the company, are intended to identify forward-looking statements. Statements regarding the declaration or payment of dividends, the implementation of principal operating and financing strategies and capital expenditure plans, the direction of future operations and the factors or trends affecting financial condition, liquidity or results of operations are examples of forward-looking statements. Such statements reflect the current views of management and are subject to a number of risks and uncertainties. There is no guarantee that the expected events, trends or results will actually occur. The statements are based on many assumptions and factors, including general economic and market conditions, industry conditions, and operating factors. Any changes in such assumptions or factors could cause actual results to differ materially from current expectations.