Engie Energia Chile S A : Press Release EECL 1Q24 English

About this update from Engie Energia Chile S.a.

May 2, 2024 ENGIE ENERGÍA CHILE REPORTED EBITDA OF US$138 MILLION AND A NET PROFIT OF US$46 MILLION IN THE FIRST QUARTER OF 2024. EBITDA REACHED US$138.3 MILLION IN THE FIRST QUARTER OF 2024, REPRESENTING A 36% INCREASE COMPARED TO THE FIRST QUARTER OF 2023. THIS QUARTER HAS BEEN MARKED BY LOW MARGINAL COSTS, ACCOMPANIED BY REDUCED GENERATION COSTS DUE TO LOWER GLOBAL FUEL PRICES, RESULTING IN AN IMPROVED OPERATIONAL RESULT. • Operational revenues amounted to US$442.7 million in the first quarter of 2024, decreasing by 25% compared to the same period in the previous year. This decline was due to lower average monomic prices for both regulated and non-regulated customers. EBITDA for the first quarter of 2024 amounted to US$138.3 million, representing a 36% increase compared to the first quarter of the previous year. This growth was primarily driven by the recovery in the electricity margin. In the first quarter, net income was US$46.1 million, compared to US$19.7 million in the same period of the previous year. This improvement can be attributed to better operational performance. Financial Highlights (in US$ millions) 1Q23 1Q24 Var % Total operating revenues 587.8 442.7 -25% Operating income 57.3 103.3 n.a EBITDA 102.0 138.3 36% EBITDA margin 17.3% 31.2% 80% Total non-operating results (30.3) (39.9) n.a Net income after tax 19.7 46.1 134% Net income attributed to controlling shareholders 19.7 46.1 134% Earnings per share (US$/share) 0.019 43.725 Total energy sales (GWh) 2,938 3,142 7% Total net generation (GWh) 1,555 1,240 -20% Energy purchases on the spot market (GWh) 552 935 69% Energy purchases - back up (GWh) 800 986 23% ENGIE ENERGÍA CHILE S.A. ("ECL") is engaged in the generation, transmission and supply of electricity and the transportation of natural gas in Chile. ECL is the fourth largest electricity generation company in Chile and one of the largest electricity generation companies in the northern segment of the SEN national grid (formerly known as SING). As of March 31, 2024, ECL accounted for 7% of the SEN's installed capacity. ECL primarily supplies electricity to large mining and industrial customers, and it also supplies electricity to distribution companies throughout Chile. ECL is currently 59.99% indirectly owned by the French company, ENGIE LATAM. The remaining 40.01% of ECL's shares are publicly traded on the Santiago stock exchange. For more information, please refer to www.engie-energia.cl . Contents HIGHLIGHTS: 3 RECENT EVENTS 3 FIRST QUARTER 2024 3 INDUSTRY OVERVIEW 3 Marginal Costs 4 Fuel prices 5 Generation 5 Management's Discussion and Analysis of Financial Results 7 First quarter 2024 compared to first quarter 2023 and fourth quarter 2023 7 Operating Revenues 7 Operating Costs 8 Electricity Margin 9 Operating Results 10 Financial Results 10 Liquidity and Capital Resources 11 Cash Flow from Operating Activities 12 Cash Flow Used in Investing Activities 12 Cash Flow from Financing Activities 13 Contractual Obligations 13 Dividend Policy 15 Risk management policy 16 Hedging Policy 17 Business Risk and Commodity Hedging 17 Foreign Currency Hedging 18 Interest Rate Hedging 19 Credit Risk 20 OWNERSHIP STRUCTURE AS OF MARCH 31, 2024 22 Number of shareholders: 1,750 22 APPENDIX 1 23 PHYSICAL DATA AND SUMMARIZED QUARTERLY FINANCIAL STATEMENTS 23 Physical Sales 23 Quarterly Income Statement 24 Quarterly Balance Sheet 25 Main Balance Sheet Variations 25 APPENDIX 2 27 Financial information 27 Financial Ratios 27 CONFERENCE CALL 1Q24 29 2 HIGHLIGHTS: RECENT EVENTS Annual Ordinary Shareholders' Meeting : On Tuesday, April 30, 2024, the Company's shareholders agreed on the following: Dividend Policy : No final dividends will be distributed on account of 2023's net results given the reported losses in the period. Auditors : To appoint EY Servicios Profesionales de Auditoría y Asesorías SpA as the Company's external auditing firm. Financing: On April 17 th , EECL completed a bond issuance in the international markets for a total amount of USD 500.000.000. This issuance was carried out in accordance with the rules 144-A and Regulation S (Reg S) of the United States Securities Act of 1933. The bonds have a 10-year maturity and a 6.375% p.a. coupon interest rate. Interest payments will be made semi-annually, starting on October 17 th , 2024 and the principal will be amortized in one single final payment ("bullet") on April 17 th , 2034. The obligations arising from these bonds are not secured by any guarantees. Additionally, in compliance with applicable regulations, the bonds will not be registered with the Securities and Exchange Commission of the United States or with the CMF (Chilean Market Commission), and therefore, they will not be subject to public offering in either the United States or the Republic of Chile. This is ENGIE Chile´s first green bond issuance in the international markets, to finance renewable energy and storage projects. In April, Engie Energía Chile announced its fifth storage project called "BESS Tocopilla" . This project will have an installed capacity of 116 MW/660 MWh. The initiative will be located where former coal and fuel oil units operated, giving new life to the site, while contributing to the flexibility and security of supply of both the National Electric System (SEN) and ENGIE's portfolio. FIRST QUARTER 2024 BESS Coya received authorization from the National Electric Coordinator to begin operations during the first quarter. This battery storage system has a 139 MW/638 MWh installed capacity and allows for the storage of energy generated by the Coya Solar Plant, located in María Elena, Antofagasta region. It is currently the largest energy storage battery park in Latin America. BESS Coya consists of 232 containers, evenly distributed across the 58 inverters of the solar plant. It can supply energy for up to 5 hours, equivalent to an average annual delivery of 200 GWh. Additionally, it plays a crucial role in the environment by providing green energy to approximately 100,000 households, avoiding the emission of 65,642 tons of CO2, annually. In January 2024, the Company monetized payment documents issued by the Treasury of the Republic under the second law of price stabilization for regulated customers (MPC law or "PEC-2"), following mechanisms agreed upon with the Inter-American Development Bank, for a value of USD 9.6 million. INDUSTRY OVERVIEW The SING and SIC power grids operated independently until November 24, 2017, when the interconnection of both grids was perfected through EECL's 50%-owned TEN project, giving birth to the SEN ( "Sistema Eléctrico Nacional" ). Currently, the company's generation assets are predominantly located in the northern segment of the SEN, in the area that used to be covered by the so-called SING Grid ( "Sistema Interconectado del Norte Grande" ), which serves a major portion of the country's mining industry. Given local conditions, the northern segment of the 3 SEN is predominantly a thermoelectric system, with generation based on coal and LNG, with growing penetration of renewable sources, including wind, solar, geothermal, and storage systems, which allow to cope with the renewable energy generation intermittence, decoupling and curtailment. In 2018, EECL began its geographical diversification with the acquisition of renewable generation assets in other regions of the country and with the start of supply under PPAs awarded with distribution companies in the center-south region. The interconnection of the grids and the entry into operations of the Cardones-Polpaico Interconnection Project of InterChile, on May 30, 2019, allowed for the coupling of transmission bars in the different substations of the system, reducing the curtailment of renewable energy supply due to the insufficiency of the transmission infrastructure. However, the accelerated installation of renewable energy projects in recent years has exceeded the capacity of the transmission infrastructure, making it necessary to expand it to prevent renewable energy losses. Marginal Costs 2023 Mes Ene Feb Mar Abr May Jun Jul Ago Sep Oct Nov Dec YTD Real (Monthly Average per Node) 2024 Crucero 22 Polpaico 220 Charrúa 220 Pto. Montt 22Temuco 220 Mes 96 94 91 197 89 Ene 114 114 110 215 107 Feb 106 133 132 207 128 Mar 109 133 132 160 130 Abr 106 123 123 138 118 May 93 104 102 90 88 Jun 60 59 56 48 47 Jul 54 52 48 36 36 Ago 53 50 46 32 33 Sep 44 41 33 35 27 Oct 41 33 25 20 20 Nov 47 41 34 49 28 Dec 77 81 78 102 71 YTD Real (Monthly Average per Node) Crucero PAN DE AZ Polpaico Charrua P. Montt 42 40 41 37 79 54 51 53 50 108 51 49 49 47 60 49 47 48 45 83 Source: Coordinador Eléctrico Nacional In the first quarter of 2024, the average marginal cost of the system was 54 USD/MWh. In the northern zone, it was 49 USD/MWh, 47 USD/MWh in the center, and 84 USD/MWh in the southern region. Overall, the rainfall during the winter of 2023 led to a significant increase in reservoir levels and accumulated snow volume. This is reflected in the November 2023 thaw forecast issued by the National Electric Coordinator (CEN). Additionally, fuel prices showed a downward trend in the last months of 2023. Coupled with the increased generation capacity from new power plants, this has resulted in a decrease in marginal costs since mid- 2023. 4 Fuel prices International Fuel Prices Index WTI (US$/Barrel) 2023 2024 % Variation YoY Jan 78.1 74.1 -5% Feb 77.3 77.8 1% March 72.5 81.3 12% April 79.6 May 71.7 June 70.4 July 75.8 August 81.6 September 89.6 October 86.0 November 77.9 December 71.8 Source: Bloomberg, IEA Brent (US$/Barrel) 2023 2024 % Variation YoY 82.2 80.2 -2% 83.2 83.8 1% 77.5 85.4 10% 83.9 79.7 79.5 79.9 86.3 93.9 90.8 83.2 77.6 Henry Hub (US$/MMBtu) 2023 2024 % Variation YoY 3.18 3.17 0% 2.39 1.67 -30% 2.26 1.49 -34% 2.16 2.15 2.12 2.55 2.61 2.63 2.95 2.75 2.52 European coal (API 2) (US$/Ton) 2023 2024 % Variation YoY 167.5 106.1 -37% 138.3 95.8 -31% 138.3 114.4 -17% 140.3 119.0 115.6 110.5 117.7 123.3 136.1 123.6 117.6 As shown in the table above, when comparing 2024 to 2023, we can see a continued downward trend in international fuel prices. Generation The following graphs provide a breakdown of generation in the SEN by fuel type and by company for the first quarter of 2023 and 2024: 3M23: Generation by source 3M24: Generation by source other coal other coal 4% 4% 17% 16% Gas Gas 24% 16% 21.671 GWh renewables renewable hydro 36% hydro 35% 28% 20% Source: Coordinador Eléctrico Nacional During the first quarter of 2024, demand reached a maximum of 12,190.5 MWh/h on January 31st, a 5.6% over peak demand of 2023. Accumulated sales as of March 2024, reached 20,138 GWh, with a 3.5% increase in unregulated customer sales and a 2.7% increase in the regulated client segment as compared to the same period in 2023. Regarding renewable energy, solar generation increased by 14%, while wind generation rose by 7% as compared to 2023. As of March 2024, the National Electricity System (SEN) reported total gross installed capacity 5 of 35,338 MW, including 16,533.2 MW qualifying as non-conventional renewable energy capacity, as defined by Law #20,257. In terms of hydraulic generation for the SEN, as of March, the estimated probability of exceedance for the April 2023-March 2024 hydrological year was 59.4% (medium-dry year). Electricity production in the SEN grid, broken down by company, was as follows: 3M23: Generation by company 3M24: Generation by company ENGIE ENGIE 6% 6% Colbún Colbún 16% 15% Other Other 43% 44% AES AES 21.671 GWh 11% 8% Enel Enel 24% 27% Source: Coordinador Eléctrico Nacional 6 MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL RESULTS The following discussion is based on our unaudited consolidated financial statements for the three-month periods ended March 31, 2024, and March 31, 2023. These financial statements have been prepared in U.S. dollars in accordance with IFRS and should be read in conjunction with the financial statements and the notes thereto published by the Comisión para el Mercado Financiero ( www.cmfchile.cl ). First quarter 2024 compared to first quarter 2023 and fourth quarter 2023 Operating Revenues Quarterly Information (In US$ millions) 1Q23 4Q23 1Q24 % Variation Operating Revenues Amount % of total Amount % of total Amount % of total QoQ YoY Unregulated customers sales………………….. 228.6 43% 209.2 48% 194.4 48% -7% -15% Regulated customers sales……………………. 249.6 47% 171.5 40% 190.6 47% 11% -24% Spot market sales……………………………….. 53.5 10% 51.6 12% 17.3 4% -67% -68% Total revenues from energy and capacity sales 531.8 90% 432.4 91% 402.2 91% -7% -24% Gas sales………………………….. 25.6 4% 13.2 3% 7.2 2% -45% -72% Other operating revenue………………………. 30.4 5% 31.2 7% 33.3 8% 7% 10% Total operating revenues…………………. 587.8 100% 476.8 100% 442.7 100% -7% -25% Physical Data (in GWh) Sales of energy to unregulated customers (1)…… 1,655 56% 1,783 58% 1,745 56% -2% 5% Sales of energy regulated customers…… 1,252 43% 1,220 40% 1,374 44% 13% 10% Sales of energy to the spot market……………. 31 1% 47 2% 22 1% -53% -28% Total energy sales…………………………. 2,938 100% 3,050 100% 3,142 100% 3% 7% Average monomic price unregulated customers(U.S.$/MWh)(2) 138.1 117.4 111.4 -5% -19% Average monomic price regulated customers (U.S.$/MWh)(3) 199.4 140.6 138.7 -1% -30% Energy and capacity sales reached US$402.2 million in the first quarter of 2024, representing a 24% decrease (US$129.6 million), compared to the same quarter of the previous year. This decline can be attributed to lower average monomic prices for both regulated and unregulated customers. The drop in tariffs is a result of decreases in inflation rates and fuel prices used in the indexation formulas of the contracts, which are reflected in this quarter's results. When compared to the immediately preceding quarter, energy and capacity sales decreased by 7% (US$37.1 million), explained by lower sales volumes to regulated customers and declines in the average monomic prices of both unregulated and regulated customers. In 2023 energy sales in the spot market included energy injections from the Kelar Power Plant operated by BHP under a tolling agreement with fuel provided by EECL. This explained the increase in this category for that period. In the first quarter of 2024, there was no tolling agreement, and physical sales to the spot market amounted to 22 GWh. In the first quarter of 2024 gas sales decreased due to a drop in volumes sold as well as lower prices. The most relevant items in the 'Other operating revenue' account are sub-transmission tolls and regulatory transmission revenues, which starting 2018 include a single charge called "cargo único" , as well as port and maintenance services. 7 Operating Costs Quarterly Information (In US$ millions) 1Q23 4Q23 Operating Costs Amount % of total Amount % of total Fuel and lubricants……………………………… (177.3) 33% (99.1) 33% Energy and capacity purchases on the spot (219.4) 41% (182.7) 41% market…………………………… Depreciation and amortization attributable to cost of goods (43.4) 8% (44.3) 8% sold……………………………. Other costs of goods sold……………………. (83.5) 16% (95.7) 16% Total cost of goods sold……………….. (523.5) 99% (421.8) 99% Selling, general and administrative expenses… (8.8) 2% (13.8) 2% Depreciation and amortization in selling, general and administrative expenses………… (1.3) 0% (1.0) 0% Other operating revenue/costs………………………. 3.1 -1% 5.4 -1% Total operating costs….………………. (530.5) 100% (431.3) 100% Physical Data (in GWh) Gross electricity generation Coal…………………………………………. 351 22% 433 22% Gas………………………………………….. 850 53% 205 53% Diesel Oil and Fuel Oil……………………. 7 0% 0 0% Hydro/Solar/Wind………………………………. 407 25% 415 25% Bess - - - - Total gross generation…………………. 1,615 100% 1,054 100% Minus Own consumption……………….. (61) -4% (53) -4% Total net generation……………………. 1,555 53% 1,000 53% Energy purchases on the spot market……….. 552 19% 1,299 19% Energy purchases- bridge……….. 800 28% 966 28% Total energy available for sale before transmission losses……………………… 2,906 100% 3,265 100% 1Q24 Amount % of total (81.6) 24% (157.6) 46% (34.1) 10% (59.8) 18% (333.1) 98% (10.6) 3% (0.9) 0% 5.1 -2% (339.4) 100% 495 38% 413 32% 0 0% 343 26% 51 4% 1,303 100% -5% 1,240 39% 935 30% 986 31% 3,161 100% Variation QoQ YoY -18%-54% -14% -28% -23% -21% -37% -28% -21% -36% -24% 20% -14% -30% -21% -36% 14% 41% 101% -51% -67% -100% -17% -16% - - 24% -19% 18% 4% 24% -20% -28% 69% 2% 23% -3% 9% Gross electricity generation decreased by 19%, compared to the same quarter of 2023, and increased by 24% compared to the previous quarter. The increase in coal-based generation is explained primarily by higher dispatch priority of coal units. The increase in gas generation during the quarter compared to the fourth quarter of 2023 is explained by higher availability of this fuel, including gas coming from Argentina. However, when compared to the first quarter of 2023, gas generation decreased. Generation with renewables decreased compared to both the first quarter of 2023 and the previous quarter, in part due to curtailment related to transmission restrictions. On the other hand, for the first time the company registered generation associated with our BESS projects, which accounted for a 4% of our net generation during the first quarter. Renewable generation decreased 17% compared to the fourth quarter of 2023, primarily due to lower solar, wind and hydro generation. Notably, ENGIE Chile's renewable portfolio, as of March 2024, includes the following additions: (i) Calama wind farm (151.2 MW) at the end of 2021, (ii) the Tamaya solar PV plant (114 MWac) which started its commercial operations in January 2022, (iii) the first injections of the Capricornio solar PV plant (88 MWac) starting April 2022, iv) the Coya PV plant (180 MWac) operational since August 2022, which obtained its COD as of March 2023 and v) the incorporation of the San Pedro wind farms in mid-December 2022. In the first quarter of 2024, BESS Coya obtained the authorization by the CEN to start its commercial operation. This battery energy storage system has a 139 MW/638 MWh installed capacity and allows for the storage of energy generated by the Coya photovoltaic plant located in María Elena in the Antofagasta region. The fuel cost item showed a 54% decrease compared to the same quarter of the previous year as a result of lower fuel prices and lower own generation. Compared to the fourth quarter of 2023, the fuel cost decreased by 18%, due to the reduction in fuel prices. The 'Cost of energy and capacity purchases in the spot market' decreased compared to previous periods, mainly due to lower average spot prices, despite increased volumes of energy purchased in the spot market as well as through back-up contracts with other generators. Purchases under back-up supply contracts reached 986 GWh in the quarter compared to 800 GWh in the same quarter of the previous year. During the first quarter of 2024, there was a reduction in hydraulic supply as well as a drop in solar and wind generation. The cost of coal continued its 8 reduction as compared to the levels shown in 2022 and the beginning of 2023 and also due to the gradual consumption of inventories purchased at higher prices in the second half of 2022. Other direct operating costs included, among others, transmission tolls, plant personnel salaries, operating and maintenance costs, insurance premiums and cost of fuels sold. These costs increased from the previous quarter mainly due to higher performance bonuses, severance provisions and maintenance costs. SG&A expenses (excluding their depreciation) increased as compared to those in the first quarter of 2023 and decreased as compared to the previous quarter, mainly due to lower advisory and third party services. The Other operating revenue/cost item includes water sales as well as recoveries, single transmission charges ( "cargo único" ) and provisions and other miscellaneous income. EECL's share in TEN's net income, which amounted to US$0.8 million in the first quarter, is also included in this item. Electricity Margin Quarterly Information (In US$ millions) 2023 2024 1Q23 2Q23 3Q23 4Q23 2023 1Q24 Electricity Margin Total revenues from energy and capacity sales……… 531.8 552.3 469.5 432.4 1,986.0 402.2 Fuel and lubricants………………….. (177.3) (194.2) (120.7) (99.1) (591.3) (81.6) Energy and capacity purchases on the spot market…… (219.4) (224.3) (189.2) (182.7) (815.6) (157.6) Gross Electricity Profit 135.1 133.8 159.6 150.6 579.1 163.0 Electricity Margin 25% 24% 34% 35% 29% 41% In the first quarter of 2024, the electricity margin, or gross profit from the electricity generation business, recovered with a US$27.9 million increase, when compared to the same quarter of the previous year, increasing from 25% to 41% of energy and capacity revenues. This was due to lower fuel costs and lower electricity purchase costs, which together represented a 40% decrease, while there was also a decrease in revenues from energy and capacity sales which represented a 24% decrease. Meanwhile, compared to the previous quarter, there was a US$12.4 million increase in the gross profit of the business, resulting in a raise from a 35% to a 41% profit margin. However, there were lower revenues from energy and capacity sales (US$30.2 million) due to the decline in average prices of energy sold, as a result of a decrease in the main tariff indexers (CPI and gas and coal prices). Additionally, there was a decrease in costs, both for fuels (amounting to US$17.6 million), attributed to falling prices, and for the energy and capacity purchases in the spot market (totaling US$25.1 million), primarily due to reduced volumes of purchases from the system. 9 Operating Results Quarterly Information (in US$ millions) EBITDA 1Q23 4Q23 1Q24 % Variation Amount % of total Amount % of total Amount % of total QoQ YoY Total operating revenues……………………… 587.8 100% 476.8 100% 442.7 100% -7% -25% Total cost of goods sold…………………… (523.5) -89% (421.8) -89% (333.1) -75% -21% -36% Gross income…………………………. 64.3 11% 55.0 11% 109.6 25% 99% 71% Total selling, general and administrative expenses and other operating income/(costs). (7.0) -1% (9.4) -1% (6.3) -1% -33% -10% Operating income….………………. 57.3 10% 45.5 10% 103.3 23% 127% 80% Depreciation and amortization……...………… 44.7 8% 45.4 8% 35.0 8% -23% -22% EBITDA…………….….………………. 102.0 17.3% 90.9 17.3% 138.3 31.2% 52% 36% EBITDA for the first quarter of 2024 reached US$138.3 million, a 52% increase compared to the previous quarter and a 36% increase compared to the first quarter of 2023, mainly due to the recovery in the electricity margin explained in the previous paragraph. Financial Results Quarterly Information (In US$ millions) 1Q23 4Q23 1Q24 % Variation Non-operating results Amount % of total Amount % of total Amount % of total QoQ YoY Financial income………..……………………… 1.3 0% 3.2 1% 4.1 1% 27% 214% Financial expense………….………………… (27.9) -6% (26.2) -4% (33.7) -5% 29% 21% Foreign exchange translation, net…………… (0.3) 0% 1.6 0% (10.3) -2% n.a. n.a. Other non-operating income/(expense) net… (3.4) -1% (604.9) -103% - 0% n.a. n.a. Total non-operating results……………. (30.3) -6% (626.3) -107% (39.9) -6% Income before tax……………………. ……… 27.1 6% (580.8) -99% 63.4 10% n.a. 134% Income tax……………………………………… (7.4) -2% 100.2 17% (17.3) -3% n.a. 136% Net income from continuing operations after taxes … 19.7 4% (480.6) -82% 46.1 7% n.a. n.a. Net income to EECL's shareholders 19.7 4% (480.6) -82% 46.1 7% n.a. n.a. Earnings per share…………………….. 0.019 (0.456) 43.725 In the first quarter of 2024, net interest expense increased by US$3 million compared to the first quarter of 2023. The US$5.8 million increase in financial expenses, explained by higher debt balances at higher interest rates, could have been higher had it not been for a US$4.5 million increase in capitalized interest. The successive increase in global interest rates and higher cash balances explained a US$2.8 million increase in financial income that contributed to offset the increase in financial expenses. When comparing with the fourth quarter of 2023, financial expenses increased by US$3.8 million, mainly due to higher debt balances and fees paid on new loan disbursements, while interest income increased by US$0.9 million. Exchange rate differences resulted in a US$10.3 million loss in the first quarter of 2024 due to foreign exchange volatility, with a depreciating trend of the Chilean peso, particularly in January. This compared with a US$0.3 million foreign exchange loss in the first quarter of 2023 and a US$1.6 million foreign exchange gain in the fourth quarter of 2023. Fluctuations in exchange rates affect the value of certain assets and liabilities denominated in currencies other than the US dollar, the company's functional currency. These include some accounts receivable and payable, advances to suppliers, value-added tax credit and, more importantly, liabilities for onerous concessions on land and other assets recorded on the balance sheet under the IFRS16 norm. 10

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