Slides
Page 1
ENGIE RESULTS PRESENTATION . 2026 August 5 , 2026 ENGIE Brasil Energia S.A.
Page 2
1 2 3 4 5 2Results Presentation 2Q26 This publication may include forward-looking statements on events or results pursuant to Brazilian and international securities’ regulations. These forward-looking statements are based on certain assumptions and analyzes made by ENGIE Brasil Energia S.A. (“ENGIE Brasil Energia” or “Company”), in accordance with its experience and the economic scenario, market conditions and expected events, many of which are outside the control of ENGIE Brasil Energia. Important factors which can lead to significant differences between effective results and the forward-looking statements with respect to events or results, include the business strategy of ENGIE Brasil Energia, economic and international conditions, technology, financial strategy, development of the government services industry, hydrological conditions, conditions in the financial markets, uncertainty surrounding the results of its future operations, plans, objectives, expectations and intentions and other factors. In the light of these factors, the effective results of ENGIE Brasil Energia may differ significantly from those indicated or implicit in the forward-looking statements with respect to events or results. The information and opinions contained herein should not be understood as a recommendation to potential investors and no investment decision should be based on the veracity, topicality or completeness of this information or these opinions. None of the advisors to ENGIE Brasil Energia or the parties related thereto, or their representatives shall accept responsibility for any losses, which may occur as a result of the use or the content in this presentation. This material includes forward-looking statements as to events subject to risks and uncertainties, which based on existing expectations and forecasts on future events and tendencies, may affect the businesses of ENGIE Brasil Energia. These forward-looking statements include forecasts of economic growth and energy supply and demand as well as information on competitive position, the regulatory environment, growth potential opportunities and other matters. Innumerous factors can affect adversely the estimates and assumptions on which these statements are based. Disclaimer
Page 3
1 2 3 4 5 3Results Presentation 2Q26 CONTENTS 01 Highlights and ESG KPIs 02 Operating Highlights 03 Financial Performance 08 04 13 04 Expansion 05 Supporting Data 28 22
Page 4
01 HIGHLIGHTS AND ESG KPIs
Page 5
1 2 3 4 5 5Results Presentation 2Q26 Highlights Total Offering Amount: R$ 8.36 billion At the EGM held on July 2nd, the valuation report and the value of the Jirau Energia shares, for capital contribution purposes, were approved exclusively by the minority shareholders. Value assigned: R$ 5.74 billion Minority Shareholders' Participation: R$ 2.62 billion On July 17th, the settlement of the 274,082,684 shares issued as part of the Public Offering was completed, and the Company now holds a direct 40% equity interest in Jirau Energia. On June 10th, the Board of Directors approved the execution of a Primary Public Offering of Shares and the convening of an Extraordinary General Meeting (EGM) to approve the valuation assigned to the Jirau Energia shares held by the controlling shareholder. Primary Share Offering (EGIE3 Follow-on): Interim Dividends: R$ 770.8 million (R$ 0.5442 per share), corresponding to 55% of distributable net income in 1H26, excluding the financial gain from the renegotiation of the Use of Public Asset (UBP). • Ex-dividend date: August 21, 2026. • Payment date to be announced in due course. In 2Q26, the Company recognized its participation in the Public Asset Use (UBP) renegotiation mechanism, regarding future obligations associated with the Cana Brava and Ponte de Pedra hydroelectric power plants (HPPs). The financial settlement was completed on July 20th, with a total payment of BRL 2.23 billion. At the Extraordinary General Meeting (EGM) held on July 31 st, the merger of the Company's wholly owned subsidiary, Companhia Energética do Jari - CEJA, into the Company was approved to streamline the corporate structure. 40% stake in Jirau Energia
Page 6
6Results Presentation 2Q26 1 2 3 4 5 | Adjusted Ebitda1 (R$ million) | Adjusted Net Income (R$ million) Main drivers of the result vs . 2Q25 Note: 1Adjusted Ebitda: net income + income tax and social contribution + financial result + depreciation and amortization + non-recurring. Highlights Generation Segment R$ 269 million R$ 89 million R$ 69 million R$ 25 million Income Taxes Result of Equity Income (TAG) R$ 69 million Transmission Segment R$ 113 million Depreciation and amortization Financial Result
Page 7
7Results Presentation 2Q26 1 2 3 4 5 ESG KPIs *Nº of accidents / millions of hours of exposure to the risk*Source: Ministry of Science, Technology and Innovation | Emissions intensity1 (tCO2e/MWh) | Investments in Innovation2 (R$ million) | Health and Safety – Frequency rate (own employees + service providers)* | Gender distribution in leadership positions (%) | Engaged People – “Conexão” Community Relationship Program| Social Responsibility Investments (R$ million) Notes: 1 Emissions data are subject to revision upon completion of the annual emissions inventory consolidation. 2 As of 2026, investments are reported on an actual basis, replacing the previously adopted accrued amount methodology.
Page 8
02 OPERATING HIGHLIGHTS
Page 9
9 1 2 3 4 5 Results Presentation 2Q26 Generating and Transmission Uptime Operational excellence in generation and transmission assets Note: Considering programmed and forced stoppages.
Page 10
10 1 2 3 4 5 Results Presentation 2Q26 Energy Generation Increase in solar generation driven by organic growth Hydro generation from MRE higher than 2Q25, measured by GSF’ 1 Note: 1GSF’: without the effects of seasonality of the agents. | Generating Scaling Factor ( GSF’ ) | Generation by Complementary Source (avg MW)
Page 11
11 1 2 3 4 5 Results Presentation 2Q26 | % of Curtailment over Generation – 2Q26 (avg MW) | % of Curtailment* per source 2Q25 2Q26 Wind Solar Total Wind Solar Total ENGIE 12% 26% 16% 17% 27% 20% SIN 11% 26% 15% 15% 29% 19% Source: ENGIE Brasil Energia internal study based on premises disclosed by ONS and subject to updates. Energy Generation: Curtailment 2Q26 curtailment was 4 p.p. above 2Q25. Curtailment compensation: (MME Ordinance No. 140/2026, published on July 21, 2026) Eligible period: September 1, 2023 to November 25, 2025; Compensation: external unavailability and electrical reliability; Commitment agreement: 20-day period to indicate preliminary interest.
Page 12
12 1 2 3 4 5 Results Presentation 2Q26 Energy Commercial Strategy | Uncontracted energy compared to the availability of a given period 4,981 (+21.7% compared to 2Q25) Consumer Units served in 2Q262 2,790 (+42.3% compared to 2Q25) Number of free consumers in 2Q262 Evolution of the number of free customers and consumer units Notes: 1 Indicative commercial hedge, subject to fluctuation depending on market conditions. 2 Considers all consumer units with active contracts. Gradual sale of energy, with hedge preservation for portfolio risk protection | Energy Balance (% of total; in avg MW) as of June 30, 2026 1
Page 13
03 FINANCIAL PERFORMANCE
Page 14
14 1 2 3 4 5 Results Presentation 2Q26 Net Operating Revenue Change Net Operating Revenue (R$ million) Generation and portfolio sale Trading Transmission
Page 15
15 1 2 3 4 5 Results Presentation 2Q26 | TAG’s Net Income Change (R$ million) Result of Equity Income Contribution of the Result from Transportadora Associada de Gás (TAG) to the Ebitda of the Company Stake of 17.5% in TAG, resulting in the contribution of R$ 130 million through equity income to the Company’s Ebitda in 2Q26. Contribution to Ebitda130(69)199
Page 16
16 1 2 3 4 5 Results Presentation 2Q26 Notes: 1 Considering the result from generation and trading segments. *IFRS: International Financial Reporting Standards Adjusted Ebitda: net income + income tax and social contribution + financial result + depreciation and amortization + non-recurring. Ebitda Change Ebitda (R$ million) Generation and trading1 Equity Income (TAG) Transmission
Page 17
17Results Presentation 2Q26 1 2 3 4 5 Public Asset Use (UBP) Renegotiation On July 20th, the settlement of the renegotiated outstanding UBP payments related to the Cana Brava and Ponte de Pedra hydropower concessions was completed. Value creation | Key milestones: ✓ April 16: Board of Directors approval ✓ April 30: Formal adherence ✓ June 8: Execution of the Amendment Agreement ✓ July 20: Financial settlement R$ 4.2 billion Updated outstanding balance 1 R$ 2.2 billion Renegotiated balance settled 2 Notes: 1 The December 2025 balance reflects the liability adjusted by the SELIC rate, less payments made during the period. 2 The final payment was settled on July 16th, 2026 (UHPP) and July 20th, 2026 (UHCB). R$ 105 million/year Payment maintained R$ 773 million/year Payment settled Taxes: R$ 0.7 billion Net Gain: R$ 1.3 billion
Page 18
18 1 2 3 4 5 Results Presentation 2Q26 Net Income Change (R$ million) Non - recurring in 2Q26 due to the UBP capital gain, net of taxes.
Page 19
19 1 2 3 4 5 Results Presentation 2Q26 Balanced Debt Notes: 1 Gross debt, net of hedge operations. 2 Adjusted Ebitda in the past 12 months. With no currency exposure | Debt Overview (R$ million) Debt control ensure balanced levels of the Net Debt/Ebitda ratio. successful investment decisions active management of debt costs + + (R$ million) Total Debt / Ebitda2 Local Currency Debt1 Net Debt / LTM Adjusted Ebitda2Total Debt / LTM Adjusted Ebitda2 25,210 20,905 24,442 29,329 32,152 6,449 492 2023 2024 2025 2Q26 Cash and equivalents Escrow deposits Net Debt 2Q26 2.9x 3.3x 3.8x 3.9x 2.1x 2.7x 3.3x 3.1x
Page 20
20 1 2 3 4 5 Results Presentation 2Q26 Debt Profile and Composition Indexation of energy sales contracts mitigates exposure of debt to IPCA and cash position mitigates part of CDI exposure. 2Q26: Nominal cost of debt: 11.3% p.a. (equivalent to IPCA + 6.4%) Average debt term: 7.1 years 2Q25: 11.8% p.a. (equiv. to IPCA + 6.1%) AAA rating and robust cash generation translate into competitive costs of debt for financing growth | Maturity Debt Schedule as from June 30, 2026 (R$ million) Debt breakdown IPCA CDI TJLP 53.9% 39.9% 6.2% PRE
Page 21
21 1 2 3 4 5 Results Presentation 2Q26 Notes: 1 Assuming a payout ratio equivalent to 100% of adjusted distributable net income, excluding the hydrological risk renegotiation effects. 2 For comparability purposes, the dividend per share has been adjusted to reflect the stock bonus issues approved on December 7, 2018, and November 5, 2025. 3 Based on the year's distributable net income. 4 Based on the volume-weighted closing price of the common shares during the period. 5 Payout ratio equivalent to 55% of distributable net income (excluding gains from the partial disposal of investments in TAG). 6 Payout ratio equivalent to 55% of distributable net income (excluding the financial gain from the UBP renegotiation). 5 1 By-law minimum payout: 30% of distributable net income Frequency: biannual Management Commitment: minimum payout of 55% of distributable net income Dividend per Share2 (R$) Payout3 Dividend Yield4 Dividend Policy 6 6.1% 8.6% 9.2% 3.5% 5.7% 6.2% 8.1% 5.6% 5.6% 4.2% 1.6% | Dividends (based on distributable net income)
Page 22
04 EXPANSION
Page 23
23 1 2 3 4 5 Results Presentation 2Q26 Jirau HPP: completion of the transfer process • The Board of Directors authorized the commencement of feasibility studies for a potential transfer transaction; • Establishment of the Independent Special Committee for Related-Party Transactions; • Studies and analyses conducted to assess the most appropriate structure for the transfer of Jirau Energia shares. • Recommendation issued by the Special Committee for Related-Party Transactions. Dec/25 – Jun/26 Share Offering June 10th: Transaction approved by the Board of Directors and Extraordinary Shareholders' Meeting convened; July 2nd: Extraordinary Shareholders' Meeting approved the Valuation Report, exclusively by the minority shareholders; July 14–17th: Pricing and settlement of the Share Offering, and completion of the transfer transaction Process focused on governance and transparency Strategic and Economic Rationale • Aligned with the Company's hydropower generation expansion strategy; • Fully operational asset with immediate earnings contribution. • Contribution through the equity method (40% stake); • Strengthening of the Company's capital structure and leverage management. • Enhances the longevity of the Company's asset portfolio.
Page 24
24 1 2 3 4 5 Results Presentation 2Q26 Notes: 1 Subject to final settlement and accounting by the CCEE. 2 MME Ordinance No. 2,946 established new firm energy certificate amounts for Jirau HPP of 2,222.6 aMW for operations at the expanded 90-meter level and 2,335.1 aMW for operations at the constant 90-meter level. Of the total increase, one-third is allocated to the Government of Bolivia. Accordingly, the share attributable to Brazil corresponds to 2,182.2 aMW (expanded level) and 2,257.2 aMW (constant level). 3 Concession term extended until August 16, 2047, as approved by Aneel on July 14, 2026, pursuant to Homologatory Resolution No. 3,598. | PPAs portfolio³ (avg MW) Installed Capacity: 3,750 MW 50 Generating Units Physical Guarantee2: 2,182 aMW 90m expanded 2,257 aMW 90m constant 75 MW each GU Shareholding Structure: as of July 17, 2026 Uptime Ratio (FID) in 2Q26: 100%1 | Gross Generation (avg MW) Brasil Energia S.A. 40% 40% 2 0% AXIA Energia MITSUI & CO. Hydropower asset with long - term contracted revenues Concession term extended until 2047 Jirau HPP: operating data
Page 25
25 1 2 3 4 5 Results Presentation 2Q26 Capacity Reserve Auction: Jaguara HPP Jaguara HPP (MG) Current installed capacity: 424 MW Commercial capacity: 324 MW Concession period: June 2048 Notes: 1 Baseline: September 2025 (annual adjustment in August based on the IPCA). 2 Baseline: March 2026. Increase of installed capacity: +232 MW (2 turbines of 116 MW) Technical features: • 70% of commercial capacity under quota regime (ACR), free of GSF. • 30% of commercial capacity directed to the Free Contracting Environment (ACL). MG BA ES Value generation in a hydropower asset with regulated revenue Auction features Power capacity contracted (MW) 195.78 MW Contract term 15 years Beginning of operation August 2030 Annual fixed revenue R$ 270.4 million1 Estimated Capex R$ 1.2 billion2 Expansion of Jaguara HPP aligned with the Company’s strategy to invest in high- performance assets with 100% clean energy. Jaguara HPP Start of activities related to the executive project.
Page 26
26 1 2 3 4 5 Results Presentation 2Q26 Key technical features: • construction of ~738 km length (6 new transmission lines) and 2 new substations; • brownfield section: operation of 4 existing lines (162 km) and 2 own substations • 47 municipalities. Contracted RAP1: R$ 281.0 million Capex Aneel2: R$ 2,933.6 million Concession period : 30 years Deadline to start operation: December 2029 (60 months) Graúna Transmissora de Energia (SC, PR, SP, MG, ES) Transmission Projects Under Implementation Asa Branca Transmissora de Energia (BA, MG, ES) LT 500kV Morro do Chapéu II – Poções III section (BA), with 334 kilometers of length was energized on November 26, 2025, representing 32.3% of total RAP. In 2Q26, the full Installation License was obtained, enabling the start of civil works related to the transmission lines and substation expansion projects. Contracted RAP1: R$ 296.0 million Capex Aneel2: R$ 2,667 million Concession period: 30 years Deadline to start operation: March 2029 (66 months) Notes: 1 Value as of June/26. 2 Value as of December/22. Key technical features: • estimated length of 1,000 Km; • 4 transmission lines of 500 kV single-circuit, crossing 60 municipalities in the states of Bahia, Minas Gerais and Espírito Santo. Notes: 1 Valor as of June/25. 2 Valor as of December/22. In 2Q26, the Preliminary License was obtained for the section subject to licensing by Santa Catarina's environmental authority. Mobilization notices issued to initiate expansion works at the existing Jaguara 345 kV and Araxá III 345 kV substations. BA MG ES SP PR Graúna Graúna SC Asa Branca under implementation under operation Graúna: 5% of RAP Asa Branca: 32.3% of RAP Asa Branca
Page 27
27 1 2 3 4 5 Results Presentation 2Q26 Transmission Project Under Implementation Colibri (SC, PR, CE, RN) Contracted RAP1: R$ 122.8 million Capex Aneel1: R$ 1,574.7 million Concession period: 30 years Note: 1 Value as of August/25. Deadline to start operation: December 2029 (42 months) Key technical features: • Lot 2: construction of one 230 kV transmission line, approximately 143 km length. • Sublots 3A–3B–3C–3D: installation of five synchronous condensers. Colibri Transmissora de Energia (Auction 01/2026) SC PR Sinergy: • The transmission line connects to the Ponta Grossa Substation (Gralha Azul) Colibri Sul (Lot 2): 143Km 3-A (RN): 1 synchronous compensator 3-B (CE): 1 synchronous compensator 3-C (CE): 2 synchronous compensators 3-D (RN): 1 synchronous compensator Colibri A, B, C, D (Sublots 3) RNCE Relevant local and operational synergies with Company’s other assets. The Concession Agreement was signed on June 26th, 2026.
Page 28
05 SUPPORTING DATA
Page 29
29 1 2 3 4 5 Results Presentation 2Q26 Resilient Financial Performance Notes: ENGIE Brasil Energia internal study based on the Company’s Financial Statements. 1 ROE: net income of the past 4 quarters / shareholders’ equity. Adjusted ROE net of non-recurring. 2 ROIC: effective tax rate x EBIT / invested capital (invested capital: debt – cash and cash equivalents – deposits earmarked for debt servicing + SE). Adjusted ROIC net of non-recurring. 3 Nominal amount. Good portfolio management and diversification into other regulated segments, such as transmission, natural gas transportation and energy contracts in the ACR, result in stability and predictability of results. Recent Capex cycle linked to renewables and transmission expansion still not fully contributing to Ebitda. Adjusted Ebitda: +141% Adjusted Net Income: +74% Dividends and Interest on Equity: R$ 18.9 billion From 2016 – 2025 3 | Adjusted Ebitda breakdown: | ROE1 – Adjusted Return on Equity (%) | ROIC2 – Adjusted Return on Invested Capital (%) Amounted to R$ 44.2 billion, with 79% leverage Investments: 3,205 km under operation and 6 own substations Transmission: Total: +52% Value creation in the gas segment, through TAG Renewable: +79% Proprietary installed capacity: 2016 6M262025
Page 30
30 1 2 3 4 5 Results Presentation 2Q26 Key Performance Indicators Notes: 1 Ebitda: net income + income tax and social contribution + financial result + depreciation and amortization. 2 Adjusted Ebitda represents: net income + income tax and social contribution + financial result + depreciation and amortization + impairment + non-recurring. 3 Adjusted Ebitda, less the effects of IFRS in the transmission segment and quota plants. 4 ROE: adjusted net income of the past 4 quarters/ shareholders’ equity. 5 ROIC: effective tax rate x adjusted EBIT / invested capital (invested capital: debt – cash and cash equivalents – deposits earmarked for debt servicing + SE). 6 Adjusted amount, net of gains from hedge operations. 7 Total electricity output from the plants operated by ENGIE Brasil Energia. 8 Disregarding sales for quotas regime (Jaguara and Miranda HPPs). 9 Net of taxes, exports and trading operations. Consolidated (in R$ million) 2Q26 2Q25 Chg. 6M26 6M25 Chg. Net Operating Revenue (NOR) 3,511 3,086 13.8% 6,920 6,100 13.4% Results from Operations (EBIT) 1,761 1,541 14.3% 3,626 3,262 11.2% Ebitda 1 2,179 1,871 16.5% 4,427 3,915 13.1% Adjusted Ebitda 2 2,179 1,866 16.8% 4,423 3,906 13.2% Adjusted Ebitda by transmission and quota effects 3 1,939 1,715 13.1% 4,027 3,523 14.3% Ebitda / NOR - (%) 1 62.1 60.6 1.5 p.p. 64.0 64.2 -0.2 p.p. Adjusted Ebitda / NOR - (%) 2 62.1 60.5 1.6 p.p. 63.9 64.0 -0.1 p.p. Net Income 1,962 567 246.0% 2,754 1,394 97.6% Adjusted Net Income 694 564 23.0% 1,483 1,387 6.9% Adjusted Return on Equity (ROE) 4 18.3 23.1 -4.9 p.p. 18.3 23.1 -4.9 p.p. Adjusted Return on Invested Capital (ROIC) 5 13.9 15.4 -1.5 p.p. 13.9 15.4 -1.5 p.p. Net Debt 6 25,210 21,561 16.9% 25,210 21,561 16.9% Gross Power Production (avg MW) 7 4,355 4,088 6.5% 5,093 4,736 7.5% Energy Sold (avg MW) 8 4,852 4,254 14.1% 4,878 4,346 12.2% Average Net Sales Price (R$/MWh) 9 208.28 217.01 -4.0% 212.38 215.50 -1.4% Number of Employees - Total 1,402 1,265 10.8% 1,402 1,265 10.8% EBE Employees 1,366 1,240 10.2% 1,366 1,240 10.2% Employees on Under Construction Plants 36 25 44.0% 36 25 44.0%
Page 31
31 1 2 3 4 5 Results Presentation 2Q26 Hydro Power Plants Installed Capacity (MW) Commercial Capacity (aMW) 1 Salto Santiago 1,420.0 702.2 2 Itá 1,126.91 528.71 3 Salto Osório 1,103.7 487.3 4 Cana Brava 450.0 247.8 5 Estreito 435.61 244.11 6 Jaguara 424.0 324.0 7 Miranda 408.0 188.3 8 Santo Antonio do Jari 393.0 211.3 9 Machadinho 414.81 143.71 10 São Salvador 243.2 140.8 11 Passo Fundo 226.0 107.5 12 Cachoeira Caldeirão 219.0 123.3 13 Ponte de Pedra 176.1 127.6 Total 7,040.2 3,576.6 Gas Pipelines Length Compression Substations 39 Transportadora Associada de Gás (TAG) ~4,600 Km 11 Transmission Length Substations 34 Gralha Azul 909 km 5 new and expansion of 5 existing 35 Novo Estado 1,800 km 1 new and expansion of 3 existing 36 Gavião Real - New yard in 1 existing 37 Graúna – operational 162 km 2 existing 38 Asa Branca – operational 334 km Expansion of 2 associates Total 3,205 km Complementary Plants Installed Capacity (MW) Commercial Capacity (aMW) 14 Serra do Assuruá Complex (Wind) 846.0 410.2 15 Assú Sol Complex (Solar) 752.7 229.6 16 Santo Agostinho I Complex (Wind) 434.0 224.2 17 Campo Largo II Complex (Wind) 361.2 192.5 18 Umburanas Complex (Wind) 360.0 213.3 19 Campo Largo I Complex (Wind) 326.7 166.5 20 Trairi Complex (Wind) 212.6 97.2 21 Lar do Sol Complex (Solar) 198.0 49.02 22 Paracatu (Solar) 132.0 34.0 23 Juazeiro Complex (Solar) 120.0 34.8 24 Sertão Solar Complex (Solar) 94.6 26.1 25 Floresta (Solar) 86.0 25.1 26 Sol do Futuro Complex (Solar) 81.0 16.2 27 Ferrari (Biomass) 72.5 12.4 28 São Pedro Complex (Solar) 54.0 16.0 29 Assú V (Solar) 34.0 9.2 30 Rondonópolis (SHP) 26.6 14.0 31 José G. da Rocha (SHP) 24.4 9.2 32 Nova Aurora (Solar) 3.0 0.2 33 Tubarão (Wind) 6.3 0.3 Total 4,225.6 1,780.1 Notes: 1 Portion owned by ENGIE Brasil Energia. 2 Lar do Sol Photovoltaic Complex does not have a declared physical guarantee, therefore its commercial capacity is based on expected generation. Own installed capacity of energy Generation of 11,266 MW (5,376 aMW) 3,205 Km of transmission lines under operation Stake of 17.5% in TAG Hydro Complementary Transmission TAG 32 332 11 9 3 1 34 27 6 7 22 21 37 38 39 2423 14 17 18 28 19 4 10 13 3130 35 36 5 8 12 39 20 26 25 15 16 29 Diversified Portfolio of Assets as of June 30, 2026
Page 32
32 1 2 3 4 5 Results Presentation 2Q26 ~779 MW + ~609 MW Projects under construction Transmission Asa Branca Transmissora de Energia – BA/MG/ES Length: ~1,000 Km Graúna Transmissora de Energia – SC/PR/SP/MG/ES Length: ~732 Km Projects under development Santo Agostinho Wind Complex (Phase II) – RN Installed capacity: 279 MW Santo Agostinho Photovoltaic Complex – RN Installed capacity: ~509 MW Umburanas Wind Complex (Phase II) – BA Installed capacity: 250 MW Campo Largo Wind Complex (Phase III) – BA Installed capacity: 250 MW Alvorada Photovoltaic Complex - BA Installed capacity: ~100 MW B B A A B 5 43 1 2 1 2 3 4 5 ~1,388 MW Colibri Transmissora de Energia – SC/PR/CE/RN Length: ~143 Km (SC/PR) 5 synchronous compensators (CE/RN) C C C Generation LRCAP – Jaguara HPP Expansion - MG Capacity: +232 MW D D Expansion C
Page 33
33 1 2 3 4 5 Results Presentation 2Q26 (in average MW) 2026 2027 2028 2029 2030 Own Resources 5,169 5,202 5,202 5,202 5,161 Auction Reference Gross Price Net Price of + Purchases for Resale 800 527 381 232 248 Gross Price Date Adjusted PIS/COFINS/P&D = Total Resources (A) 5,969 5,729 5,583 5,434 5,409 (R$/MWh) (R$/MWh) (R$/MWh) Government Auction Sales2 2,178 2,347 2,433 2,249 2,163 2005-NE-2010-30 200 200 200 200 200 115.1 Dec-05 337.4 303.1 2006-NE-2009-30 493 493 493 493 493 128.4 Jun-06 370.2 332.6 2006-NE-2011-30 148 148 148 148 148 135.0 Nov-06 386.4 347.2 2007-NE-2012-30 256 256 256 256 256 126.6 Oct-07 348.5 313.1 Proinfa 19 19 19 19 19 147.8 Jun-04 407.4 392.5 2014-NE-2019-25 10 10 10 10 10 206.2 Nov-14 391.5 377.2 2014-NE-2019-20 82 82 82 82 82 139.3 Nov-14 256.0 232.3 2015-NE-2018-20 46 46 46 46 46 188.5 Aug-15 321.0 291.3 8th Reserve Energy Auction (Assú V/Floresta/Paracatu/Juazeiro/Sol do Futuro) 119 119 119 119 119 298.2 Nov-15 493.5 447.9 7th Reserve Energy Auction (São Pedro) 15 15 15 15 15 301.8 Nov-15 515.3 467.7 2017-NE-2019-20 48 48 48 48 48 136.4 Nov-14 256.5 232.8 2017-NE-2021-20 (Sertão Solar) 27 27 27 27 27 189.5 Nov-14 218.1 197.9 2024-EE-2025-2 15 - - - - 162.6 - 162.6 147.6 2012-EN-2017-30 151 151 151 151 151 95.3 Dec-12 192.5 174.7 2010-EN-2015-30 190 190 190 190 190 104.0 Dec-10 243.5 220.9 2025-EE-2027-3 - 184 270 86 - 207.7 Nov-25 207.7 188.5 Government Auction - Quotas regime 2018 - Quotas (UHJA) - 2018-30 227 227 227 227 227 - Jul-17 220.0 209.9 2018 - Quotas (UHMI) - 2018-30 132 132 132 132 132 - Jul-17 253.0 241.3 + Bilateral Sales 3,160 2,539 1,959 1,208 1,050 = Total Sales (B) 5,338 4,886 4,392 3,457 3,213 - Commercial hedge 572 572 572 572 572 Balance (A - B) 59 271 619 1,405 1,624 Sales Average Price (R$/MWh) (net)3,4: 244.1 232.2 239.8 Purchases Average Price (R$/MWh) (net)5: 214.7 195.4 174.1 Energy Balance as of June 30, 2026 Diversified contracting with duration of about 13 years in ACR and 3 years in ACL 1 2 XXXX-YY-WWWW-ZZ, where: XXXX -> year of auction YY -> EN = existing energy or EN = new energy WWWW -> year of delivery start ZZ -> supply contract duration (in years) 1 Average term weighted by the amount of energy sold, including trading operations. 3 Sales price, including trading operations, net of ICMS and taxes over revenue (PIS/Cofins, R&D), i.e. future inflation is notbeing considered. 4 Disregarding sales for quotas regime (Jaguara and Miranda HPPs). 5 Purchase net price, considering trading operations and benefits from PIS/Cofins credits, i.e. future inflation is not being considered. Notes: • The balance refers to the settlement point (net of losses and internal consumption of the plants). • The average prices are considered simply estimates and are based on financial planning revisions, not capturing volume changes, which are updated quarterly.
Page 34
34 1 2 3 4 5 Results Presentation 2Q26 Note: 1Does not consider employees posted to projects under construction. Headcount 1 | Number of employees | By gender | By academic qualification| By age group
Page 35
35 1 2 3 4 5 Results Presentation 2Q26 Sustainability KPIs Theme Unit of measurement Performance 2Q26 Performance 2Q25 Change Performance 6M26 Performance 6M25 Change Emissions intensity by energy generation (Scope 1, 2 and 3) tonCO2e/MWh 0.0022 0.0027 -17.6% 0.0015 0.0022 -33.5% Emissions intensity by revenue tCO2e/million R$ 6.0 7.5 -20.0% 4.7 7.3 -35.6% Total emissions (Scope 1, 2 and 3) Tons 20,913.3 23,231.5 -10.0% 32,506.7 44,596.8 -27.1% Water consumption intensity m3/MWh 0.030 0.058 -47.9% 0.019 0.034 -43.0% Engaged people - "Conexão" Community Relationship Program 1 People 25,171 29,622 -15.0% 42,846 43,311 -1.1% Frequency rate - Direct employees + service providers nº accid/million hours 0.976 0.212 0.76 p.p. 1.041 0.324 0.72 p.p. Frequency rate - Direct employees nº accid/million hours 0.000 0.000 0.00 p.p. 0.787 0.000 0.79 p.p. Frequency rate - Service providers nº accid/million hours 1.412 0.243 1.17 p.p. 1.167 0.369 0.80 p.p. % of employees formally trained % 70.6% 19.2% 51.4 p.p. 85.4% 99.4% -14.0 p.p. Turnover rate % 2.0% 2.1% -0.2 p.p. 4.4% 3.2% 1.2 p.p. Voluntary turnover rate % 0.9% 1.3% -0.4 p.p. 2.0% 1.7% 0.3 p.p. Investments in Social Responsibility - Incentivized Resources R$ 713,000 3,976,751 -82.1% 3,063,290 5,000,751 -38.7% Investments in Social Responsibility - Own Resources R$ 878,694 1,183,310 -25.7% 2,152,798 2,687,139 -19.9% Investment in Innovation 2 R$ 14,601,018 16,106,338 -9.3% 27,875,979 29,790,316 -6.4% Headcount Employees 1,366 1,215 12.4% 1,366 1,215 12.4% % of employees in certified operations (ISO 9.001, 14.001, 45.001) % 78.8% 84.4% -5.7 p.p. 78.8% 84.4% -5.7 p.p. % of women in the Company % 31.8% 32.0% -0.2 p.p. 31.8% 32.0% -0.2 p.p. % of men in the Company % 68.2% 68.0% 0.2 p.p. 68.2% 68.0% 0.2 p.p. % of women in leadership positions % 31.6% 30.6% 1.0 p.p. 31.6% 30.6% 1.0 p.p. % of men in leadership positions % 68.4% 69.4% -1.0 p.p. 68.4% 69.4% -1.0 p.p. % employees with disabilities % 4.3% 5.1% -0.8 p.p. 4.3% 5.1% -0.8 p.p. 1 - The Connection Program encompasses visits to the Company's operations across the country, dialogues with the community and environmental education. 2 - Investments in 2026 are now disclosed based on realized value, as opposed to the previously adopted provisioned amount. G Aspect E S
Page 36
36 1 2 3 4 5 Results Presentation 2Q26 Transportadora Associada de Gás – TAG Protagonism for the liberalization of the gas market Contracts | % of Net Operating Revenue5 29 clients (include Petrobras) from 26 different economic groups. 1,005 firm contracts signed until 2Q26 (vs. 647 YTD in 2Q25). In 2026, TAG began offering short-term products on every business day, simplifying and making the customer journey more flexible. Contract/Section Lenght (km) Agreement Maturity Capacity2 (MM m³/day) Type Client Readjustment index4 Gasene 1,400 Nov-2033 30.3 Legacy Petrobras 46% Basket IGP1; 54% US PPI Urucu-Coari- Manaus 800 Nov-2030 6.7 Legacy Petrobras 50% IGP-M; 50% IPCA Pilar-Ipojuca 200 Nov-2031 15.0 Legacy Petrobras IGP-M Malha NE1 2,100 - -3 Non-legacy Various - Lagoa Parda-Vitória1 100 Annual 0.3 Non-legacy Various 55% IGP-M; 45% IPCA Conexão GNL – Sergipe1 25 Oct-2054 14.0 Access connection Eneva 20% IGP-M; 80% IPCA Total ~4,600 Notes: 1 Contracted capacity under the entry–exit regime through the Capacity Offer Portal (POC). 2 Reference volume provided for in the contract for ship-or-pay purposes. The effectively contracted volume may vary from period to period. 3 Volume to be defined in the tariff review process conducted by ANP. 4 1/3 IGP-M; 1/3 IPA-DI; 1/3 IGP-DI. 5 Subject to the tariff review to be determined by the ANP. 6 Contracted daily volume. | QDC6 Acumulada
Page 37
37 1 2 3 4 5 Results Presentation 2Q26 Transportadora Associada de Gás – TAG Domestic market: 2nd Debentures (Dec/23 to Dec/33): IPCA + 5.99% p.a., amortization in the last 3 years 3rd Debentures (Jun/24 to Jun/29): CDI + 0.98% p.a., bullet maturing 4th Debentures (May/25 to May/30): CDI + 0.67 % p.a., annual amortization Foreign market: Bank Loan3 (Jun/19 to Jun/31): MUSD 1,864 • SOFR + spread (between 2.5% and 3.3%) + CAS (0.42826%) • Semi-annual amortization 5 .8 billion 9 .7 billion 1 Notes: 1 Not audited. 2Figures considering amount as of June 30, 2026. 3 Exposure to the dollar is 100% hedged by dollar-denominated contracts. Debt structure with competitive cost Rating Local AAA | Internacional BB+ (Fitch Ratings) Debt Profile (R$) – TAG as of June 30, 2026 Transportadora Associada de Gás - TAG Net Debt/Ebitda (x) – TAG 4Q25 1.95x 2Q262 2.44x
Page 38
www.engie.com.br/investidores ri.brenergia@engie.com Eduardo SATTAMINI Chief Executive Officer Pierre LEBLANC Chief Financial and Investor Relations Officer CONTACTS Investor Relations Team Leonardo Germano Depiné Investor Relations Manager leonardo.depine@engie.com Adriana Wagner Investor Relations Analyst adriana.wagner@engie.com Raquel Suzaki Investor Relations Analyst raquel.suzaki@engie.com Otávio Péres Investor Relations Intern otavio.peres@engie.com Ivani Angeli Investor Relations Analyst ivani.angeli@engie.com Vitor Montessanti Investor Relations Analyst vitor.montessanti@engie.com
Page 39
www.engie.com.br