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