UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

REPORT OF FOREIGN PRIVATE ISSUER

PURSUANT TO RULE 13a-16 OR 15d-16

UNDER THE SECURITIES EXCHANGE ACT OF 1934

For the month of May 2023

Commission File Number 001-36487

Atlantica Sustainable Infrastructure plc

(Exact name of Registrant as Specified in its Charter)

Not Applicable

(Translation of Registrant’s name into English)

Great West House, GW1, 17th floor

Great West Road

Brentford, TW8 9DF

United Kingdom

Tel.: +44 203 499 0465

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

☒  Form 20-F ☐  Form 40-F

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(1):  ☐

Indicate by check mark if the registrant is submitting the Form 6-K in paper as permitted by Regulation S-T Rule 101(b)(7):  ☐

This Report on Form 6-K is incorporated by reference into the Registration Statement on Form F-3 of the Registrant filed with the Securities and Exchange Commission on August 3, 2021 (File 333-258395).

ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC

TABLE OF CONTENTS

		Page
PART I – FINANCIAL INFORMATION
Item 1	Financial Statements	10
Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	39
Item 3	Quantitative and Qualitative Disclosures about Market Risk	66
Item 4	Controls and Procedures	70
PART II – OTHER INFORMATION
Item 1	Legal Proceedings	70
Item 1A	Risk Factors	70
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	70
Item 3	Defaults upon Senior Securities	71
Item 4	Mine Safety Disclosures	71
Item 5	Other Information	71
Item 6	Exhibits	71
Signature		72

2

Definitions

Unless otherwise specified or the context requires otherwise in this quarterly report:

• references to “2020 Green Private Placement” refer to the €290 million ($316 million) senior secured notes maturing on June 20, 2026 which were issued under a senior secured note purchase agreement entered with a group of institutional investors as purchasers of the notes issued thereunder as further described in “Item 2 — Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—2020 Green Private Placement”;

• references to “Abengoa” refer to Abengoa, S.A. and, where the context requires, Abengoa, S.A  together with its subsidiaries;

• references to “ACT” refer to the gas-fired cogeneration facility located inside the Nuevo Pemex Gas Processing Facility near the city of Villahermosa in the State of Tabasco, Mexico;

• references to “Adjusted EBITDA” have the meaning set forth in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”;

• references to “Albisu” refer to the 10 MW solar PV plant located in Uruguay;

• references to “Algonquin” refer to, as the context requires, either Algonquin Power & Utilities Corp., a North American diversified generation, transmission and distribution utility, or Algonquin Power & Utilities Corp. together with its subsidiaries;

• references to “Amherst” refer to Amherst Island Partnership, the holding company of Windlectric Inc;

• references to “Annual Consolidated Financial Statements” refer to the audited annual consolidated financial statements as of December 31, 2022 and 2021 and for the years ended December 31, 2022, 2021 and 2020, including the related notes thereto, prepared in accordance with IFRS as issued by the IASB (as such terms are defined herein), included in our Annual Report;

• references to “Annual Report” refer to our Annual Report on Form 20-F for the year ended December 31, 2022, filed with the SEC on March 1, 2023;

• references to “Atlantica Jersey” refer to Atlantica Sustainable Infrastructure Jersey Limited, a wholly-owned subsidiary of Atlantica;

• references to “ATM Plan Letter Agreement” refer to the agreement by and among the Company and Algonquin dated August 3, 2021, pursuant to which the Company offers Algonquin shall have the right but not the obligation, on a quarterly basis, to purchase a number of ordinary shares to maintain its percentage interest in Atlantica at the average price of the shares sold under the Distribution Agreement in the previous quarter, as adjusted;

• references to “ATN” refer to ATN S.A., the operational electric transmission asset in Peru, which is part of the Guaranteed Transmission System;

• references to “ATS” refer to Atlantica Transmision Sur S.A.;

• references to “AYES Canada” refer to Atlantica Sustainable Infrastructure Energy Solutions Canada Inc., a vehicle formed by Atlantica and Algonquin to channel co-investment opportunities;

• references to “Befesa Agua Tenes” refer to Befesa Agua Tenes, S.L.U.;

• references to “cash available for distribution” or “CAFD” refer to the cash distributions received by the Company from its subsidiaries minus cash expenses of the Company, including third-party debt service and general and administrative expenses;

3

• references to “Calgary District Heating” or “Calgary” refer to the 55 MWt thermal capacity district heating asset in the city of Calgary which we acquired in May 2021;

• references to “Chile PV 1” refer to the solar PV plant of 55 MW located in Chile;

• references to “Chile PV 2” refer to the solar PV plant of 40 MW located in Chile;

• references to “Chile PV 3” refer to the solar PV plant of 73 MW located in Chile;

• references to “Chile TL3” refer to the 50-mile transmission line located in Chile;

• references to “Chile TL4” refer to the 63-mile transmission line located in Chile;

• references to “Consolidated Condensed Interim Financial Statements” refer to the consolidated condensed unaudited interim financial statements as of March 31, 2023 and for the three-month periods ended March 31, 2023 and 2022, including the related notes thereto prepared in accordance with IFRS as issued by the IASB, which form a part of this quarterly report;

• references to “COD” refer to the commercial operation date of the applicable facility;

• references to “Coso” refer to the 135 MW geothermal plant located in California;

• references to “Distribution Agreement” refer to the agreement entered into with BofA Securities, Inc., MUFG Securities Americas Inc. and RBC Capital Markets LLC, as sales agents, dated February 28, 2022 as amended on May 9, 2022, under which we may offer and sell from time to time up to $150 million of our ordinary shares and pursuant to which such sales agents may sell our ordinary shares by any method permitted by law deemed to be an “at the market offering” as defined by Rule 415(a)(4) promulgated under the U.S. Securities Act of 1933;

• references to “EMEA” refer to Europe, Middle East and Africa;

• references to “Eskom” refer to Eskom Holdings SOC Limited, together with its subsidiaries, unless the context otherwise requires;

• references to “EURIBOR” refer to Euro Interbank Offered Rate, a daily reference rate published by the European Money Markets Institute, based on the average interest rates at which Eurozone banks offer to lend unsecured funds to other banks in the euro wholesale money market;

• references to “EU” refer to the European Union;

• references to “Exchange Act” refer to the U.S. Securities Exchange Act of 1934, or any successor statute, and the rules and regulations promulgated by the SEC thereunder;

• references to “Federal Financing Bank” refer to a U.S. government corporation by that name;

• references to “Fitch” refer to Fitch Ratings Inc.;

• references to “Green Exchangeable Notes” refer to the $115 million green exchangeable senior notes due in 2025 issued by Atlantica Jersey on July 17, 2020, and fully and unconditionally guaranteed on a senior, unsecured basis, by Atlantica, as further described in “Item 2 — Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Green Exchangeable Notes”;

• references to “Green Senior Notes” refer to the $400 million green senior notes due in 2028, as further described in “Item 2 — Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—-Green Senior Notes”;

4

• references to “gross capacity” refer to the maximum, or rated, power generation capacity, in MW, of a facility or group of facilities, without adjusting for the facility’s power parasitics’ consumption, or by our percentage of ownership interest in such facility as of the date of this quarterly report;

• references to “GWh” refer to gigawatt hour;

• references to “IAS” refer to International Accounting Standards issued by the IASB;

• references to “IASB” refer to the International Accounting Standards Board;

• references to “IFRIC 12” refer to International Financial Reporting Interpretations Committee’s Interpretation 12—Service Concessions Arrangements;

• references to “IFRS as issued by the IASB” refer to International Financial Reporting Standards as issued by the IASB;

• references to “IRA” refer to the U.S. Inflation Reduction Act;

• references to “Italy PV” refer to the solar PV plants with combined capacity of 9.8 MW located in Italy;

• references to “ITC” refer to investment tax credits;

• references to “Kaxu” refer to the 100 MW solar plant located in South Africa;

• references to “La Sierpe” refer to the 20 MW solar PV plant located in Colombia;

• references to “La Tolua” refer to the 20 MW solar PV plant located in Colombia;

• references to “LIBOR” refer to London Interbank Offered Rate;

• references to “M ft3” refer to million standard cubic feet;

• references to “Monterrey” refer to the 142 MW gas-fired engine facility including 130 MW installed capacity and 12 MW battery capacity, located in Monterrey, Mexico;

• references to “Multinational Investment Guarantee Agency” refer to the Multinational Investment Guarantee Agency, a financial institution member of the World Bank Group which provides political insurance and credit enhancement guarantees;

• references to “MW” refer to megawatts;

• references to “MWh” refer to megawatt hour;

• references to “MWt” refer to thermal megawatts;

• references to “Moody’s” refer to Moody’s Investor Service Inc.;

• references to “Note Issuance Facility 2020” refer to the senior unsecured note facility dated July 8, 2020, as amended on March 30, 2021 of €140 million ($153 million), with Lucid Agency Services Limited, as facility agent and a group of funds managed by Westbourne Capital, as purchasers of the notes issued thereunder as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Note Issuance Facility 2020”;

• references to “O&M” refer to operation and maintenance services provided at our various facilities;

• references to “operation” refer to the status of projects that have reached COD;

• references to “Pemex” refer to Petróleos Mexicanos;

• references to “PG&E” refer to PG&E Corporation and its regulated utility subsidiary, Pacific Gas and Electric Company, collectively;

5

• references to “PPA” refer to the power purchase agreements through which our power generating assets have contracted to sell energy to various off-takers;

• references to “PV” refer to photovoltaic power;

• references to “Revolving Credit Facility” refer to the credit and guaranty agreement with a syndicate of banks entered into on May 10, 2018 as amended on January 24, 2019, August 2, 2019, December 17, 2019, August 28, 2020, March 1, 2021 and May 5, 2022 providing for a senior secured revolving credit facility in an aggregate principal amount of $450 million as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Revolving Credit Facility”;

• references to “Skikda” refer to the seawater desalination plant in Algeria, which is 34% owned by Atlantica;

• references to “SOFR” refer to Secured Overnight Financing Rate;

• references to “S&P” refer to S&P Global Rating;

• references to “Tenes” refer to Ténès Lilmiyah SpA, a water desalination plant in Algeria, which is 51% owned by Befesa Agua Tenes;

• references to “Tierra Linda” refer to the 10 MW solar PV plant located in Colombia;

• references to “U.K.” refer to the United Kingdom;

• references to “U.S.” or “United States” refer to the United States of America;

• references to “Vento II” refer to the wind portfolio in the U.S. in which we acquired a 49% interest in June 2021; and

• references to “we,” “us,” “our,” “Atlantica” and the “Company” refer to Atlantica Sustainable Infrastructure plc and its consolidated subsidiaries, and where the context otherwise requires to Atlantica Sustainable Infrastructure plc.

6

CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS

This report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as may result, are expected to, will continue, is anticipated, likely to be, believe, will, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict, aim and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Such statements occur throughout this report and include statements with respect to our expected trends and outlook, potential market and currency fluctuations, occurrence and effects of certain trigger and conversion events, our capital requirements, changes in market price of our shares, future regulatory requirements, the ability to identify and/or make future investments and acquisitions on favorable terms, ability to capture growth opportunities, reputational risks, divergence of interests between our company and that of our largest shareholder, tax and insurance implications, and more. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, important factors included in “Part I - Item 3.D.—Risk Factors” in our Annual Report (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on our operations and financial results, and could cause our actual results, performance or achievements, to differ materially from the future results, performance or achievements expressed or implied in forward-looking statements made by us or on our behalf in this report, in our Annual Report, in presentations, on our website, in response to questions or otherwise. These forward-looking statements include, but are not limited to, statements relating to:

• the condition of and changes in the debt and equity capital markets and other traditional liquidity sources and our ability to borrow additional funds, refinance existing debt and access capital markets, as well as our substantial indebtedness and the possibility that we may incur additional indebtedness going forward;

• the ability of our counterparties, including Pemex, to satisfy their financial commitments or business obligations and our ability to seek new counterparties in a competitive market;

• government regulation, including compliance with regulatory and permit requirements and changes in, market rules, rates, tariffs, environmental laws and policies affecting renewable energy, including the IRA and recent changes in regulation defining the remuneration of our solar assets in Spain;

• potential regulatory changes in Spain in relation to the proposed remuneration parameters for the year 2023 to be applicable to our solar assets in Spain published on December 28, 2022 in draft form and which are subject to final publication;

• changes in tax laws and regulations, including new taxes recently announced in Italy, Spain and the U.K.;

• risks relating to our activities in areas subject to economic, social and political uncertainties;

• global recession risks, volatility in the financial markets, a persistent inflationary environment, increases in interest rates and supply chain issues, and the related increases in prices of materials, labor, services and other costs and expenses required to operate our business;

• risks related to our ability to capture growth opportunities, develop, build and complete projects in time and within budget, including construction risks and risks associated with the arrangements with our joint venture partners;

• our ability to grow organically and inorganically, which depends on our ability to identify attractive development opportunities, attractive potential acquisitions, finance such opportunities and make new investments and acquisitions on favorable terms;

7

• risks relating to new assets and businesses which have a higher risk profile and our ability to transition these successfully;

• potential environmental liabilities and the cost and conditions of compliance with applicable environmental laws and regulations;

• risks related to our reliance on third-party contractors or suppliers, including issues with our O&M suppliers and their employees, among others, resulting from disagreements with subcontractors;

• risks related to disagreements and disputes with our employees, a union and employees represented by a union;

• risks related to our ability to maintain appropriate insurance over our assets;

• risks related to our facilities not performing as expected, unplanned outages, higher than expected operating costs and/ or capital expenditures, including as a result of interruptions or disruptions caused by supply chain issues and trade restrictions;

• risks related to our exposure in the labor market;

• risks related to extreme and chronic weather events related to climate change could damage our assets or result in significant liabilities and cause an increase in our operation and maintenance costs;

• the effects of litigation and other legal proceedings (including bankruptcy) against us our subsidiaries, our assets and our employees;

• price fluctuations, revocation and termination provisions in our off-take agreements and PPAs;

• risks related to information technology systems and cyber-attacks could significantly impact our operations and business;

• our electricity generation, our projections thereof and factors affecting production;

• risks related to our current or previous relationship with Abengoa, our former largest shareholder and formerly one of our main O&M suppliers, including bankruptcy and reputational risk and particularly the potential impact of Abengoa’s insolvency filing and liquidation process, as well as litigation risk;

• performing the O&M services directly and the successful integration of the O&M employees where the services thereunder have been recently replaced and internalized;

• our guidance targets or expectations with respect to Adjusted EBITDA derived from low-carbon footprint assets;

• risks related to our relationship with our shareholders, including Algonquin, our major shareholder;

• the process to explore and evaluate potential strategic alternatives, including the risk that this process may not lead to the approval or completion of any transaction or other strategic change;

• potential impact of the continuance of the COVID-19 pandemic and other potential pandemics on our business and our off-takers’, financial condition, results of operations and cash flows;

• reputational and financial damage caused by our off-takers PG&E, Pemex and Eskom;

• our plans relating to our financings, including refinancing plans;

• risks related to Russian military actions in Ukraine and across global geopolitical tensions; and

• other factors discussed in “Part I, Item 3.D.—Risk Factors” in our Annual Report.

8

Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time, and it is not possible for management to predict all of these factors, nor can it assess the impact of each of these factors on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

9

Consolidated condensed statements of financial position as of March 31, 2023 and December 31, 2022

Amounts in thousands of U.S. dollars

			As of March 31,		As of December 31,
	Note (1)		2023		2022
Assets
Non-current assets
Contracted concessional, PP&E and other intangible assets		6		7,432,696		7,483,259
Investments carried under the equity method		7		258,264		260,031
Other financial assets		8		158,320		176,237
Deferred tax assets				163,535		149,656
Total non-current assets				8,012,815		8,069,183
Current assets
Inventories				35,205		34,511
Trade and other receivables		12		268,053		200,334
Other financial assets		8		186,754		195,893
Cash and cash equivalents				602,856		600,990
Total current assets				1,092,868		1,031,728
Total assets				9,105,683		9,100,911

(1) Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

10

Consolidated condensed statements of financial position as of March 31, 2023 and December 31, 2022

Amounts in thousands of U.S. dollars

			As of March 31,			As of December 31,
	Note (1)		2023			2022
Equity and liabilities
Equity attributable to the Company
Share capital		13		11,615			11,606
Share premium		13		986,594			986,594
Capital reserves		13		763,263			814,951
Other reserves		9		326,922			345,567
Accumulated currency translation differences		13		(154,194	)		(161,307	)
Accumulated deficit		13		(407,739	)		(397,540	)
Non-controlling interests		13		183,368			189,176
Total equity				1,709,829			1,789,047
Non-current liabilities
Long-term corporate debt		14		1,040,998			1,000,503
Long-term project debt		15		4,252,226			4,226,518
Grants and other liabilities		16		1,246,433			1,252,513
Derivative liabilities		9		26,302			16,847
Deferred tax liabilities				283,738			296,481
Total non-current liabilities				6,849,697			6,792,862
Current liabilities
Short-term corporate debt		14		36,362			16,697
Short-term project debt		15		344,397			326,534
Trade payables and other current liabilities		17		134,007			140,230
Income and other tax payables				31,391			35,541
Total current liabilities				546,157			519,002
Total equity and liabilities				9,105,683			9,100,911

(1) Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

11

Consolidated condensed income statements for the three-month periods ended March 31, 2023 and 2022

Amounts in thousands of U.S. dollars

	Note (1)		For the three-month period ended March 31,
			2023			2022
Revenue		4		242,509			247,452
Other operating income		20		22,620			19,373
Employee benefit expenses				(23,840	)		(19,469	)
Depreciation, amortization, and impairment charges		4		(103,790	)		(100,925	)
Other operating expenses		20		(78,881	)		(87,933	)
Operating profit				58,618			58,498
Financial income		19		7,997			992
Financial expense		19		(84,852	)		(83,402	)
Net exchange differences		19		1,705			3,073
Other financial expense, net		19		(5,284	)		(1,130	)
Financial expense, net				(80,434	)		(80,467	)
Share of profit of entities carried under the equity method				6,187			8,221
Loss before income tax				(15,629	)		(13,748	)
Income tax		18		9,656			3,906
Loss for the period				(5,973	)		(9,842	)
Profit attributable to non-controlling interests				(5,017	)		(2,200	)
Loss for the period attributable to the Company				(10,990	)		(12,042	)
Weighted average number of ordinary shares outstanding (thousands) - basic		21		116,140			112,741
Weighted average number of ordinary shares outstanding (thousands) - diluted		21		119,487			116,894
Basic earnings per share (U.S. dollar per share)		21		(0.09	)		(0.11	)
Diluted earnings per share (U.S. dollar per share) (*)		21		(0.09	)		(0.11	)

(*) Antidilutive effect applied in the case of loss for the period (see Note 21)

(1) Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

12

Consolidated condensed statements of comprehensive income for the three-month periods ended March 31, 2023 and 2022

Amounts in thousands of U.S. dollars

			For the three-month period ended March 31,
	Note (1)		2023			2022
Loss for the period				(5,973	)		(9,842	)
Items that may be subject to transfer to income statement
Change in fair value of cash flow hedges				(19,902	)		79,781
Currency translation differences				8,430			(5,134	)
Tax effect				3,629			(15,863	)
Net income recognized directly in equity				(7,843	)		58,784
Cash flow hedges		9		(6,069	)		12,140
Tax effect				1,517			(3,035	)
Transfers to income statement				(4,552	)		9,105
Other comprehensive income/(loss)				(12,395	)		67,889
Total comprehensive income/(loss) for the period				(18,368	)		58,047
Total comprehensive income attributable to non-controlling interests				(4,154	)		(9,060	)
Total comprehensive income/(loss) attributable to the Company				(22,522	)		48,987

(1) Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

13

Consolidated condensed statements of changes in equity for the three-month periods ended March 31, 2023 and 2022

Amounts in thousands of U.S. dollars

	Share capital		Share premium		Capital reserves			Other reserves			Accumulated currency translation differences			Accumulated deficit			Total equity attributable to the Company			Non- controlling interests			Total equity
Balance as of January 1, 2022		11,240		872,011		1,020,027			171,272			(133,450	)		(398,701	)		1,542,399			206,206			1,748,605
Profit/(loss) for the three -month period after taxes		-		-		-			-			-			(12,042	)		(12,042	)		2,200			(9,842	)
Change in fair value of cash flow hedges net of transfer to income statement		-		-		-			81,227			-			1,230			82,457			9,464			91,921
Currency translation differences		-		-		-			-			(4,754	)		-			(4,754	)		(380	)		(5,134	)
Tax effect		-		-		-			(16,674	)		-			-			(16,674	)		(2,224	)		(18,898	)
Other comprehensive income		-		-		-			64,553			(4,754	)		1,230			61,029			6,860			67,889
Total comprehensive income		-		-		-			64,553			(4,754	)		(10,812	)		48,987			9,060			58,047
Capital increase (Note 13)		170		52,231		(834	)		-			-			-			51,567			-			51,567
Share-based compensation (Note 13)		-		-		-			-			-			1,239			1,239			-			1,239
Distributions (Note 13)		-		-		(49,674	)		-			-			-			(49,674	)		(7,288	)		(56,962	)
Balance as of March 31, 2022		11,410		924,242		969,519			235,825			(138,204	)		(408,274	)		1,594,518			207,978			1,802,496

Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

14

	Share capital		Share premium		Capital reserves			Other reserves			Accumulated currency translation differences			Accumulated deficit			Total equity attributable to the Company			Non- controlling interests			Total equity
Balance as of January 1, 2023		11,606		986,594		814,951			345,567			(161,307	)		(397,540	)		1,599,871			189,176			1,789,047
Profit/(loss) for the three -month period after taxes		-		-		-			-			-			(10,990	)		(10,990	)		5,017			(5,973	)
Change in fair value of cash flow hedges net of transfer to income statement		-		-		-			(23,164	)		-			-			(23,164	)		(2,807	)		(25,971	)
Currency translation differences		-		-		-			-			7,113			-			7,113			1,317			8,430
Tax effect		-		-		-			4,519			-			-			4,519			627			5,146
Other comprehensive income		-		-		-			(18,645	)		7,113			-			(11,532	)		(863	)		(12,395	)
Total comprehensive income		-		-		-			(18,645	)		7,113			(10,990	)		(22,522	)		4,154			(18,368	)
Changes in the scope (Note 7)		-		-		-			-			-			-			-			(2,817	)		(2,817	)
Share-based compensation (Note 13)		9		-		-			-			-			791			800			-			800
Distributions (Note 13)		-		-		(51,688	)		-			-			-			(51,688	)		(7,145	)		(58,833	)
Balance as of March 31, 2023		11,615		986,594		763,263			326,922			(154,194	)		(407,739	)		1,526,461			183,368			1,709,829

Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

15

Consolidated condensed cash flows statements for the three-month periods ended March 31, 2023 and 2022

Amounts in thousands of U.S. dollars

	Note (1)		For the three-month periods ended March 31,
			2023			2022
I. Loss for the period				(5,973	)		(9,842	)
Financial expense and non-monetary adjustments				171,121			182,751
II. Loss for the period adjusted by non-monetary items				165,148			172,909
III. Changes in working capital				(93,263	)		(19,048	)
Net interest and income tax paid				(30,179	)		(16,546	)
A. Net cash provided by operating activities				41,706			137,315
Acquisitions of subsidiaries and entities under the equity method		5&7		(2,496	)		(39,009	)
Investments in operating concessional assets		6		(7,630	)		(2,907	)
Investments in assets under development or construction		6		(7,019	)		(3,601	)
Distributions from entities under the equity method		7		12,401			31,870
Net (investment)/divestment in other non-current financial assets				5,613			697
B. Net cash provided by/(used in) investing activities				869			(12,950	)
Proceeds from project debt		15		213,884			-
Proceeds from corporate debt		14		65,078			47,593
Repayment of project debt		15		(244,427	)		(43,882	)
Repayment of corporate debt		14		(18,971	)		(8,171	)
Dividends paid to Company´s shareholders		13		(51,688	)		(49,674	)
Dividends paid to non-controlling interests		13		(6,011	)		(6,221	)
Capital increase		13		-			51,553
C. Net cash used in financing activities				(42,135	)		(8,802	)
Net increase in cash and cash equivalents				440			115,563
Cash and cash equivalents at the beginning of the period				600,990			622,689
Translation differences in cash and cash equivalents				1,426			749
Cash and cash equivalents at the end of the period				602,856			739,001

(1) Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.

16

Notes to the consolidated condensed interim financial statements

Note 1.- Nature of the business	18
Note 2.- Basis of preparation	20
Note 3.- Financial risk management	21
Note 4.- Financial information by segment	21
Note 5.- Business combinations	26
Note 6.- Contracted concessional, PP&E and other intangible assets	27
Note 7.- Investments carried under the equity method	28
Note 8.- Financial assets	29
Note 9.- Derivative financial instruments	29
Note 10.- Fair value of financial instruments	30
Note 11.- Related parties	30
Note 12.- Trade and other receivables	31
Note 13.- Equity	31
Note 14.- Corporate debt	32
Note 15.- Project debt	34
Note 16.- Grants and other liabilities	35
Note 17.-Trade payables and other current liabilities	36
Note 18.- Income tax	36
Note 19.- Financial expense, net	36
Note 20.- Other operating income and expenses	37
Note 21.- Earnings per share	37
Note 22.- Subsequent events	38

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Note 1. - Nature of the business

Atlantica Sustainable Infrastructure plc (“Atlantica” or the “Company”) is a sustainable infrastructure company with a majority of its business in renewable energy assets. Atlantica currently owns, manages and invests in renewable energy, storage, efficient natural gas and heat, electric transmission lines and water assets focused on North America (the United States, Canada and Mexico), South America (Peru, Chile, Colombia and Uruguay) and EMEA (Spain, Italy, Algeria and South Africa).

Atlantica’s shares trade on the NASDAQ Global Select Market under the symbol “AY”.

In March 2023, the Company completed the process of transitioning the O&M services for the assets in Spain where Abengoa was still the supplier to an Atlantica’ subsidiary (Note 5). After this transfer, the Company performs, through the subsidiary Rioglass Servicios S.L.U., the O&M services with its own personnel for assets representing approximately 72% of the consolidated revenue in 2022. Abengoa currently provides O&M services for assets representing less than 5% of the consolidated revenue of the Company for the year ended December 31, 2022.

The following three assets that the Company had under construction during 2022, finished construction and reached COD in the first quarter of 2023:

- Albisu, a 10 MW PV asset wholly owned by the Company. Albisu is located in the city of Salto (Uruguay). The asset has a 15-year PPA with Montevideo Refrescos, S.R.L, a subsidiary of Coca-Cola Femsa., S.A.B. de C.V. The PPA is denominated in local currency with a maximum and minimum price in U.S. dollars and is adjusted monthly based on a formula referring to U.S. Producer Price Index (PPI), Uruguay’s Consumer Price Index (CPI) and the applicable UYU/U.S. dollar exchange rate.

- La Tolua and Tierra Linda, two solar PV assets in Colombia with a combined capacity of 30 MW. Each plant has a 10-year PPA in local currency indexed to local inflation with Coenersa, the largest independent electricity wholesaler in Colombia.

During the year 2022, the Company completed the following investments:

- On January 17, 2022, the Company closed the acquisition of Chile TL4, a 63-mile transmission line and 2 substations in Chile for a total equity investment of $38.4 million (Note 5). The Company expects to expand the transmission line in 2024, which would represent an additional investment of approximately $8 million. The asset has fully contracted revenues in U.S dollars, with inflation escalation and a 50-year remaining contract life. The off-takers are several mini-hydro plants that receive contracted or regulated payments.

- On April 4, 2022, the Company closed the acquisition of Italy PV 4, a 3.6 MW solar portfolio in Italy for a total equity investment of $3.7 million (Note 5). The asset has regulated revenues under a feed in tariff until 2031.

- On September 2, 2022, the Company completed its third investment through its Chilean renewable energy platform in a 73 MW solar PV plant, Chile PV 3, located in Chile, for $7.7 million corresponding to a 35% of equity interest (Note 5). The Company expects to install batteries with a capacity of approximately 100 MWh in 2023-2024. Total investment including batteries is expected to be in the range of $15 million to $25 million depending on the capital structure. Part of the asset’s revenue is currently based on capacity payments. Adding storage would increase the portion of capacity payments.

- On November 16, 2022, the Company closed the acquisition of a 49% interest, with joint control, in an 80 MW portfolio of solar PV projects in Chile, Chile PMGD, which is currently starting construction. Atlantica´s economic rights are expected to be approximately 70%. Total investment in equity and preferred equity is expected to be approximately $30 million and Commercial Operation Date (“COD”) is expected to be progressive in 2023 and 2024. Revenue for these assets is regulated under the Small Distributed Generation Means Regulation Regime (“PMGD”) for projects with a capacity equal or lower than 9MW, which allows to sell electricity through a stabilized price.

The following table provides an overview of the main operating assets the Company owned or had an interest in as of March 31, 2023:

Assets	Type	Ownership	Location	Currency(9)	Capacity (Gross)	Counterparty Credit Ratings(10)	COD*	Contract Years Remaining(17)
Solana	Renewable (Solar)	100%	Arizona (USA)	USD	280 MW	BBB+/A3/BBB+	2013	21
Mojave	Renewable (Solar)	100%	California (USA)	USD	280 MW	BB-/ Ba2/BB+	2014	17
Coso	Renewable (Geothermal)	100%	California (USA)	USD	135 MW	Investment Grade(11)	1987-1989	19

18

Elkhorn Valley(16)	Renewable (Wind)	49%	Oregon (USA)	USD	101 MW	BBB/Baa1/--	2007	5
Prairie Star(16)	Renewable (Wind)	49%	Minnesota (USA)	USD	101 MW	--/A3/A-	2007	5
Twin Groves II(16)	Renewable (Wind)	49%	Illinois (USA)	USD	198 MW	BBB/Baa2/--	2008	3
Lone Star II(16)	Renewable (Wind)	49%	Texas (USA)	USD	196 MW	N/A	2008	N/A
Chile PV 1	Renewable (Solar)	35%(1)	Chile	USD	55 MW	N/A	2016	N/A
Chile PV 2	Renewable (Solar)	35%(1)	Chile	USD	40 MW	Not rated	2017	8
Chile PV 3	Renewable (Solar)	35%(1)	Chile	USD	73 MW	N/A	2014	N/A
La Sierpe	Renewable (Solar)	100%	Colombia	COP	20 MW	Not rated	2021	13
La Tolua	Renewable (Solar)	100%	Colombia	COP	20 MW	Not rated	2023	10
Tierra Linda	Renewable (Solar)	100%	Colombia	COP	10 MW	Not rated	2023	10
Albisu	Renewable (Solar)	100%	Uruguay	UYU	10 MW	Not rated	2023	15
Palmatir	Renewable (Wind)	100%	Uruguay	USD	50 MW	BBB+/Baa2/BBB-(12)	2014	11
Cadonal	Renewable (Wind)	100%	Uruguay	USD	50 MW	BBB+/Baa2/BBB-(12)	2014	12
Melowind	Renewable (Wind)	100%	Uruguay	USD	50 MW	BBB+/Baa2/BBB-	2015	13
Mini-Hydro	Renewable (Hydraulic)	100%	Peru	USD	4 MW	BBB/Baa1/BBB	2012	10
Solaben 2 & 3	Renewable (Solar)	70%(2)	Spain	Euro	2x50 MW	A/Baa1/A-	2012	14/15
Solacor 1 & 2	Renewable (Solar)	87%(3)	Spain	Euro	2x50 MW	A/Baa1/A-	2012	14/14
PS10 & PS20	Renewable (Solar)	100%	Spain	Euro	31 MW	A/Baa1/A-	2007&2009	9/11
Helioenergy 1 & 2	Renewable (Solar)	100%	Spain	Euro	2x50 MW	A/Baa1/A-	2011	14/14
Helios 1 & 2	Renewable (Solar)	100%	Spain	Euro	2x50 MW	A/Baa1/A-	2012	14/14
Solnova 1, 3 & 4	Renewable (Solar)	100%	Spain	Euro	3x50 MW	A/Baa1/A-	2010	12/12/12
Solaben 1 & 6	Renewable (Solar)	100%	Spain	Euro	2x50 MW	A/Baa1/A-	2013	15/15
Seville PV	Renewable (Solar)	80%(4)	Spain	Euro	1 MW	A/Baa1/A-	2006	13
Italy PV 1	Renewable (Solar)	100%	Italy	Euro	1.6 MW	BBB/Baa3/BBB	2010	8
Italy PV 2	Renewable (Solar)	100%	Italy	Euro	2.1 MW	BBB/Baa3/BBB	2011	8
Italy PV 3	Renewable (Solar)	100%	Italy	Euro	2.5 MW	BBB/Baa3/BBB	2012	9
Italy PV 4	Renewable (Solar)	100%	Italy	Euro	3.6 MW	BBB/Baa3/BBB	2011	8

Kaxu	Renewable (Solar)	51%(5)	South Africa	Rand	100 MW	BB-/Ba2/BB-(13)	2015	12
Calgary	Efficient natural gas &heat	100%	Canada	CAD	55 MWt	~41% A+ or higher(14)	2010	18
ACT	Efficient natural gas & heat	100%	Mexico	USD	300 MW	BBB/B1/BB-	2013	10
Monterrey	Efficient natural gas &heat	30%	Mexico	USD	142 MW	Not rated	2018	23
ATN (15)	Transmission line	100%	Peru	USD	379 miles	BBB/Baa1/BBB	2011	18
ATS	Transmission line	100%	Peru	USD	569 miles	BBB/Baa1/BBB	2014	21
ATN 2	Transmission line	100%	Peru	USD	81 miles	Not rated	2015	10
Quadra 1 & 2	Transmission line	100%	Chile	USD	49 miles/32 miles	Not rated	2014	12/12
Palmucho	Transmission line	100%	Chile	USD	6 miles	BBB/ -- /BBB+	2007	15
Chile TL3	Transmission line	100%	Chile	USD	50 miles	A/A2/A-	1993	N/A
Chile TL4	Transmission line	100%	Chile	USD	63 miles	Not rated	2016	49
Skikda	Water	34.20%(6)	Algeria	USD	3.5 M ft3/day	Not rated	2009	11
Honaine	Water	25.50%(7)	Algeria	USD	7 M ft3/day	Not rated	2012	14
Tenes	Water	51%(8)	Algeria	USD	7 M ft3/day	Not rated	2015	17

(1) 65% of the shares in Chile PV 1, Chile PV 2 and Chile PV 3 are indirectly held by financial partners through the renewable energy platform of the Company in Chile.

(2) Itochu Corporation holds 30% of the shares in each of Solaben 2 and Solaben 3.

(3) JGC holds 13% of the shares in each of Solacor 1 and Solacor 2.

(4) Instituto para la Diversificación y Ahorro de la Energía (“Idae”) holds 20% of the shares in Seville PV.

(5) Kaxu is owned by the Company (51%), Industrial Development Corporation of South Africa (“IDC”, 29%) and Kaxu Community Trust (20%).

(6) Algerian Energy Company, SPA owns 49% of Skikda and Sacyr Agua, S.L. owns the remaining 16.8%.

(7) Algerian Energy Company, SPA owns 49% of Honaine and Sacyr Agua, S.L. owns the remaining 25.5%.

(8) Algerian Energy Company, SPA owns 49% of Tenes. The Company has an investment in Tenes through a secured loan to Befesa Agua Tenes (the holding company of Tenes) and the right to appoint a majority at the board of directors of the project company. Therefore, the Company controls Tenes since May 31, 2020, and fully consolidates the asset from that date.

(9) Certain contracts denominated in U.S. dollars are payable in local currency.

(10) Reflects the counterparty’s credit ratings issued by Standard & Poor’s Ratings Services, or S&P, Moody’s Investors Service Inc., or Moody’s, and Fitch Ratings Ltd, or Fitch. Not applicable (“N/A”) when the asset has no PPA.

(11) Refers to the credit rating of two Community Choice Aggregators: Silicon Valley Clean Energy and Monterrey Bar Community Power, both with A Rating from S&P and Southern California Public Power Authority. The third off-taker is not rated.

(12) Refers to the credit rating of Uruguay, as UTE (Administración Nacional de Usinas y Transmisoras Eléctricas) is unrated.

(13) Refers to the credit rating of the Republic of South Africa. The off-taker is Eskom, which is a state-owned utility company in South Africa.

19

(14) Refers to the credit rating of a diversified mix of 22 high credit quality clients (~41% A+ rating or higher, the rest is unrated).

(15) Including ATN Expansion 1 & 2.

(16) Part of Vento II Portfolio.

(17) As of March 31, 2023.

(*) Commercial Operation Date.

Note 2. - Basis of preparation

The accompanying Consolidated Condensed Interim Financial Statements represent the consolidated results of the Company and its subsidiaries.

The Company’s annual consolidated financial statements as of December 31, 2022, were approved by the Board of Directors on February 28, 2023.

These Consolidated Condensed Interim Financial Statements are presented in accordance with International Accounting Standards (“IAS”) 34, “Interim Financial Reporting”. In accordance with IAS 34, interim financial information is prepared solely in order to update the most recent annual consolidated financial statements prepared by the Company, placing emphasis on new activities, occurrences and circumstances that have taken place during the three-month period ended March 31, 2023, and not duplicating the information previously published in the annual consolidated financial statements for the year ended December 31, 2022. Therefore, the Consolidated Condensed Interim Financial Statements do not include all the information that would be required in a complete set of consolidated financial statements prepared in accordance with the IFRS-IASB (“International Financial Reporting Standards-International Accounting Standards Board”). In view of the above, for an adequate understanding of the information, these Consolidated Condensed Interim Financial Statements must be read together with Atlantica’s consolidated financial statements for the year ended December 31, 2022 included in the 2022 20-F.

In determining the information to be disclosed in the notes to the Consolidated Condensed Interim Financial Statements, Atlantica, in accordance with IAS 34, has taken into account its materiality in relation to the Consolidated Condensed Interim Financial Statements.

The Consolidated Condensed Interim Financial Statements are presented in U.S. dollars, which is the parent company’s functional and presentation currency. Amounts included in these Consolidated Condensed Interim Financial Statements are all expressed in thousands of U.S. dollars, unless otherwise indicated.

These Consolidated Condensed Interim Financial Statements were approved by the Board of Directors of the Company on May 4, 2023.

Application of new accounting standards

a) Standards, interpretations and amendments effective from January 1, 2023 under IFRS-IASB, applied by the Company in the preparation of these Consolidated Condensed Interim Financial Statements:

The applications of these amendments have not had any impact on these Consolidated Condensed Interim Financial Statements.

b) Standards, interpretations and amendments published by the IASB that will be effective for periods beginning on or after January 1, 2024:

The Company does not anticipate any significant impact on the Consolidated Condensed Interim Financial Statements derived from the application of the new standards and amendments that will be effective for annual periods beginning on or after January 1, 2024, although it is currently still in the process of evaluating such application.

The Company has not early adopted any standard, interpretation or amendment that has been issued but is not yet effective.

Use of estimates

Some of the accounting policies applied require the application of significant judgment by management to select the appropriate assumptions to determine these estimates. These assumptions and estimates are based on the Company´s historical experience, advice from experienced consultants, forecasts and other circumstances and expectations as of the close of the financial period. The assessment is considered in relation to the global economic situation of the industries and regions where the Company operates, taking into account future development of its businesses. By their nature, these judgments are subject to an inherent degree of uncertainty; therefore, actual results could materially differ from the estimates and assumptions used. In such cases, the carrying values of assets and liabilities are adjusted.

20

The most critical accounting policies, which require significant management estimates and judgment are as follows:

Estimates:

- Impairment of contracted concessional, PP&E and other intangible assets.

- Recoverability of deferred tax assets.

- Fair value of derivative financial instruments

- Fair value of identifiable assets and liabilities arising from a business combination

Judgement:

- Assessment of assets agreements.

- Assessment of control.

As of the date of preparation of these Consolidated Condensed Interim Financial Statements, no relevant changes in estimates made are anticipated and, therefore, no significant changes in the value of assets and liabilities recognized at March 31, 2023, are expected.

Although these estimates and assumptions are being made using all available facts and circumstances, it is possible that future events may require management to amend such estimates and assumptions in future periods. Changes in accounting estimates are recognized prospectively, in accordance with IAS 8, in the consolidated income statement of the period in which the change occurs.

Note 3. - Financial risk management

Atlantica’s activities are exposed to various financial risks: market risk (including currency risk and interest rate risk), credit risk and liquidity risk. Risk is managed by the Company’s Risk Management and Finance Departments, which are responsible for identifying and evaluating financial risks, quantifying them by project, region and company, in accordance with mandatory internal management rules. The internal management rules provide written policies for the management of overall risk, as well as for specific areas. The internal management policies of the Company also define the use of hedging instruments and derivatives and the investment of excess cash.

These Consolidated Condensed Interim Financial Statements do not include all financial risk management information and disclosures required for annual financial statements and should be read together with the information included in Note 3 to Atlantica’s annual consolidated financial statements as of December 31, 2022 included in the 2022 20-F.

Note 4. - Financial information by segment

Atlantica’s segment structure reflects how management currently makes financial decisions and allocates resources. Its operating and reportable segments are based on the following geographies where the contracted concessional assets are located: North America, South America and EMEA. In addition, based on the type of business, as of March 31, 2023, the Company had the following business sectors: Renewable energy, Efficient natural gas and Heat, Transmission lines and Water.

Atlantica’s Chief Operating Decision Maker (CODM), which is the CEO, assesses the performance and assignment of resources according to the identified operating segments. The CODM considers the revenue as a measure of the business activity and the Adjusted EBITDA as a measure of the performance of each segment. Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interests, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the these Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of Atlantica’s equity ownership).

In order to assess performance of the business, the CODM receives reports of each reportable segment using revenue and Adjusted EBITDA. Net interest expense evolution is assessed on a consolidated basis. Financial expense and amortization are not taken into consideration by the CODM for the allocation of resources.

In the three-month period ended March 31, 2023, Atlantica had three customers with revenues representing more than 10% of total revenue, two in the renewable energy and one in the efficient natural gas and heat business sectors. In the three-month period ended March 31, 2022, Atlantica had one customer with revenues representing more than 10% of total revenue, in the renewable energy business sector.

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a) The following tables show Revenue and Adjusted EBITDA by operating segments and business sectors for the three-month periods ended March 31, 2023 and 2022:

	Revenue				Adjusted EBITDA
	For the three-month period ended March 31,				For the three-month period ended March 31,
	($ in thousands)
Geography	2023		2022		2023		2022
North America		72,840		74,304		51,969		58,266
South America		43,720		38,528		33,788		29,129
EMEA		125,949		134,620		88,447		86,231
Total		242,509		247,452		174,204		173,626

	Revenue				Adjusted EBITDA
	For the three-month period ended March 31,				For the three-month period ended March 31,
	($ in thousands)
Business sectors	2023		2022		2023		2022
Renewable energy		172,601		182,101		119,122		122,223
Efficient natural gas & heat		27,403		25,327		22,610		21,699
Transmission lines		28,831		26,620		23,470		20,523
Water		13,674		13,404		9,002		9,181
Total		242,509		247,452		174,204		173,626

The reconciliation of segment Adjusted EBITDA with the loss attributable to the Company is as follows:

	For the three-month period ended March 31, ($ in thousands)
	2023			2022
Loss attributable to the Company		(10,990	)		(12,042	)
Profit attributable to non-controlling interests		5,017			2,200
Income tax		(9,656	)		(3,906	)
Financial expense, net		80,434			80,467
Depreciation, amortization, and impairment charges		103,790			100,925
Depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of Atlantica’s equity ownership)		5,609			5,982
Total segment Adjusted EBITDA		174,204			173,626

b) The assets and liabilities by operating segments and business sector as of March 31, 2023 and December 31, 2022 are as follows:

Assets and liabilities by geography as of March 31, 2023:

	North America		South America		EMEA		Balance as of March 31, 2023
	($ in thousands)
Assets allocated
Contracted concessional, PP&E and other intangible assets		3,138,564		1,226,461		3,067,671		7,432,696
Investments carried under the equity method		202,969		8,236		47,059		258,264
Other current financial assets		106,038		31,233		49,483		186,754
Cash and cash equivalents (project companies)		159,132		96,217		237,712		493,061
Subtotal allocated		3,606,703		1,362,147		3,401,925		8,370,775
Unallocated assets
Other non-current assets								321,855
Other current assets (including cash and cash equivalents at holding company level)								413,053
Subtotal unallocated								734,908
Total assets								9,105,683

22

	North America		South America		EMEA		Balance as of March 31, 2023
	($ in thousands)
Liabilities allocated
Long-term and short-term project debt		1,714,357		843,014		2,039,252		4,596,623
Grants and other liabilities		980,663		30,272		235,498		1,246,433
Subtotal allocated		2,695,020		873,286		2,274,750		5,843,056
Unallocated liabilities
Long-term and short-term corporate debt								1,077,360
Other non-current liabilities								310,040
Other current liabilities								165,398
Subtotal unallocated								1,552,798
Total liabilities								7,395,854
Equity unallocated								1,709,829
Total liabilities and equity unallocated								3,262,627
Total liabilities and equity								9,105,683

Assets and liabilities by geography as of December 31, 2022:

	North America		South America		EMEA		Balance as of December 31, 2022
Assets allocated
Contracted concessional, PP&E and other intangible assets		3,167,490		1,241,879		3,073,889		7,483,259
Investments carried under the equity method		210,704		4,450		44,878		260,031
Other current financial assets		118,385		31,136		46,373		195,893
Cash and cash equivalents (project companies)		187,568		85,697		266,557		539,822
Subtotal allocated		3,684,147		1,363,162		3,431,697		8,479,005
Unallocated assets
Other non-current assets								325,893
Other current assets (including cash and cash equivalents at holding company level)								296,013
Subtotal unallocated								621,906
Total assets								9,100,911

	North America		South America		EMEA		Balance as of December 31, 2022
Liabilities allocated
Long-term and short-term project debt		1,713,125		841,906		1,998,021		4,553,052
Grants and other liabilities		994,874		25,031		232,608		1,252,513
Subtotal allocated		2,707,999		866,937		2,230,629		5,805,565
Unallocated liabilities
Long-term and short-term corporate debt								1,017,200
Other non-current liabilities								313,328
Other current liabilities								175,771
Subtotal unallocated								1,506,299
Total liabilities								7,311,864
Equity unallocated								1,789,047
Total liabilities and equity unallocated								3,295,346
Total liabilities and equity								9,100,911

23

Assets and liabilities by business sector as of March 31, 2023:

	Renewable energy		Efficient natural gas & heat		Transmission lines		Water		Balance as of March 31, 2023
	($ in thousands)
Assets allocated
Contracted concessional assets, PP&E and other intangible assets		5,995,445		479,715		792,405		165,131		7,432,696
Investments carried under the equity method		199,817		9,563		4,450		44,434		258,264
Other current financial assets		5,120		104,851		30,656		46,127		186,754
Cash and cash equivalents (project companies)		361,982		40,116		67,235		23,728		493,061
Subtotal allocated		6,562,364		634,245		894,746		279,420		8,370,775
Unallocated assets
Other non-current assets										321,855
Other current assets (including cash and cash equivalents at holding company level)										413,053
Subtotal unallocated										734,908
Total assets										9,105,683

	Renewable energy		Efficient natural gas & heat		Transmission lines		Water		Balance as of March 31, 2023
	($ in thousands)
Liabilities allocated
Long-term and short-term project debt		3,495,259		428,079		588,356		84,929		4,596,623
Grants and other liabilities		1,206,035		32,090		5,814		2,494		1,246,433
Subtotal allocated		4,701,294		460,169		594,170		87,423		5,843,056
Unallocated liabilities
Long-term and short-term corporate debt										1,077,360
Other non-current liabilities										310,040
Other current liabilities										165,398
Subtotal unallocated										1,552,798
Total liabilities										7,395,854
Equity unallocated										1,709,829
Total liabilities and equity unallocated										3,262,627
Total liabilities and equity										9,105,683

Assets and liabilities by business sector as of December 31, 2022:

	Renewable energy		Efficient natural gas & Heat		Transmission lines		Water		Balance as of December 31, 2022
Assets allocated
Contracted concessional, PP&E and other intangible assets		6,035,091		485,431		800,067		162,670		7,483,259
Investments carried under the equity method		203,420		10,034		4,450		42,128		260,031
Other current financial assets		6,706		116,366		30,582		42,240		195,893
Cash and cash equivalents (project companies)		392,577		73,673		48,073		25,498		539,822
Subtotal allocated		6,637,794		685,504		883,172		272,536		8,479,005
Unallocated assets
Other non-current assets										325,893
Other current assets (including cash and cash equivalents at holding company level)										296,013
Subtotal unallocated										621,906
Total assets										9,100,911

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	Renewable energy		Efficient natural gas & Heat		Transmission lines		Water		Balance as of December 31, 2022
Liabilities allocated
Long-term and short-term project debt		3,442,625		440,999		582,689		86,739		4,553,052
Grants and other liabilities		1,211,878		32,138		6,040		2,457		1,252,513
Subtotal allocated		4,654,503		473,137		588,729		89,196		5,805,565
Unallocated liabilities
Long-term and short-term corporate debt										1,017,200
Other non-current liabilities										313,328
Other current liabilities										175,771
Subtotal unallocated										1,506,299
Total liabilities										7,311,864
Equity unallocated										1,789,047
Total liabilities and equity unallocated										3,295,346
Total liabilities and equity										9,100,911

c) The amount of depreciation, amortization and impairment charges recognized for the three-month periods ended March 31, 2023 and 2022 are as follows:

	For the three-month period ended March 31,
Depreciation, amortization and impairment by geography	2023			2022
	($ in thousands)
North America		(36,347	)		(31,692	)
South America		(14,203	)		(14,205	)
EMEA		(53,240	)		(55,028	)
Total		(103,790	)		(100,925	)

	For the three-month period ended March 31,
Depreciation, amortization and impairment by business sectors	2023			2022
	($ in thousands)
Renewable energy		(93,248	)		(95,270	)
Efficient natural gas & heat		(3,054	)		2,144
Transmission lines		(7,223	)		(7,407	)
Water		(265	)		(392	)
Total		(103,790	)		(100,925	)

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Note 5. – Business combinations

For the three-month period ended March 31, 2023

On March 1, 2023, the Company completed the process of transitioning the O&M services for the assets in Spain where Abengoa was still the supplier to an Atlantica’ subsidiary. This acquisition has been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. The O&M services are included within Renewable energy sector and the EMEA geography.

The fair value of assets and liabilities consolidated at the effective acquisition date is shown in the following table:

	Business combinations for the three-month period ended March 31, 2023
Property, plant and equipment under IAS 16		55
Intangible assets under IAS 38		4,871
Other current and non-current liabilities		(3,000	)
Total net assets acquired at fair value		1,926
Asset acquisition – purchase price		(1,926	)
Net result of business combinations		-

The purchase price equals the fair value of the net assets acquired.

The allocation of the purchase price is provisional as of March 31, 2023 and amounts indicated above may be adjusted during the measurement period to reflect new information obtained about facts and circumstances that existed at the acquisition date that, if known, would have affected the amounts recognized as of March 31, 2023. The measurement period will not exceed one year from the acquisition date.

The amount of revenue contributed by the acquisitions during the three-month period ended March 31, 2023 to the Consolidated Condensed Interim Financial Statements of the Company is nil, and the amount of profit after tax is $0.7 million. Had the acquisitions been consolidated from January 1, 2023, the consolidated statement of comprehensive income would not have included additional revenue and profit after tax of $2.0 million.

For the year ended December 31, 2022

On January 17, 2022, the Company closed the acquisition of Chile TL4, a 63-mile transmission line and 2 substations in Chile for a total equity investment of $38.4 million. Atlantica has control over Chile TL4 under IFRS 10, Consolidated Financial Statements. The acquisition of Chile TL4 had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Chile TL4 is included within the Transmission Lines sector and the South America geography.

On April 4, 2022, the Company closed the acquisition of Italy PV 4, a 3.6 MW solar portfolio in Italy for a total equity investment of $3.7 million. Atlantica has control over Italy PV 4 under IFRS 10, Consolidated Financial Statements. The acquisition of Italy PV 4 had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Italy PV4 is included within the Renewable energy sector and the EMEA geography.

On September 2, 2022 the Company closed the acquisition of Chile PV 3, a 73 MW solar PV plant through its renewable energy platform in Chile for a total equity investment of $7.7 million. Atlantica has control over Chile PV 3 under IFRS 10, Consolidated Financial Statements. The acquisition of Chile PV 3 had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations, showing 65% of non-controlling interests. Chile PV 3 is included within the Renewable energy sector and the South America geography.

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The fair value of assets and liabilities consolidated at the effective acquisition date is shown in aggregate on the basis that they are individually not significant in the following table:

	Business combinations for the year ended December 31, 2022
Property, plant and equipment under IAS 16		55,135
Rights of use under IFRS 16 (lessee) or intangible assets under IAS 38		26,794
Cash and cash equivalents		1,057
Other current assets		8,283
Non-current Project debt		(1,301	)
Current Project debt		(148	)
Other current and non-current liabilities		(25,853	)
Non-controlling interests		(14,300	)
Total net assets acquired at fair value		49,667
Asset acquisition – purchase price		(49,667	)
Net result of business combinations		-

The purchase price equaled the fair value of the net assets acquired.

The amount of revenue contributed by the acquisitions performed during 2022 to the Consolidated Financial Statements of the Company for the year 2022 was $6.2 million, and the amount of profit after tax was $1.7 million. Had the acquisitions been consolidated from January 1, 2022, the consolidated statement of comprehensive income would have included additional revenue of $4.8 million and additional profit after tax of $1.7 million.

In January 2023, the provisional period for the purchase price allocation of Chile TL4 closed and did not result in significant adjustments to the initial amounts recognized.

Note 6. - Contracted concessional, PP&E and other intangible assets

The Company has assets recorded as contracted concessional assets in accordance with IFRIC 12, property plant and equipment in accordance with IAS 16 and right of use assets under IFRS 16 or intangible assets under IAS 38.

The detail of assets included in the heading ‘Contracted concessional, PP&E and other intangible assets’ as of March 31, 2023 and December 31, 2022 is as follows:

	Financial assets under IFRIC 12			Financial assets under IFRS 16 (Lessor)		Intangible assets under IFRIC 12			Right of use assets under IFRS 16 (Lessee) and intangible assets under IAS 38			Property, plant and equipment under IAS 16			Total
	($ in thousands)
Cost		816,348			2,724		9,031,763			123,314			962,641			10,936,790
Amortization and impairment		(72,065	)		-		(3,195,237	)		(28,731	)		(208,061	)		(3,504,094	)
Total as of March 31, 2023		744,283			2,724		5,836,526			94,583			754,580			7,432,696

	Financial assets under IFRIC 12			Financial assets under IFRS 16 (Lessor)		Intangible assets under IFRIC 12			Right of use assets under IFRS 16 (Lessee) and intangible assets under IAS 38			Property, plant and equipment under IAS 16			Total
	($ in thousands)
Cost		818,170			2,787		8,976,243			109,176			956,606			10,862,982
Amortization and impairment		(69,557	)		-		(3,088,778	)		(26,316	)		(195,072	)		(3,379,723	)
Total as of December 31, 2022		748,613			2,787		5,887,465			82,860			761,534			7,483,259

No losses from impairment of contracted concessional, PP&E and other intangible assets, excluding the change in the provision for expected credit losses under IFRS 9, Financial instruments, were recorded during the three-month periods ended March 31, 2023 and 2022. The impairment provision based on the expected credit losses on contracted concessional financial assets increased by $3 million in the three-month period ended March 31, 2023 (decrease of $3 million in the three-month period ended March 31, 2022), primarily in ACT.

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Note 7. - Investments carried under the equity method

The table below shows the breakdown of the investments held in associates and joint ventures as of March 31, 2023 and December 31, 2022:

	Balance as of March 31, 2023		Balance as of December 31, 2022
	($ in thousands)
2007 Vento II, LLC		180,482		181,735
Windlectric Inc		12,923		18,935
Myah Bahr Honaine, S.P.A.		44,434		42,128
Pemcorp SAPI de CV		9,563		10,034
Akuo Atlantica PMGD  Holding S.P.A.		4,422		4,450
Colombian portfolio of renewable energy entities		3,786		-
Pectonex, R.F. Proprietary Limited		1,391		1,411
Evacuación Valdecaballeros, S.L.		812		858
Fontanil Solar, S.L.U.		229		229
Murum Solar, S.L.U.		222		222
Liberty Infraestructuras S.L.		-		29
Total		258,264		260,031

None of the entities referred to above is a listed company.

2007 Vento II, LLC, is the holding company of a 596 MW portfolio of wind assets (“Vento II”) in the U.S., 49% owned by Atlantica since June 16, 2021, and accounted for under the equity method in these Consolidated Condensed Interim Financial Statements.

Windlectric Inc., the project entity, is 100% owned by Amherst Island Partnership, itself 30% owned by Atlantica Yield Energy Solutions Canada Inc. (“AYES Canada”) and therefore accounted for under the equity method in these Consolidated Condensed Interim Financial Statements.

Myah Bahr Honaine, S.P.A., the project entity, is 51% owned by Geida Tlemcen, S.L., which is accounted for using the equity method in these Consolidated Condensed Interim Financial Statements. Geida Tlemcen, S.L. is 50% owned by Atlantica.

Pemcorp SAPI de CV, Monterrey´s project entity, is 100% owned by Arroyo Netherlands II B.V., which is accounted for under the equity method in these Consolidated Condensed Interim Financial Statements. Arroyo Netherlands II B.V. is 30% owned by Atlantica.

Akuo Atlantica PMGD Holding S.P.A.(“Akuo”) is the holding company of a 80 MW portfolio of solar PV assets in Chile, which is currently starting construction, 49% owned by Atlantica, with joint control since November 2022 and accounted for under the equity method in these Consolidated Condensed Interim Financial Statements.

The Colombian portfolio of renewable energy entities includes the following entities: VO Renovables SOL 1 S.A.S. E.S.P., SJ Renovables Sun 1 S.A.S. E.S, AC Renovables Sol 1 S.A.S. E.S, SJ Renovables Wind 1 S.A.S. E., PA Renovables Sol 1 S.A.S. E.S and Atlantica Hidro Colombia S.A.S. In March 2023, Atlantica sold part of its equity interest in these entities to a partner, which now holds a 50% equity interest. Atlantica and the partner hold 50% of the shares each and have joint control over these entities in accordance with IFRS 11, Joint arrangements. As a result, the subsidiaries, which were previously fully consolidated showing 30% of non-controlling interest, are now recorded as an investment in joint ventures under the equity method in these Consolidated Condensed Interim Financial Statements in accordance with IAS 28, Investments in associates and joint ventures. Carrying amount of the non-controlling interests in these entities were derecognized at the date control was lost by Atlantica. Further to the sale of part of its equity interest, Atlantica recorded a gain of $4.6 million as Other operating income in the three-month period ended March 31, 2023 (Note 20).

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The decrease in investments carried under the equity method as of March 31, 2023, is primarily due to the distributions received by AYES Canada from Amherst Island Partnership for $6.1 million related to the investment in Windlectric Inc. A significant portion of the distributions received from Amherst are distributed by the Company to its partner in this project (Note 13). This decrease is partially offset by the recognition of the Colombian portfolio of renewable energy entities as entities accounted for under the equity method in the period.

Note 8. - Financial assets

The detail of Non-current and Current financial assets as of March 31, 2023 and December 31, 2022 is as follows:

	Balance as of March 31, 2023		Balance as of December 31, 2022
	($ in thousands)
Fair Value through OCI (Investment in Ten West link)		12,459		15,959
Derivative assets (Note 9)		75,162		89,806
Other receivable accounts at amortized cost		70,699		70,472
Total non-current financial assets		158,320		176,237
Contracted concessional financial assets		179,450		186,841
Derivative assets (Note 9)		6,236		7,575
Other receivable accounts at amortized cost		1,068		1,477
Total current financial assets		186,754		195,893

Investment in Ten West Link is a 12.5% interest in a 114-mile transmission line in the U.S., currently under construction.

Note 9. - Derivative financial instruments

The breakdowns of the fair value amount of the derivative financial instruments as of March 31, 2023 and December 31, 2022 are as follows:

	Balance as of March 31, 2023				Balance as of December 31, 2022
	($ in thousands)
	Assets		Liabilities		Assets		Liabilities
Interest rate cash flow hedge		77,982		18,661		94,192		12,159
Foreign exchange derivatives instruments		3,416		-		3,189		-
Notes conversion option (Note 14)		-		7,641		-		4,688
Total		81,398		26,302		97,381		16,847

The derivatives are primarily interest rate cash flow hedges. All are classified as non-current assets or non-current liabilities, as they hedge long-term financing agreements.

The net amount of the fair value of interest rate derivatives designated as cash flow hedges transferred to the consolidated condensed income statement is a profit of $6.1 million for the three-month period ended March 31, 2023 (loss of $12.1 million for the three-month period ended March 31, 2022).

The after-tax results accumulated in equity in connection with derivatives designated as cash flow hedges as of March 31, 2023 and December 31, 2022 amount to a profit of $326.9 million and $345.6 million, respectively.

Additionally, the Company has currency options with leading international financial institutions, which guarantee minimum Euro-U.S. dollar exchange rates. The strategy of the Company is to hedge the exchange rate for the net distributions from its European assets after deducting euro-denominated interest payments and euro-denominated general and administrative expenses. Through currency options, the strategy of the Company is to hedge 100% of its euro-denominated net exposure for the next 12 months and 75% of its euro denominated net exposure for the following 12 months, on a rolling basis. Change in fair value of these foreign exchange derivatives instruments are directly recorded in the consolidated income statement.

Finally, the conversion option of the Green Exchangeable Notes issued in July 2020 (Note 14) is recorded as a derivative with a fair value (liability) of $7.6 million as of March 31, 2023 ($4.7 million as of December 31, 2022).

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Note 10. - Fair value of financial instruments

Financial instruments measured at fair value are classified based on the nature of the inputs used for the calculation of fair value:

● Level 1: Inputs are quoted prices in active markets for identical assets or liabilities.

● Level 2: Fair value is measured based on inputs other than quoted prices included within Level 1 that are observable for the asset or liability, either directly (i.e. as prices) or indirectly (i.e. derived from prices).

● Level 3: Fair value is measured based on unobservable inputs for the asset or liability.

As of March 31, 2023, all the financial instruments measured at fair value correspond to derivatives and have been classified as Level 2, except for the investments held in Ten West Link, which has been classified as Level 3.

Note 11. - Related parties

The related parties of the Company are primarily Algonquin Power & Utilities Corp. (“Algonquin”) and its subsidiaries, non-controlling interests (Note 13), entities accounted for under the equity method (Note 7), as well as the Directors and the Senior Management of the Company.

Details of balances with related parties as of March 31, 2023 and December 31, 2022 are as follows:

	At the end of the period	Receivables (current)	Receivables (non- current)	Payables (current)	Payables (non- current)
Entities accounted for under the equity method:		$000	$000	$000	$000
Arroyo Netherland II B.V	2023	1,390	17,092	-	-
	2022	1,097	17,006	-	-
Akuo Atlantica PMGD  Holding S.P.A	2023	-	2,674	-	-
	2022	-	504	-	-
Colombian portfolio of renewable energy entities	2023	-	2,127	-	-
	2022	-	-	-	-
Other	2023	-	-	-	-
	2022	127	-	-	-
Non controlling interest:
Algonquin	2023	94	-	5,926	-
	2022	-	-	4,762	-
JGC Corporation	2023	-	-	-	5,831
	2022	-	-	-	6,088
Other	2023	58	-	22	-
	2022	-	-	21	-
Other related parties:
	2023	1,312	-	-	-
Atlantica´s partner in Colombia (Note 7)	2022	-	-	-	-
Total	2023	2,854	21,892	5,947	5,831
	2022	1,224	17,511	4,783	6,088

Receivables with Arroyo Netherland II B.V, the holding company of Pemcorp SAPI de CV, Monterrey´s project entity (Note 7), correspond to the short and long term portion of the loan that was granted at acquisition date of the project and accrues an interest of Libor plus 6.31%.

Current payables primarily include the dividend to be paid by AYES Canada to Algonquin.

Non-current payables with JGC Corporation include a subordinated debt with Solacor 1 and Solacor 2 that accrues an interest of Euribor plus 2.5% and with maturity date in 2037.

30

Non-current receivables with Akuo Atlantica PMGD Holding S.P.A. include a loan that accrues a fixed interest of 8.75%.

Current receivables with the partner of the Company in Colombia include Atlantica´s pending purchase price payment to be received for the partial sale of its investment in the Colombian portfolio of renewable energy entities (Note 7).

The profit and loss impact of transactions carried out by entities included in these Consolidated Condensed Interim Financial Statements with related parties, for the three-month periods ended March 31, 2023 and 2022 have been as follows:

		Financial income		Financial expense
Entities accounted for under the equity method:			$000		$000
Arroyo Netherland II B.V	2023		347		-
	2022		382		-
Non controlling interest:
Other	2023		-		(79	)
	2022		-		(120	)
Total	2023		347		(79	)
	2022		382		(120	)

Note 12. - Trade and other receivables

Trade and other receivables as of March 31, 2023 and December 31, 2022, consist of the following:

	Balance as of March 31,		Balance as of December 31,
	2023		2022
	($ in thousands)
Trade receivables		206,880		125,437
Tax receivables		39,749		45,680
Prepayments		16,297		11,827
Other accounts receivable		5,127		17,390
Total		268,053		200,334

The increase in trade receivables is primarily due to collections pending from the Spanish state-owner regulator, Comision Nacional de los Mercados y de la Competencia or "CNMC" in the solar assets of the Company in Spain and from Pemex in ACT.

During the year 2022, in the assets in Spain, the Company collected revenue in line with the parameters corresponding to the regulation in place at the beginning of the year 2022, as the new parameters, reflecting lower revenue, became final on December 14, 2022. As a result, as of December 31, 2022, trade receivables in the assets in Spain were lower than usual. In the first quarter of 2023, collections at these assets in Spain were regularized.

The increase in prepayments is primarily due to the timing of insurance payments.

As of March 31, 2023, and December 31, 2022, the fair value of trade and other receivables accounts does not differ significantly from its carrying value.

Note 13. - Equity

As of March 31, 2023, the share capital of the Company amounts to $11,615,327 (11,605,513 as of December 31, 2022) represented by 116,153,273 ordinary shares (116,055,126 ordinary shares as of December 31,2022) fully subscribed and disbursed with a nominal value of $0.10 each, all in the same class and series. Each share grants one voting right.

Algonquin owns 42.2% of the shares of the Company and is its largest shareholder as of March 31, 2023. Algonquin’s voting rights and rights to appoint directors are limited to 41.5% and the difference between Algonquin´s ownership and 41.5% will vote replicating non-Algonquin’s shareholders’ vote.

The Company accounts for its existing long-term incentive plans granted to employees as equity-settled in accordance with IFRS 2, Share-based Payment when incentives are being settled in shares. In the first quarter of 2023, the Company issued 98,147 new shares (136,114 new shares in the first quarter of 2022) to its employees to settle a portion of these plans.

31

On August 3, 2021, the Company established an “at-the-market program” and entered into a distribution agreement with J.P. Morgan Securities LLC, as sales agent, under which the Company may offer and sell from time to time up to $150 million of its ordinary shares. The Company also entered into an agreement with Algonquin pursuant to which the Company has offered Algonquin the right but not the obligation, on a quarterly basis, to purchase a number of ordinary shares to maintain its percentage interest in Atlantica at the average price of the shares sold under the distribution agreement in the previous quarter (the “ATM Plan Letter Agreement”). On February 28, 2022, the Company established a new “at-the-market program” and entered into a distribution agreement with BofA Securities, MUFG and RBC Capital Markets, as its sales agents, under which the Company may offer and sell from time to time up to $150 million of its ordinary shares. Upon entry into the distribution agreement, the Company terminated its prior “at-the-market program” established on August 3, 2021 and the related distribution agreement dated such date, entered into with J.P. Morgan Securities LLC. During the first quarter of 2022, the Company sold 1,556,758 shares at an average market price of $33.65 pursuant to its distribution agreement, representing net proceeds of $51 million. During the first quarter of 2023, the Company did not sell any share under this program. Pursuant to the ATM Plan Letter Agreement, the Company delivers a notice to Algonquin quarterly in order for them to exercise their rights thereunder.

Atlantica´s reserves as of March 31, 2023 are made up of share premium account and capital reserves.

Other reserves primarily include the change in fair value of cash flow hedges and its tax effect.

Accumulated currency translation differences primarily include the result of translating the financial statements of subsidiaries prepared in a foreign currency into the presentation currency of the Company, the U.S. dollar.

Accumulated deficit primarily includes results attributable to Atlantica.

Non-controlling interests fully relate to interests held by JGC in Solacor 1 and Solacor 2, by Idae in Seville PV, by Itochu Corporation in Solaben 2 and Solaben 3, by Algerian Energy Company, SPA and Sacyr Agua S.L. in Skikda, by Algerian Energy Company, SPA in Tenes, by Industrial Development Corporation of South Africa (IDC) and Kaxu Community Trust in Kaxu, by Algonquin Power Co. in AYES Canada, and by partners of the Company in the Chilean renewable energy platform in Chile PV 1, Chile PV 2 and Chile PV 3.

On February 28, 2023, the Board of Directors declared a dividend of $0.445 per share corresponding to the fourth quarter of 2022. The dividend was paid on March 25, 2023 for a total amount of $51.7 million.

In addition, the Company declared dividends to non-controlling interests, primarily to Algonquin (interests in Amherst through AYES Canada, see Note 7) and to IDC and Kaxu Community Trust for $5.9 million and $1.2 million respectively, in the three-month period ended March 31, 2023 ($7.3 million and nil in the three-month period ended March 31, 2022, respectively).

As of March 31, 2023 and December 31, 2022, there was no treasury stock and there have been no transactions with treasury stock during the period then ended.

Note 14. - Corporate debt

The breakdown of corporate debt as of March 31, 2023 and December 31, 2022 is as follows:

	Balance as of March 31,		Balance as of December 31,
	2023		2022
	($ in thousands)
Non-current		1,040,998		1,000,503
Current		36,362		16,697
Total Corporate Debt		1,077,360		1,017,200

On July 20, 2017, the Company signed a credit facility (the “2017 Credit Facility”) for up to €10 million ($10.9 million), which is available in euros or U.S. dollars. Amounts drawn down accrue interest at a rate per year equal to EURIBOR plus 2% or LIBOR plus 2%, depending on the currency, with a floor of 0% on the LIBOR and EURIBOR. As of March 31, 2023, the 2017 Credit Facility was fully available ($6.4 million were drawn down as of December 31, 2022). The credit facility maturity is July 1, 2024.

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On May 10, 2018, the Company entered into the Revolving Credit Facility for $215 million with a syndicate of banks. Amounts drawn down accrue interest at a rate per year equal to (A) for Eurodollar rate loans, Term SOFR, plus a Term SOFR Adjustment equal to 0.10% per annum, plus a percentage determined by reference to the leverage ratio of the Company, ranging between 1.60% and 2.25% and (B) for base rate loans, the highest of (i) the rate per annum equal to the weighted average of the rates on overnight U.S. Federal funds transactions with members of the U.S. Federal Reserve System arranged by U.S. Federal funds brokers on such day plus ½ of 1.00%, (ii) the U.S. prime rate and (iii) Term SOFR plus 1.00%, in any case, plus a percentage determined by reference to the leverage ratio of the Company, ranging between 0.60% and 1.00%. Letters of credit may be issued using up to $100 million of the Revolving Credit Facility. Since then, the amount of the Revolving Credit Facility increased to $450 million. On May 5, 2022, the maturity was extended to December 31, 2024. On March 31, 2023, $60 million were drawn down ($30 million as of December 31, 2022). On March 31, 2023, the Company issued letters of credit for $25 million ($35 million as of December 31, 2022). As of March 31, 2023, therefore, $365 million of the Revolving Credit Facility were available ($385 million as of December 31, 2022).

On October 8, 2019, the Company filed a euro commercial paper program (the “Commercial Paper”) with the Alternative Fixed Income Market (MARF) in Spain. The program had an original maturity of twelve months and has been extended for annual periods until October 2023. The program allows Atlantica to issue short term notes over the next twelve months for up to €50 million ($55 million), with such notes having a tenor of up to two years. As of March 31, 2023, the Company had €24.3 million ($26.5 million) issued and outstanding under the program at an average cost of 3.61% (€9.3 million, or $9.9 million, as of December 31, 2022).

On April 1, 2020, the Company closed the secured 2020 Green Private Placement for €290 million ($316 million). The private placement accrues interest at an annual 1.96% interest rate, payable quarterly and has a June 2026 maturity.

On July 8, 2020, the Company entered into the Note Issuance Facility 2020, a senior unsecured financing with a group of funds managed by Westbourne Capital as purchasers of the notes issued thereunder for a total amount of $153 million which is denominated in euros (€140 million). The Note Issuance Facility 2020 was issued on August 12, 2020, interest accrues at a rate per annum equal to the sum of the 3-month EURIBOR plus a margin of 5.25% with a floor of 0% for the EURIBOR, payable quarterly and has a maturity of seven years from the closing date. The Company has entered into a cap at 0% for the EURIBOR with 3.5 years maturity to hedge the variable interest rate risk.

On July 17, 2020, ASI Jersey Ltd, a subsidiary of the Company issued the Green Exchangeable Notes for $100 million in aggregate principal amount of 4.00% convertible bonds due in 2025. On July 29, 2020, the Company closed an additional $15 million aggregate principal amount of the Green Exchangeable Notes. The notes mature on July 15, 2025 and bear interest at a rate of 4.00% per annum. The initial exchange rate of the notes is 29.1070 ordinary shares per $1,000 principal amount of notes, which is equivalent to an initial exchange price of $34.36 per ordinary share. Noteholders may exchange their notes at their option at any time prior to the close of business on the scheduled trading day immediately preceding April 15, 2025, only during certain periods and upon satisfaction of certain conditions. On or after April 15, 2025, noteholders may exchange their notes at any time. Upon exchange, the notes may be settled, at the election of the Company, into Atlantica ordinary shares, cash or a combination thereof. The exchange rate is subject to adjustment upon the occurrence of certain events.

As per IAS 32, “Financial Instruments: Presentation”, the conversion option of the Green Exchangeable Notes is an embedded derivative classified within the line “Derivative liabilities” of these Consolidated Condensed Interim Financial Statements (Note 9). It was initially valued at the transaction date for $10 million, and prospective changes to its fair value are accounted for directly through the profit and loss statement. The principal element of the Green Exchangeable Notes, classified within the line “Corporate debt” of these Consolidated Condensed Interim Financial Statements, is initially valued as the difference between the consideration received from the holders of the instrument and the value of the embedded derivative, and thereafter, at amortized cost using the effective interest method as per IFRS 9, Financial Instruments.

On May 18, 2021, the Company issued the Green Senior Notes due in 2028 in an aggregate principal amount of $400 million. The notes mature on May 15, 2028 and bear interest at a rate of 4.125% per annum payable on June 15 and December 15 of each year, commencing December 15, 2021.

Since 2020, the Company entered into loans with different banks as follows:

- a €5 million ($5.5 million) loan on December 4, 2020, which accrues interest at a rate per year equal to 2.50%. The maturity date is December 4, 2025.

- a €5 million ($5.5 million) loan on January 31, 2022, which accrues interest at a rate per year equal to 1.90%. The maturity date is January 31, 2026.

- a €7 million ($7.6 million) loan on February 24, 2023, which accrues interest at a rate per year equal to 4.21%. The maturity date is February 24, 2028.

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The repayment schedule for the corporate debt as of March 31, 2023 is as follows:

	Remainder of 2023		Between January and March 2024		Between April and December 2024		2025		2026		2027		Subsequent years		Total
	($ in thousands)
2017 Credit Facility		2		-		-		-		-		-		-		2
Revolving Credit Facility		112		-		59,492		-		-		-		-		59,604
Commercial Paper		26,548		-		-		-		-		-		-		26,548
2020 Green Private Placement		430		-		-		-		314,335		-		-		314,765
2020 Note Issuance Facility		-		-		-		-		-		150,122		-		150,122
Green Exchangeable Notes		958		-		-		107,751		-		-		-		108,709
Green Senior Notes		5,087		-		-		-		-		-		395,285		400,372
Other bank loans		2,547		678		2,503		3,185		699		-		7,626		17,238
Total		35,684		678		61,995		110,936		315,034		150,122		402,911		1,077,360

The repayment schedule for the corporate debt as of December 31, 2022, was as follows:

	2023		2024		2025		2026		2027		Subsequent years		Total
2017 Credit Facility		8		6,423		-		-		-		-		6,431
Revolving Credit Facility		112		29,387										29,499
Commercial Paper		9,937		-		-		-		-		-		9,937
2020 Green Private Placement		423		-		-		308,389		-		-		308,812
2020 Note Issuance Facility		-		-		-		-		147,257		-		147,257
Green Exchangeable Notes		2,107		-		107,055		-		-		-		109,162
Green Senior Note		964		-		-		-		-		395,060		396,024
Other bank Loans		3,146		3,122		3,124		686		-		-		10,078
Total		16,697		38,932		110,179		309,075		147,257		395,060		1,017,200

Note 15. - Project debt

This note shows the project debt linked to the assets included in Note 6 of these Consolidated Condensed Interim Financial Statements.

Project debt is generally used to finance contracted assets, exclusively using as guarantee the assets and cash flows of the company or group of companies carrying out the activities financed. In addition, the cash of the Company´s projects include funds held to satisfy the customary requirements of certain non-recourse debt agreements and other restricted cash for an amount of $202 million as of March 31, 2023 ($208 million as of December 31, 2022).

The breakdown of project debt for both non-current and current liabilities as of March 31, 2023 and December 31, 2022 is as follows:

	Balance as of March 31,		Balance as of December 31,
	2023		2022
	($ in thousands)
Non-current		4,252,226		4,226,518
Current		344,397		326,534
Total Project debt		4,596,623		4,553,052

During the first quarter of 2023, the Company refinanced Solaben 2&3 assets, entering into two green senior euro-denominated loan agreements for the two assets with a syndicate of banks for a total amount of €198.0 million. The new project debt replaced the previous project loans and maturity was extended from December 2030 to June 2037.

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The repayment schedule for project debt in accordance with the financing arrangements as of March 31, 2023 is as follows and is consistent with the projected cash flows of the related projects:

Remainder of 2023
Interest payment		Nominal repayment		Between January and March 2024		Between April and December 2024		2025		2026		2027		Subsequent years		Total
($ in thousands)
	52,924		269,208		22,265		289,308		434,937		344,987		490,139		2,692,855		4,596,623

The repayment schedule for project debt in accordance with the financing arrangements as of December 31, 2022, was as follows and was consistent with the projected cash flows of the related projects:

2023				2024		2025		2026		2027		Subsequent years		Total
Interest payment		Nominal repayment
	15,053		311,481		323,731		442,920		358,444		504,954		2,596,469		4,553,052

Note 16. - Grants and other liabilities

	Balance as of March 31,		Balance as of December 31,
	2023		2022
	($ in thousands)
Grants		896,970		911,593
Other liabilities and provisions		349,463		340,920
Dismantling provision		141,113		140,595
Lease liabilities		70,318		63,076
Accruals on Spanish market prices differences		94,192		91,884
Others		43,840		45,365
Grants and other non-current liabilities		1,246,433		1,252,513

As of March 31, 2023, the amount recorded in Grants primarily corresponds to the ITC Grant awarded by the U.S. Department of the Treasury to Solana and Mojave for a total amount of $602 million ($610 million as of December 31, 2022). The amount recorded in Grants as a liability is progressively recorded as other income over the useful life of the asset.

The remaining balance of the “Grants” account corresponds to loans with interest rates below market rates for Solana and Mojave for a total amount of $293 million as of March 31, 2023 ($299 million as of December 31, 2022). Loans with the Federal Financing Bank guaranteed by the Department of Energy for these projects bear interest at a rate below market rates for these types of projects and terms. The difference between proceeds received from these loans and its fair value, is initially recorded as “Grants” in the consolidated statement of financial position, and subsequently recorded progressively in “Other operating income”.

Total amount of income for these two types of grants for Solana and Mojave is $14.6 million and $14.6 million for the three-month periods ended March 31, 2023 and 2022, respectively (Note 20).

The “Accruals on Spanish market prices differences” corresponds to the payables related to the high market prices in Spain at which the solar assets in Spain invoiced electricity up to March 31, 2023, as a result of a negative adjustment to the regulated revenues for the deviation from the estimated market prices used by the Administration in Spain, which is expected to be compensated over the remaining regulatory life of the solar assets of the Company.

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Note 17. - Trade payables and other current liabilities

Trade payables and other current liabilities as of March 31, 2023 and December 31, 2022 are as follows:

	Balance as of March 31,		Balance as of December 31,
	2023		2022
	($ in thousands)
Trade accounts payable		88,660		84,465
Down payments from clients		712		11,169
Other accounts payable		44,635		44,596
Total		134,007		140,230

Trade accounts payable mainly relate to the operation and maintenance of the plants.

Nominal values of trade payables and other current liabilities are considered to be approximately equal to fair values and the effect of discounting them is not significant.

Note 18. - Income Tax

The effective tax rate for the periods presented has been established based on management’s best estimates, taking into account the tax treatment of permanent differences and tax credits.

For the three-month period ended March 31, 2023, income tax amounted to a $9,656 thousand profit with respect to a loss before income tax of $15,629 thousand. In the three-month period ended March 31, 2022, income tax amounted to a $3,906 thousand profit with respect to a loss before income tax of $13,748 thousand. The effective tax rate differs from the nominal tax rate mainly due to unrecognized tax loss carryforwards and permanent tax differences in some jurisdictions.

Note 19. - Financial expense, net

Financial income and expense

The following table sets forth financial income and expenses for the three-month periods ended March 31, 2023 and 2022:

	For the three-month period ended March 31,
	2023		2022
Financial income	($ in thousands)
Interest income from loans and credits		365		383
Interest rate gains on derivatives: cash flow hedges		7,632		609
Total		7,997		992

	For the three-month period ended March 31,
	2023			2022
Financial expense	($ in thousands)
Interest on loans and notes		(83,288	)		(71,126	)
Interest rates losses derivatives: cash flow hedges		(1,564	)		(12,276	)
Total		(84,852	)		(83,402	)

Interest on loans and notes primarily include interest on corporate and project debt.

Gains and losses from interest rate derivatives designated as cash flow hedges primarily correspond to transfers from equity to financial expense when the hedged item impacts the consolidated income statement. The decrease of losses and increase of gains in the three-month period ended March 31, 2023 compared to the three month period ended March 31, 2022, is due to an increase in the spot interest rates in 2023 compared to 2022, which implies lower interest payments on the derivatives instruments contracted.

Net exchange differences

Net exchange differences primarily correspond to realized and unrealized exchange gains and losses on transactions in foreign currencies as part of the normal course of business of the Company.

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Other financial income and expenses

The following table sets out Other financial income and expenses for the three-month periods ended March 31, 2023, and 2022:

	For the three-month period ended March 31,
Other financial income / (expenses)	2023			2022
	($ in thousands)
Other financial income		4,208			4,124
Other financial losses		(9,492	)		(5,254	)
Total		(5,284	)		(1,130	)

Other financial income in the three-month period ended March 31, 2023, primarily include interest on deposits and loans. Additionally, in the three-month period ended March 31, 2022 other financial income included an income for non-monetary change to the fair value of derivatives of Kaxu for which hedge accounting is not applied for $1.1 million, and $2.0 million of income further to the change in the fair value of the conversion option of the Green Exchangeable Notes in the period (Note 14).

Other financial losses primarily include guarantees and letters of credit, and other bank fees. In addition, in the three-month period ended March 31, 2023, other financial losses include $3.0 million of expense further to the change in the fair value of the conversion option of the Green Exchangeable Notes in the period (Note 14).

Note 20.- Other operating income and expenses

The table below shows the detail of Other operating income and expenses for the three-month periods ended March 31, 2023, and 2022:

Other operating income	For the three-month period ended March 31,
	2023		2022
	($ in thousands)
Grants (Note 16)		14,667		14,993
Insurance proceeds and other		7,953		4,440
Total		22,620		19,373

Insurance proceeds and other for the three-month period ended March 31, 2023 includes a gain of $4.6 million related to the sale of part of Atlantica’s equity interest in the Colombian portlfolio of renewable energy entities (Note 7).

Other operating expenses	For the three-month period ended March 31,
	2023			2022
	($ in thousands)
Raw materials and consumables used		(9,071	)		(5,010	)
Leases and fees		(3,650	)		(2,866	)
Operation and maintenance		(29,502	)		(36,317	)
Independent professional services		(7,646	)		(8,561	)
Supplies		(10,712	)		(15,061	)
Insurance		(10,698	)		(11,666	)
Levies and duties		(3,598	)		(4,672	)
Other expenses		(4,005	)		(3,780	)
Total		(78,881	)		(87,933	)

Note 21. - Earnings per share

Basic earnings per share have been calculated by dividing the loss attributable to equity holders of the Company by the average number of outstanding shares.

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Average number of outstanding diluted shares for the three-month period ended March 31, 2023 have been calculated considering the potential issuance of 3,347,305 shares (3,347,305 shares for the three-month period ended March 31, 2022) on the settlement of the Green Exchangeable Notes (Note 14). It also included the potential issuance of 1,167,185 shares to Algonquin for the three-month period ended March 31, 2022 under the agreement signed on August 3, 2021, according to which Algonquin has the option, on a quarterly basis, to subscribe such number of shares to maintain its percentage in Atlantica in relation to the use of the ATM program (Note 13).

Item	For the three-month period ended March 31,
	2023			2022
	($ in thousands)
Loss attributable to Atlantica		(10,990	)		(12,042	)
Average number of ordinary shares outstanding (thousands) - basic		116,140			112,741
Average number of ordinary shares outstanding (thousands) - diluted		119,487			116,894
Earnings per share for the period (U.S. dollar per share) - basic		(0.09	)		(0.11	)
Earnings per share for the period (U.S. dollar per share) - diluted (*)		(0.09	)		(0.11	)

(*) The potential ordinary shares related to the Green Exchangeable Notes and the ATM program have not been considered in the calculation of diluted earnings per share for the three-month periods ended March 31, 2023 and 2022, as they have an antidilutive effect.

Note 22. - Subsequent events

On May 4, 2023, the Board of Directors of the Company approved a dividend of $0.445 per share, which is expected to be paid on June 15, 2023.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis should be read together with, and is qualified in its entirety by reference to, our Consolidated Condensed Interim Financial Statements and our Annual Consolidated Financial Statements prepared in accordance with IFRS as issued by the IASB and other disclosures including the disclosures under “Part II, Item 1.A.—Risk Factors” of this quarterly report and “Part I, Item 3.D.—Risk Factors” in our Annual Report. The following discussion contains forward-looking statements that reflect our plans, estimates and beliefs, which are based on assumptions we believe to be reasonable. Our actual results could differ materially from those discussed in such forward-looking statements. The results shown here are not necessarily indicative of the results expected in any future period. Please see our Annual Report for additional discussion of various factors affecting our results of operations.

Overview

We are a sustainable infrastructure company with a majority of our business in renewable energy assets. Our purpose is to support the transition towards a more sustainable world by investing in and managing sustainable infrastructure, while creating long-term value for our investors and the rest of our stakeholders. In 2022, our renewable sector represented 75% of our revenue, with solar energy representing 64%. We complement our renewable assets portfolio with storage, efficient natural gas and transmission infrastructure assets, as enablers of the transition towards a clean energy mix. We also hold water assets, a relevant sector for sustainable development.

As of the date of this quarterly report, we own or have an interest in a portfolio of assets and new projects under development, diversified both in terms of business sector and geographic footprint. Our portfolio consists of 44 assets with 2,161 MW of aggregate renewable energy installed generation capacity (of which approximately 73% is solar), 343 MW of efficient natural gas-fired power generation capacity, 55 MWt of district heating capacity, 1,229 miles of electric transmission lines and 17.5 M ft3 per day of water desalination.

We currently own and manage operating facilities and projects under development in North America (United States, Canada and Mexico), South America (Peru, Chile, Colombia and Uruguay) and EMEA (Spain, Italy, Algeria and South Africa). Our assets generally have contracted or regulated revenue. As of March 31, 2023, our assets had a weighted average remaining contract life of approximately 14 years¹.

We intend to grow our business through the development and construction opportunities and third-party acquisitions, as well as the optimization of the existing portfolio, expansion or repowering opportunities and greenfield development. We currently have a pipeline of assets under development of approximately 2.0 GW of renewable energy and 5.8 GWh of storage. Approximately 43% of the projects are PV, 40% storage and 15% wind, while 17% of the projects are expected to reach ready to build (“Rtb”) in 2023 or 2024, 16% are in an advanced development stage and 67% are in early stage. 25% correspond to expansion or repower opportunities of existing assets and 75% to greenfield developments.

Our objective is to pay a consistent and growing cash dividend to shareholders that is sustainable on a long-term basis. We expect to distribute a significant percentage of our cash available for distribution as cash dividends and we will seek to increase such cash dividends over time through organic growth, investments in new assets and acquisitions.

¹ Calculated as weighted average years remaining as of March 31, 2023 based on CAFD estimates for the 2023-2026 period.

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Recent Investments

• In January 2022, we closed the acquisition of Chile TL4, a 63-mile transmission line and two substations in Chile for a total equity investment of $38.4 million. We expect to expand the transmission line in 2024, which would represent an additional investment of approximately $8 million. The asset has fully contracted revenues in U.S. dollars, with annual inflation adjustments and a 50-year remaining contract life. The off-takers are several mini-hydro plants that receive contracted or regulated payments.

• In April 2022, we closed the acquisition of Italy PV 4, a 3.6 MW solar portfolio in Italy for a total equity investment of $3.7 million. The asset has regulated revenues under a feed in tariff until 2031.

• In July 2022 we closed a 12-year transmission service agreement denominated in U.S. dollars that will allow us to build a substation and a 2.4-mile transmission line connected to our ATN transmission line serving a new mine in Peru. The substation is expected to enter in operation in 2024 and the investment is expected to be approximately $12 million.

• In September 2022, we closed the acquisition of Chile PV 3, a 73 MW solar PV plant through our renewable energy platform in Chile. The equity investment corresponding to our 35% equity interest was $7.7 million, and we expect to install batteries with a capacity of approximately 100 MWh in 2023-2024. Total investment including batteries is expected to be in the range of $15 million to $25 million depending on the capital structure. Part of the asset’s revenue is currently based on capacity payments. Adding storage would increase the portion of capacity payments.

• In September 2022, we agreed our first investment in a standalone battery storage project of 100 MWh (4 hours) capacity located inside Coso, our geothermal asset in California. Our investment is expected to be in the range of $40 million to $50 million. This project is at an advanced stage and we are preparing to start construction, with COD expected in 2024.

• In November 2022, we closed the acquisition of a 49% interest, with joint control, in an 80 MW portfolio of solar PV projects in Chile which is currently starting construction (Chile PMGD). Our economic rights are expected to be approximately 70%. Total investment in equity and preferred equity is expected to be approximately $30 million and COD is expected to be progressive in 2023 and 2024. Revenue for these assets is regulated under the Small Distributed Generation Means Regulation Regime (“PMGD”) for projects with a capacity equal or lower than 9 MW which allows to sell electricity at a stabilized price.

In addition, we have finished construction of the three assets that we had under construction during 2022:

- Albisu, the 10 MW PV asset wholly owned by us reached COD in January 2023. Albisu is located in Uruguay and has a 15-year PPA with Montevideo Refrescos, S.R.L., a subsidiary of Coca-Cola Femsa, S.A.B. de C.V. The PPA is denominated in local currency with a maximum and minimum price in U.S. dollars and is adjusted monthly based on a formula referring to the U.S. Producer Price Index (PPI), Uruguay’s Consumer Price Index (CPI) and the applicable UYU/U.S. dollar exchange rate.

- La Tolua and Tierra Linda are two solar PV assets in Colombia with a combined capacity of 30 MW. Each plant has a 10-year PPA (commencing on COD) in local currency with Coenersa, the largest independent electricity wholesaler in Colombia.

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Recent Developments

• Operation and Maintenance. In March 2023, we completed the process of transitioning the O&M services for the assets in Spain through the acquisition of the Abengoa subsidiary which was still providing those services to some of our assets. After this transfer, we perform the O&M services with our own personnel for assets representing approximately 72% of our consolidated revenue for the year ended December 31, 2022 and the number of our employees increased to approximately 1,350. Abengoa currently provides O&M services for assets representing less than 5% of our consolidated revenue for the year ended December 31, 2022.

• Strategic review. On February 21, 2023, Atlantica’s board of directors commenced a process to explore and evaluate potential strategic alternatives that may be available to Atlantica to maximize shareholder value. The Company believes it has attractive growth and other opportunities in front of it and is committed to ensuring it is best positioned to take advantage of those opportunities. The decision has the support of the Company’s largest shareholder, Algonquin. Atlantica expects to continue executing on its existing plans while the review of strategic alternatives is ongoing, including its current growth plan. There is no assurance that any specific transaction will be consummated or other strategic change will be implemented as a result of this strategic review. See “Cautionary Statements Regarding Forward-Looking Statements” and “Item 3.D—Risk Factors” in our Annual Report.

• Regulation in Spain. On December 28, 2022 the proposed parameters for the year 2023 were published in draft form. They are subject to changes (the public information phase ended on January 20, 2023) and are as follows:

	Useful Life	Remuneration on Investment 2023 (euros/MW)		Remuneration on Operation 2023 (euros/GWh)		Maximum Hours		Minimum Hours		Operating Threshold
Solaben 2	25 years		358,562		0		2,004		1,202		701
Solaben 3	25 years		358,562		0		2,004		1,202		701
Solacor 1	25 years		358,562		0		2,004		1,202		701
Solacor 2	25 years		358,562		0		2,004		1,202		701
PS 10	25 years		509,713		0		1,837		1,102		643
PS 20	25 years		373,114		0		1,837		1,102		643
Helioenergy 1	25 years		351,751		0		2,004		1,202		701
Helioenergy 2	25 years		351,751		0		2,004		1,202		701
Helios 1	25 years		365,595		0		2,004		1,202		701
Helios 2	25 years		365,595		0		2,004		1,202		701
Solnova 1	25 years		368,603		0		2,004		1,202		701
Solnova 3	25 years		368,603		0		2,004		1,202		701
Solnova 4	25 years		368,603		0		2,004		1,202		701
Solaben 1	25 years		363,530		0		2,004		1,202		701
Solaben 6	25 years		363,530		0		2,004		1,202		701
Seville PV	30 years		654,194		0		2,030		1,218		711

• Dividend. On May 4, 2023, our board of directors approved a dividend of $0.445 per share. The dividend is expected to be paid on June 15, 2023, to shareholders of record as of May 31, 2023.

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Potential Implications of Abengoa Developments

Prior to the transfer of the O&M services from Abengoa to us previously mentioned, Abengoa, S.A. and its subsidiary in Spain performing the O&M services at some of our plants, filed for insolvency proceedings. There may be unanticipated consequences of such insolvency filings and potential liquidation process. See “Part I, Item 3.D Risk Factors—Risks Related to Our Relationship with Algonquin and Abengoa” in our Annual Report.

Factors Affecting the Comparability of Our Results of Operations

Investments

The results of operations of Italy PV 4 and Chile PV 3 have been fully consolidated since April 2022 and September 2022, respectively and the results of Albisu, Tierra Linda and La Tolua have been fully consolidated since these assets entered into operation in the first quarter of 2023. These investments represented additional revenue for $2.5 million and additional Adjusted EBITDA of $1.5 million for the three-month period ended March 31, 2023.

Impairment

IFRS 9 requires impairment provisions to be based on expected credit losses on financial assets rather than on actual credit losses. For the first quarter of 2023 we recorded an expected credit loss impairment provision of $3.0 million

and for the first quarter of 2022, we recorded a $3.0 million reversal of the expected credit loss impairment provision, each of which is reflected in the line item “Depreciation, amortization, and impairment charges” and were primarily related to ACT.

Electricity market prices

In addition to regulated revenue, our solar assets in Spain receive revenue from the sale of electricity at market prices. The average electricity market price for our assets was approximately €81 per MWh in the first quarter of 2023 compared to approximately €198 per MWh in the first quarter of 2022. Revenue from the sale of electricity at current market prices represented $14.0 million in the first quarter of 2023, compared to $25.4 million in the first quarter of 2022. Regulated revenues are revised periodically to reflect, among other things, the difference between expected and actual market prices if the difference is higher than a pre-defined threshold and as a result we record a provision. We decreased our provision by $1.2 million in the first quarter of 2023, with no cash impact on the current period, compared to an increase of $7.2 million in the first quarter of 2022.

On May 12, 2022 remuneration parameters in Spain for the year 2022 were published and became final on December 14, 2022, with a decrease in regulated revenue. In addition, on December 28, 2022 the proposed parameters for the year 2023 were published in draft form and are subject to final publication. Revenue from the sale of electricity at market prices plus Ro (Remuneration on operation) less incremental market price provision was $15.1 million for the three-month period ended March 31, 2023, compared to $23.9 million for the three-month period ended March 31, 2022.

In 2022 we collected revenue from our assets in line with the parameters corresponding to the regulation in place at the beginning of the year 2022, as the new parameters became final on December 14, 2022, while revenue for the year ended December 31, 2022, was recorded in accordance with the new parameters. Collections were regularized in the first quarter of 2023.

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Exchange rates

We refer to “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Significant Trends Affecting Results of Operations—Exchange Rates” below.

Significant Trends Affecting Results of Operations

Investments

If the acquisitions recently closed and new assets recently built perform as expected, we expect these assets to positively impact our results of operations in 2023 and upcoming years.

Solar, wind and geothermal resources

The availability of solar, wind and geothermal resources affects the financial performance of our renewable assets, which may impact our overall financial performance. Due to the variable nature of solar, wind and geothermal resources, we cannot predict future availabilities or potential variances from expected performance levels from quarter to quarter. Based on the extent to which the solar, wind and geothermal resources are not available at expected levels, this could have a negative impact on our results of operations.

Capital markets conditions

The capital markets in general are subject to volatility that is unrelated to the operating performance of companies. Our growth strategy depends on our ability to close acquisitions, which often requires access to debt and equity financing to complete these acquisitions. Volatility in capital markets may affect our ability to access this capital through debt or equity financings.

Exchange rates

Our presentation currency and the functional currency of most of our subsidiaries is the U.S. dollar, as most of their revenue and expenses are denominated or linked to U.S. dollars. All our companies located in North America, with the exception of Calgary, with revenue in Canadian dollars, and most of our companies in South America have their revenue and financing contracts signed in or indexed totally or partially to U.S. dollars. Our solar power plants in Europe have their revenue and expenses denominated in euros, Kaxu, our solar plant in South Africa, has its revenue and expenses denominated in South African rand, La Sierpe, La Tolua and Tierra Linda our solar plants in Colombia have their revenue and expenses denominated in Colombian pesos and Albisu, our solar plant in Uruguay, has its revenue denominated in Uruguayan pesos, with a maximum and a minimum price in U.S. dollars.

Project financing is typically denominated in the same currency as that of the contracted revenue agreement, which limits our exposure to foreign exchange risk. In addition, we maintain part of our corporate general and administrative expenses and part of our corporate debt in euros which creates a natural hedge for the distributions we receive from our assets in Europe. To further mitigate this exposure, our strategy is to hedge cash distributions from our assets in Europe. We hedge the exchange rate for the net distributions in euros (after deducting interest payments and general and administrative expenses in euros). Through currency options, we have hedged 100% of our euro-denominated net exposure for the next 12 months and 75% of our euro-denominated net exposure for the following 12 months. We expect to continue with this hedging strategy on a rolling basis.

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Although we hedge cash-flows in euros, fluctuations in the value of the euro in relation to the U.S. dollar may affect our operating results. For example, revenue in euro-denominated companies could decrease when translated to U.S. dollars at the average foreign exchange rate solely due to a decrease in the average foreign exchange rate, in spite of revenue in the original currency being stable. Fluctuations in the value of South African rand and Colombian peso with respect to the U.S. dollar may also affect our operating results.

In our discussion of operating results, we have included foreign exchange impacts in our revenue by providing constant currency revenue growth. The constant currency presentation is not a measure recognized under IFRS and excludes the impact of fluctuations in foreign currency exchange rates. We believe providing constant currency information provides valuable supplemental information regarding our results of operations. We calculate constant currency amounts by converting our current period local currency revenue using the prior period foreign currency average exchange rates and comparing these adjusted amounts to our prior period reported results. This calculation may differ from similarly titled measures used by others and, accordingly, the constant currency presentation is not meant to substitute recorded amounts presented in conformity with IFRS as issued by the IASB, nor should such amounts be considered in isolation.

Impacts associated with fluctuations in foreign currency are discussed in more detail under “Item 3 — Quantitative and Qualitative Disclosure about Market Risk—Foreign exchange risk”.

Interest rates

We incur significant indebtedness at the corporate and asset level. The interest rate risk arises mainly from indebtedness at variable interest rates. To mitigate interest rate risk, we primarily use long-term interest rate swaps and interest rate options which, in exchange for a fee, offer protection against a rise in interest rates. As of March 31, 2023, approximately 92% of our project debt and close to 95% of our corporate debt either has fixed interest rates or has been hedged with swaps or caps. Nevertheless, our results of operations can be affected by changes in interest rates with respect to the unhedged portion of our indebtedness that bears interest at floating rates, which typically bear a spread over EURIBOR, LIBOR, SOFR or over the alternative rates replacing these.

Electricity market prices

As previously discussed, our solar assets in Spain receive revenue from the sale of electricity at market prices in addition to regulated revenue. Regulated revenues are revised periodically to reflect the difference between expected and actual market prices if the difference is higher than a pre-defined threshold. On December 28, 2022, the parameters applicable for the year 2023 were published in draft form and are subject to final publication (see “Item 4 —Information on the Company — Regulation — Spain” in our Annual Report). Additionally, our assets in Italy have contracted revenues through a regulated feed-in premium in addition to merchant revenues for the energy sold to the wholesale market.

Furthermore, we currently have three assets with merchant revenues (Chile PV 1 and Chile PV 3, where we have a 35% ownership, and Lone Star II, where we have a 49% ownership) and one asset with partially contracted revenues (Chile PV 2, where we have a 35% ownership). Our exposure to merchant electricity prices represents less than 2% of our portfolio² in terms of Adjusted EBITDA. In Lone Star II we are analyzing, together with our partner, the option to repower the asset in the context of the IRA, at a point in time to be determined.

² Calculated as a percentage of our Adjusted EBITDA in 2022.

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Key Financial Measures

We regularly review a number of financial measurements and operating metrics to evaluate our performance, measure our growth and make strategic decisions. In addition to traditional IFRS performance measures, such as total revenue, we also consider Adjusted EBITDA.

Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership).

Our management believes Adjusted EBITDA is useful to investors and other users of our financial statements in evaluating our operating performance because it provides them with an additional tool to compare business performance across companies and across periods. EBITDA is widely used by investors to measure a company’s operating performance without regard to items such as interest expense, taxes, depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Adjusted EBITDA is widely used by other companies in our industry.

The non-GAAP financial measures including Adjusted EBITDA may not be comparable to other similarly titled measures of other companies and has limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our operating results as reported under IFRS as issued by the IASB. Non-GAAP financial measures and ratios are not measurements of our performance or liquidity under IFRS as issued by the IASB and should not be considered as alternatives to operating profit or profit for the period or any other performance measures derived in accordance with IFRS as issued by the IASB or any other generally accepted accounting principles or as alternatives to cash flow from operating, investing or financing activities. Adjusted EBITDA excludes the impact of cash costs of financing activities and taxes, and the effects of changes in operating working capital balances, and therefore are not necessarily indicative of operating profit or cash flow from operations as determined under IFRS GAAP.

Our revenue and Adjusted EBITDA by geography and business sector for the three-month period ended March 31, 2023 and 2022 are set forth in the following tables:

Revenue by geography

	Three-month period ended March 31,
Revenue by geography	2023					2022
	$ in millions		% of revenue			$ in millions		% of revenue
North America	$	72.8		30.0	%	$	74.4		30.0	%
South America		43.7		18.0	%		38.5		15.6	%
EMEA		126.0		52.0	%		134.6		54.4	%
Total revenue	$	242.5		100.0	%	$	247.5		100	%

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Revenue by business sector

	Three-month period ended March 31,
Revenue by business sector	2023					2022
	$ in millions		% of revenue			$ in millions		% of revenue
Renewable energy	$	172.6		71.2	%	$	182.1		73.6	%
Efficient natural gas & heat		27.4		11.3	%		25.3		10.2	%
Transmission lines		28.8		11.9	%		26.6		10.7	%
Water		13.7		5.6	%		13.5		5.4	%
Total revenue	$	242.5		100.0	%	$	247.5		100	%

Adjusted EBITDA by geography

	Three-month period ended March 31,
Adjusted EBITDA by geography	2023					2022
	$ in millions		% of Adjusted EBITDA			$ in millions		% of Adjusted EBITDA
North America	$	52.0		29.8	%	$	58.3		33.5	%
South America		33.8		19.4	%		29.1		16.8	%
EMEA		88.4		50.8	%		86.2		49.7	%
Total Adjusted EBITDA(1)	$	174.2		100.0	%	$	173.6		100.0	%

Adjusted EBITDA by business sector

	Three-month period ended March 31,
Adjusted EBITDA by business sector	2023					2022
	$ in millions		% of Adjusted EBITDA			$ in millions		% of Adjusted EBITDA
Renewable energy	$	119.1		68.4	%	$	122.2		70.4	%
Efficient natural gas & heat		22.6		13.0	%		21.7		12.5	%
Transmission lines		23.5		13.5	%		20.5		11.8	%
Water		9.0		5.1	%		9.2		5.3	%
Total Adjusted EBITDA(1)	$	174.2		100.0	%	$	173.6		100.0	%

Note:

(1) Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.

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Reconciliation of loss for the period to Adjusted EBITDA

The following table sets forth a reconciliation of Adjusted EBITDA to our loss for the period attributable to the Company:

	Three-month period ended March 31,
	2023			2022
	($ in millions)
Loss for the period attributable to the Company	$	(11.0	)		(12.0	)
Profit attributable to non-controlling interests		5.0			2.2
Income tax		(9.7	)		(3.9	)
Financial expense, net		80.4			80.5
Depreciation, amortization and impairment charges		103.8			100.9
Depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of our equity ownership)		5.7			5.9
Adjusted EBITDA	$	174.2			173.6

Reconciliation of net cash provided by operating activities to Adjusted EBITDA

The following table sets forth a reconciliation of Adjusted EBITDA to our net cash flow provided by operating activities:

	Three-month period ended March 31,
	2023			2022
	($ in millions)
Net cash flow provided by operating activities	$	41.7		$	137.3
Net interest /taxes paid		30.2			16.5
Variations in working capital		93.3			19.0
Non-monetary items and other		(2.8	)		(13.4	)
Share of profit/(loss) of associates carried under the equity method, depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership)		11.8			14.2
Adjusted EBITDA	$	174.2		$	173.6

Operational Metrics

In addition to the factors described above, we closely monitor the following key drivers of our business sectors’ performance to plan for our needs, and to adjust our expectations, financial budgets and forecasts appropriately.

• MW in operation in the case of Renewable energy and Efficient natural gas and heat assets, miles in operation in the case of Transmission lines and Mft³ per day in operation in the case of Water assets, are indicators which provide information about the installed capacity or size of our portfolio of assets.

• Production measured in GWh in our Renewable energy and Efficient natural gas and heat assets provides information about the performance of these assets.

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• Availability in the case of our Efficient natural gas and heat assets, Transmission lines and Water assets also provides information on the performance of the assets. In these business segments revenues are based on availability, which is the time during which the asset was available to our client totally or partially divided by contracted availability or budgeted availability, as applicable.

 Key Performance Indicators

	Volume sold and availability levels As of and for the three-month period ended March 31,
Key performance indicator	2023			2022
Renewable energy
MW in operation(1)		2,161			2,044
GWh produced(2)		1,192			1,094
Efficient natural gas & heat
MW in operation(3)		398			398
GWh produced(4)		600			625
Availability (%)		94.9	%		100.3	%
Transmission lines
Miles in operation		1,229			1,229
Availability (%)		100.0	%		99.9	%
Water
Mft3 in operation(1)		17.5			17.5
Availability (%)		100.8	%		104.5	%

Notes:

⁽¹⁾ Represents total installed capacity in assets owned or consolidated for the three-month period ended March 31, 2023 and 2022, respectively, regardless of our percentage of ownership in each of the assets except for Vento II for which we have included our 49% interest.

⁽²⁾ Includes 49% of Vento II wind portfolio production since its acquisition. Includes curtailment in wind assets for which we receive compensation.

⁽³⁾ Includes 43 MW corresponding to our 30% share in Monterrey and 55MWt corresponding to thermal capacity from Calgary District Heating.

⁽⁴⁾ GWh produced includes 30% of the production from Monterrey.

Production in the renewable business sector increased by 9.0% in the three-month period ended March 31, 2023, compared to the same period of the previous year. The increase was largely due to the increase in production in our solar assets in Spain, where solar radiation was very good in the period, and to the contribution from the assets recently consolidated or which have entered into operation recently, including Chile PV3, La Tolua, Tierra Linda, Albisu and Italy PV 4, bringing approximately 51 GWh of additional electricity generation.

In our solar assets in the U.S. production decreased by 11.7% in the three-month period ended March 31, 2023 compared to the same period of the previous year mainly due to lower solar radiation, which decreased by approximately 20% compared to the same period of the previous year. In addition, production in Solana was also affected by the delays in the repairs and replacements in the storage system, as well as lower than expected performance of the solar field which is currently being addressed. In our wind assets in the U.S., wind resource was generally in line with expectations in the three-month period ended March 31, 2023.

In Chile, solar radiation in the three-month period ended March 31, 2023 was in line with the same period of the previous year and production at our PV assets increased mainly as a result of lower curtailments. In our wind assets in Uruguay, wind resource and production were stable compared to the same period of the previous year.

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In Spain, production at our solar assets increased by 65.5 GWh in the three-month period ended March 31, 2023 as a result of very good solar radiation compared to the same period of the previous year. In Kaxu, production also increased mainly due to better solar radiation compared to the same quarter of the previous year.

In our efficient natural gas and heat segment availability decreased in the three-month period ended March 31, 2023 mostly due to the scheduled major overhaul performed in one of the turbines at ACT and still ongoing in the second turbine. Since these major maintenance was scheduled, it does not impact revenue.

Our Water assets and Transmission lines, for which revenue is based on availability, continued to achieve very high levels of availability in the first quarter of 2023.

Results of Operations

The table below illustrates our results of operations for the three-month period ended March 31, 2023 and 2022.

	Three-month period ended March 31
	2023			2022			% Changes
	($ in millions)
Revenue	$	242.5			247.5			(2.0	)%
Other operating income		22.6			19.3			17.1	%
Employee benefit expenses		(23.8	)		(19.5	)		22.1	%
Depreciation, amortization, and impairment charges		(103.8	)		(100.9	)		2.9	%
Other operating expenses		(78.9	)		(87.9	)		(10.2	)%
Operating profit	$	58.6			58.5			0.2	%
Financial income		8.0			1.0			700.0	%
Financial expense		(84.9	)		(83.4	)		1.8	%
Net exchange differences		1.7			3.1			(45.2	)%
Other financial income/(expense), net		(5.3	)		(1.1	)		(381.8	)%
Financial expense, net	$	(80.4	)		(80.4	)		0.0	%
Share of profit of associates carried under the equity method		6.2			8.2			(24.4	)%
Loss before income tax	$	(15.6	)		(13.7	)		13.9	%
Income tax		9.7			3.9			148.7	%
Loss for the period	$	(6.0	)		(9.8	)		44.9	%
Profit attributable to non-controlling interests		(5.0	)		(2.2	)		77.3	%
Loss for the period attributable to the company	$	(11.0	)		(12.0	)		50.8	%
Weighted average number of ordinary shares outstanding-basic		116.1			112.7
Weighted average number of ordinary shares outstanding-diluted		119.5			116.9
Basic earnings per share (U.S. dollar per share)		(0.09	)		(0.11	)
Diluted earnings per share (U.S. dollar per share)		(0.09	)		(0.11	)
Dividend paid per share(1)		0.445			0.44

Note:

(1) On February 28, 2023, our board of directors approved a dividend of $0.445 per share corresponding to the fourth quarter of 2022 which was paid on March 25, 2023. On February 25, 2022, our board of directors approved a dividend of $0.44 per share corresponding to the fourth quarter of 2021 which was paid on March 25, 2022.

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Comparison of the Three-Month Period Ended March 31, 2023 and 2022.

The significant variances or variances of the significant components of the results of operations are discussed in the following section.

Revenue

Revenue decreased to $242.5 million for the three-month period ended March 31, 2023, which represents a decrease of 2.0% compared to $247.5 million for the three-month period ended March 31, 2022. On a constant currency basis, revenue for the three-month period ended March 31, 2023 was $251.2 million, which represents a 1.5% increase compared to the three-month period ended March 31, 2022.

This increase (on a constant currency basis) was mainly due to higher revenue at Kaxu resulting from higher production and to the indexation of its revenue to inflation. In addition, assets recently consolidated and assets which entered in operation recently represented a total of $2.5 million of additional revenue in the three-month period ended March 31, 2023 compared to the same period of the previous year. Furthermore, revenue also increased  in our transmission lines in three-month period ended March 31, 2023 compared to the same period from previous year mostly as a result of inflation adjustments to the tariff. These effects were partially offset by the decrease in revenue at our solar assets in Spain in spite of higher production during the period, primarily due to lower electricity prices net of its corresponding accounting provision (see “Factors Affecting the Comparability of Our Results of Operations—Electricity market prices”). Revenue was also lower at our solar assets in the U.S. due to lower electricity production as previously explained.

Other operating income

The following table sets forth our Other operating income for the three-month period ended March 31, 2023, and 2022:

	Three-month period ended March 31,
Other operating income	2023		2022
	($ in millions)
Grants	$	14.7	$	14.9
Insurance proceeds and other		8.0		4.4
Total	$	22.6	$	19.3

“Grants” represent the financial support provided by the U.S. Department of the Treasury to Solana and Mojave and consist of an ITC Cash Grant and an implicit grant related to the below market interest rates of the project loans with the Federal Financing Bank. Grants were stable for the three-month period ended March 31, 2023, compared to same period of the previous year.

“Insurance proceeds and other” for the three-month period ended March 31, 2023 included $4.5 million resulting from the sale of part of our equity interest in our development company in Colombia to a partner who now holds a 50% equity interest, with joint control. This gain was the main reason for the increase compared to same period of the previous year.

Employee benefit expenses

Employee benefit expenses increased by 22.1% to $23.8 million for the three-month period ended March 31, 2023, compared to $19.5 million for the three-month period ended March 31, 2022. The increase was mainly due to the internalization of the operation and maintenance services in Kaxu and in our solar assets in Spain.

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Depreciation, amortization and impairment charges

Depreciation, amortization and impairment charges increased by 2.9% to $103.8 million for the three-month period ended March 31, 2023, compared to $100.9 million for the three-month period ended March 31, 2022. The increase was mainly due to an increase of the expected credit loss impairment provision at ACT. IFRS 9 requires impairment provisions to be based on the expected credit loss of the financial assets in addition to actual credit losses. ACT recorded a credit loss impairment provision of $2.7 million for the three-month period ended March 31, 2023, while for the three-month period ended March 31, 2022, there was a reversal of the expected credit loss provision of $2.5 million. Depreciation, amortization and impairment charges also increased due to the consolidation of assets recently acquired or which entered in operation recently. On the other hand, depreciation, amortization and impairment charges decreased in our assets in Spain mainly due to the depreciation of the euro against the U.S. dollar.

Other operating expenses

The following table sets forth our Other operating expenses for the three-month periods ended March 31, 2023 and 2022:

	Three-month period ended March 31,
Other operating expenses	2023					2022
	$ in millions		% of revenue			$ in millions		% of revenue
Raw materials and consumables used	$	9.1		3.8	%	$	5.0		2.0	%
Leases and fees		3.6		1.5	%		2.9		1.2	%
Operation and maintenance		29.5		12.2	%		36.3		14.7	%
Independent professional services		7.7		3.2	%		8.6		3.5	%
Supplies		10.7		4.4	%		15.0		6.1	%
Insurance		10.7		4.4	%		11.7		4.7	%
Levies and duties		3.6		1.5	%		4.7		1.9	%
Other expenses		4.0		1.6	%		3.7		1.5	%
Total	$	78.9		32.5	%	$	87.9		35.5	%

Other operating expenses decreased by 10.3% to $78.9 million for the three-month period ended March 31, 2023, compared to $87.9 million for the three-month period ended March 31, 2022, mainly due to lower operation and maintenance costs and lower cost of supplies.

Our operation and maintenance costs decreased during the three-month period ended March 31, 2023, compared to the same period of the previous year mainly due to lower O&M costs in Spain and Kaxu where these services have been internalized and are now provided by employees of Atlantica, with the cost classified in “Employee benefit expenses”. In addition, the cost of supplies decreased mostly due to lower price of electricity and natural gas in our assets in Spain.

On the other hand, the cost of raw materials increased in the subsidiaries which are now performing the operation and maintenance which was previously subcontracted, as these costs are now assumed directly by subsidiaries of Atlantica.

Operating profit

As a result of the above-mentioned factors, operating profit remained stable at $58.6 million for the three-month period ended March, 2023, compared with $58.5 million for the three-month period ended March 31, 2022.

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Financial income and financial expense

	Three-month period ended March 31,
Financial income and financial expense	2023			2022
	($ in millions)
Financial income	$	8.0		$	1.0
Financial expense		(84.9	)		(83.4	)
Net exchange differences		1.7			3.1
Other financial income/(expense), net		(5.2	)		(1.1	)
Financial expense, net	$	(80.4	)	$	(80.4	)

Financial income

The following table sets forth our Financial income for the three-month periods ended March 31, 2023, and 2022:

	For the three-month period ended March 31,
	2023		2022
Financial income	($ in thousands)
Interest income from loans and credits		0.4		0.4
Interest rate gains on derivatives: cash flow hedges		7.6		0.6
Total		8.0		1.0

Financial income increased from $1.0 million for the three-month period ended March 31, 2022 to $8.0 million for the three-month period ended March 31, 2023 mostly due to higher “Interest rate gains on derivatives: cash flow hedges”, which correspond to the transfer from equity to financial income when the hedged item impacts the consolidated income statement. The increase is due to higher gains in derivatives hedging loans indexed to EURIBOR, LIBOR and SOFR primarily due to the increase in the reference in the three-month period ended March 31, 2023, compared to the same period of the previous year. We also recorded a $2.5 million gain corresponding to the transfer from equity to financial income of the cumulative fair value of the Solaben 2&3 swap, after it was canceled following the refinancing of these assets.

Financial expense

The following table sets forth our Financial expense for the three-month period ended March 31, 2023, and 2022:

	For the three-month period ended March 31,
Financial expense	2023			2022
	($ in millions)
Interest on loans and notes	$	(83.0	)	$	(71.1	)
Interest rates losses derivatives: cash flow hedges		(1.9	)		(12.3	)
Total	$	(84.9	)	$	(83.4	)

Financial expense increased by 1.8% to $84.9 million for the three-month period ended March 31, 2023, compared to $83.4 million for the three-month period ended March 31, 2022.

“Interest on loans and notes” expense increased in the three-month period ended March 31, 2023 when compared to the three-month period ended March 31, 2022 mainly as a result of higher interest rates in our variable rate debt. This effect was more than offset by the decrease of “Interest rate losses on derivatives: cash flow hedges” and the increase of “Interest rate gains on derivatives: cash flow hedges”, where we record transfers from equity to the income statement when the hedged item impacts profit and loss. The decrease in “Interest rate losses on derivatives: cash flow hedges” was due to lower losses in derivatives hedging loans indexed to EURIBOR, LIBOR and SOFR primarily due to the increase in the reference rates in the three-month period ended March 31, 2023, compared to the same period of the previous year and to lower notional amounts, as we progressively repay our project debt.

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Net exchange differences

Net exchange differences decreased to a $1.7 million income in the three-month period ended March 31, 2023 compared to $3.1 million income in the same period of the previous year. The decrease was mainly due to the change in fair value of caps hedging our net cash flows in Euros, which decreased in the first quarter of 2023 while it increased in the first quarter of 2022.

Other financial income/(expense), net

The following table sets forth our Other financial income/(expense), net for the three-month periods ended March 31, 2023, and 2022:

	Three-month period ended March 31,
Other financial income /(expense), net	2023			2022
	($ in millions)
Other financial income	$	4.2		$	4.1
Other financial expense		(9.5	)		(5.2	)
Total	$	(5.3	)	$	(1.1	)

Other financial income/(expense), net decreased to a net expense of $5.3 million for the three-month period ended March 31, 2023, compared to a net expense of $1.1 million for the three-month period ended March 31, 2022.

Other financial income in the three-month period ended March 31, 2023 primarily includes interest on deposits and loans. In the three-month period ended March 31, 2022 Other financial income primarily included income from the non-monetary change in the fair value of Kaxu’s derivatives for which hedge accounting is not applied for $1.1 million, and $2.0 million of income due to the change in the fair value of the conversion option of the Green Exchangeable Notes in the period. Other financial expense increased in the three-month period ended March 31, 2023, mainly due to a $3.0 million decrease in the change in the fair value of the derivative liability embedded in the Green Exchangeable Notes. Other financial expense also includes expenses for guarantees and letters of credit, wire transfers, other bank fees and other minor financial expenses.

Share of profit of associates carried under the equity method

Share of profit of associates carried under the equity method decreased to $6.2 million for the three-month period ended March 31, 2023, compared to $8.2 million for the three-month period ended March 31, 2022 primarily due to lower profit at Vento II.

Loss before income tax

As a result of the previously mentioned factors, we reported a loss before income tax of $15.6 million for the three-month period ended March 31, 2023, compared to a loss before income tax of $13.7 million for the three-month period ended March 31, 2022.

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Income tax

The effective tax rate for the periods presented has been established based on management’s best estimates. For the three-month period ended March 31, 2023, income tax amounted to an income of $9.7 million, with a loss before income tax of $15.6 million. For the three-month period ended March 31, 2022, income tax amounted to an income of $3.9 million, with a loss before income tax of $13.7 million. The effective tax rate differs from the nominal tax rate mainly due to unrecognized tax losses carryforwards and permanent tax differences in some jurisdictions.

Profit attributable to non-controlling interests

Profit attributable to non-controlling interests increased to $5.0 million for the three-month period ended March 31, 2023 compared to $2.2 million for the three-month period ended March 31, 2022. Profit attributable to non-controlling interests corresponds to the portion attributable to our partners in the assets that we consolidate (Kaxu, Skikda, Solaben 2 & 3, Solacor 1 & 2, Seville PV, Chile PV 1, Chile PV 2, Chile PV 3 and Tenes). The increase in profit attributable to non-controlling interest is mainly due to higher profit at Kaxu and at our desalinations assets.

Loss attributable to the parent company

As a result of the previously mentioned factors, loss attributable to the parent company was $11.0 million for the three-month period ended March 31, 2023, compared to a loss of $12.0 million for the three-month period ended March 31, 2022.

Segment Reporting

We organize our business into the following three geographies where the contracted assets and concessions are located: North America, South America and EMEA. In addition, we have identified four business sectors based on the type of activity: Renewable energy, Efficient natural gas and heat, Transmission and Water. We report our results in accordance with both criteria.

Comparison of the Three-Month Periods Ended March 31, 2023 and 2022

Revenue and Adjusted EBITDA by geography

The following table sets forth our revenue, Adjusted EBITDA and volumes for the three-month periods ended March 31, 2023 and 2022, by geographic region:

Revenue by geography

	Three-month period ended March 31,
Revenue by geography	2023					2022
	$ in millions		% of revenue			$ in millions		% of revenue
North America	$	72.8		30.0	%	$	74.4		30.0	%
South America		43.7		18.0	%		38.5		15.6	%
EMEA		126.0		52.0	%		134.6		54.4	%
Total revenue	$	242.5		100.0	%	$	247.5		100.0	%

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	Three-month period ended March 31,
Adjusted EBITDA by geography	2023					2022
	$ in millions		% of Adjusted EBITDA			$ in millions		% of Adjusted EBITDA
North America	$	52.0		29.8	%	$	58.3		33.6	%
South America		33.8		19.4	%		29.1		16.8	%
EMEA		88.4		50.8	%		86.2		49.7	%
Total Adjusted EBITDA(1)	$	174.2		100.0	%	$	173.6		100.0	%

Note:

(1) Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.

	Volume produced/availability
	Three-month period ended March 31,
Volume /availability by geography	2023			2022
North America (GWh) (1)		1,286			1,348
North America availability(2)		94.9	%		100.3	%
South America (GWh) (3)		234			183
South America availability(2)		100.0	%		99.9	%
EMEA (GWh)		272			188
EMEA availability		100.8	%		104.5	%

Note:

(1) GWh produced includes 30% of the production from Monterrey and our 49% of Vento II wind portfolio production since its acquisition.

(2) Availability includes only those assets that have revenue based on availability.

(3) Includes curtailment production in wind assets for which we receive compensation.

North America

Revenue decreased by 2.1% to $72.8 million for the three-month period ended March 31, 2023, compared to $74.4 million for the three-month period ended March 31, 2022, while Adjusted EBITDA decreased by 10.8% to $52.0 million for the three-month period ended March 31, 2023, compared to $58.3 million for the three-month period ended March 31, 2022. The decrease of Revenue was mainly due to lower production in our solar assets in the U.S. as previously discussed and it was partially offset by higher revenue at ACT (see “Efficient natural gas & heat” below). Adjusted EBITDA decreased more than revenue due to lower EBITDA at Vento II, mostly due to lower prices at Lone Star 2 after the end of its PPA and higher operating costs in Solana.

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South America

Revenue increased by 13.5% to $43.7 million for the three-month period ended March 31, 2023, compared to $38.5 million for the three-month period ended March 31, 2022. The increase was mainly due to assets recently consolidated and assets which entered in operation recently. Revenue also increased due to indexation to inflation in our revenue in transmission lines and wind assets and to higher revenue at our PV assets in Chile, where production increased. Adjusted EBITDA increased by 16.1% to $33.8 million for the three-month period ended March 31, 2023, compared to $29.1 million for the three-month period ended March 31, 2022, mostly due to the same reasons.

EMEA

Revenue decreased to $126.0 million for the three-month period ended March 31, 2023, which represents a decrease of 6.4% compared to $134.6 million for the three-month period ended March, 2022. On a constant currency basis, revenue for the three-month period ended March 31, 2023, was $134.6 million, which represents a decrease of 0.2% compared to the three-month period ended March 31, 2022. The decrease was mainly due to lower revenue at our solar assets in Spain in spite of higher production during the period, primarily due to lower electricity prices net of its corresponding accounting provision (see “Factors Affecting the Comparability of Our Results of Operations—Electricity market prices”). This decrease was partially offset by higher revenue at Kaxu resulting from higher production and to the indexation of its revenue to inflation.

Adjusted EBITDA increased to $88.4 million for the three-month period ended March 31, 2023, which represents an increase of 2.6% compared to $86.2 million for the three-month period ended March 31, 2022. On a constant currency basis, Adjusted EBITDA for the three-month period ended March 31, 2023, was $94.7 million which represents an increase of 9.8% compared to the three-month period ended March 31, 2022. The increase in Adjusted EBITDA in spite of the stable revenue was mainly due to lower operation and maintenance costs in the assets where we have recently internalized the O&M, mostly due to seasonality in part of the costs that are now internal, and to lower costs of supplies in our assets in Spain, resulting from a decrease in the price of natural gas.

Revenue and Adjusted EBITDA by business sector

The following table sets forth our revenue, Adjusted EBITDA and volumes for the three-month period ended March 31, 2023, and 2022, by business sector:

	Three-month period ended March 31,
Revenue by business sector	2023					2022
	$ in millions		% of revenue			$ in millions		% of revenue
Renewable energy	$	172.6		71.2	%	$	182.1		73.6	%
Efficient natural gas & heat		27.4		11.3	%		25.3		10.2	%
Transmission lines		28.8		11.9	%		26.6		10.7	%
Water		13.7		5.6	%		13.5		5.4	%
Total revenue	$	242.5		100.0	%	$	247.5		100	%

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	Three-month period ended March 31,
Adjusted EBITDA by business sector	2023					2022
	$ in millions		% of Adjusted EBITDA			$ in millions		% of Adjusted EBITDA
Renewable energy	$	119.1		68.4	%	$	122.2		70.4	%
Efficient natural gas & heat		22.6		13.0	%		21.7		12.5	%
Transmission lines		23.5		13.5	%		20.5		11.8	%
Water		9.0		5.1	%		9.2		5.3	%
Total Adjusted EBITDA(1)	$	174.2		100.0	%	$	173.6		100.0	%

Note:

(1) Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.

Volume by business sector

	Volume produced/availability
	three-month period ended March 31,
Volume /availability by business sector	2023			2022
Renewable energy (GWh) (1)		1.192			1,094
Efficient natural gas & heat (GWh) (2)		600			625
Efficient natural gas & heat availability		94.9	%		100.3	%
Transmission availability		100.0	%		99.9	%
Water availability		100.8	%		104.5	%

Note:

(1) Includes curtailment production in wind assets for which we receive compensation. Includes our 49% of Vento II wind portfolio production since its acquisition.

(2) GWh produced includes 30% of the production from Monterrey.

Renewable energy

Revenue decreased to $172.6 million for the three-month period ended March 31, 2023, which represents a 5.2% decrease compared to $182.1 million for the three-month period ended March 31, 2022. On a constant currency basis, revenue for the three-month period ended March 31, 2023, was $181.3 million, which represents a 0.5% decrease compared to the three-month period ended March, 2022. The decrease in revenue was primarily due to lower revenue at our solar assets in Spain as previously discussed. Revenue also decreased at our solar assets in the U.S. due to lower electricity production as previously explained. On the other hand, revenue increased due to higher production at Kaxu and to the indexation of its revenue to inflation, as well as the contribution of assets recently consolidated.

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Adjusted EBITDA decreased to $119.1 million for the three-month period ended March 31, 2023, which represents an decrease of 2.5% compared to $122.2 million for the three-month period ended March 31, 2022. On a constant currency basis, Adjusted EBITDA for the three-month period ended March 31, 2023, was $125.4 million which represents a 2.7% increase compared to the three-month period ended March 31, 2022. The increase in Adjusted EBITDA in spite of the stable revenue was mainly due to lower operation and maintenance costs in the assets where we have recently internalized the O&M and to lower costs of supplies in our assets in Spain, following a decrease in the price of natural gas.

Efficient natural gas & heat

Revenue increased by 8.3% to $27.4 million for the three-month period ended March 31, 2023, compared to $25.3 million for three-month period ended March 31, 2022, while Adjusted EBITDA increased by 4.1% to $22.6 million for the three-month period ended March 31, 2023, compared to $21.7 million for the three-month period ended March 31, 2022. Revenue increased at ACT mainly due to higher operation and maintenance costs, since there is a portion of revenue related to operation and maintenance services plus a margin. At ACT, operation and maintenance costs were higher as it happens in the quarters preceding any major maintenance works, and higher O&M costs result in higher revenue in the portion of revenue related to operation and maintenance services plus a margin. Adjusted EBITDA increased to a lower extent given that the revenue increase was partially offset by the O&M cost increase.

Transmission lines

Revenue increased by 8.3% to $28.8 million for the three-month period ended March 31, 2023, compared to $26.6 million for the three-month period ended March 31, 2022, while Adjusted EBITDA increased by 14.6% to $23.5 million for the three-month period ended March 31, 2023 compared to $20.5 million for the three-month period ended March 31, 2022. The increase in revenue and Adjusted EBITDA was mainly due to tariff indexation to inflation.

Water

Revenue remained stable at $13.7 million for the three-month period ended March 31, 2023, compared to $13.5 million for the three-month period ended March 31, 2022. Adjusted EBITDA also remained stable at $9.0 million for the three-month period ended March 31, 2023, compared to $9.2 million for three-month period ended March 31, 2022.

Liquidity and Capital Resources

Our principal liquidity and capital requirements consist of the following:

• debt service requirements on our existing and future debt;

• cash dividends to investors; and

• investments in new assets and companies and operations (See “Recent Investments”).

As a normal part of our business, depending on market conditions, we will from time to time consider opportunities to repay, redeem, repurchase or refinance our indebtedness. Changes in our operating plans, lower than anticipated sales, increased expenses, acquisitions or other events may cause us to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all. Debt financing, if available, could impose additional cash payment obligations and additional covenants and operating restrictions. In addition, any of the items discussed in detail under “Part I, Item 3.D.—Risk Factors” in our Annual Report and other factors may also significantly impact our liquidity.

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Liquidity position

	As of March 31, 2023		As of December 31, 2022
	($ in millions)
Corporate Liquidity
Cash and cash equivalents at Atlantica Sustainable Infrastructure, plc, excluding subsidiaries	$	109.4	$	60.8
Revolving Credit Facility availability		365.1		385.1
Total Corporate Liquidity(1)	$	474.5	$	445.9
Liquidity at project companies
Restricted Cash		202.0		207.6
Non-restricted cash		291.4		332.6
Total cash at project companies	$	493.4	$	540.2

Note:

(1) Corporate Liquidity means cash and cash equivalents held at Atlantica Sustainable Infrastructure plc as of March 31, 2023, and available revolver capacity as of March 31, 2023.

Cash at the project level includes $202.0 million and $207.6 million restricted cash balances as of March 31, 2023 and December 31, 2022, respectively. Restricted cash consists primarily of funds required to meet the requirements of certain project debt arrangements. In the case of Solana, part of the restricted cash is being used and is expected to be used for equipment replacement.

Non-restricted cash at project companies includes among others, the cash that is required for day-to-day management of the companies, as well as amounts that are earmarked to be used for debt service in the future.

As of March 31, 2023, we had $24.9 million of letters of credit were outstanding under the Revolving Credit Facility and we had $60 million of borrowings. As a result, as of March 31, 2023, $365.1 million was available under the Revolving Credit Facility. As of December 31, 2022, we had $30 million of borrowings and $34.9 million of letters of credit outstanding and $385.1 million was available under our Revolving Credit Facility.

Management believes that the Company’s liquidity position, cash flows from operations and availability under its Revolving Credit Facility will be adequate to meet the Company’s financial commitments and debt obligations; growth, operating and maintenance capital expenditures; and dividend distributions to shareholders. Management continues to regularly monitor the Company’s ability to finance the needs of its operating, financing and investing activities within the guidelines of prudent balance sheet management.

Credit ratings

Credit rating agencies rate us and part of our debt securities. These ratings are used by the debt markets to evaluate our credit risk. Ratings influence the price paid to issue new debt securities as they indicate to the market our ability to pay principal, interest and dividends.

The following table summarizes our credit ratings as of March 31, 2023. The ratings outlook is stable for S&P and Fitch.

	S&P	Fitch
Atlantica Sustainable Infrastructure Corporate Rating	BB+	BB+
Senior Secured Debt	BBB-	BBB-
Senior Unsecured Debt	BB	BB+

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Sources of liquidity

We expect our ongoing sources of liquidity to include cash on hand, cash generated from our operations, project debt arrangements, corporate debt and the issuance of additional equity securities, as appropriate, and given market conditions. Our financing agreements consist mainly of the project-level financing for our various assets and our corporate debt financings, including our Green Exchangeable Notes, the Note Issuance Facility 2020, the 2020 Green Private Placement, the Green Senior Notes, the Revolving Credit Facility, the “at-the-market program”, other credit lines and our commercial paper program.

			As of March 31, 2023		As of December 31, 2022
	Maturity		($ in millions)
Revolving Credit Facility	2024		$	59.5		29.4
Other Facilities(1)		2023-2028		50.4		30.1
Green Exchangeable Notes		2025		107.8		107.0
2020 Green Private Placement		2026		314.3		308.4
Note Issuance Facility 2020		2027		150.1		147.2
Green Senior Notes		2028		395.3		395.1
Total Corporate Debt(2)			$	1,077.4		1,017.2
Total Project Debt			$	4,596.6		4,553.1

Note:

(1) Other facilities include the commercial paper program issued in October 2020, accrued interest payable and other debts.

(2) Accounting amounts may differ from notional amounts.

In the three-month period ended March 31, 2023, project debt increased by $43.5 million mainly due to interest accrued and not paid during the quarter for $43.3 million, given that many of our assets have semi-annual debt service payments and to foreign exchange translation differences for $25.6 million, mainly due the depreciation of the Euro against the U.S. dollar. These effects were partially offset by the scheduled repayment of our project debt for $30.5 million.

 A) Corporate debt agreements

Green Senior Notes

On May 18, 2021, we issued the Green Senior Notes with an aggregate principal amount of $400 million due in 2028. The Green Senior Notes bear interest at a rate of 4.125% per year, payable on June 15 and December 15 of each year, commencing December 15, 2021, and will mature on June 15, 2028.

The Green Senior Notes were issued pursuant to an Indenture, dated May 18, 2021, by and among Atlantica as issuer, Atlantica Peru S.A., ACT Holding, S.A. de C.V., Atlantica Infraestructura Sostenible, S.L.U., Atlantica Investments Limited, Atlantica Newco Limited, Atlantica North America LLC, as guarantors, BNY Mellon Corporate Trustee Services Limited, as trustee, The Bank of New York Mellon, London Branch, as paying agent, and The Bank of New York Mellon SA/NV, Dublin Branch, as registrar and transfer agent.

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Our obligations under the Green Senior Notes rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Note Issuance Facility 2020 and the Green Exchangeable Notes.

Green Exchangeable Notes

On July 17, 2020, we issued 4.00% Green Exchangeable Notes amounting to an aggregate principal amount of $100 million due in 2025. On July 29, 2020, we issued an additional $15 million aggregate principal amount in Green Exchangeable Notes. The Green Exchangeable Notes are the senior unsecured obligations of Atlantica Jersey, a wholly owned subsidiary of Atlantica, and fully and unconditionally guaranteed by Atlantica on a senior, unsecured basis. The notes mature on July 15, 2025, unless they are repurchased or redeemed earlier by Atlantica or exchanged, and bear interest at a rate of 4.00% per annum.

Noteholders may exchange all or any portion of their notes at their option at any time prior to the close of business on the scheduled trading day immediately preceding April 15, 2025, only during certain periods and upon satisfaction of certain conditions. Noteholders may exchange all or any portion of their notes during any calendar quarter if the last reported sale price of Atlantica’s ordinary shares for at least 20 trading days during a period of 30 consecutive trading days, ending on the last trading day of the immediately preceding calendar quarter is greater than 120% of the exchange price on each applicable trading day. On or after April 15, 2025, until the close of business on the second scheduled trading day immediately preceding the maturity date thereof, noteholders may exchange any of their notes at any time, at the option of the noteholder. Upon exchange, the notes may be settled, at our election, into Atlantica ordinary shares, cash or a combination of both. The initial exchange rate of the notes is 29.1070 ordinary shares per $1,000 of the principal amount of notes (which is equivalent to an initial exchange price of $34.36 per ordinary share). The exchange rate is subject to adjustment upon the occurrence of certain events.

Our obligations under the Green Exchangeable Notes rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Note Issuance Facility 2020 and the Green Senior Notes.

Note Issuance Facility 2020

On July 8, 2020, we entered into the Note Issuance Facility 2020, a senior unsecured euro-denominated financing with a group of funds managed by Westbourne Capital as purchasers of the notes issued thereunder for a total amount of €140 million ($153 million). The notes under the Note Issuance Facility 2020 were issued on August 12, 2020 and are due on August 12, 2027. Interest accrues at a rate per annum equal to the sum of the three-month EURIBOR plus a margin of 5.25% with a floor of 0% for the EURIBOR. We have entered into a cap at 0% for the EURIBOR with 3.5 years maturity to hedge the variable interest rate risk.

Our obligations under the Note Issuance Facility 2020 rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Green Exchangeable Notes and the Green Senior Notes. The notes issued under the Note Issuance Facility 2020 are guaranteed on a senior unsecured basis by our subsidiaries Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC.

2020 Green Private Placement

On March 20, 2020, we entered into a senior secured note purchase agreement with a group of institutional investors as purchasers providing for the 2020 Green Private Placement. The transaction closed on April 1, 2020, and we issued notes for a total principal amount of €290 million ($316 million), maturing on June 20, 2026. Interest accrues at a rate per annum equal to 1.96%. If at any time the rating of these senior secured notes is below investment grade, the interest rate thereon would increase by 100 basis points until such notes are again rated investment grade.

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Our obligations under the 2020 Green Private Placement rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the Note Issuance Facility 2020 and the Green Senior Notes. Our payment obligations under the 2020 Green Private Placement are guaranteed on a senior secured basis by our subsidiaries Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC. The 2020 Green Private Placement is also secured with a pledge over the shares of the subsidiary guarantors, the collateral of which is shared with the lenders under the Revolving Credit Facility.

Revolving Credit Facility

On May 10, 2018, we entered into a $215 million Revolving Credit Facility with a syndicate of banks. The Revolving Credit Facility was increased by $85 million to $300 million on January 25, 2019, and was further increased by $125 million (to a total limit of $425 million) on August 2, 2019. On March 1, 2021, this facility was further increased by $25 million (to a total limit of $450 million). On May 5, 2022, the maturity of the Revolving Credit Facility was extended to December 31, 2024. Under the Revolving Credit Facility, we are also able to request the issuance of letters of credit, which are subject to a sublimit of $100 million that are included in the aggregate commitments available under the Revolving Credit Facility.

Loans under the Revolving Credit Facility accrue interest at a rate per annum equal to: (A) for eurodollar rate loans, Term SOFR, plus a Term SOFR Adjustment equal to 0.10% per annum, plus a percentage determined by reference to our leverage ratio, ranging between 1.60% and 2.25% and (B) for base rate loans, the highest of (i) the rate per annum equal to the weighted average of the rates on overnight U.S. Federal funds transactions with members of the U.S. Federal Reserve System arranged by U.S. federal funds brokers on such day plus ½ of 1.00%, (ii) the prime rate of the administrative agent under the Revolving Credit Facility and (iii) Term SOFR plus 1.00%, in any case, plus a percentage determined by reference to our leverage ratio, ranging between 0.60% and 1.00%.

Our obligations under the Revolving Credit Facility rank equal in right of payment with our outstanding obligations under the 2020 Green Private Placement, the Note Issuance Facility 2020, the Green Exchangeable Notes and the Green Senior Notes. Our payment obligations under the Revolving Credit Facility are guaranteed on a senior secured basis by Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC. The Revolving Credit Facility is also secured with a pledge over the shares of the subsidiary guarantors, the collateral of which is shared with the holders of the notes issued under the 2020 Green Private Placement.

Other Credit Lines

In July 2017, we signed a line of credit with a bank for up to €10.0 million ($10.9 million) which was available in euros or U.S. dollars. Amounts drawn accrue interest at a rate per annum equal to the sum of the three-month EURIBOR or LIBOR, plus a margin of 2%, with a floor of 0% for the EURIBOR or LIBOR. On July 1, 2022, the maturity was extended to July 1, 2024. As of March 31, 2023, no amount was drawn under this line of credit.

In December 2020 and January 2022, we also entered into two different loans with banks for €5 million ($5.5 million) each. The maturity dates are December 4, 2025 and January 31, 2026, respectively, and such loans accrue interest at a rate per annum equal to 2.50% and 1.90%, respectively. Furthermore, in February 2023, we entered into a loan with a bank for €7 million ($7.6 million) with maturity in February 2028 accrues interest rate at a rate per annual equal to 4.2%.

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Commercial Paper Program

On October 8, 2019, we filed a euro commercial paper program with the Alternative Fixed Income Market (MARF) in Spain. The program had an original maturity of twelve months and has been extended twice, for annual periods. The program allows Atlantica to issue short term notes for up to €50 million, with such notes having a tenor of up to two years. As of March 31, 2023, we had €24.3 million ($26.5 million) issued and outstanding under the Commercial Paper Program at an average cost of 3.6% maturing on or before November 2023.

Covenants, restrictions and events of default

The Note Issuance Facility 2020, the 2020 Green Private Placement, the Green Senior Notes and the Revolving Credit Facility contain covenants that limit certain of our and the guarantors’ activities. The Note Issuance Facility 2020, the 2020 Green Private Placement and the Green Exchangeable Notes also contain customary events of default, including a cross-default with respect to our indebtedness, indebtedness of the guarantors thereunder and indebtedness of our material non-recourse subsidiaries (project-subsidiaries) representing more than 25% of our cash available for distribution distributed in the previous four fiscal quarters, which in excess of certain thresholds could trigger a default. Additionally, under the 2020 Green Private Placement, the Revolving Credit Facility and the Note Issuance Facility 2020 we are required to comply with a leverage ratio of our corporate indebtedness excluding non-recourse project debt to our cash available for distribution of 5.00:1.00 (which may be increased under certain conditions to 5.50:1.00 for a limited period in the event we consummate certain acquisitions).

Furthermore, our corporate debt agreements contain customary change of control provisions (as such term is defined in each of those agreements) or similar provisions. Under the Revolving Credit Facility, a change of control without required lenders’ consent would trigger an event of default. In the other corporate debt agreements or securities, a change of control or similar provision without the consent of the relevant required holders would trigger the obligation to make an offer to purchase the respective notes at (i) 100% of the principal amount in the case of the 2020 Green Private Placement and Green Exchangeable Notes and at (ii) 101% of the principal amount in the case of the Note Issuance Facility 2020 and the Green Senior Notes. In the case of the Green Senior Notes, such prepayment obligation would be triggered only if there is a credit rating downgrade by any of the agencies.

 B) At-The-Market Program

On February 28, 2022, we established an “at-the-market program” and entered into the Distribution Agreement with BofA Securities, Inc., MUFG Securities Americas Inc. and RBC Capital Markets LLC, as our sales agents, under which we may offer and sell from time to time up to $150 million of our ordinary shares, including in “at-the-market” offerings under our shelf registration statement on Form F-3 filed with the SEC on August 3, 2021, and a prospectus supplement that we filed on February 28, 2022. During the three-month period ended March 31, 2023, we did not issue and sell any ordinary shares under the program.

C) Project debt refinancing

In March 2023 we refinanced Solaben 2&3. We entered into two green senior euro-denominated loan agreements for the two assets with a syndicate of banks for a total amount of €198.0 million. The new project debt replaced the previous project loans and maturity was extended from December 2030 to June 2037.

The interest rate for the loans accrues at a rate per annum equal to the sum of six-month EURIBOR plus a margin of 1.50% between 2023 and June 2028, 1.60% between June 2028 and June 2033 and 1.70% from June 2033 onwards. The principal is 90% hedged for the life of the loan through a combination of the following instruments:

• a pre-existing cap with a 1.0% strike with notional of €115.1 million starting in March 2023 and decreasing over time until December 2025.

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• a swap with a 3.16% strike with initial notional of €64.9 million starting in March 2023. The notional increases progressively until June 2026 and decreases progressively thereafter until maturity to ensure that the principal hedged stays at 90% over the life of the loan.

The financing agreement also includes a mechanism under which, in the case that electricity market prices are above certain levels defined in the contract, a reserve account should be established and funded on a six-month rolling basis for the additional revenue arising from the difference between actual prices and prices defined in the agreement. Under certain conditions, such amounts, if any, should be used for early prepayments upon regulatory parameters changes.

See “Item 5.B –Liquidity and Capital Resources – Financing Arrangements” in our Annual Report for further detail on the rest of our financing arrangements.

Uses of liquidity and capital requirements

Cash dividends to investors

We intend to distribute a significant portion of our cash available for distribution to shareholders on an annual basis less all cash expenses including corporate debt service and corporate general and administrative expenses and less reserves for the prudent conduct of our business (including, among other things, dividend shortfall as a result of fluctuations in our cash flows), on an annual basis. We intend to distribute a quarterly dividend to shareholders. Our board of directors may, by resolution, amend the cash dividend policy at any time. The determination of the amount of the cash dividends to be paid to shareholders will be made by our board of directors and will depend upon our financial condition, results of operations, cash flow, long-term prospects and any other matters that our board of directors deem relevant. Our board of directors may, by resolution, amend the cash dividend policy at any time.

Our cash available for distribution is likely to fluctuate from quarter to quarter and, in some cases, significantly as a result of the seasonality of our assets, the terms of our financing arrangements, maintenance and outage schedules, among other factors. Accordingly, during quarters in which our projects generate cash available for distribution in excess of the amount necessary for us to pay our stated quarterly dividend, we may reserve a portion of the excess to fund cash distributions in future quarters. During quarters in which we do not generate sufficient cash available for distribution to fund our stated quarterly cash dividend, if our board of directors so determines, we may use retained cash flow from other quarters, and other sources of cash to pay dividends to our shareholders.

The latest dividends paid and declared are presented below:

Declared	Record Date	Payment Date	$ per share
February 25, 2022	March 14, 2022	March 25, 2022		0.44
May 5, 2022	May 31, 2022	June 15, 2022		0.44
August 2, 2022	August 31, 2022	September 15, 2022		0.445
November 8, 2022	November 30, 2022	December 15, 2022		0.445
February 28, 2023	March 14, 2023	March 25, 2023		0.445
May 4, 2023	May 31, 2023	June 15, 2023	0.445

Investments and Acquisitions

The acquisitions and investments detailed in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Recent Investments” have been part of the use of our liquidity in 2022 and 2023. In addition, we have made investments in assets which are currently under development or construction. We expect to continue making investments in assets in operation or under construction or development to grow our portfolio.

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Our uses of liquidity also include debt service and contractual obligations (refer to our Annual Report for further detail).

Cash flow

The following table sets forth cash flow data for the three-month periods ended March 31, 2023 and 2022:

	Three-month period ended March 31,
	2023			2022
	($ in millions)
Gross cash flows from operating activities
Loss for the period	$	(6.0	)	$	(9.8	)
Financial expense and non-monetary adjustments		171.1			182.7
Profit for the period adjusted by non-monetary items	$	165.1		$	172.9
Changes in working capital	$	(93.3	)	$	(19.1	)
Net interest and income tax paid		(30.2	)		(16.5	)
Net cash provided by operating activities	$	41.7		$	137.3
Net cash used in investing activities	$	0.9		$	(12.9	)
Net cash provided by / (used in) financing activities	$	(42.1	)	$	(8.8	)
Net increase in cash and cash equivalents		0.5			115.6
Cash and cash equivalents at beginning of the period		601.0			622.7
Translation differences in cash or cash equivalents		1.4			0.7
Cash and cash equivalents at the end of the period	$	602.9		$	739.0

Net cash provided by operating activities

For the three-month period ended March 31, 2023, net cash provided by operating activities was $41.7 million, a 69.6% decrease compared to $137.3 million in the three-month period ended March 31, 2022. The decrease was due to the negative impact of changes in working capital in the period, mostly in Spain and Mexico. During the year 2022, in our assets in Spain we collected revenue in line with the parameters corresponding to the regulation in place at the beginning of the year 2022, as the new parameters, reflecting lower revenue, became final on December 14, 2022. This resulted in a positive change in working capital in 2022. In the first quarter of 2023, collections at these assets in Spain were regularized, which caused a negative change in working capital. Collections from Pemex in ACT were also lower during the first quarter of 2023 compared the same quarter of the previous year. In addition, income tax payments increased due to timing differences in the tax refund of corporate income tax installments.

Net cash used in investing activities

For the three-month period ended March 31, 2023, net cash used in investing activities amounted to $0.9 million and corresponded mainly to $14.6 million investments in development and construction and in existing assets, including investments and replacements in Solana. These cash outflows were partially offset by $12.4 million of dividends received from associates under the equity method, of which $6.1 million corresponded to Amherst by AYES Canada, most of which were paid to our partner in this project.

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For the three-month period ended March 31, 2022, net cash used in investing activities amounted to $12.9 million and corresponded mainly to $30.5 million paid for the acquisitions of Chile TL4 and investments in concessional assets for $5.0 million. These cash outflows were partially offset by $31.9 million of dividends received from associates under the equity method, of which $13.9 million corresponded to Amherst by AYES Canada, most of which were paid to our partner in this project.

Net cash (used in) financing activities

For the three-month period ended March 31, 2023, net cash used in financing activities amounted to $42.1 million and includes the scheduled repayment of principal of our project financing for $30.5 million and dividends paid to shareholders for $51.7 million and non-controlling interests for $6.0 million. These cash outflows were partially offset by the proceeds of corporate debt mainly related to the Revolving Credit Facility, which was drawn for $30 million in the first quarter of 2023.

For the three-month period ended March 31, 2022, net cash used in financing activities amounted to $8.8 million and includes the repayment of principal of our project financing agreements for $43.9 million and dividends paid to shareholders and non-controlling interests for $55.9 million. These cash outflows were partially offset by the proceeds from the equity raised under the at-the-market programs for a net amount of $51.6 million, net of transaction costs and the withdrawal of $35 million from the Revolving Credit Facility.

Item 3. Quantitative and Qualitative Disclosure about Market Risk

Our activities are undertaken through our segments and are exposed to market risks that include foreign exchange risk, interest rate risk, credit risk, liquidity risk, electricity price risk and country risk. Our objective is to protect Atlantica  against material economic exposures and variability of results from those risks. Risk is managed by our Risk Management and Finance Departments in accordance with mandatory internal management rules. The internal management rules provide written policies for the management of overall risk, as well as for specific areas, such as foreign exchange rate risk, interest rate risk, credit risk and liquidity risk, among others. Our internal management policies also define the use of hedging instruments and derivatives and the investment of excess cash. We use swaps and options on interest rates and foreign exchange rates to manage certain of our risks. None of the derivative contracts signed has an unlimited loss exposure.

The following table outlines Atlantica´s market risks and how they are managed:

Market Risk	Description of Risk	Management of Risk
Foreign exchange risk	We are exposed to foreign currency risk – including Euro, Canadian dollar, South African rand,  Colombian peso and Uruguayan peso – related to operations and certain foreign currency debt. Our presentation currency and the functional currency of most of our subsidiaries is the U.S. dollar, as most of our revenue and expenses are denominated or linked to U.S. dollars. All our companies located in North America, with the exception of Calgary, whose revenue is in Canadian dollars, and most of our companies in South America have their revenue and financing contracts signed in or indexed totally or partially to U.S. dollars. Our solar power plants in Europe have their revenue and expenses denominated in euros; Kaxu, our solar plant in South Africa, has its revenue and expenses denominated in South African rand, La Sierpe, La Tolua and Tierra Linda, our solar plants in Colombia, have their revenue and expenses denominated in Colombian pesos and Albisu, our solar plant in Uruguay, has its revenue denominated in Uruguayan pesos, with a maximum and a minimum price in US dollars in the case of Uruguayan peso.	The main cash flows in our subsidiaries are cash collections arising from long-term contracts with clients and debt payments arising from project finance repayment. Project financing is typically denominated in the same currency as that of the contracted revenue agreement, which limits our exposure to foreign exchange risk. In addition, we maintain part of our corporate general and administrative expenses and part of our corporate debt in euros which creates a natural hedge for the distributions we receive from our assets in Europe. To further mitigate this exposure, our strategy is to hedge cash distributions from our assets in Europe. We hedge the exchange rate for the net distributions in euros (after deducting interest payments and general and administrative expenses in euros). Through currency options, we have hedged 100% of our euro-denominated net exposure for the next 12 months and 75% of our euro-denominated net exposure for the following 12 months. We expect to continue with this hedging strategy on a rolling basis. The difference between the euro/U.S. dollar hedged rate for the year 2023 and the current rate reduced by 5% would create a negative impact on cash available for distribution of approximately $3 million. This amount has been calculated as the average net euro exposure expected for the years 2023 to 2026 multiplied by the difference between the average hedged euro /U.S. dollar rate for 2023 and the euro/U.S. dollar rate as of the date of this quarterly report reduced by 5%. Although we hedge cash-flows in euros, fluctuations in the value of the euro in relation to the U.S. dollar may affect our operating results. For example, revenue in euro-denominated companies could decrease when translated to U.S. dollars at the average foreign exchange rate solely due to a decrease in the average foreign exchange rate, in spite of revenue in the original currency being stable. Fluctuations in the value of the South African rand, the Colombian peso and the Uruguayan Peso with respect to the U.S. dollar may also affect our operating results. Apart from the impact of these translation differences, the exposure of our income statement to fluctuations of foreign currencies is limited, as the financing of projects is typically denominated in the same currency as that of the contracted revenue agreement.

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Interest rate risk   We are exposed to interest rate risk on our variable-rate debt.   Interest rate risk arises mainly from our financial liabilities at variable interest rate (less than 10% of our consolidated debt).   The most significant impact on our consolidated condensed interim financial statements related to interest rates corresponds to the potential impact of changes in EURIBOR, SOFR or LIBOR on the debt with interest rates based on these reference rates and on derivative positions.   In relation to our interest rate swaps positions, an increase in EURIBOR, SOFR or LIBOR above the contracted fixed interest rate would create an increase in our financial expense which would be positively mitigated by our hedges, reducing our financial expense to our contracted fixed interest rate. However, an increase in EURIBOR, SOFR or LIBOR that does not exceed the contracted fixed interest rate would not be offset by our derivative position and would result in a stable net expense recognized in our consolidated income statement. In relation to our interest rate options positions, an increase in EURIBOR, SOFR or LIBOR above the strike price would result in higher interest expenses, which would be positively mitigated by our hedges, reducing our financial expense to our capped interest rate. However, an increase in these rates of reference below the strike price would result in higher interest expenses. Our assets largely consist of long duration physical assets, and financial liabilities consist primarily of long-term fixed-rate debt or floating-rate debt that has been swapped to fixed rates with interest rate financial instruments to minimize the exposure to interest rate fluctuations.   We use interest rate swaps and interest rate options (caps) to mitigate interest rate risk. As of March 31, 2023, approximately 92% of our project debt and approximately 95% of our corporate debt either has fixed interest rates or has been hedged with swaps or caps. Our revolving credit facility has variable interest rates and is not hedged as further described in “Item 5.B— Operating and Financial Review and Prospects— Liquidity and Capital Resources— Corporate debt agreements —Revolving Credit Facility”;   In the event that EURIBOR, SOFR and LIBOR had risen by 25 basis points as of March 31, 2023, with the rest of the variables remaining constant, the effect in the consolidated income statement would have been a loss of $0.8 million and an increase in hedging reserves of $20.2 million. The increase in hedging reserves would be mainly due to an increase in the fair value of interest rate swaps designated as hedges.  

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Credit Risk	We are exposed to credit risk mainly from operating activities, the maximum exposure of which is represented by the carrying amounts reported in the statements of financial position. We are exposed to credit risk if counterparties to our contracts, trade receivables, interest rate swaps, foreign exchange hedge contracts are unable to meet their obligations. The credit rating of Eskom is currently CCC+ from S&P , Caa1 from Moody’s and B from Fitch. Eskom is the off-taker of our Kaxu solar plant, a state-owned, limited liability company, wholly owned by the Republic of South Africa. In addition, Pemex’s credit rating is currently BBB from S&P, B1 from Moody’s and BB- from Fitch. We have experienced delays in collections in the past, especially since the second half of 2019, which have been significant in certain quarters.	The diversification by geography and business sector helps to diversify credit risk exposure by diluting our exposure to a single client. In the case of Kaxu, Eskom’s payment guarantees to our Kaxu solar plant are underwritten by the South African Department of Mineral Resources and Energy, under the terms of an implementation agreement. The credit ratings of the Republic of South Africa as of the date of this quarterly report are BB-/Ba2/BB- by S&P, Moody’s and Fitch, respectively. In the case of Pemex, we continue to maintain a pro-active approach including fluent dialogue with our client.
Liquidity risk	We are exposed to liquidity risk for financial liabilities. Our liquidity at the corporate level depends on distribution from the project level entities, most of which have project debt in place. Distributions are generally subject to the compliance with covenants and other conditions under our project finance agreements.	The objective of our financing and liquidity policy is to ensure that we maintain sufficient funds to meet our financial obligations as they fall due. Project finance borrowing permits us to finance projects through project debt and thereby insulate the rest of our assets from such credit exposure. We incur project finance debt on a project-by-project basis or by groups of projects. The repayment profile of each project is established based on the projected cash flow generation of the business. This ensures that sufficient financing is available to meet deadlines and maturities, which mitigates the liquidity risk. In addition, we maintain a periodic communication with our lenders and regular monitoring of debt covenants and minimum ratios. As of March 31, 2023, we had $474.5 million liquidity at the corporate level, comprised of $109.4 million of cash on hand at the corporate level and $365.1 million available under our Revolving Credit Facility. We believe that the Company’s liquidity position, cash flows from operations and availability under our revolving credit facility will be adequate to meet the Company’s financial commitments and debt obligations; growth, operating and maintenance capital expenditures; and dividend distributions to shareholders. Management continues to regularly monitor the Company’s ability to finance the needs of its operating, financing and investing activities within the guidelines of prudent balance sheet management.

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Electricity price risk	We currently have three assets with merchant revenues (Chile PV 1 and Chile PV 3, where we have a 35% ownership, and Lone Star II, where we have a 49% ownership) and one asset with partially contracted revenues (Chile PV 2, where we have a 35% ownership). In addition, in several of the jurisdictions in which we operate including Spain, Chile and Italy we are exposed to remuneration schemes which contain both regulated incentives and market price components. In such jurisdictions, the regulated incentive or the contracted component may not fully compensate for fluctuations in the market price component, and, consequently, total remuneration may be volatile. In addition, operating costs in certain of our existing or future projects depend to some extent on market prices of electricity used for self-consumption and, to a lower extent, on market prices of natural gas. In Spain, for example, operating costs increased during 2021 and 2022 as a result of the increase in the price of electricity and natural gas.	We manage our exposure to electricity price risk by ensuring that most of our revenues are not exposed to fluctuations in electricity prices. As of March 31, 2023, assets with merchant exposure represent less than a 2%3 of our portfolio in terms of Adjusted EBITDA. Regarding regulated assets with exposure to electricity market prices, these assets have the right to receive a “reasonable rate of return” (see “Item 4—Information on the Company— Regulation”). As a result, fluctuations in market prices may cause volatility in results of operations and cash flows, but it should not affect the net value of these assets.
Country risk	We consider that Algeria and South Africa, which represent a small portion of the portfolio in terms of cash available for distribution, are the geographies with a higher political risk profile.	Most of the countries in which we have operations are OECD countries. In 2019, we entered into a political risk insurance agreement with the Multinational Investment Guarantee Agency for Kaxu. The insurance provides protection for breach of contract up to $58.0 million in the event the South African Department of Mineral Resources and Energy does not comply with its obligations as guarantor. We also have a political risk insurance in place for two of our assets in Algeria for up to $37.2 million, including two years dividend coverage. These insurance policies do not cover credit risk.

³ Calculated as a percentage of our Adjusted EBITDA in 2022.

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Item 4. CONTROLS AND PROCEDURES

Not Applicable

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

In 2018, an insurance company covering certain Abengoa obligations in Mexico claimed certain amounts related to a potential loss. Atlantica reached an agreement under which Atlantica´s maximum theoretical exposure would in any case be limited to approximately $35 million, including $2.5 million to be held in an escrow account. In January 2019, the insurance company called on this $2.5 million from the escrow account and Abengoa reimbursed this amount. The insurance company could claim additional amounts if they faced new losses after following a process agreed between the parties and, in any case, Atlantica would only make payments if and when the actual loss has been confirmed and after arbitration if the Company initiates it. The Company used to have indemnities from Abengoa for certain potential losses, but such indemnities are no longer valid following the insolvency filing by Abengoa S.A. in February 2021.

In addition, during 2021 and 2022, several lawsuits were filed related to the February 2021 winter storm in Texas against among others Electric Reliability Council of Texas (ERCOT), two utilities in Texas and more than 230 individual power generators, including Post Oak Wind, LLC, the project company owner of Lone Star I, one of the wind assets in Vento II where the Company currently has a 49% equity interest. The basis for the lawsuit is that the defendants failed to properly prepare for cold weather, including failure to implement measures and equipment to protect against cold weather, and failed to properly conduct their operations before and during the storm.

Except as described above, Atlantica is not a party to any other significant legal proceedings other than legal proceedings (including administrative and regulatory proceedings) arising in the ordinary course of its business. Atlantica is party to various administrative and regulatory proceedings that have arisen in the ordinary course of business.

While Atlantica does not expect these proceedings, either individually or in combination, to have a material adverse effect on its financial position or results of operations, because of the nature of these proceedings Atlantica is not able to predict their ultimate outcomes, some of which may be unfavorable to Atlantica.

Item 1A. Risk Factors

None

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

Recent sales of unregistered securities

None.

Use of proceeds from the sale of registered securities

None.

Purchases of equity securities by the issuer and affiliated purchasers

None

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Item 3. Defaults Upon Senior Securities

None.

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

Not Applicable.

Item 6 Exhibits

Not Applicable.

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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: May 5, 2023
	ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC
		By:	/s/ Santiago Seage
		Name: Santiago Seage
		Title: Chief Executive Officer
	ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC
		By:	/s/ Francisco Martinez-Davis
		Name: Francisco Martinez-Davis
		Title: Chief Financial Officer

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