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 November, 2022
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): ☐

Q3 2022 Earnings Presentation November 9, 2022

DISCLAIMER Forward Looking Statements This presentation contains forward-looking statements. These forward-looking statements include, but are not limited to, all statements other than statements of historical facts contained in this presentation, including, without limitation, those regarding our future financial position and results of operations, our strategy, plans, objectives, goals and targets, future developments in the markets in which we operate or are seeking to operate. In some cases, you can identify forward-looking statements by terminology such as “aim,” "anticipate," "believe," "could," "estimate," "expect,“, "guidance," "intend," "may," "plan," "predict," "should" or "will" or the negative of such terms or other similar expressions or terminology. By their nature, forward-looking statements involve risks and uncertainties because they relate to events and depend on circumstances that may or may not occur in the future. Forward-looking statements speak only as of the date of this presentation and are not guarantees of future performance and are based on numerous assumptions. Our actual results of operations, financial condition and the development of events may differ materially from (and be more negative than) those made in, or suggested by, the forward-looking statements. Except as required by law, we do not undertake any obligation to update any forward-looking statements to reflect events or circumstances after the date hereof or to reflect anticipated or unanticipated events or circumstances. Investors should read the section entitled "Item 3.D.—Risk Factors" and the description of our segments and business sectors in the section entitled "Item 4.B. Information on the Company—Business Overview", each in our Annual Report on Form 20-F for the fiscal year ended December 31, 2021, filed with the Securities and Exchange Commission (“SEC”), for a more complete discussion of the risks and factors that could affect us. Forward-looking statements include, but are not limited to, statements relating to: expected value, new investments and projects, including their expected development, completion, commercial operations date (“COD”), expected financial and operating performance (including enterprise value to EBITDA multiples), as well as statements with respect to potential acquisitions; expected output capacity, ability to add leverage or capacity, anticipated synergies and market dynamics relating to such investments and projects; the Inflation Reduction Act in the U.S. (“IRA”) and tax grants thereunder; our anticipated exposure to current market risks, including the potential impact from foreign exchange rates and interest rates on cash available for distribution (“CAFD”); the impact from potential caps on market prices in the net value of our assets; taxes on electricity companies in Spain; equity investments; estimated returns, CAFD estimates, including per currency, geography, sector and escalation factors; net corporate leverage based on CAFD estimates; debt refinancing; the quality of our off-takers and the performance of our long-term contracts; self-amortizing project debt structure and debt reduction; the use of non-GAAP measures as a useful tool for investors; the possibility to extend asset life; dividends; and various other factors, including those factors discussed under “Item 3.D.—Risk Factors” and “Item 5.A.—Operating Results” in our Annual Report on Form 20-F for the fiscal year ended December 31, 2021 filed with the SEC. Non-GAAP Financial Information This presentation also includes certain non-GAAP financial measures, including Adjusted EBITDA, CAFD, CAFD per share and enterprise value to EBITDA. Non-GAAP financial measures are not measurements of our performance or liquidity under IFRS as issued by IASB and should not be considered alternatives to operating profit or profit for the period or net cash provided by operating activities 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. Please refer to the appendix of this presentation for a reconciliation of the non-GAAP financial measures included in this presentation to the most directly comparable financial measures prepared in accordance with IFRS as well as the reasons why management believes the use of non-GAAP financial measures (including CAFD, CAFD per share, Adjusted EBITDA and enterprise value to EBITDA) in this presentation provides useful information to investors. In our discussion of operating results, we have included foreign exchange impacts in our revenue and adjusted by providing constant currency 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 that 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 and Adjusted EBITDA 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 be a substitute for recorded amounts presented in conformity with IFRS as issued by the IASB nor should such amounts be considered in isolation.

Key Messages Revenue and Adjusted EBITDA growth of 4.9%1 and 4.3%1 in 9M 2022, on a comparable basis ~$150 million in new investments in storage and PV committed Q3 2022 dividend of $0.445 per share Compared to the nine-month period ended September 30, 2021, on a constant currency basis and adjusted for the consolidation of a non-recurrent Rioglass solar project in the nine-month period ended September 30, 2021. +6.2% year-over-year CAFD growth in 9M 2022 up to $179.0 million Net Corporate Debt ratio at 3.0x, providing significant financial flexibility

∆ Excluding FX impact & non-recurrent project US$ in million (except CAFD per share) 2022 2021 ∆ Reported Revenue 858.4 940.4 (8.7)% Adjusted EBITDA1 630.6 634.1 (0.6)% CAFD 179.0 168.5 6.2% CAFD per share3 1.57 1.52 3.0% HIGHLIGHTS 6.2% CAFD Growth in 9M 2022 Adjusted EBITDA previously excluded share of profit/(loss) of associates carried under the equity method and did not include depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership) (which is equivalent to our pro-rata share of Adjusted EBITDA from unconsolidated affiliates) and now includes it (see reconciliation on page 28). Prior periods have been presented accordingly. Compared to the first nine months of 2021, on a constant currency basis and adjusted for the consolidation of a non-recurrent Rioglass solar project in the first nine months of 2021. Calculated by dividing CAFD for the period by weighted average number of shares for the period (see reconciliation on page 29). 4.9%2 First 9 Months 4.3%2

HIGHLIGHTS Performance by Sector and Region WATER 9M 2022 9M 2021 ∆ 40.4 40.7 (1)% 27.8 28.6 (3)% RENEWABLES US$ in million 9M 2022 9M 20212 ∆ Revenue 652.8 725.8 (10)% Adjusted EBITDA 469.8 464.9 +1% EFFICIENT NAT. GAS & HEAT 9M 2022 9M 2021 ∆ 81.9 93.5 (12)% 66.8 76.4 (13)% TRANSMISSION LINES 9M 2022 9M 2021 ∆ 83.3 80.4 +4% 66.2 64.2 +3% By Sector EMEA NORTH AMERICA US$ in million 9M 2022 9M 2021 ∆ Revenue 323.7 308.7 +5% Adjusted EBITDA 258.1 243.4 +6% SOUTH AMERICA 9M 2022 9M 20211 ∆ 412.2 514.6 (20)% 277.4 300.1 (8)% By Region 9M 2022 9M 2021 ∆ 122.5 117.1 +5% 95.1 90.6 +5% Includes Revenue and Adjusted EBITDA of a non-recurrent Rioglass solar project. Compared to the first nine months of 2021, on a constant currency basis and excluding the effect from the non-recurrent solar project, Revenue and Adjusted EBITDA for the first nine months of 2022 increased 4.9% and 2.6%, respectively. Includes Revenue and Adjusted EBITDA of a non-recurrent Rioglass solar project. Compared to the first nine months of 2021, on a constant currency basis and excluding the effect from the non-recurrent solar project, Revenue and Adjusted EBITDA for the first nine months of 2022 increased 7.9% and 7.7%, respectively.

Includes 49% of Vento II production since its acquisition. Includes curtailment in wind assets for which we receive compensation. Represents total installed capacity in assets owned or consolidated at the end of the period, regardless of our percentage of ownership in each of the assets, except for Vento II, for which we have included our 49% interest. GWh produced includes 30% share of the production from Monterrey. Availability refers to the time during which the asset was available to our client totally or partially divided by contracted or budgeted availability, as applicable. Includes 43 MW corresponding to our 30% share in Monterrey and 55 MWt corresponding to thermal capacity from Calgary District Heating. WATER RENEWABLES TRANSMISSION LINES EFFICIENT NATURAL GAS & HEAT 9M 2022 9M 2021 Availability4 102.6% 99.8% Mft3 in operation2 17.5 17.5 9M 2022 9M 2021 GWh produced1 4,155 3,460 MW in operation2 2,121 2,022 9M 2022 9M 2021 GWh produced3 1,898 1,665 Availability4 100.4% 99.8% MW in operation5 398 398 9M 2022 9M 2021 Availability4 99.9% 100.0% Miles in operation 1,229 1,166 KEY OPERATIONAL METRICS Steady Operational Performance

Consolidated cash as of September 30, 2022 increased by $204.5 million vs December 31, 2021, including FX translation differences of $(45.7) million. CASH FLOW Operating Cash Flow US$ in million 2022 2021 Adjusted EBITDA 630.6 XX 634.1 Share in Adjusted EBITDA of unconsolidated affiliates (37.6) (16.0) Net interest and income tax paid (162.1) (209.0) Changes in working capital 47.8 (4.6) Non-monetary adjustments and other 37.0 37.4 OPERATING CASH FLOW 515.7 441.9 Acquisitions of subsidiaries and entities under the equity method and investments in assets under development and construction (76.0) (340.2) Distributions from entities under the equity method & other 27.9 17.3 INVESTING CASH FLOW (48.1) (322.9) FINANCING CASH FLOW (263.1) (207.9) Net change in consolidated cash1 204.5 (88.9) First 9 Months +16.7%

Net corporate debt is calculated as long-term corporate debt plus short-term corporate debt minus cash and cash equivalents at Atlantica’s corporate level. Net corporate leverage is calculated as net corporate debt divided by midpoint 2022 CAFD guidance before corporate debt service. CAFD pre-corporate debt service is calculated as CAFD plus corporate debt interest paid by Atlantica. Net project debt is calculated as long-term project debt plus short-term project debt minus cash and cash equivalents at the consolidated project level. NET DEBT Net Corporate Debt to CAFD pre corporate debt service at 3.0x US$ in million 3.0x 3.5x Net Corporate Debt / CAFD pre corporate debt service2 Net Project Debt3 Net Corporate Debt1
Net corporate debt is calculated as long-term corporate debt plus short-term corporate debt minus cash and cash equivalents at Atlantica’s corporate level. Net corporate leverage is calculated as net corporate debt divided by midpoint 2022 CAFD guidance before corporate debt service. CAFD pre-corporate debt service is calculated as CAFD plus corporate debt interest paid by Atlantica. Net project debt is calculated as long-term project debt plus short-term project debt minus cash and cash equivalents at the consolidated project level. NET DEBT Net Corporate Debt to CAFD pre corporate interest at 3.0x US$ in million 3.0x 3.5x Net Corporate Debt / CAFD pre corporate interest2 Net Project Debt3 Net Corporate Debt1

GROWTH UPDATE ~$150 Million in New Investments 35% ownership through our renewable energy platform. 73 MW represents total installed capacity in the asset. Substation and a 2.4-mile transmission line in Peru connected to our ATN transmission line as previously announced. 100 MWh battery system with expected COD in 2024 Storage Acquired 73 MW in operation1 and intend to add 100 MWh of batteries in 2023 Exclusivity agreement to co-invest in an 80 MW PV portfolio starting construction Solar PV Expansion of existing transmission line, under construction2 Repayment of a higher cost non-recourse debt tranche Others

GROWTH UPDATE Inflation Reduction Act as a Growth Opportunity Enterprise value means the expected investment of Atlantica in this battery storage system. Expected 2025 EBITDA of the Coso Battery Storage Project. See reconciliation on page 30. Developing and preparing to start construction of a battery storage system located inside our Coso geothermal plant in California Capacity: 100 MWh (4 hours) COD expected in 2024 First project of a pipeline in the Southwest that includes 6 projects with a total 300 MW of PV and over 2,000 MWh of storage First Project: Battery Storage Asset at our Coso Plant Investment Highlights Attractive market for storage Synergies with existing assets ITC (IRA) Option to include leverage in the future 10x EV1 / EBITDA2

GROWTH UPDATE First Investment in PV + Batteries Acquired through our renewable energy platform in Chile Plant in operation Batteries are expected to capture additional capacity revenues, as well as one of the highest daily price spreads Investment Highlights Attractive market for storage Synergies with other existing assets in Chile Strong operational track-record 6x EV1 / EBITDA2 Additional investment in Batteries (100 MWh) ~73 MW PV plant in Chile Enterprise value means the investment of Atlantica in this Chile PV 3 plant. Average EBITDA for the years 2021 and 2020 of the Chile PV 3 plant. See reconciliation on page 30.

Calculated as the average net euro exposure expected for the years 2024-2027 multiplied by the difference between our average euro/dollar hedged rate for 2022 and the euro/dollar rate as of October 31, 2022, and dividing the result by the midpoint CAFD 2022 Guidance. Based on CAFD estimates for the 2022-2026 period as of February 28, 2022, including the acquisitions announced as of November 9, 2022. See “Disclaimer – Forward Looking Statements”. Expected annual impact calculated on existing debt as of September 30, 2022, with interest rates as of October 31, 2022, divided by the midpoint CAFD 2022 Guidance. RISK MITIGATION STRATEGY Limited Exposure to Current Market Risks Limited Impact from Euro FX on CAFD Natural hedge: distributions of assets in Europe are partially offset with corporate interest and corporate G&A paid in euros The resulting net euro exposure is hedged through currency options on a rolling basis: 100% for the next 12 months and 75% for the following 12 months After month 24: 2-3% potential impact on CAFD calculated as the difference of net euro exposure converted at current rate and at average hedged rate for 20221 ~50% of the Portfolio with Indexed Revenue 40% Indexed to inflation or formula based on inflation 12% Indexed to a fixed number 48% Not indexed Interest Rate Risk Highly Covered An increase of 100bp in reference interest rates would have an impact on CAFD of ~1.5%3 Regulated Assets in Europe No expected impact from potential caps on market prices on the net value of our assets Taxes on energy companies announced in Spain not expected to be applicable ü

Appendix

CURRENCY2 SECTOR GEOGRAPHY Based on CAFD estimates for the 2022-2026 period as of February 28, 2022, including the acquisitions closed as of November 9, 2022. See “Disclaimer – Forward Looking Statements”. Including the effect of currency hedges. As of September 30, 2022. of interest rates in project debt are fixed or hedged2,3 ~ 93% 90 Denominated in USD % > 70% Renewable 15% Eff. Natural Gas & Heat 12% Transmission Lines 3% Water 46% North America 31% Europe 15% South America 8% RoW SIZEABLE AND DIVERSIFIED ASSET PORTFOLIO Portfolio Breakdown Based on Estimated CAFD1 INTEREST RATES AND INFLATION Indexed to inflation or formula based on inflation Indexed to a fixed number Not indexed Escalation factors included in contracts
CURRENCY2 SECTOR GEOGRAPHY Based on CAFD estimates for the 2022-2026 period as of February 28, 2022, including the acquisitions closed as of November 9, 2022. See “Disclaimer – Forward Looking Statements”. Including the effect of currency hedges. As of September 30, 2022. of interest rates in project debt are fixed or hedged2,3 ~ 93% 90 Denominated in USD % > 70% Renewable 15% Eff. Natural Gas & Heat 12% Transmission Lines 3% Water 46% North America 31% Europe 15% South America 8% RoW SIZEABLE AND DIVERSIFIED ASSET PORTFOLIO Portfolio Breakdown Based on Estimated CAFD1 INTEREST RATES AND INFLATION Indexed to inflation or formula based on inflation Indexed to a fixed number Not indexed Escalation factors included in contracts1

HISTORICAL FINANCIAL REVIEW Key Financials by Quarter (1/2) “Deposits into/ withdrawals from restricted accounts” and “Change in non-restricted cash at project level” are calculated on a constant currency basis to reflect actual cash movements isolated from the impact of variations generated by foreign exchange changes during the period. Prior periods have been recalculated to conform to this presentation. Dividends are paid to shareholders in the quarter after they are declared. (3) Number of shares outstanding on the record date corresponding to each dividend, except the shares issued under the ATM program between the dividend declaration date and the dividend record date. 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 Revenue 210,403 255,344 302,987 244,526 1,013,260 268,178 342,997 329,244 271,331 1,211,749 247,452 307,832 303,121 Adjusted EBITDA 165,962 214,107 240,958 175,096 796,123 171,249 232,985 229,846 190,307 824,388 173,626 228,678 228,336 Atlantica’s pro-rata share of EBITDA from unconsolidated affiliates (3,553) (3,959) (3,943) (3,013) (14,468) (3,298) (4,295) (8,451) (15,013) (31,057) (14,202) (15,988) (7,387) Non-monetary items (9,823) (9,161) (10,843) (14,116) (43,943) (6,834) 8,625 33,675 20,346 55,809 10,413 10,940 10,839 Accounting provision for electricity market prices in Spain (5,489) (5,478) (5,516) (5,827) (22,311) (659) 11,643 41,582 24,489 77,055 7,141 10,585 10,507 Difference between billings and revenue in assets accounted for as concessional financial assets 10,383 11,034 9,390 12,536 43,344 8,501 11,659 6,771 11,959 38,890 18,169 15,050 14,978 Income from cash grants in the US (14,717) (14,717) (14,717) (14,717) (58,868) (14,678) (14,678) (14,678) (14,678) (58,711) (14,897) (14,695) (14,645) Other non-monetary items - - - (6,108) (6,108) - - - (1,424) (1,424) - - - Maintenance Capex - (1,723) (1,291) (1,603) (4,618) (3,278) (1,098) (246) (13,100) (17,722) (2,844) (3,614) (7,283) Dividends from unconsolidated affiliates 5,120 5,262 9,758 2,106 22,246 8,799 4,431 11,385 10,268 34,883 31,870 11,921 12,411 Net interest and income tax paid (11,436) (119,517) (31,625) (124,661) (287,239) (30,872) (132,857) (45,301) (133,234) (342,263) (16,546) (112,705) (32,885) Changes in other assets and liabilities (61,353) 393 (39,352) 111,851 4,140 35,459 (1,699) (11,873) 21,806 43,696 (5,588) 6,415 52,186 Deposits into/withdrawals from debt service accounts1 32,921 17,605 8,280 24,230 90,433 (29,639) 17,229 (8,456) 23,595 2,729 11,805 8,020 (20,503) Change in non-restricted cash at project companies1 (50,467) 31,257 (94,192) 34,784 (78,618) (71,162) 47,730 (89,947) 115,588 2,209 (103,116) 51,501 (135,718) Dividends paid to non-controlling interests (4,915) (9,246) (6,833) (1,950) (22,944) (4,215) (7,395) (11,717) (4,807) (28,134) (6,221) (9,800) (10,421) Principal amortization of indebtedness net of new indebtedness at projects (14,898) (75,301) (18,963) (151,260) (260,422) (14,972) (104,999) (40,336) (158,684) (318,991) (24,789) (112,427) (27,912) Cash Available For Distribution (CAFD) 47,558 49,717 51,953 51,463 200,691 51,237 58,657 58,580 57,073 225,547 54,407 62,941 61,662 Dividends declared2 41,657 42,673 42,673 46,491 173,494 47,643 47,807 48,493 49,479 193,422 50,202 51,332 51,645 # of shares3 101,601,662 101,601,662 101,601,662 110,691,722 110,797,738 111,178,846 111,477,263 112,451,438 114,095,845 115,352,085 116,055,126 DPS (in $ per share) 0.41 0.42 0.42 0.42 1.67 0.43 0.43 0.435 0.44 1.735 0.44 0.445 0.445 Key Financials US$ in thousands

Debt details 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 Project debt 4,777.2 5,007.6 5,281.2 5,237.6 5,237.6 5,200.2 5,374.2 5,278.9 5,036.2 5,036.2 5,037.0 4,735.5 4,621.9 Project cash (535.3) (510.1) (602.2) (533.3) (533.3) (624.6) (603.1) (685.0) (534.4) (534.4) (625.9) (545.1) (675.8) Net Project debt 4,241.9 4,497.5 4,679.0 4,704.3 4,704.3 4,575.6 4,771.1 4,593,9 4,501.8 4,501.8 4,411.1 4,190.4 3,946.1 Corporate debt 807.3 837.0 959.7 993.7 993.7 965.3 1,025.1 1,030.1 1,023.1 1,023.1 1,056.1 1,000.1 955.5 Corporate cash (154.9) (278.7) (186.7) (335.2) (335.2) (434.2) (83.2) (78.6) (88.3) (88.3) (113.1) (123.1) (105.8) Net Corporate debt 652.4 558.3 773.0 658.5 658.5 531.1 941.8 951.5 934.8 934.8 943.0 877.0 849.7 Total Net debt 4,894.4 5,055.8 5,452.0 5,362.8 5,362.8 5,106.7 5,713.0 5,545.1 5,436.6 5,436.6 5,354.1 5,067.4 4,795.8 Net Corporate debt / CAFD pre corporate interests1 2.4x 2.3x 3.3x 3.0x 3.0x 2.6x2 3.4x 3.5x 3.5x 3.5x 3.3x 3.1x 3.0x HISTORICAL FINANCIAL REVIEW Key Financials by Quarter (2/2) US$ in million (1) Ratios presented are the ratios shown on each earnings presentation relating to such period. (2) Net corporate debt as of March 31, 2021, was calculated pro-forma including the payment of $170 million for the Coso investment ($130 million equity investment paid in April 2021 and additional $40 million paid in July 2021 to reduce debt).

HISTORICAL FINANCIAL REVIEW Segment Financials by Quarter 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 by Geography NORTH AMERICA 59,283 98,648 109,757 63,233 330,921 60,585 118,216 129,860 87,114 395,775 74,304 124,968 124,423 SOUTH AMERICA 35,654 39,375 36,990 39,441 151,460 38,308 40,043 38,778 37,856 154,985 38,528 39,804 44,217 EMEA 115,466 117,321 156,240 141,852 530,879 169,285 217,726 160,606 146,361 660,989 134,620 143,060 134,481 by Business Sector RENEWABLES 150,793 193,881 234,556 173,859 753,089 199,679 271,945 254,132 202,768 928,525 182,101 238,234 232,423 EFFICIENT NAT. GAS & HEAT 26,403 25,629 28,086 30,912 111,030 28,408 30,097 35,019 30,168 123,692 25,327 28,091 28,526 TRANSMISSION LINES 26,608 26,787 25,834 26,813 106,042 26,614 26,975 26,840 25,251 105,680 26,620 28,234 28,425 WATER 6,599 9,047 14,511 12,942 43,099 13,477 13,979 13,253 13,143 53,852 13,404 13,273 13,747 Total Revenue 210,403 255,344 302,987 244,526 1,013,260 268,178 342,996 329,244 271,331 1,211,749 247,452 307,832 303,121 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 by Geography NORTH AMERICA 52,661 89,954 95,879 40,871 279,365 40,287 94,574 108,500 68,442 311,803 58,266 102,913 96,981 SOUTH AMERICA 28,422 31,380 29,947 30,275 120,023 29,943 30,279 30,404 28,921 119,547 29,129 29,715 36,236 EMEA 84,879 92,773 115,132 103,950 396,735 101,019 108,133 90,942 92,944 393,038 86,231 96,051 95,118 by Business Sector RENEWABLES 113,670 161,415 181,788 119,412 576,285 117,036 177,995 169,830 137,722 602,583 122,223 174,606 173,022 EFFICIENT NAT. GAS & HEAT 24,462 23,303 27,479 25,762 101,006 23,182 24,039 29,166 23,548 99,935 21,699 22,315 22,794 TRANSMISSION LINES 21,922 22,423 21,702 21,225 87,272 21,203 21,319 21,721 19,392 83,635 20,523 22,656 23,047 WATER 5,908 6,966 9,989 8,697 31,560 9,828 9,633 9,129 9,645 38,235 9,181 9,102 9,473 Total Adjusted EBITDA 165,962 214,107 240,958 175,096 796,123 171,249 232,985 229,846 190,307 824,388 173,626 228,678 228,336 Adjusted EBITDA Revenue US $ in thousands

1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 RENEWABLES3 (GWh) 526 957 1,125 636 3,244 606 1,377 1,477 1,195 4,655 1,094 1,554 1,507 (GWh)4 644 624 664 642 2,574 542 501 622 627 2,292 625 626 647 (availability %)5 102.4% 100.9% 103.8% 101.2% 102.1% 98.3% 100.1% 101.1% 103.0% 100.6% 100.3% 99.9% 101.1% TRANSMISSION LINES (availability %)5 99.9% 99.9% 100.0% 100.0% 100.0% 100.0% 99.9% 100.0% 100.0% 100.0% 99.9% 99.9% 100.0% WATER (availability %)5 101.8% 102.2% 101.1% 95.4% 100.1% 97.5% 101.9% 99.8% 91.9% 97.9% 104.5% 99.9% 103.3% 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 RENEWABLES1 (MW) 1,496 1,551 1,551 1,551 1,551 1,591 2,018 2,022 2,044 2,044 2,044 2,048 2,121 EFFICIENT NAT. GAS & HEAT2 (MW) 343 343 343 343 343 343 398 398 398 398 398 398 398 TRANSMISSION LINES (Miles) 1,166 1,166 1,166 1,166 1,166 1,166 1,166 1,166 1,166 1,166 1,229 1,229 1,229 WATER1 (Mft3/day) 10.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 17.5 Capacity in operation (at the end of the period) Production / Availability Represents total installed capacity in assets owned or consolidated at the end of the period, regardless of our percentage of ownership in each of the assets, except for Vento II, for which we have included our 49% interest. Includes 43 MW corresponding to our 30% share in Monterrey and 55 MWt corresponding to thermal capacity from Calgary District Heating since May 14, 2021. Includes 49% of Vento II production since its acquisition. Includes curtailment in wind assets for which we receive compensation. GWh produced includes 30% share of the production from Monterrey. Availability refers to the time during which the asset was available to our client totally or partially divided by contracted or budgeted availability, as applicable. EFFICIENT NAT. GAS & HEAT HISTORICAL FINANCIAL REVIEW Key Performance Indicators

Historical Capacity Factors1 1Q20 2Q20 3Q20 4Q20 2020 1Q21 2Q21 3Q21 4Q21 2021 1Q22 2Q22 3Q22 SOLAR US 18.2% 37.5% 35.2% 17.6% 27.1% 18.0% 38.6% 31,0% 17.0% 26.1% 17.2% 39.1% 32.4% Chile2 - 27.9% 29.8% 38.2% 32.0% 28.4% 20.9% 20.6% 25.8% 23.9% 25.3% 20.4% 24.6% Spain 8.0% 22.1% 28.6% 8.3% 16.8% 9.1% 24.8% 29.6% 10.7% 18.6% 7.3% 23.6% 27.9% Italy - - - - - - - 18.6% 8.3% 16.5% 12.7% 19.7% 20.0% Kaxu 28.9% 8.6% 26.8% 44.7% 27.3% 38.9% 26.9% 20.2% 48.4% 33.6% 36.9% 27.2% 28.8% US - - - - - - - 21.6% 35.4% 28.3% 38.1% 35.6% 20.3% Uruguay3 34.6% 40.8% 40.6% 42.8% 39.7% 32.6% 38.3% 38.2% 38.3% 36.9% 34.5% 27.7% 38.2% Capacity factor ratio represents actual electrical energy output over a given period of time divided by the maximum possible electrical energy output assuming continuous operation at full nameplate capacity over that period. Historical Capacity Factors are calculated from the date of entry into operation or the acquisition of each asset. Some capacity factors are not indicative of a full period of operations. Includes Chile PV 1 since Q2 2020, Chile PV 2 since Q1 2021 and Chile PV 3 since Q3 2022. Includes curtailment production in wind assets for which we receive compensation. HISTORICAL FINANCIAL REVIEW Capacity Factors WIND

Exchange rates as of September 30, 2022 (EUR/USD = 0.9802) and December 31, 2021 (EUR/USD = 1.1370). Restricted cash is cash which is restricted generally due to requirements of certain project finance agreements. US $ in million1 As of Sept. 30 2022 As of Dec. 31 2021 Corporate cash at Atlantica 105.8 88.3 Existing available revolver capacity 440.0 440.0 Total Corporate Liquidity 545.8 528.3 Cash at project companies 675.8 534.4 - Restricted2 230.9 254.3 - Other 444.9 280.1 LIQUIDITY Liquidity Position

LIQUIDITY AND DEBT MATURITIES SUMMARY Healthy Balance Sheet and Strong Liquidity Strong Liquidity and No Significant Corporate Debt Maturities in the Short-term ~$546 million @ 30/09/22 Corporate Liquidity ~4.5 years average maturity2 of current corporate debt Revolving Credit Facility’s total limit is $450 million, of which $440 million are available as of September 30, 2022 $545.8 million available liquidity, out of which $105.8 million is corporate cash as of Sept. 30, 2022 Corporate Debt Maturities1 Corporate Debt is the indebtedness where Atlantica Sustainable Infrastructure plc. is the primary obligor. Corporate Debt Maturities as of September 30, 2022. Corporate Liquidity means cash and cash equivalents held a Atlantica Sustainable Infrastructure plc. level plus available capacity under the Revolving Credit Facility as of September 30, 2022. Corporate Cash corresponds to cash and cash equivalents held at Atlantica Sustainable Infrastructure plc. 12 3 4

Key principle: non-recourse project financing in ring-fenced subsidiaries 100% project debt self-amortizing progressively before the end of the contracted life Low interest rate risk, with +93% of interest rates fixed or hedged ~$2bn planned debt reduction in the next 5 years1 FINANCING Self-Amortizing Project Debt Structure Project debt amortization schedule as of December 31, 2021. Does not include new project debt.

Weighted Average Life Project debt term PPAs with predefined prices for ~15 years on average1 Refinancing opportunities could increase CAFD in earlier years Possibility to extend life in many assets (excluding ATN and ATS) Tails in most assets after debt amortization Contract term2 Represents weighted average years remaining as of September 30, 2022. Regulation term in the case of Spain and Chile TL3. (3) From the total amount of $211 million project debt, $74 million are progressively repaid following a theoretical 2036 maturity, with a legal maturity in 2027. The remaining $137 million are expected to be refinanced in or before 2027. LONG-TERM STABLE CASH FLOW Portfolio of Assets 3

CORPORATE DEBT DETAILS Corporate Debt as of September 30, 2022 No significant maturities in the near term Exchange rates as of September 30, 2022 (EUR/USD = 0.9802). Amounts include principal amounts outstanding, unless stated otherwise. As of September 30, 2022, letters of credit with face value in an amount equal to $10 million were outstanding and $440 million were available under the Revolving Credit Facility. The latter has a total limit of $450 million. US $ in million1 Maturity Amounts2 Credit Facilities (Revolving Credit Facility)3 2024 - (Other facilities)4 2022 – 2026 37.5 Green Exchangeable Notes5 2025 106.3 2020 Green Private Placement6 (€ denominated) 2026 282.1 Note Issuance Facility 20207 (€ denominated) 2027 134.8 Green Senior Notes8 2028 394.8 Total 955.5 Other facilities include the Commercial Paper Program, accrued interest payable and other debt. Senior unsecured notes dated July 17, 2020, exchangeable into ordinary shares of Atlantica, cash, or a combination of both, at Atlantica’s election. Senior secured notes dated April 1, 2020, of €290 million. Senior unsecured note facility dated July 8, 2020, of €140 million. Green Senior Unsecured Notes dated May 18, 2021, of $400 million.

fixed or hedged1 Project Debt As of September 30, 2022. (2) See our Annual Report on form 20-F for the fiscal year ended December 31, 2021 for additional information on the specific interest rates and hedges. (3) Percentage fixed or hedged. INTEREST RATE RISK COVERAGE 94%1 of Debt Fixed or Hedged2 ASSET INTEREST TYPE FIXED1,3 Solana Fixed 100% Mojave Fixed 100% Coso Hedged 100% Chile PV 1 & 2 Hedged 80% Palmatir Hedged 94% Cadonal Hedged 73% Melowind Hedged 75% Solaben 2 Hedged 100% Solaben 3 Hedged 100% Logrosan5 Hedged 100% Solacor 17 Hedged 90% Solacor 27 Hedged 90% PS 20 Hedged 100% Helioenergy 1 Hedged 99% Helioenergy 2 Hedged 99% Helios 1/2 Hedged 100% Solnova 1 Hedged 100% Solnova 3 Hedged 100% Solnova 4 Hedged 100% Solaben 1/6 Fixed 100% Kaxu Hedged 58% ACT Hedged 75% ATN Fixed 100% ATS Fixed 100% ATN 2 Fixed 100% Quadra 1 & 2 Hedged 75% Skikda Fixed 100% Tenes Fixed 100% Other Hedged 64% Hedged4 45.6% Fixed4 47.4% Total Fixed or Hedged 93.0% (4) Weighted average based on outstanding balance as of September 30, 2022. (5) Subholding company of Solaben 1, 2, 3 & 6. (6) Other facilities include the Commercial Paper Program, accrued interest payable and other debt. (7) Debt refinanced in October, 2022. % fixed or hedged calculated with outstanding debt post refinancing. INSTRUMENT INTEREST TYPE SEPT. 30, 2022 Revolving Credit Facility (RCF) Variable - Green Exchangeable Notes Fixed 106 2020 Green Private Placement Fixed 282 Note Issuance Facility 2020 Hedged (100%) 135 Green Senior Notes Fixed 395 Other facilities6 Fixed 38 Total Outstanding Debt 956 Hedged4 14.1% Fixed4 85.0% Total Fixed or Hedged 99.1% Corporate Debt of Corporate Debt ~99% of Project Debt & ~93%

Our management believes Adjusted EBITDA, CAFD, CAFD per share, and enterprise value to EBITDA are useful to investors and other users of our financial statements in evaluating our operating performance because such measures provide investors with additional tools to compare business performance across companies and across periods. Adjusted 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. Our management believes CAFD and CAFD per share are relevant supplemental measure of the Company’s ability to earn and distribute cash returns to investors and is useful to investors in evaluating our operating performance because securities analysts and other interested parties use such calculations as a measure of our ability to make quarterly distributions. In addition, CAFD is used by our management team for determining future acquisitions and managing our growth. Our management uses Adjusted EBITDA, CAFD and CAFD per share as measures of operating performance to assist in comparing performance from period to period and aims to use them on a consistent basis moving forward. They also readily view operating trends as a measure for planning and forecasting overall expectations, for evaluating actual results against such expectations, and for communicating with our board of directors, shareholders, creditors, analysts and investors concerning our financial performance. Our management believes enterprise value to EBITDA is a useful valuation tool widely used by investors when evaluating transactions as it compares the investment's value to its earnings before interest, taxes, depreciation, and amortization. We present non-GAAP financial measures because we believe that they and other similar measures are widely used by certain investors, securities analysts and other interested parties as supplemental measures of performance and liquidity. The non-GAAP financial measures may not be comparable to other similarly titled measures employed by other companies and they may have limitations as analytical tools. These measures may not be fit for isolated consideration 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. Thus, they should not be considered as alternatives to operating profit, profit for the period, any other performance measures derived in accordance with IFRS as issued by the IASB, any other generally accepted accounting principles or as alternatives to cash flow from operating, investing or financing activities. Some of the limitations of these non-GAAP measures are: they do not reflect our cash expenditures, future requirements for capital expenditures or contractual commitments; they do not reflect changes in, or cash requirements for, our working capital needs; they may not reflect the significant interest expense, or the cash requirements necessary, to service interest or principal payments, on our debts; although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often need to be replaced in the future and Adjusted EBITDA, CAFD, CAFD per share, and enterprise value to EBITDA do not reflect any cash requirements that would be required for such replacements; some of the exceptional items that we eliminate in calculating Adjusted EBITDA reflect cash payments that were made, or will be made in the future; and the fact that other companies in our industry may calculate Adjusted EBITDA, CAFD, CAFD per share, and enterprise value to EBITDA differently than we do, which limits their usefulness as comparative measures. We define Adjusted EBITDA as profit/(loss) for the period attributable to the parent company, after previously adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in our consolidated financial statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). Until September 30, 2021, Adjusted EBITDA excluded equity of profit/(loss) of associates carried under the equity method and did not include depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). Prior periods have been presented accordingly. CAFD is calculated as cash distributions received by the Company from its subsidiaries minus cash expenses of the Company, including debt service and general and administrative expenses. CAFD per share is calculated by dividing CAFD for the period by weighted average number of shares for the period. We define enterprise value to EBITDA as an investment's enterprise value divided by its earnings before interest, taxes, depreciation, and amortization. NON-GAAP FINANCIAL INFORMATION Reconciliation of Non-GAAP Measures

Information presented as the pro-rata share of our unconsolidated affiliates reflects our proportionate ownership of each asset in our property portfolio that we do not consolidate and has been calculated by multiplying our unconsolidated affiliates’ financial statement line items by our percentage ownership thereto. Note 7 to our consolidated financial statements as of and for the period ended September 30, 2022 includes a description of our unconsolidated affiliates and our pro rata share thereof. We do not control the unconsolidated affiliates. Multiplying our unconsolidated affiliates’ financial statement line items by our percentage ownership may not accurately represent the legal and economic implications of holding a noncontrolling interest in an unconsolidated affiliate. We include pro-rata share of depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates because we believe it assists investors in estimating the effect of such items in the profit/(loss) of associates carried under the equity method (which is included in the calculation of our Adjusted EBITDA) based on our economic interest in such unconsolidated affiliates. Each unconsolidated affiliate may report a specific line item in its financial statements in a different manner. In addition, other companies in our industry may calculate their proportionate interest in unconsolidated affiliates differently than we do, limiting the usefulness of such information as a comparative measure. Because of these limitations, the information presented as the pro-rata share of our unconsolidated affiliates should not be considered in isolation or as a substitute for our or such unconsolidated affiliates’ financial statements as reported under applicable accounting principles. NON-GAAP FINANCIAL INFORMATION Reconciliation of Non-GAAP Measures

“Deposits into/ withdrawals from restricted accounts” and “Change in non-restricted cash at project level” are calculated on a constant currency basis to reflect actual cash movements isolated from the impact of variations generated by foreign exchange changes during the period. (in thousands of U.S. dollars) For the three-month period ended September 30 For the nine-month period ended September 30 2022 2021 2022 2021 Profit/(loss) for the period attributable to the Company (13,543) (11,337) (9,473) (18,166) Profit/(loss) attributable to non-controlling interest 4,550 405 11,278 11,720 Income tax 6,925 9,262 12,975 42,390 Depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of our equity ownership) 5,040 6,861 16,909 11,799 Financial expense, net 69,114 78,615 224,893 251,422 Depreciation, amortization, and impairment charges 156,250 146,040 374,059 334,916 Adjusted EBITDA 228,336 229,846 630,641 634,081 Atlantica’s pro-rata share of EBITDA from unconsolidated affiliates (7,387) (8,451) (37,577) (16,044) Non-monetary items 10,839 33,675 32,192 35,463 Accounting provision for electricity market prices in Spain 10,507 41,582 28,233 52,566 Difference between billings and revenue in assets accounted for as concessional financial assets 14,978 6,771 48,197 26,931 Income from cash grants in the US (14,645) (14,678) (44,238) (44,034) Maintenance Capex (7,283) (246) (13,742) (4,623) Dividends from equity method investments 12,411 11,385 56,202 24,615 Net interest and income tax paid (32,885) (45,301) (162,136) (209,030) Changes in other assets and liabilities 52,186 (11,873) 53,012 21,887 Deposits into/ withdrawals from restricted accounts1 (20,503) (8,456) (679) (20,866) Change in non-restricted cash at project level1 (135,718) (89,947) (187,334) (113,379) Dividends paid to non-controlling interests (10,421) (11,717) (26,442) (23,327) Debt principal repayments (27,912) (40,336) (165,128) (160,307) Cash Available For Distribution 61,662 58,580 179,010 168,474 RECONCILIATION Reconciliation of CAFD and Adjusted EBITDA to Profit for the period attributable to the Company

RECONCILIATION Reconciliation of Adjusted EBITDA to Net Cash Provided by Operating Activities (in thousands of U.S. dollars) For the three-month period ended September 30 For the three-month period ended June 30 For the nine-month period ended September 30 2022 2021 2022 2021 Net cash provided by operating activities 251,590 195,623 515,726 441,940 Net interest and income tax paid 32,885 45,301 162,136 209,030 Changes in working capital (50,094) 14,009 (47,778) 4,576 Non-monetary items & other (13,432) (33,537) (37,020) (37,511) Atlantica’s pro-rata share of EBITDA from unconsolidated affiliates 7,387 8,451 37,577 16,044 Adjusted EBITDA 228,336 229,846 630,641 634,081 Reconciliation of CAFD to CAFD per share For the three-month period ended September 30 For the nine-month period ended September 30 2022 2021 2022 2021 CAFD (in thousands of U.S. dollars) 61,662 58,580 179,010 168,474 Weighted average number of shares (basic) for the period (in thousands) 115,604 111,055 114,236 110,749 CAFD per share (in U.S. dollars) 0.5334 0.5275 1.5670 1.5212

RECONCILIATION Reconciliation of EBITDA to Net Income of the Coso Battery Storage Project and the Chile PV 3 Acquisition Based on Unaudited Financial Statements for the year ended December 31, 2021 and Audited Financial Statements for the year ended December 31, 2020, presented on a 100% basis. (in millions of U.S. dollars) Coso battery storage project Expected 2025 Chile PV 3 Average 2020-20211 Net Income 1.6 (12.5) Income tax expense 0.6 3.4 Interest expense - 7.3 Depreciation and amortization 2.1 6.0 EBITDA 4.3 4.2

As of September 30, 2022 ASSET TYPE STAKE LOCATION GROSSCAPACITY OFFTAKER RATING1 YEARS INCONTRACT LEFT CURRENCY RENEWABLE ENERGY Solana 100% USA (Arizona) 280 MW APS BBB+/A3/BBB+ 21 USD Mojave 100% USA (California) 280 MW PG&E BB-/--/BB 17 USD Coso 100% USA (California) 135 MW SCPPA & two CCAs5 Investment grade5 17 USD Elkhorn Valley 49% USA (Oregon) 101 MW Idaho Power Company BBB/Baa1/-- 5 USD Prairie Star 49% USA (Minnesota) 101 MW Great River Energy --/A3/A- 5 USD Twin Groves II 49% USA (Illinois) 198 MW Exelon Generation Co. BBB/Baa2/-- 3 USD Lone Star II 49% USA (Texas) 196 MW EDPR Not rated 0 USD Chile PV 1 35% Chile 55 MW n/a n/a n/a USD 4 Chile PV 2 35% Chile 40 MW n/a Not rated 8 USD 4 Chile PV 3 35% Chile 73 MW n/a n/a n/a USD 4 La Sierpe 100% Colombia 20 MW Synermin6 Not rated 13 COP Palmatir 100% Uruguay 50 MW UTE BBB/Baa2/BBB-2 12 USD Cadonal 100% Uruguay 50 MW UTE BBB/Baa2/BBB-2 12 USD Melowind 100% Uruguay 50 MW UTE BBB/Baa2/BBB-2 13 USD Mini-Hydro 100% Peru 4 MW Peru BBB/Baa1/BBB 10 USD 4 Solaben 2/3 70% Spain 2x50 MW Kingdom of Spain A/Baa1/A- 15/15 EUR 3 Solacor 1/2 87% Spain 2x50 MW Kingdom of Spain A/Baa1/A- 14/14 EUR 3 PS 10/20 100% Spain 31 MW Kingdom of Spain A/Baa1/A- 10/12 EUR 3 Helioenergy 1/2 100% Spain 2x50 MW Kingdom of Spain A/Baa1/A- 14/14 EUR 3 Helios 1/2 100% Spain 2x50 MW Kingdom of Spain A/Baa1/A- 15/15 EUR 3 Solnova 1/3/4 100% Spain 3x50 MW Kingdom of Spain A/Baa1/A- 13/13/13 EUR 3 Solaben 1/6 100% Spain 2x50 MW Kingdom of Spain A/Baa1/A- 16/16 EUR 3 Seville PV 80% Spain 1 MW Kingdom of Spain A/Baa1/A- 13 EUR 3 Italy PV 1 100% Italy 1.6 MW Italy BBB/Baa3/BBB 8 EUR 3 Italy PV 2 100% Italy 2.1 MW Italy BBB/Baa3/BBB 9 EUR 3 Italy PV 3 100% Italy 2.5 MW Italy BBB/Baa3/BBB 10 EUR 3 Italy PV 4 100% Italy 3.6 MW Italy BBB/Baa3/BBB 9 EUR 3 Kaxu 51% South Africa 100 MW Eskom BB-/Ba2/BB-2 12 ZAR Reflects the counterparties’ issuer credit ratings issued by S&P, Moody’s and Fitch, respectively, as of November 9, 2022. For Kaxu, it refers to the credit rating of the Republic of South Africa, and for Palmatir, Cadonal and Melowind, it refers to the credit rating of Uruguay, as UTE is unrated. Gross cash in euros dollarized through currency hedges. USD denominated but payable in local currency. AT A GLANCE Sizeable and Diversified Asset Portfolio (5) 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; Southern California Public Power Authority, the third off-taker, is not rated. (6) Largest electricity wholesaler in Colombia.

As of September 30, 2022 ASSET TYPE STAKE LOCATION GROSSCAPACITY OFFTAKER RATING1 YEARS INCONTRACT LEFT CURRENCY EFFICIENT NAT. GAS & HEAT Calgary 100% Canada 55 MWt 22 High quality clients3 ~41% A+ or higher3 18 CAD ACT 100% Mexico 300 MW Pemex BBB/B1/BB- 11 USD 2 Monterrey 30% Mexico 142 MW Industrial Customers Not rated 24 USD 2 TRANSMISSION LINES ATN 100% Peru 379 miles Peru BBB/Baa1/BBB 18 USD 2 ATS 100% Peru 569 miles Peru BBB/Baa1/BBB 21 USD 2 ATN 2 100% Peru 81 miles Minera Las Bambas Not rated 11 USD 2 Quadra 1/2 100% Chile 49 miles / 32 miles Sierra Gorda Not rated 13/13 USD 2 Palmucho 100% Chile 6 miles Enel Generacion Chile BBB/-/A- 15 USD 2 Chile TL3 100% Chile 50 miles CNE A/A2/A- n/a USD 2 Chile TL4 100% Chile 63 miles Several Mini-hydro plants Not rated 49 USD WATER Skikda 34% Algeria 3.5 Mft3/day Sonatrach & ADE Not rated 11 USD 2 Honaine 26% Algeria 7 Mft3/day Sonatrach & ADE Not rated 15 USD 2 Tenes 51% Algeria 7 Mft3/day Sonatrach & ADE Not rated 18 USD 2 Reflects the counterparties’ issuer credit ratings issued by S&P, Moody’s and Fitch, respectively, as of November 9, 2022. USD denominated but payable in local currency. Diversified mix of 22 high credit quality clients (~41% A+ rating or higher, the rest unrated). AT A GLANCE Sizeable and Diversified Asset Portfolio

Great West House, GW1, 17th floor, Great West Road Brentford TW8 9DF London (United Kingdom)

SIGNATURES
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.

| Atlantica Sustainable Infrastructure plc

Date: November 9, 2022 | By: | /s/ Santiago Seage

|  | Name: | Santiago Seage
|  | Title: | Chief Executive Officer