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auren 2Q26 Results Presentation AUGUST 2026
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This material contains summarized information and involves a certain degree of risk and uncertainty regarding business trends, financial performance, strategies, economic conditions, among other matters. Such information is based on assumptions, data, or methodologies that, although considered reasonable by the Company, may prove to be incorrect or inaccurate, may not materialize, or may be beyond the Company's control. As a result of these factors, the Company's actual results may differ materially from those expressed or implied in this material. The Company makes no representation or warranty, either expressly or implicitly, in any form or to any extent, that the trends disclosed in this material will be achieved or confirmed. The information and opinions contained herein should not be construed as a recommendation to current or potential investors, and no investment decision should be based on the timeliness, accuracy, or completeness of such information or opinions. Neither the Company's representatives, advisors, nor any parties related to them shall have any liability whatsoever for any losses arising from the use of, or reliance upon, the contents of this material Disclaimer 2
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Agenda 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks 3
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Auren reports Adjusted EBITDA of R$ 859 million in 2Q26, highlighted by the start of the run-test activities at the Cajuína 3 Complex ..:: 2Q26 Highlights 4 Portfolio Resilience Financial Management Discipline Progress in the Corporate Reorganization Modulation gains of R$ 71 million in 2Q26 mitigated a significant portion of the curtailment impact (R$ 98 million). The result was 75% higher than in 2Q25, reflecting the Company's generation profile, higher price volatility, and higher average PLD during the period. Completion of Phase 1 of the Corporate Reorganization, with the merger of Auren Participações into Auren Operações. Phase 2, which includes the merger of Auren Operações into Cesp, has been approved and remains subject to the fulfillment of conditions precedent and regulatory approvals. Net debt decreased by R$ 194 million in 2Q26, with leverage ending the period at 5.3x Adjusted Net Debt/Adjusted EBITDA. The deleveraging trajectory remains on track, with stabilization expected in 2026 and reduction beginning in 2027. Construction of Cajuína 3 Selo Pró-Ética¹ The Cajuína 3 project (112.1 MW) is approximately 88% complete, with run- test activities initiated for the first 6 of its wind turbines. Full commercial operation remains expected by December 2026. Auren received the CGU Selo Pró-Ética, a recognition awarded to companies with effective integrity and anti-corruption programs. Earned in its first participation in the program, the certification reinforces our commitment to high standards of ethics, governance, transparency, and integrity. Publication of the ordinance regulating the procedures for compensation of generation curtailments occurred between September 2023 and November 2025. Auren estimates compensation of approximately R$ 300 million and is evaluating its initial enrollment in the mechanism. Curtailment Compensation 1 – Pro-Ethics Certification (free translation).
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Agenda 5 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks
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0 20 40 60 80 100 120 140 Jan-24 Apr-24 Jul-24 Oct-24 Jan-25 Apr-25 Jul-25 Oct-25 Jan-26 Apr-26 LTA (GWavg) Gross ENA (GWavg) Storable ENA (GWavg) Following the beginning of the wet season marked by below-average inflows, hydrological conditions improved in 2Q26, with reservoir recovery and the maintenance of comfortable storage levels across the SIN ..:: Performance of the National Interconnected System - SIN 6 Natural Energy Inflow (ENA) (SIN, % LTA) ▪ The quarter was marked by improved hydrological conditions. In May, the South region recorded ENA of 112% of LTA, supporting reservoir recovery, while the SE/CW region reported average ENA of 87% of LTA during the quarter, contributing to the maintenance of comfortable storage levels across the SIN. ▪ Average ENA in the SIN reached 82% of LTA in 2Q26, 3 p.p. above the 79% recorded in 1Q26 and 4 p.p. above the level observed in 2Q25, reflecting a gradual improvement in inflows throughout the period. Equivalent Reservoir Level (SIN) ▪ The recovery of inflows in the South and rainfall observed in the SE/CW contributed to the stability of SIN reservoirs, which remained between 70% and 72% of maximum capacity throughout the quarter. ▪ The SIN closed 2Q26 with 71% storage, 14 p.p. above the average of the last ten years and 1 p.p. above the level observed at the end of 2Q25. 43% 56% 57% 41% 38% 53% 64% 70% 70% 56% 45% 50% 59% 69% 71% 72% 71% 30% 40% 50% 60% 70% 80% 90% 100% Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec (% Max. Storage) 10-Year Average 2023 2024 2025 2026 Submarket Mar/26 Jun/26 SE/CW 65% 66% S 31% 65% NE 90% 89% N 94% 94% Source: ONS -18 GWavg (80% of LTA) Jan/26 – Jun/26 -14 GWavg (82% of LTA) 2Q26 -18 GWavg (81% of LTA) -25 GWavg (74% of LTA) 2Q24 Jan/25 – Jun/25 2Q25 Jan/24 – Jun/24 -17 GWavg (78% of LTA) -12 GWavg (85% of LTA)
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Improved hydrological conditions contributed to the GSF reaching 99% in 2Q26, while the contribution of the different sources to meeting demand remained stable compared to 2Q25 ..:: Energy Mix Evolution and Hydroelectric Displacement 7 Nível do Reservatório Equivalente (SIN) Hydroelectric Displacement (GWavg, % GSF) 72% 66% 53% 55% 68% 60% 48% 52% 63% 60% 9% 10% 16% 15% 8% 11% 18% 17% 12% 11% 10% 15% 21% 17% 12% 17% 21% 16% 11% 16% 4% 4% 4% 5% 5% 5% 5% 5% 5% 5% 6% 6% 6% 8% 8% 7% 8% 10% 9% 8% 82 79 78 81 86 79 78 82 87 82 0,0 10,0 20,0 30,0 40,0 50,0 60,0 70,0 80,0 90,0 100,0 1Q24 2Q24 3Q24 4Q24 1Q25 2Q25 3Q25 4Q25 1Q26 2Q26 Hydro Thermal Wind Solar MMDG Energy Supply by Source (SIN, GWavg) [#] Total Load (GWavg) ▪ GSF reached 99% in 2Q26, above the level recorded in 2Q25 (96%). ▪ Of the 3 p.p. increase in GSF, approximately 2 p.p. were driven by higher hydroelectric generation within the MRE (45 GWavg in 2Q26 vs. 44 GWavg in 2Q25). The remaining 1 p.p. resulted from lower physical guarantee allocation by MRE participants (45 GWavg in 2Q26 vs. 46 GWavg in 2Q25). ▪ SIN load increased by 3.2% compared to 2Q25 but remained 2% below ONS projections, influenced by below-average temperatures in the SE/CW region for the fifth consecutive quarter. ▪ Solar generation, considering both utility-scale plants and MMGD, continued to increase its share in serving SIN load, reaching 13% in 2Q26 (vs. 12% in 2Q25), while wind generation reduced its contribution by 1 p.p., reflecting lower wind resource availability and higher curtailment levels compared to the same periods. Source: CCEESource: ONS 62 48 49 54 52 46 54 60 57 45 56 48 39 43 56 44 35 40 52 45 90% 99% 79% 80% 107% 96% 65% 68% 91% 99% 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 2024 2025 2026 GW médio Seasonalized Physical Guarantee MRE's Hydropower Generation (Gravity Center) GSF
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8 ..:: PLD and Volatility The combination of improved hydrological conditions and lower demand reduced prices in 2026, while uncertainty regarding the impacts of El Niño continues to support prices in 2027 ▪ Average PLD in the SE/CW submarket was R$ 207/MWh in 2Q26, below the R$ 216/MWh recorded in 2Q25 and significantly lower than the R$ 308/MWh recorded in 1Q26, while intraday volatility remained at elevated levels (45% in both 2Q26 and 1Q26, compared to 42% in 2Q25) ▪ High volatility is primarily driven by the concentration of energy production during specific periods of the day, reflecting the expansion of MMGD capacity. ▪ Given the higher PLD levels in the North and Northeast submarkets compared to 2Q25, the spread between these regions and the Southeast/Center-West submarket remained below, with an average difference of only R$ 43/MWh, compared to R$ 62/MWh recorded in the same period of the previous year. Compared to 1Q26, however, the spread was R$ 21/MWh. Market Price and SE/CW PLD Evolution (R$/MWh) PLD and Volatility (R$/MWh) R$ 216/MWh 2Q25 Average PLD 42% Intraday Vol R$ 207/MWh 2Q26 Average PLD 45% Intraday Vol 297 246 229 204 171 342 234 279 253 228 201 2026 2027 2028 2029 2030 Dec/25 Jan/26 Jul/26 R$ 108/MWh decline in the 2026 price between the Jan/26 and Jul/26 Dcide curves +33 +24 +24 +30 -108 243 298 320 319 320 321 349 247 382 302 211 220 188 135 100 140 180 220 260 300 340 380 420 Jan-26 Mar-26 May-26 Jul-26 Market Curve in January 27, 2026 (DCIDE) Average PLD Observed -214 Source: Dcide, ONS and CCEE Long-Term Curve – 2026 to 2030 (R$/MWh)Price Evolution in 2026 (R$/MWh) 78 106 86 122 113 65 202 213 235 211 220 188 0 50 100 150 200 250 300 350 400 450 500 Jan/25 Mar/25 May/25 Jul/25 Sep/25 Nov/25 Jan/26 Mar/26 May/26 PLD SE/CO (R$/MWh) Standard Deviation SE/CW PLD (R$/MWh)
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..:: Curtailment 9 In 2Q26, curtailment represented 16% of total SIN wind generation and 26% of solar generation, according to ONS ▪ Total curtailment for wind generation in the SIN reached 16% (2.2 GWavg) in 2Q26, significantly above the 12% (1.7 GWavg) recorded in 2Q25 and the 15% (1.6 GWavg) registered in 1Q26. ▪ For solar generation, curtailment reached 26% (1.3 GWavg) during the quarter, exceeding the 23% (1.0 GWavg) recorded in 2Q25 and well above the 16% (0.8 GWavg) observed in 1Q26. ▪ Curtailments classified as reliability-related (CNF) and external unavailability (REL) accounted for 26% of total curtailment during the quarter, down from 35% in 2Q25. Monthly Curtailment in the SIN (GWavg, consolidated wind and solar) 1,2 4,7 1,9 1,3 3,3 3,3 4,3 5,8 6,8 8,0 4,6 2,7 4,0 1,1 2,0 3,0 3,9 3,5 0 1 2 3 4 5 6 7 8 9 Jan-25 Feb-25 Mar-25 Apr-25 May-25 Jun-25 Jul-25 Aug-25 Sep-25 Oct-25 Nov-25 Dec-25 Jan-26 Feb-26 Mar-26 Apr-26 May-26 Jun-26 Curtailment (GWavg) Energy-Based (ENE) Reliability-Based (CNF) External Unavailability (REL) 65% 26% 8% 74% 12% 14% 2.6 GWavg 3.5 GWavg 2Q26 2Q25 Source: ONS and CCEE
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Agenda 10 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks
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..:: Consolidated Operational Performance 11 2Q25 2Q26 2,075 1.279 1.153 2Q25 2Q26 144 155 2Q25 2Q26 Generation vs. Firm Energy Generation1 vs. Certification Generation1 vs. Certification 209 228 208 217 Energy production from the Company's assets was impacted by lower wind resource availability during the quarter, offset by stronger solar resource conditions and higher hydro dispatch from MRE plants Proprietary Hydroelectric Assets Minority Interests (HPPs) Wind Assets Solar Assets ▪ 9% increase in dispatch compared to 2Q25 ▪ Availability3 of 95% vs. ANEEL Reference4 of 93% 3.3 GWavg 1 – Considers energy generation plus generation restrictions due to the External Unavailability Ratio (REL) eligible for reimbur sement; 2 – Considers the sum of total energy generated and total curtailment volume; 3 – Considers the Verified Availability Index – 60 months (IDv60), which measures a plant’s actual availability to operate compared to its referen ce capacity over the last five years; 4 – Reference availability weighted by each plant’s installed capacity. 1,414 1,297 1,253 1,368 1,784 1,943 P90P50Firm Energy Potential Generation²Generation1 +9% 35% Wind 60% Hydro 5% Solar -10% +7% Hydro Wind Solar 2Q26 Generation by Source ▪ Availability of 93% in both 2Q26 and 2Q25 ▪ Generation¹ at 92% of P90 ▪ Potential generation² at 103% of P90 and 95% of P50 ▪ Availability of 99% in both 2Q26 and 2Q25 ▪ Generation¹ at 74% of P90 ▪ Potential generation² at 104% of P90 and 95% of P50
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Agenda 12 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks
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Curtailment Repurchase Value Average Hourly Price by Submarket SE/CW Submarket (R$/MWh) NE Submarket (R$/MWh) The negative financial impact of generation shortfalls resulting from curtailment at facilities that sold energy in the free market was mitigated due to lower spot price (PLD) levels during the hours in which the cuts occurred Greater hourly volatility in the SIN increased modulation gains in 2026 ..:: Systemic Effects on the Portfolio January to June - 2025 (R$/MWh) January to June - 2026 (R$/MWh) 327 202 213 235 210 287 260 250 278 266 247 382 302 211 220 188 57 102 241 147 112 126 105 158 132 130 139 140 151 132 65 73 82 95 Jan-25 Mar-25 May-25 Jul-25 Sep-25 Nov-25 Jan-26 Mar-26 May-26 PLD Solar 59 59 59 107 125 231 206 269 246 218 275 266 239 380 250 139 167 184 61 78 145132 179 162156 189 186 220 181 63 86 103 119 59 59 59 59 71 109104 119 107 98 146 143 174 198 59 66 80 90 Jan-25 Mar-25 May-25 Jul-25 Sep-25 Nov-25 Jan-26 Mar-26 May-26 PLD Wind Solar 121 114 111 10999 83 83 88 107 129 121 117 114 210 190 184 197182 141 128 139 183 226 232 228 219 0 100 200 300 400 500 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 NE SE/CW 265 244 243 226 177 124 124 143 194 299 342 305 265 304 275 271 275 234 134 124 145 222 327 396 365 313 0 100 200 300 400 500 0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 NE SE/CW
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14 ..:: Systemic Effects on the Portfolio Curtailment and Modulation (R$ million) 1 – Net amount of the reimbursable portion related to curtailments resulting from external unavailability (REL), subject to reimbursement. Auren Portfolio Composition (% of Firm Energy) 57%37% 6% Hydro Wind Solar -2 -6 0 -1 -20 -19 -8 -26 -44 -38 -88 -53-2 -6 0 -1 -28 -28 -10 -38 -71 -61 -98 -65 1Q23 2Q23 3Q23 4Q23 1Q24 2Q24 3Q24 4Q24 1Q25 2Q25 3Q25 4Q25 1Q26 2Q26 Observed Ex-Curtailment/Ex-Turbinable Spilled Energy (EVT) Scenario 1 2 0 0 5 9 3 13 17 19 26 18 1 2 0 0 5 9 3 10 15 18 20 15 -1 -1 0 0 3 2 0 0 19 17 12 7 -1 -1 0 0 -1 -2 0 -7 -1 -2 -1 -3 Auren captured modulation gains of R$ 71 million in the quarter and R$ 168 million in 6M26, mitigating more than 90% of the adverse effects of curtailment year-to-date Curtailment Impact and Modulation Gains -51 -76 -196 -208 -86 -98 19 40 66 70 97 71 1Q25 2Q25 3Q25 4Q25 1Q26 2Q26 Curtailment¹ Modulation Modulation Spread by Source (SIN, R$/MWh) Hydro Wind Solar
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15 ..:: Generation Energy Balance – Integrated Portfolio Management Strong trading activity, with more than 800 MWavg transacted in 2026. During the quarter, Auren kept its long position for the 2027-2030 period Consolidated Portfolio Contracted Level 95% 76%92% 89% 72% 67% 1.086 1.086 1.187 1.081 1.081 1.080 8.238 5.668 4.608 3.212 2.682 2.153 318 517 476 899 1.148 1.380 128 25 113 135 148 187 2026 2027 2028 2029 2030 2031 9,674 7,179 6,351 5,374 5,012 4,718 Requisite (Contracted Energy in Regulated Market) Consolidated Energy Balance¹ (MWavg) Requisite (Contracted Energy in Free Market) Uncontracted Conventional Energy Uncontracted Incentivized Energy The higher uncontracted volume from 2029 onward positions Auren to capture the increase in long-term energy prices Generation Portfolio Contracting Level and Average Generation Sales Price² (R$/MWh, net) 196 216212 210 222 90% 75%88% 86% 68% 227 62% 1 – Includes the Company’s proprietary assets and 50% of the assured energy of Tucano Holding III, a joint venture between Auren Participações and Unipar Carbocloro. Assured energy is net of grid losses for all years and net of GSF only for the period already completed (6M26). The energy balance does not consider the potential effects of future GSF or curtailment; 2 – Price net of taxes (PIS/COFINS and ISS), base date: June 30, 2026.
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Agenda 16 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks
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..:: Financial Performance – Revenue and EBITDA 17 Adjusted EBITDA of R$ 859 million, with net debt reduction during the quarter Consolidated: Adjusted EBITDA decreased by 12%, primarily driven by the weaker performance of the Commercialization segment, lower wind resource availability, and higher curtailment levels. These effects were partially offset by modulation gains (+R$ 30 million vs. 2Q25), which mitigated a significant portion of the curtailment impact during the period. Generation: Adjusted EBITDA declined by 5%, reflecting weaker results in the wind segment (-R$ 45 million vs. 2Q25) due to lower generation, and in the hydro segment (-R$ 10 million vs. 2Q25), driven by lower prices in the free market contracts (ACL), partially offset by higher modulation gains. Commercialization: excluding the effect of the assignment of the long-term power sale agreement for 150 MWavg, EBITDA would have been approximately negative R$ 1 million. The variation compared to 2Q25 was mainly driven by lower trading margins. PMSO: increased by 9% compared to 2Q25, mainly due to inflation during the period, the consolidation of Way2, and the step-up of O&M contracts for the wind assets. Dividends from Minority Interests in Hydroelectric: R$ 110 million in 2Q26, up 45% compared to 2Q25 (+R$ 34 million), reflecting the stronger performance recorded during the period. Generation Commercialization +6% 2.886 3.056 2Q25 2Q26 5.838 6.130 6M25 6M26 +5% 1.597 1.766 2Q25 2Q26 1.894 2.000 2Q25 2Q26 Generation Commercialization 3.218 3.469 6M25 6M26 3.682 4.025 6M25 6M26 Generation Commercialization -12% 981 859 2Q25 2Q26 2.186 1.785 6M25 6M26 -18% 946 902 2Q25 2Q26 53 -17 2Q25 2Q26 Generation Commercialization 2.003 1.879 6M25 6M26 215 -41 6M25 6M26 Net Revenue (R$ million) Adjusted EBITDA (R$ million)
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67% 21% 11% IPCA CDI TJLP Pré IPCA+5.7% CDI-0.1% TJLP+2.3% ..:: Financial Performance – Disciplined Capital Structure Management 18 Gross Debt Principal Amortization Schedule (R$ billion) Net Debt Profile 18.7 19.1 18.9 4,8x 5,2x 5,3x Jun/25 Mar/26 Jun/26 Net Debt ND/Adj. EBITDA Leverage Evolution Gross Debt Movement (R$ billion) AAA Auren Energia and Subsidiaries 4,7 0,3 1,6 1,9 2,7 2,3 14,5 Cash¹ 2026 2027 2028 2029 2030 2031+ Average Term: ~7 years Cash position covers more than 3 years The deleveraging trajectory remains on track, with stabilization expected in 2026 and reduction beginning in 2027 1 – Cash, cash equivalents, financial investments, liquidity fund (reserve account). 00 -01 00 00 25 23 23 Dec/25 Funding Principal Amortization Others Jun/26 TIET19 Prepayment Jun/26 (proforma) CDI-2.1% Cost of Debt
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Agenda 19 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks
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..:: Curtailment: Advances on the Regulatory Front 20 On July 21, the MME issued Ordinance No. 140/2026, establishing the Commitment Agreement and the guidelines for financial compensation for generation curtailments at wind and solar plants in the SIN between September 2023 and November 2025 Next Steps (estimated timeline) July 21, 2026 Publication of Ordinance No. 140 (Commitment Agreement) By August 10, 2026 Initial expression of interest (non- binding) (under evaluation by Auren) 2Q27 (estimated) Execution of the Commitment Agreement, following ONS/CCEE validation of compensation amounts 2nd half of 2027 (estimated) 1 2 3 4 • Curtailments due to Reliability (CNF) and External Unavailability (REL) at wind and solar plants. • Coverage period: September 2023 to November 2025. • Right to compensation through the Commitment Agreement (Article 1º-B of Law No. 10,848/2004). What the Ordinance recognizes • Curtailments due to Energy Reasons are not recognized. • No regulatory treatment has been defined for the transitional period (from November 2025 to the present). • Future curtailments (from November 2025 onward) depend on ANEEL regulation. Outstanding Issues ~R$ 300 million estimated compensation for Auren Beginning of compensation payments
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Simpler, more efficient corporate structure aligned with the Company’s new scale 21 ..:: Corporate Reorganization Key Objectives: • Consolidation of hydro assets under a single vehicle; • Rationalization and simplification of the Group’s corporate structure; • Reduction in the number of publicly listed companies; • Greater efficiency in cash management and debt allocation. Next Steps: On May 31, Auren completed Phase 1 of the Corporate Reorganization, with the merger of Auren Participações into Auren Operações. On June 24, Phase 2 was approved, involving the merger of Auren Operações into CESP, subject to regulatory approvals and the fulfillment of other conditions precedent Simplified corporate structure after reorganization (estimated structure in 2027) Capital contribution by Auren Energia to CESP, including 100% of the shares issued by Auren Operações and the drop-down of Auren Energia’s 3rd Debenture Issuance (R$ 2.5 billion) Merger between Auren Operações and CESP VA III Auren Energia Auren Operações Auren Part. Other Assets CESP Other Assets VdP I, II and III Sol do Piauí Non-Controlling Interests a. Phase 1 c. Phase 2 – Step 2 Auren Energia Auren Operações Other Assets CESP Other Assets VA III VdP I, II and III Sol do Piauí Non-Controlling Interests Auren Energia CESP Other Assets VA III VdP I, II and III Sol do Piauí Non-Controlling Interests b. Phase 2 – Step 1 VA III CESP Other Assets VdP I, II and III Sol do Piauí Non-Controlling Interests Capital contribution Other Assets Auren Operações Auren Energia
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Agenda 1. 2Q26 Highlights 2. Energy Market 3. Operational Performance 4. Commercial Performance 5. Financial Performance 6. Corporate Strategy 7. Closing Remarks 22
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Auren Energia - Confidencial ..:: Key Takeaways 23 2026 outlook: we remain focused on the disciplined execution of the Company's operational and financial strategy, with emphasis on improving internal processes, capturing efficiencies through Zero-Based Budgeting (ZBB), completing the Corporate Reorganization, and advancing the Company's artificial intelligence strategy. Discipline in capital allocation and continued progress on the efficiency agenda remain key pillars for enhancing competitiveness and sustaining long-term value creation. Well positioned to capture market opportunities: higher energy prices are expected to have a positive impact on the Company's results, particularly from 2029 onward, as more than 30% of Auren's consolidated long-term portfolio remains uncontracted. In an environment of structurally higher prices, the Company remains well positioned to capture value. Deleveraging trajectory: the Company aims to achieve a leverage ratio between 3.0x and 3.5x over the coming years. The expected debt reduction starting in 2027 continues to be supported by lower Capex requirements and higher EBITDA driven by the commercial operation of Cajuína 3 and the increase in the average contracted price. Regulatory: The publication of MME Ordinance No. 140 represented an important step toward defining the compensation mechanism for generation curtailments occurring between 2023 and 2025. At the same time, the Company continues to monitor regulatory discussions regarding the treatment of future curtailments, as well as the publication of the adjustment factors and payment structure for compensation related to CESP's prudent investments.
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Investor Relations ri.aurenenergia.com.br ri@aurenenergia.com.br