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 August 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):  ☐

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

ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC
TABLE OF CONTENTS

   
Page
PART I – FINANCIAL INFORMATION
     
Item 1
9
     
Item 2
44
     
Item 3
73
     
Item 4
 75
     
PART II – OTHER INFORMATION
     
Item 1
75
     
Item 1A
76
     
Item 2
76
     
Item 3
76
     
Item 4
76
     
Item 5
76
     
Item 6
76
     
77

2
Definitions
 
Unless otherwise specified or the context requires otherwise in this quarterly report:
 
•
references to “2020 Green Private Placement” refer to the €290 million ($303 million) senior secured notes maturing on June 20, 2026 which were issued under a senior secured note purchase agreement entered with a group of institutional investors as purchasers of the notes issued thereunder as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—2020 Green Private Placement”;
 
•
references to “Abengoa” refer to Abengoa, S.A., together with its subsidiaries, unless the context otherwise requires;
 
•
references to “ACT” refer to the gas-fired cogeneration facility located inside the Nuevo Pemex Gas Processing Facility near the city of Villahermosa in the State of Tabasco, Mexico;
 
•
references to “Adjusted EBITDA” have the meaning set forth in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”;
 
•
references to “Algonquin” refer to, as the context requires, either Algonquin Power & Utilities Corp., a North American diversified generation, transmission and distribution utility, or Algonquin Power & Utilities Corp. together with its subsidiaries;
 
•
references to “Amherst Island Partnership” refer to the holding company of Windlectric Inc.;
 
•
references to “Annual Consolidated Financial Statements” refer to the audited annual consolidated financial statements as of December 31, 2021 and 2020 and for the years ended December 31, 2021, 2020 and 2019, including the related notes thereto, prepared in accordance with IFRS as issued by the IASB (as such terms are defined herein), included in our Annual Report;
 
•
references to “Annual Report” refer to our Annual Report on Form 20-F for the year ended December 31, 2021, filed with the SEC on February 28, 2022, as amended by Amendment No. 1 on Form 20-F/A, filed with the SEC on March 24, 2022;
 
•
references to “Atlantica Jersey” refer to Atlantica Sustainable Infrastructure Jersey Limited, a wholly-owned subsidiary of Atlantica;
 
•
references to “ATN” refer to ATN S.A., the operational electronic transmission asset in Peru, which is part of the Guaranteed Transmission System;
 
•
references to “AYES Canada” refer to Atlantica Sustainable Infrastructure Energy Solutions Canada Inc., a vehicle formed by Atlantica and Algonquin to channel co-investment opportunities;
 
•
references to “Befesa Agua Tenes” refer to Befesa Agua Tenes, S.L.U.;
 
•
references to “cash available for distribution” or “CAFD” refer to the cash distributions received by the Company from its subsidiaries minus cash expenses of the Company, including third-party debt service and general and administrative expenses;
 
•
references to “Calgary District Heating” or “Calgary” refer to the 55 MWt thermal capacity district heating asset in the city of Calgary which we acquired in May 2021;
 
•
references to “Chile PV 1” refer to the solar PV plant of 55 MW located in Chile;
 
•
references to “Chile PV 2” refer to the solar PV plant of 40 MW located in Chile;
 
•
references to “Chile TL3” refer to the 50-mile transmission line located in Chile;
 
•
references to “Chile TL4” refer to the 63-mile transmission line located in Chile;
 
3
•
references to “Consolidated Condensed Interim Financial Statements” refer to the consolidated condensed unaudited interim financial statements as of June 30, 2022 and for the six-month periods ended June 30, 2022 and 2021, including the related notes thereto prepared in accordance with IFRS as issued by the IASB, which form a part of this quarterly report;
 
•
references to “COD” refer to the commercial operation date of the applicable facility;
 
•
references to “Coso” refer to the 135 MW geothermal plant located in California;
 
•
references to the “Distribution Agreement” refer to the agreement entered into with BofA Securities, Inc., MUFG Securities Americas Inc. and RBC Capital Markets LLC, as sales agents, dated February 28, 2022 as amended on May 9, 2022, under which we may offer and sell from time to time up to $150 million of our ordinary shares and pursuant to which such sales agents may sell our ordinary shares by any method permitted by law deemed to be an “at the market offering” as defined by Rule 415(a)(4) promulgated under the Securities Act of 1933, as amended;
 
•
references to “EMEA” refer to Europe, Middle East and Africa;
 
•
references to “Eskom” refer to Eskom Holdings SOC Limited, together with its subsidiaries, unless the context otherwise requires;
 
•
references to “EURIBOR” refer to Euro Interbank Offered Rate, a daily reference rate published by the European Money Markets Institute, based on the average interest rates at which Eurozone banks offer to lend unsecured funds to other banks in the euro wholesale money market;
 
•
references to “EU” refer to the European Union;
 
•
references to “Exchange Act” refer to the U.S. Securities Exchange Act of 1934, as amended, or any successor statute, and the rules and regulations promulgated by the SEC thereunder;
 
•
references to “Federal Financing Bank” refer to a U.S. government corporation by that name;
 
•
references to “Fitch” refer to Fitch Ratings Inc.;
 
•
references to “Green Exchangeable Notes” refer to the $115 million green exchangeable senior notes due in 2025 issued by Atlantica Jersey on July 17, 2020, and fully and unconditionally guaranteed on a senior, unsecured basis, by Atlantica, as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Green Exchangeable Notes”;
 
•
references to “Green Senior Notes” refer to the $400 million green senior notes due in 2028, as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—-Green Senior Notes”;
 
•
references to “gross capacity” refer to the maximum, or rated, power generation capacity, in MW, of a facility or group of facilities, without adjusting for the facility’s power parasitics’ consumption, or by our percentage of ownership interest in such facility as of the date of this quarterly report;
 
•
references to “GWh” refer to gigawatt hour;
 
•
references to “IAS” refer to International Accounting Standards issued by the IASB;
 
•
references to “IASB” refer to the International Accounting Standards Board;
 
•
references to “IFRIC 12” refer to International Financial Reporting Interpretations Committee’s Interpretation 12—Service Concessions Arrangements;
 
•
references to “IFRS as issued by the IASB” refer to International Financial Reporting Standards as issued by the IASB;
 
4
•
references to “Italy PV” refer to the solar PV plants located in Italy with combined capacity of 9.8 MW;
 
•
references to “ITC” refer to investment tax credits;
 
•
references to “Kaxu” refer to the 100 MW solar plant located in South Africa;
 
•
references to “La Sierpe” refer to the 20 MW solar PV plant located in Colombia;
 
•
references to “Liberty GES” refer to Liberty Global Energy Solutions B.V., a subsidiary of Algonquin (formerly known as Abengoa-Algonquin Global Energy Solutions B.V. (AAGES)) which invests in the development and construction of contracted clean energy and water infrastructure assets;
 
•
references to “Liberty GES ROFO Agreement” refer to the agreement we entered into with Liberty GES on March 5, 2018, that provides us a right of first offer to purchase any of the assets offered for sale thereunder, as amended and restated from time to time;
 
•
references to “LIBOR” refer to London Interbank Offered Rate;
 
•
references to “M ft3” refer to million standard cubic feet;
 
•
references to “Monterrey” refer to the 142 MW gas-fired engine facility including 130 MW installed capacity and 12 MW battery capacity, located in Monterrey, Mexico;
 
•
references to “Multinational Investment Guarantee Agency” refer to the Multinational Investment Guarantee Agency, a financial institution member of the World Bank Group which provides political insurance and credit enhancement guarantees;
 
•
references to “MW” refer to megawatts;
 
•
references to “MWh” refer to megawatt hour;
 
•
references to “MWt” refer to thermal megawatts;
 
•
references to “Moody’s” refer to Moody’s Investor Service Inc.;
 
•
references to “Note Issuance Facility 2020” refer to the senior unsecured note facility dated July 8, 2020, as amended on March 30, 2021 of €140 million ($146 million), with Lucid Agency Services Limited, as facility agent and a group of funds managed by Westbourne Capital, as purchasers of the notes issued thereunder as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Note Issuance Facility 2020”;
 
•
references to “O&M” refer to operation and maintenance services provided at our various facilities;
 
•
references to “operation” refer to the status of projects that have reached COD (as defined above);
 
•
references to “Pemex” refer to Petróleos Mexicanos;
 
•
references to “PPA” refer to the power purchase agreements through which our power generating assets have contracted to sell energy to various off-takers;
 
•
references to “PV” refer to photovoltaic power;
 
•
references to “Revolving Credit Facility” refer to the credit and guaranty agreement with a syndicate of banks entered into on May 10, 2018 as amended on January 24, 2019, August 2, 2019, December 17, 2019, August 28, 2020, March 1, 2021 and May 5, 2022 providing for a senior secured revolving credit facility in an aggregate principal amount of $450 million as further described in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Sources of Liquidity—Revolving Credit Facility”;
 
5
•
references to “Rioglass” refer to Rioglass Solar Holding, S.A.;
 
•
references to “ROFO” refer to a right of first offer;
 
•
references to “Skikda” refer to the seawater desalination plant in Algeria, which is 34% owned by Atlantica;
 
•
references to “Solaben Luxembourg” refer to Solaben Luxembourg S.A.;
 
•
references to “S&P” refer to S&P Global Rating;
 
•
references to “Tenes” refer to Ténès Lilmiyah SpA, a water desalination plant in Algeria, which is 51% owned by Befesa Agua Tenes;
 
•
references to “U.K.” refer to the United Kingdom;
 
•
references to “U.S.” or “United States” refer to the United States of America;
 
•
references to “Vento II” refer to the wind portfolio in the U.S. in which we acquired a 49% interest in June 2021; and
 
•
references to “we,” “us,” “our,” “Atlantica” and the “Company” refer to Atlantica Sustainable Infrastructure plc and its consolidated subsidiaries, unless the context otherwise requires.
 
6
CAUTIONARY STATEMENTS REGARDING FORWARD-LOOKING STATEMENTS
 
This report includes forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Any statements that express, or involve discussions as to, expectations, beliefs, plans, objectives, assumptions, strategies, future events or performance (often, but not always, through the use of words or phrases such as may result, are expected to, will continue, is anticipated, believe, will, could, should, would, estimated, may, plan, potential, future, projection, goals, target, outlook, predict and intend or words of similar meaning) are not statements of historical facts and may be forward looking. Such statements occur throughout this report and include statements with respect to our expected trends and outlook, potential market and currency fluctuations, occurrence and effects of certain trigger and conversion events, our capital requirements, changes in market price of our shares, future regulatory requirements, the ability to identify and/or make future investments and acquisitions on favorable terms, reputational risks, divergence of interests between our company and that of our largest shareholder, tax and insurance implications, and more. Forward-looking statements involve estimates, assumptions and uncertainties. Accordingly, any such statements are qualified in their entirety by reference to, and are accompanied by, important factors included in Part I “Item 3.D.—Risk Factors” in our Annual Report (in addition to any assumptions and other factors referred to specifically in connection with such forward-looking statements) that could have a significant impact on our operations and financial results, and could cause our actual results, performance or achievements, to differ materially from the future results, performance or achievements expressed or implied in forward-looking statements made by us or on our behalf in this report, in our Annual Report, in presentations, on our website, in response to questions or otherwise. These forward-looking statements include, but are not limited to, statements relating to:
 
•
the condition of and changes in the debt and equity capital markets and other traditional liquidity sources and our ability to borrow additional funds, refinance existing debt and access capital markets, as well as our substantial indebtedness and the possibility that we may incur additional indebtedness going forward;
 
•
the ability of our counterparties, including Pemex, to satisfy their financial commitments or business obligations and our ability to seek new counterparties in a competitive market;
 
•
government regulation, including compliance with regulatory and permit requirements and changes in tax laws, market rules, rates, tariffs, environmental laws and policies affecting renewable energy, including changes in regulation defining the remuneration of our solar assets in Spain;
 
•
potential changes in relation to the Royal Decree Law 6/2022 published in Spain on March 30, 2022, to the Royal Decree Law 10/2022 and to the proposed detailed components of electricity pricing which have been published in draft form and are subject to comments and final publication;
 
•
changes in tax laws and regulations, including new taxes recently announced in Italy and Spain;
 
•
risks relating to our activities in areas subject to economic, social and political uncertainties;
 
•
recession risks, a persistent inflationary environment and supply chain issues, and the related increases in prices of materials, labor, services and other costs and expenses required to operate our business;
 
•
our ability to finance and make new investments and acquisitions on favorable terms, our ability to complete the construction of assets in time and budget and our ability to identify and execute development opportunities;
 
•
risks relating to new assets and businesses which have a higher risk profile and our ability to transition these successfully;
 
•
risks related to our reliance on third-party contractors or suppliers;
 
•
risks related to our ability to maintain appropriate insurance over our assets;
 
7
•
risks related to our facilities not performing as expected, unplanned outages, higher than expected operating costs and/ or capital expenditures, including as a result of interruptions or disruptions caused by supply chain issues and trade restrictions;
 
•
potential issues arising with our O&M suppliers’ including disagreement with subcontractors;
 
•
the effects of litigation and other legal proceedings (including bankruptcy) against us our subsidiaries, our assets and our employees;
 
•
price fluctuations, revocation and termination provisions in our off-take agreements and PPAs;
 
•
our electricity generation, our projections thereof and factors affecting production;
 
•
our guidance targets or expectations with respect to Adjusted EBITDA derived from low-carbon footprint assets;
 
•
our ability to grow organically and investments in new assets;
 
•
risks related to our ability to develop renewable and transmission projects, including construction risks and risks associated with the arrangements with our joint venture partners;
 
•
risks related to our current or previous relationship with Abengoa, our former largest shareholder and currently one of our operation and maintenance suppliers, including bankruptcy, reputational risk and particularly the potential impact of Abengoa’s insolvency filing and liquidation process and Abenewco1, S.A.’s and certain of its subsidiaries’ pre-insolvency filings, as well as litigation risk;
 
•
the termination of certain O&M agreements with Abengoa and performing the O&M services directly and the successful integration of the O&M employees where the services thereunder have been recently replaced and internalized;
 
•
our plans relating to our financings, including refinancing plans;
 
•
our plans relating to our “at-the-market program” and the use of proceeds from the offering thereunder;
 
•
risks related to the Russian military actions across Ukraine; and
 
•
other factors discussed in “Part I, Item 3.D.—Risk Factors” in our Annual Report.
 
Any forward-looking statement speaks only as of the date on which such statement is made, and we undertake no obligation to update any forward-looking statement to reflect events or circumstances, including, but not limited to, unanticipated events, after the date on which such statement is made, unless otherwise required by law. New factors emerge from time to time, and it is not possible for management to predict all of these factors, nor can it assess the impact of each of these factors on the business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained or implied in any forward-looking statement.

8
Consolidated condensed statements of financial position as of June 30, 2022 and December 31, 2021

Amounts in thousands of U.S. dollars

         
As of
June 30,
    
As of
December 31,
  
   
Note (1)
    
2022
    
2021
  
Assets
                  
Non-current assets
                  
Contracted concessional assets
    
6
      
7,644,952
      
8,021,568
  
Investments carried under the equity method
    
7
      
275,572
      
294,581
  
Financial investments
    
8
      
135,713
      
96,608
  
Deferred tax assets
            
135,921
      
172,268
  
                         
Total non-current assets
            
8,192,158
      
8,585,025
  
                         
Current assets
                        
Inventories
            
33,011
      
29,694
  
Trade and other receivables
    
12
      
288,844
      
307,143
  
Financial investments
    
8
      
188,804
      
207,379
  
Cash and cash equivalents
    

     
668,247
      
622,689
  
                         
Total current assets
            
1,178,906
      
1,166,905
  
                         
Total assets
            
9,371,064
      
9,751,930
  

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

9
Consolidated condensed statements of financial position as of June 30, 2022 and December 31, 2021

Amounts in thousands of U.S. dollars

         
As of
June 30,
    
As of
December 31,
  
   
Note (1)
    
2022
    
2021
  
Equity and liabilities
                  
Equity attributable to the Company
                  
Share capital
    
13
      
11,524
      
11,240
  
Share premium
    
13
      
959,252
      
872,011
  
Capital reserves
    
13
      
918,736
      
1,020,027
  
Other reserves
    
9
      
274,643
      
171,272
  
Accumulated currency translation differences
    
13
      
(169,462
)
    
(133,450
)
Accumulated deficit
    
13
      
(390,317
)
    
(398,701
)
Non-controlling interests
    
13
      
192,455
      
206,206
  
                         
Total equity
            
1,796,831
      
1,748,605
  
                         
Non-current liabilities
                        
Long-term corporate debt
    
14
      
971,586
      
995,190
  
Long-term project debt
    
15
      
4,390,459
      
4,387,674
  
Grants and other liabilities
    
16
      
1,252,349
      
1,263,744
  
Derivative liabilities
    
9
      
93,506
      
223,453
  
Deferred tax liabilities
            
296,637
      
308,859
  
                         
Total non-current liabilities
            
7,004,537
      
7,178,920
  
                         
Current liabilities
                        
Short-term corporate debt
    
14
      
28,505
      
27,881
  
Short-term project debt
    
15
      
345,041
      
648,519
  
Trade payables and other current liabilities
    
17
      
154,671
      
113,907
  
Income and other tax payables
            
41,479
      
34,098
  
                         
Total current liabilities
            
569,696
      
824,405
  
                         
Total equity and liabilities
            
9,371,064
      
9,751,930
  

(1)
Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.
 
10
Consolidated condensed income statements for the six-month periods ended June 30, 2022 and 2021

Amounts in thousands of U.S. dollars

   
Note (1)
    
For the six-month period ended June 30,
  
         
2022
     2021  
Revenue
    
4
      
555,284
      
611,175
  
Other operating income
    
20
      
36,036
      
40,270
  
Employee benefit expenses
            
(40,111
)
    
(39,012
)
Depreciation, amortization, and impairment charges
    
4
      
(217,809
)
    
(188,876
)
Other operating expenses
    
20
      
(179,096
)
    
(215,792
)
                         
Operating profit
            
154,304
      
207,765
  
                         
Financial income
    
19
      
1,620
      
1,232
  
Financial expense
    
19
      
(164,353
)
    
(189,524
)
Net exchange differences
    
19
      
7,337
      
2,184
  
Other financial income, net
    
19
      
(383
)
    
13,301
  
                         
Financial expense, net
            
(155,779
)
    
(172,807
)
                         
Share of profit of associates carried under the equity method
            
18,323
      
2,656
  
                         
Profit before income tax
            
16,848
      
37,614
  
                         
Income tax
    
18
      
(6,050
)
    
(33,128
)
                         
Profit for the period
            
10,798
      
4,486
  
                         
Profit attributable to non-controlling interests
            
(6,728
)
    
(11,315
)
                         
Profit/(loss) for the period attributable to the Company
            
4,070
      
(6,829
)
                         
Weighted average number of ordinary shares outstanding (thousands) - basic
    
21
      
113,541
      
110,594
  
Weighted average number of ordinary shares outstanding (thousands) - diluted
    
21
      
117,665
      
113,941
  
Basic earnings per share (U.S. dollar per share)
    
21
      
0.04
      
(0.06
)
Diluted earnings per share (U.S. dollar per share)
    
21
      
0.03
      
(0.06
)

(1)
Notes 1 to 22 form an integral part of the Consolidated Condensed Interim Financial Statements.
 
11
Consolidated condensed statements of comprehensive income for the six-month periods ended June 30, 2022 and 2021

Amounts in thousands of U.S. dollars

For the six-month period ended June 30,
  
   
Note (1)
    
2022
    
2021
  
Profit for the period
          
10,798
      
4,486
  
Items that may be subject to transfer to income statement
                      
Change in fair value of cash flow hedges
          
132,433
      
20,043
  
Currency translation differences
          
(46,507
)
    
(14,739
)
Tax effect
          
(34,055
)
    
(5,967
)
                       
Net income/(expense) recognized directly in equity
          
51,871
      
(663
)
                       
Cash flow hedges
    
9
      
23,395
      
30,443
  
Tax effect
            
(5,849
)
    
(7,611
)
                         
Transfers to income statement
            
17,546
      
22,832
  
                         
Other comprehensive income
            
69,417
      
22,169
  
                         
Total comprehensive income for the period
            
80,215
      
26,655
  
                         
Total comprehensive income attributable to non-controlling interests
            
(7,213
)
    
(11,796
)
                         
Total comprehensive income attributable to the Company
            
73,002
      
14,859
  

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

12
Consolidated condensed statements of changes in equity for the six-month periods ended June 30, 2022 and 2021

Amounts in thousands of U.S. dollars

   
Share
capital
    
Share
premium
    
Capital
reserves
    
Other
reserves
    
Accumulated
currency
translation
differences
    
Accumulated
Deficit
    
Total
equity
attributable
to the
Company
    
Non-
controlling
interests
    
Total
equity
  
Balance as of January 1, 2021
    
10,667
      
1,011,743
      
881,745
      
96,641
      
(99,925
)
    
(373,489
)
    
1,527,382
      
213,499
      
1,740,881
  
                                                                         
Profit/(loss) for the six -month period after taxes
    
-
      
-
      
-
      
-
      
-
      
(6,829
)
    
(6,829
)
    
11,315
      
4,486
  
Change in fair value of cash flow hedges
    
-
      
-
      
-
      
56,855
      
-
      
(10,060
)
    
46,795
      
3,691
      
50,486
  
Currency translation differences
    
-
      
-
      
-
      
-
      
(12,014
)
    
-
      
(12,014
)
    
(2,725
)
    
(14,739
)
Tax effect
    
-
      
-
      
-
      
(13,093
)
    
-
      
-
      
(13,093
)
    
(485
)
    
(13,578
)
Other comprehensive income
    
-
      
-
      
-
      
43,762
      
(12,014
)
    
(10,060
)
    
21,688
      
481
      
22,169
  
                                                                         
Total comprehensive income
    
-
      
-
      
-
      
43,762
      
(12,014
)
    
(16,889
)
    
14,859
      
11,796
      
26,655
  
                                                                         
Capital increase (Note 13)
     416       -       130,388       -       -       -       130,804       -       130,804  
                                                                         
Business combinations (Note 5)     -       -       -       -       -       -       -       8,287       8,287  
                                                                         
Share-based compensation (Note 13)
     -       -       -       -       -       10,992       10,992       -       10,992  
                                                                         
Distributions (Note 13)
    
-
      
-
      
(94,161
)
    
-
      
-
      
-
      
(94,161
)
    
(16,249
)
    
(110,410
)
                                                                         
Balance as of June 30, 2021
    
11,083
      
1,011,743
      
917,972
      
140,403
      
(111,939
)
    
(379,386
)
    
1,589,876
      
217,333
      
1,807,209
  

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

13
   
Share
capital
    
Share
premium
    
Capital
reserves
    
Other
reserves
    
Accumulated
currency
translation
differences
    
Accumulated
Deficit
    
Total
equity
attributable
to the
Company
    
Non-
controlling
interests
    
Total
equity
  
Balance as of January 1, 2022
    
11,240
      
872,011
      
1,020,027
      
171,272
      
(133,450
)
    
(398,701
)
    
1,542,399
      
206,206
      
1,748,605
  
                                                                         
Profit/(loss) for the six -month period after taxes
    
-
      
-
      
-
      
-
      
-
      
4,070
      
4,070
      
6,728
      
10,798
  
Change in fair value of cash flow hedges
    
-
      
-
      
-
      
142,024
      
-
      
1,573
      
143,597
      
12,231
      
155,828
  
Currency translation differences
    
-
      
-
      
-
      
-
      
(36,012
)
    
-
      
(36,012
)
    
(10,495
)
    
(46,507
)
Tax effect
    
-
      
-
      
-
      
(38,653
)
    
-
      
-
      
(38,653
)
    
(1,251
)
    
(39,904
)
Other comprehensive income
    
-
      
-
      
-
      
103,371
      
(36,012
)
    
1,573
      
68,932
      
485
      
69,417
  
                                                                         
Total comprehensive income
    
-
      
-
      
-
      
103,371
      
(36,012
)
    
5,643
      
73,002
      
7,213
      
80,215
  
                                                                         
Capital increase (Note 13)
    
284
      
87,241
      
(1,347
)
    
-
      
-
      
-
      
86,178
      
-
      
86,178
  
                                                                         
Share-based compensation (Note 13)
    
-
      
-
      
-
      
-
      
-
      
2,741
      
2,741
      
-
      
2,741
  
                                                                         
Distributions (Note 13)
    
-
      
-
      
(99,944
)
    
-
      
-
      
-
      
(99,944
)
    
(20,964
)
    
(120,908
)
                                                                         
Balance as of June 30, 2022
    
11,524
      
959,252
      
918,736
      
274,643
      
(169,462
)
    
(390,317
)
    
1,604,376
      
192,455
      
1,796,831
  

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

14
Consolidated condensed cash flows statements for the six-month periods ended June 30, 2022 and 2021

Amounts in thousands of U.S. dollars

   
Note (1)
    
For the six-month periods ended
June 30,
  
         
2022
    
2021
  
I. Profit for the period
          
10,798
      
4,486
  
Financial expense and non-monetary adjustments
          
384,905
      
396,130
  
                       
II. Profit for the period adjusted by non-monetary items
          
395,703
      
400,616
  
                       
III. Changes in working capital
          
(2,316
)
    
9,430
  
                       
Net interest and income tax paid
          
(129,251
)
    
(163,729
)
                       
A. Net cash provided by operating activities
          
264,136
      
246,317
  
                       
Acquisitions of subsidiaries and entities under the equity method
    
5&7
      
(41,972
)
    
(323,103
)
Investments in operating concessional assets
    
6
      
(10,288
)
    
(16,593
)
Investments in assets under development or construction
     6
       (22,076 )     (1,562 )
Distributions from entities under the equity method
    
7
      
43,791
      
13,230
  
Other non-current assets/liabilities
            
(186
)
    
1,007
  
                         
B. Net cash used in investing activities
            
(30,731
)
    
(327,021
)
                         
Proceeds from Project debt
    
15
      
-
      
9,976
  
Proceeds from Corporate debt
    
14
      
57,503
      
394,023
  
Repayment of Project debt
    
15
      
(156,309
)
    
(164,409
)
Repayment of Corporate debt     14
       (38,784 )     (361,140 )
Dividends paid to Company´s shareholders
    
13
      
(99,944
)
    
(94,161
)
Dividends paid to non-controlling interests
    
13
      
(16,021
)
    
(11,610
)
Capital increase
    
13
      
86,156
      
130,618
  
                         
C. Net cash used in financing activities
            
(167,399
)
    
(96,703
)
                         
Net increase/(decrease)  in cash and cash equivalents
            
66,006
      
(177,407
)
                         
Cash and cash equivalents at beginning of the period
            
622,689
      
868,501
  
                         
Translation differences in cash or cash equivalent
            
(20,448
)
    
(4,805
)
                         
Cash and cash equivalents at end of the period
            
668,247
      
686,289
  

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

15
Notes to the consolidated condensed interim financial statements
Note 1.- Nature of the business
17
 
 
Note 2.- Basis of preparation
 20
 
  
Note 3.- Financial risk management
23
 
 
Note 4.- Financial information by segment
23
 
 
Note 5.- Business combinations
30
 
 
Note 6.- Contracted concessional assets
31
 
 
Note 7.- Investments carried under the equity method
31
 
 
Note 8.- Financial investments
32
 
 
Note 9.- Derivative financial instruments
32
 
 
Note 10.- Fair value of financial instruments
33
 
 
Note 11.- Related parties
33
 
 
Note 12.- Trade and other receivables
34
 
 
Note 13.- Equity
35
 
 
Note 14.- Corporate debt
36
 
 
Note 15.- Project debt
38
 
 
Note 16.- Grants and other liabilities
40
 
 
Note 17.-Trade payables and other current liabilities
40
 
 
Note 18.- Income tax
41
 
 
Note 19.- Financial expense, net
41
 
 
Note 20.- Other operating income and expenses
42
 
 
Note 21.- Earnings per share
43
 
 
Note 22.- Subsequent events
43

16
Note 1. - Nature of the business
Atlantica Sustainable Infrastructure plc (“Atlantica” or the “Company”) is a sustainable infrastructure company with a majority of its business in renewable energy assets. Atlantica currently owns, manages and invests in renewable energy, storage, efficient natural gas and heat, electric transmission lines and water assets focused on North America (the United States, Canada and Mexico), South America (Peru, Chile, Colombia and Uruguay) and EMEA (Spain, Italy, Algeria and South Africa).
Atlantica’s shares trade on the NASDAQ Global Select Market under the symbol “AY”.

On January 17, 2022, the Company closed the acquisition of Chile TL4, a 63-mile transmission line and 2 substations in Chile for a total equity investment of $39 million (Note 5). The Company expects to make an expansion of the line no later than in 2023, which would represent an additional investment of approximately $8 million. The asset has fully contracted revenues in US dollars, with inflation escalation and 50-year contract life. The off-takers are several mini-hydro plants that receive contracted or regulated payments.

On April 4, 2022, the Company closed the acquisition of Italy PV 4, a 3.6 MW solar portfolio in Italy for a total equity investment of $3.7 million. The asset has regulated revenues under a feed in tariff until 2031.
During the year 2021, the Company completed the following acquisitions:
-
In 2021, the Company closed the acquisition in two stages of the 85% equity interest in Rioglass Solar Holding S.A. (“Rioglass”) that it did not previously own for a total investment of $17.1 million, resulting in a 100% ownership (Note 5). Rioglass is a supplier of spare parts and services in the solar industry and the Company gained control over the asset in January 2021.


-
On April 7, 2021, the Company closed the acquisition of Coso, a 135 MW geothermal plant in the United States with 18-year average contract life PPAs in place. The total equity investment was $130 million (Note 5). In addition, on July 15, 2021, the Company repaid $40 million to reduce project debt.


-
On May 14, 2021, the Company closed the acquisition of Calgary District Heating, a district heating asset in Canada for a total equity investment of $22.9 million (Note 5). The asset has availability-based revenue with inflation indexation and 20 years of weighted average contract life at the time of the acquisition.


-
On June 16, 2021, the Company acquired a 49% interest in Vento II, a 596 MW wind portfolio in the United States, for a total equity investment net of cash consolidated at the transaction date of approximately $180.7 million (Note 7). EDP Renewables owns the remaining 51%. The assets have PPAs with investment grade off-takers with a five-year average remaining contract life at the time of the investment.


-
On August 6, 2021, the Company closed the acquisition of Italy PV 1 and Italy PV 2, two solar PV plants in Italy with a combined capacity of 3.7 MW for a total equity investment of $9 million (Note 5). On December 14, 2021, the Company closed the acquisition of Italy PV 3, a 2.5 MW solar PV portfolio in Italy for a total equity investment of $4 million (Note 5). These assets have regulated revenues under a feed in tariff until 2030, 2031 and 2032, respectively.


-
On November 25, 2021, the Company closed the acquisition of La Sierpe, a 20 MW solar PV plant in Colombia for a total equity investment of $23.5 million (Note 5). The asset was acquired under a Right of First Offer (“ROFO”) agreement with Liberty GES.

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


-
La Tolua and Tierra Linda, two solar PV assets in Colombia with a combined capacity of 30 MW. Each plant has a 15-year PPA in local currency indexed to local inflation with Synermin, the largest independent electricity wholesaler in Colombia.

17
The following table provides an overview of the main contracted concessional assets the Company owned or had an interest in as of June 30, 2022:

Assets
Type
Ownership
Location
Currency(9)
Capacity
(Gross)
Counterparty
Credit Ratings(10)
COD*
Contract
Years
Remaining(16)
                 
Solana
Renewable (Solar)
100%
Arizona (USA)
USD
280 MW
BBB+/A3/BBB+
2013
22
Mojave
Renewable (Solar)
100%
California (USA)
USD
280 MW
BB-/ -- /BB
2014
18
Coso
 Renewable (Geothermal) 100% California (USA) USD 135 MW Investment Grade(11) 1987-1989 17
Elkhorn Valley
 Renewable (Wind) 49% Oregon (USA) USD 101 MW BBB/Baa1/-- 2007 6
Prairie Star
 Renewable (Wind) 49% Minnesota (USA) USD 101 MW --/A3/A- 2007 6
Twin Groves II
 Renewable (Wind) 49% Illinois (USA) USD 198 MW BBB-/Baa2/-- 2008 4
Lone Star II
 Renewable (Wind) 49% Texas (USA) USD 196 MW Not rated 2008 1
Chile PV 1
Renewable (Solar)
35%(1)
Chile
USD
55 MW
N/A
2016
N/A
Chile PV 2
Renewable (Solar)
35%(1)
Chile
USD
40 MW
Not rated
2017
9
La Sierpe
 Renewable (Solar) 100% Colombia COP 20 MW Not rated 2021 14
Palmatir
 Renewable (Wind) 100% Uruguay USD 50 MW BBB/Baa2/BBB-(12) 2014 12
Cadonal
 Renewable (Wind) 100% Uruguay USD 50 MW BBB/Baa2/BBB-(12) 2014 13
Melowind
 Renewable (Wind) 100% Uruguay USD 50 MW BBB/Baa2/BBB- 2015 14
Mini-Hydro
 Renewable (Hydraulic) 100% Peru USD 4 MW BBB/Baa1/BBB 2012 11
Solaben 2 & 3
Renewable (Solar)
70%(2)
Spain
Euro
2x50 MW
A/Baa1/A-
2012
16/16
Solacor 1 & 2
Renewable (Solar)
87%(3)
Spain
Euro
2x50 MW
A/Baa1/A-
2012
15/15
PS10 & PS20
Renewable (Solar)
100%
Spain
Euro
31 MW
A/Baa1/A-
2007&2009
10/12
Helioenergy 1 & 2
Renewable (Solar)
100%
Spain
Euro
2x50 MW
A/Baa1/A-
2011
15/15
Helios 1 & 2
Renewable (Solar)
100%
Spain
Euro
2x50 MW
A/Baa1/A-
2012
15/16
Solnova 1, 3 & 4
Renewable (Solar)
100%
Spain
Euro
3x50 MW
A/Baa1/A-
2010
13/13/14
Solaben 1 & 6
Renewable (Solar)
100%
Spain
Euro
2x50 MW
A/Baa1/A-
2013
17/17
Seville PV
Renewable (Solar)
80%(4)
Spain
Euro
1 MW
A/Baa1/A-
2006
14
Italy PV 1
 Renewable (Solar) 100% Italy Euro 1.6 MW BBB/Baa3/BBB 2010 9
Italy PV 2
 Renewable (Solar) 100% Italy Euro 2.1 MW BBB/Baa3/BBB 2011 9
Italy PV 3
 Renewable (Solar) 100% Italy Euro 2.5 MW BBB/Baa3/BBB 2012 10
Italy PV 4
 Renewable (Solar) 100% Italy Euro 3.6 MW BBB/Baa3/BBB 2011 9
Kaxu
Renewable (Solar)
51%(5)
South Africa
Rand
100 MW
BB-/Ba2/BB-(13)
2015
13
Calgary
Efficient natural gas &heat
100%
Canada
CAD
55 MWt
~41% A+ or higher(14)
2010
19
ACT
Efficient natural gas & heat
100%
Mexico
USD
300 MW
BBB/ Ba3/BB-
2013
11
Monterrey Efficient natural gas &heat 30% Mexico USD 142 MW Not rated
 2018 24
ATN (15)
Transmission line
100%
Peru
USD
379 miles
BBB/Baa1/BBB
2011
19
ATS
Transmission line
100%
Peru
USD
569 miles
BBB/Baa1/BBB
2014
22
ATN 2
Transmission line
100%
Peru
USD
81 miles
Not rated
2015
11
Quadra 1 & 2
Transmission line
100%
Chile
USD
49 miles/32 miles
Not rated
2014
13/13
Palmucho
Transmission line
100%
Chile
USD
6 miles
BBB/ -- /A-
2007
16
Chile TL3
Transmission line
100%
Chile
USD
50 miles
A/A1/A-
1993
Regulated
Chile TL4 Transmission line
 100%
  Chile
  USD
  63 miles
  Not rated
  2016
  50
Skikda
Water
34.2%(6)
Algeria
USD
3.5 M ft3/day
Not rated
2009
12
Honaine
Water
25.5%(7)
Algeria
USD
7 M ft3/day
Not rated
2012
16
Tenes
Water
51%(8)
Algeria
USD
7 M ft3/day
Not rated
2015
18

18
(1)
65% of the shares in Chile PV 1 and Chile PV 2 are indirectly held by financial partners through the renewable energy platform of the Company in Chile.
(2)
Itochu Corporation holds 30% of the shares in each of Solaben 2 and Solaben 3.
(3)
JGC holds 13% of the shares in each of Solacor 1 and Solacor 2.
(4)
Instituto para la Diversificación y Ahorro de la Energía (“Idae”) holds 20% of the shares in Seville PV.
(5)
Kaxu is owned by the Company (51%), Industrial Development Corporation of South Africa (29%) and Kaxu Community Trust (20%).
(6)
Algerian Energy Company, SPA owns 49% of Skikda and Sacyr Agua, S.L. owns the remaining 16.8%.
(7)
Algerian Energy Company, SPA owns 49% of Honaine and Sacyr Agua, S.L. owns the remaining 25.5%.
(8)
Algerian Energy Company, SPA owns 49% of Tenes.
(9)
Certain contracts denominated in U.S. dollars are payable in local currency.
(10)
Reflects the counterparty’s credit ratings issued by Standard & Poor’s Ratings Services, or S&P, Moody’s Investors Service Inc., or Moody’s, and Fitch Ratings Ltd, or Fitch.
(11)
Refers to the credit rating of two Community Choice Aggregators: Silicon Valley Clean Energy and Monterrey Bar Community Power, both with A Rating from S&P and Southern California Public Power Authority. The third off-taker is not rated.
(12)
Refers to the credit rating of Uruguay, as UTE (Administración Nacional de Usinas y Transmisoras Eléctricas) is unrated.
(13)
Refers to the credit rating of the Republic of South Africa. The off-taker is Eskom, which is a state-owned utility company in South Africa.
(14)
Refers to the credit rating of a diversified mix of 22 high credit quality clients (~41% A+ rating or higher, the rest is unrated).
(15)
Including ATN Expansion 1 & 2.
(16)
As of December 31, 2021. Monterrey includes a 7.5-year PPA extension signed in May 2022.
(*)
Commercial Operation Date.

The project financing arrangement for Kaxu contained a cross-default provision related to Abengoa S.A.’s insolvency filing. In September 2021, the Company obtained a waiver for such cross-default which became effective on March 31, 2022, following the transfer of the employees performing the O&M in Kaxu from an Abengoa subsidiary to an Atlantica subsidiary and other conditions. As a result, as of March 31, 2022, the Company had again an unconditional right to defer the settlement of the debt for at least twelve months, and therefore the debt previously presented as current (as of December 31, 2021) had been reclassified as non-current at that date in accordance with the financing agreements in these Consolidated Condensed Interim Financial Statements (Note 15).

As expected, the Administration in Spain has recently approved measures to adjust the regulated revenue component for renewable energy plants, following the increase since mid-2021 in the billings of these plants for the sale of electricity in the market. On March 30, 2022, the Royal Decree Law 6/2022 was published, adopting urgent measures in response to the economic and social consequences of the war in Ukraine. This Royal Decree Law contains a bundle of measures in diverse fields, including those targeted at containing the sharp rise in the prices of gas and electricity. It includes temporary changes to the detailed regulated components of revenue received by the solar assets of the Company in Spain, which are applicable from January 1, 2022.

The proposed parameters for the year 2022 were published on May 12, 2022, and, although they are still subject to comments, the Company does not expect any significant changes. As a result, the Company has recorded its revenue for the first half of 2022 following these new parameters. In addition, on May 14, 2022, the Royal Decree Law 10/2022 was published, including additional details on the changes to the regulated components of revenue.

The changes to the detailed regulated components of revenue received by the solar assets of the Company in Spain are as follows:
 
-
The statutory half-period of three years from 2020 to 2022 has been split into two statutory half-periods (1) from January 1, 2020 until December 31, 2021 and (2) calendar year 2022. As a result, the fixed monthly payment based on installed capacity (Remuneration on Investment or Rinv) for calendar year 2022 is being revised.
 
-
The market price assumed by the regulation for calendar year 2022 was changed from €48.82 per MWh to an expected price of €121.9 per MWh. As a result,  the variable payment based on net electricity produced (Remuneration on operation or Ro) is also being adjusted. The proposed Ro for the year 2022 is zero €/MWh reflecting the fact that market prices for the power sold in the market are significantly higher.
 
-
For the three-year half period starting on January 1, 2023, and ending on December 31, 2025, the adjustment for electricity price deviations in the preceding statutory half period will be progressively modified to take into account a mix of actual market prices and future market prices.
 
19
Note 2. - Basis of preparation
The accompanying Consolidated Condensed Interim Financial Statements represent the consolidated results of the Company and its subsidiaries.
The Company’s annual consolidated financial statements as of December 31, 2021, were approved by the Board of Directors on February 25, 2022.
These Consolidated Condensed Interim Financial Statements are presented in accordance with International Accounting Standards (“IAS”) 34, “Interim Financial Reporting”. In accordance with IAS 34, interim financial information is prepared solely in order to update the most recent annual consolidated financial statements prepared by the Company, placing emphasis on new activities, occurrences and circumstances that have taken place during the six-month period ended June 30, 2022, and not duplicating the information previously published in the annual consolidated financial statements for the year ended December 31, 2021. Therefore, the Consolidated Condensed Interim Financial Statements do not include all the information that would be required in a complete set of consolidated financial statements prepared in accordance with the IFRS-IASB (“International Financial Reporting Standards-International Accounting Standards Board”). In view of the above, for an adequate understanding of the information, these Consolidated Condensed Interim Financial Statements must be read together with Atlantica’s consolidated financial statements for the year ended December 31, 2021 included in the 2021 20-F.

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

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

These Consolidated Condensed Interim Financial Statements were approved by the Board of Directors of the Company on August 2, 2022.
Application of new accounting standards
a)
Standards, interpretations and amendments effective from January 1, 2022 under IFRS-IASB, applied by the Company in the preparation of these Consolidated Condensed Interim Financial Statements:
 
The applications of these amendments have not had any impact on these Consolidated Condensed Interim Financial Statements.
b)
Standards, interpretations and amendments published by the IASB that will be effective for periods beginning on or after January 1, 2023:

The Company does not anticipate any significant impact on the Consolidated Condensed Interim Financial Statements derived from the application of the new standards and amendments that will be effective for annual periods beginning on or after January 1, 2023, although it is currently still in the process of evaluating such application.

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

20
Use of estimates
Some of the accounting policies applied require the application of significant judgment by management to select the appropriate assumptions to determine these estimates. These assumptions and estimates are based on the Company´s historical experience, advice from experienced consultants, forecasts and other circumstances and expectations as of the close of the financial period. The assessment is considered in relation to the global economic situation of the industries and regions where the Company operates, taking into account future development of its businesses. By their nature, these judgments are subject to an inherent degree of uncertainty; therefore, actual results could materially differ from the estimates and assumptions used. In such cases, the carrying values of assets and liabilities are adjusted.
The most critical accounting policies, which require significant management estimates and judgment are as follows:
  ●
Assessment of contracted concessional agreements.

  ●
Impairment of contracted concessional assets.

  ●
Assessment of control.

  ●
Derivative financial instruments and fair value estimates.

  ●
Income taxes and recoverable amount of deferred tax assets.

As of the date of preparation of these Consolidated Condensed Interim Financial Statements, no relevant changes in estimates made are anticipated and, therefore, no significant changes in the value of assets and liabilities recognized at June 30, 2022, are expected.
Although these estimates and assumptions are being made using all available facts and circumstances, it is possible that future events may require management to amend such estimates and assumptions in future periods. Changes in accounting estimates are recognized prospectively, in accordance with IAS 8, in the consolidated income statement of the period in which the change occurs.

Note 3. - Financial risk management
Atlantica’s activities are exposed to various financial risks: market risk (including currency risk and interest rate risk), credit risk and liquidity risk. Risk is managed by the Company’s Risk, Finance and Compliance Departments, which are responsible for identifying and evaluating financial risks, quantifying them by project, region and company, in accordance with mandatory internal management rules. Written internal policies exist for global risk management, as well as for specific areas of risk. In addition, there are official written management regulations regarding key controls and control procedures for each company and the implementation of these controls is monitored through internal audit procedures.
These Consolidated Condensed Interim Financial Statements do not include all financial risk management information and disclosures required for annual financial statements and should be read together with the information included in Note 3 to Atlantica’s annual consolidated financial statements as of December 31, 2021 included in the 2021 20-F.

Note 4. - Financial information by segment
Atlantica’s segment structure reflects how management currently makes financial decisions and allocates resources. Its operating and reportable segments are based on the following geographies where the contracted concessional assets are located: North America, South America and EMEA. In addition, based on the type of business, as of June 30, 2022, the Company had the following business sectors: Renewable energy, Efficient natural gas and heat, Transmission lines and Water.
Atlantica’s Chief Operating Decision Maker (CODM), which is the CEO, assesses the performance and assignment of resources according to the identified operating segments. The CODM considers the revenue as a measure of the business activity and the Adjusted EBITDA as a measure of the performance of each segment. Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interests, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the these Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of Atlantica’s equity ownership). Until September 30, 2021, adjusted EBITDA 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 Atlantica’s equity ownership). Prior periods have been presented accordingly.

21
In order to assess performance of the business, the CODM receives reports of each reportable segment using revenue and Adjusted EBITDA. Net interest expense evolution is assessed on a consolidated basis. Financial expense and amortization are not taken into consideration by the CODM for the allocation of resources.

In the six-month periods ended June 30, 2022 and 2021, Atlantica had two customers with revenues representing more than 10% of total revenue, both in the renewable energy business sector.

a)
The following tables show Revenue and Adjusted EBITDA by operating segments and business sectors for the six-month periods ended June 30, 2022 and 2021:

   
Revenue
    
Adjusted EBITDA
  
   
For the six-month period ended
June 30,
    
For the six-month period ended
June 30,
  
   
($ in thousands)
  
Geography
  
2022
    
2021
    
2022
    
2021
  
North America
    
199,271
      
178,801
      
161,180
      
134,861
  
South America
    
78,331
      
78,351
      
58,843
      
60,222
  
EMEA
    
277,682
      
354,023
      
182,282
      
209,151
  
Total
    
555,284
      
611,175
      
402,305
      
404,234
  

   
Revenue
    
Adjusted EBITDA
  
   
For the six-month period ended
June 30,
    
For the six-month period ended
June 30,
  
   
($ in thousands)
  
Business sector
  
2022
    
2021
    
2022
    
2021
  
Renewable energy
    
420,335
      
471,624
      
296,830
      
295,030
  
Efficient natural gas & heat
    
53,419
      
58,505
      
44,014
      
47,221
  
Transmission lines
    
54,853
      
53,589
      
43,178
      
42,521
  
Water
    
26,677
      
27,457
      
18,283
      
19,462
  
Total
    
555,284
      
611,175
      
402,305
      
404,234
  

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

   
For the six-month period ended
June 30,
($ in thousands)
  
   
2022
    
2021
  
Profit/(loss) attributable to the Company
    
4,070
   
(6,829
)
Profit attributable to non-controlling interests
    
6,728
      
11,315
  
Income tax
    
6,050
   
33,128
  
Financial expense, net
    
155,779
      
172,807
  
Depreciation, amortization, and impairment charges
    
217,809
      
188,876
  
Depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of Atlantica’s equity ownership)
     11,869       4,937  
Total segment Adjusted EBITDA
    
402,305
      
404,234
  

22
b)
The assets and liabilities by operating segments (and business sector) as of June 30, 2022 and December 31, 2021 are as follows:

Assets and liabilities by geography as of June 30, 2022:

   
North
America
    
South
America
    
EMEA
    
Balance as of
June 30,
2022
  
   
($ in thousands)
  
Assets allocated
                        
Contracted concessional assets
    
3,287,156
      
1,258,308
      
3,099,488
      
7,644,952
  
Investments carried under the equity method
    
233,452
      
-
      
42,120
      
275,572
  
Current financial investments
    
119,396
      
28,682
      
40,726
      
188,804
  
Cash and cash equivalents (project companies)
    
182,998
      
86,282
      
274,169
      
543,449
  
Subtotal allocated
    
3,823,002
      
1,373,272
      
3,456,503
      
8,652,777
  
Unallocated assets
                                
Other non-current assets
                            
271,634
  
Other current assets (including cash and cash equivalents at holding company level)
                            
446,653
  
Subtotal unallocated
                            
718,287
  
Total assets
                            
9,371,064
  

   
North
America
    
South
America
    
EMEA
    
Balance as of
June 30,
2022
  
   
($ in thousands)
  
Liabilities allocated
                        
Long-term and short-term project debt
    
1,767,480
      
856,228
      
2,111,792
      
4,735,500
  
Grants and other liabilities
    
1,032,994
      
16,077
      
203,278
      
1,252,349
  
Subtotal allocated
    
2,800,474
      
872,305
      
2,315,070
      
5,987,849
  
Unallocated liabilities
                            
 
Long-term and short-term corporate debt
                            
1,000,091
  
Other non-current liabilities
                            
390,143
  
Other current liabilities
                            
196,150
  
Subtotal unallocated
                            
1,586,384
  
Total liabilities
                            
7,574,233
  
Equity unallocated
                            
1,796,831
  
Total liabilities and equity unallocated
                            
3,383,215
  
Total liabilities and equity
                            
9,371,064
  

23
Assets and liabilities by geography as of December 31, 2021:

   
North
America
    
South
America
    
EMEA
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
Assets allocated
                        
Contracted concessional assets
    
3,355,669
      
1,231,276
      
3,434,623
      
8,021,568
  
Investments carried under the equity method
    
253,221
      
-
      
41,360
      
294,581
  
Current financial investments
    
135,224
      
28,155
      
44,000
      
207,379
  
Cash and cash equivalents (project companies)
    
171,744
      
74,149
      
287,655
      
533,548
  
Subtotal allocated
    
3,915,858
      
1,333,580
      
3,807,638
      
9,057,076
  
Unallocated assets
                                
Other non-current assets
                            
268,876
  
Other current assets (including cash and cash equivalents at holding company level)
                            
425,978
  
Subtotal unallocated
                            
694,854
  
Total assets
                            
9,751,930
  

   
North
America
    
South
America
    
EMEA
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
Liabilities allocated
                        
Long-term and short-term project debt
    
1,792,739
      
887,497
      
2,355,957
      
5,036,193
  
Grants and other liabilities
    
1,051,679
      
14,445
      
197,620
      
1,263,744
  
Subtotal allocated
    
2,844,418
      
901,942
      
2,553,577
      
6,299,937
  
Unallocated liabilities
                            
 
Long-term and short-term corporate debt
                            
1,023,071
  
Other non-current liabilities
                            
532,312
  
Other current liabilities
                            
148,005
  
Subtotal unallocated
                            
1,703,388
  
Total liabilities
                            
8,003,325
  
Equity unallocated
                            
1,748,605
  
Total liabilities and equity unallocated
                            
3,451,993
  
Total liabilities and equity
                            
9,751,930
  

24
Assets and liabilities by business sector as of June 30, 2022:

   
Renewable
energy
    
Efficient
natural
gas & heat
    
Transmission
lines
    
Water
    
Balance as of
June 30,
2022
  
   
($ in thousands)
  
Assets allocated
                              
Contracted concessional assets
    
6,163,513
      
507,776
      
818,768
      
154,895
      
7,644,952
  
Investments carried under the equity method
    
221,332
      
14,395
      
-
      
39,845
      
275,572
  
Current financial investments
    
8,622
      
112,886
      
28,506
      
38,790
      
188,804
  
Cash and cash equivalents (project companies)
    
416,482
      
47,858
      
54,249
      
24,860
      
543,449
  
Subtotal allocated
    
6,809,949
      
682,915
      
901,523
      
258,390
      
8,652,777
  
Unallocated assets
                                        
Other non-current assets
                                    
271,634
  
Other current assets (including cash and cash equivalents at holding company level)
                                    
446,653
  
Subtotal unallocated
                                    
718,287
  
Total assets
                                    
9,371,064
  

   
Renewable
energy
    
Efficient
natural gas
& heat
    
Transmission
lines
    
Water
    
Balance as of
June 30,
2022
  
   
($ in thousands)
  
Liabilities allocated
                              
Long-term and short-term project debt
    
3,593,887
      
462,228
      
592,657
      
86,728
      
4,735,500
  
Grants and other liabilities
    
1,211,134
      
32,762
      
6,200
      
2,253
      
1,252,349
  
Subtotal allocated
    
4,805,021
      
494,990
      
598,857
      
88,981
      
5,987,849
  
Unallocated liabilities
                                    
 
Long-term and short-term corporate debt
                                    
1,000,091
  
Other non-current liabilities
                                    
390,143
  
Other current liabilities
                                    
196,150
  
Subtotal unallocated
                                    
1,586,384
  
Total liabilities
                                    
7,574,233
  
Equity unallocated
                                    
1,796,831
  
Total liabilities and equity unallocated
                                    
3,383,215
  
Total liabilities and equity
                                    
9,371,064
  

25
Assets and liabilities by business sector as of December 31, 2021:

   
Renewable
energy
    
Efficient
natural gas
& heat
    
Transmission
lines
    
Water
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
Assets allocated
                              
Contracted concessional assets
    
6,533,408
      
517,247
      
805,987
      
164,926
      
8,021,568
  
Investments carried under the equity method
    
240,302
      
15,358
      
-
      
38,921
      
294,581
  
Current financial investments
    
10,761
      
128,461
      
27,813
      
40,344
      
207,379
  
Cash and cash equivalents (project companies)
    
442,213
      
25,392
      
44,574
      
21,369
      
533,548
  
Subtotal allocated
    
7,226,684
      
686,458
      
878,374
      
265,560
      
9,057,076
  
Unallocated assets
                                      
Other non-current assets
                                    
268,876
  
Other current assets (including cash and cash equivalents at holding company level)
                                    
425,978
  
Subtotal unallocated
                                    
694,854
  
Total assets
                                    
9,751,930
  

   
Renewable
energy
    
Efficient
natural gas
& heat
    
Transmission
lines
    
Water
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
Liabilities allocated
                              
Long-term and short-term project debt
    
3,857,313
      
478,724
      
602,278
      
97,878
      
5,036,193
  
Grants and other liabilities
    
1,244,346
      
11,212
      
5,795
      
2,391
      
1,263,744
  
Subtotal allocated
    
5,101,659
      
489,936
      
608,073
      
100,269
      
6,299,937
  
Unallocated liabilities
                                      
Long-term and short-term corporate debt
                                    
1,023,071
  
Other non-current liabilities
                                    
532,312
  
Other current liabilities
                                    
148,005
  
Subtotal unallocated
                                    
1,703,388
  
Total liabilities
                                    
8,003,325
  
Equity unallocated
                                    
1,748,605
  
Total liabilities and equity unallocated
                                    
3,451,993
  
Total liabilities and equity
                                    
9,751,930
  
c)
The amount of depreciation, amortization and impairment charges recognized for the six-month periods ended June 30, 2022 and 2021 are as follows:

 
For the six-month period ended
June 30,
  
Depreciation, amortization and impairment by geography
2022
     2021
  
  ($ in thousands)  
North America
    
(79,207
)
    
(45,285
)
South America
    
(30,150
)
    
(28,190
)
EMEA
    
(108,452
)
    
(115,401
)
Total
    
(217,809
)
    
(188,876
)

   
For the six-month period ended
June 30,
  
Depreciation, amortization and impairment by business sectors
  
2022
    
2021
  
   
($ in thousands)
  
Renewable energy
    
(188,524
)
    
(193,407
)
Efficient natural gas & heat
    
(11,257
)
    
19,113
  
Transmission lines
    
(16,794
)
    
(15,565
)
Water
    
(1,234
)
    
983
  
Total
    
(217,809
)
    
(188,876
)

27
Note 5. – Business combinations


For the six-month period ended June 30, 2022



On January 17, 2022, the Company closed the acquisition of Chile TL4, a 63-mile transmission line and 2 substations in Chile for a total equity investment of $39 million. Atlantica has control over Chile TL4 under IFRS 10, Consolidated Financial Statements. The acquisition of Chile TL4 has been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Chile TL4 is included within the Transmission Lines sector and the South America geography.


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



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


   
Business
combinations
for the six-month
period ended
June 30, 2022
  
Contracted concessional assets
  

46,343
  
Cash&cash and equivalents
     1,057  
Other current assets
    
6,789
  
Non-current Project debt
     (1,629 )
Other current and non-current liabilities
     (10,593 )
Total net assets acquired at fair value
    
41,967
  
Asset acquisition – purchase price paid
    
(41,967
)
Net result of business combinations
    
-
  



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



The allocation of the purchase price is provisional as of June 30, 2022 and amounts indicated above may be adjusted during the measurement period to reflect new information obtained about facts and circumstances that existed at the acquisition date that, if known, would have affected the amounts recognized as of June 30, 2022. The measurement period will not exceed one year from the acquisition date.



The amount of revenue contributed by the acquisitions performed during the six-month period ended June 30, 2022 to the Consolidated Condensed Interim Financial Statements of the Company as of June 30, 2022 is $2.1 million, and the amount of loss after tax is $0.2 million. Had the acquisitions been consolidated from January 1, 2022, the consolidated statement of comprehensive income would have included additional revenue of $0.7 million and profit after tax of $0.2 million.

For the year ended December 31, 2021

On January 6, 2021, the Company completed its second investment through its Chilean renewable energy platform in a 40 MW solar PV plant, Chile PV 2, located in Chile, for approximately $5 million. Atlantica has control over Chile PV 2 under IFRS 10, Consolidated Financial Statements. The acquisition of Chile PV 2 had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations, showing 65% of non-controlling interests. Chile PV 2 is included within the Renewable energy sector and the South America geography.
On January 8, 2021, the Company completed the purchase of an additional 42.5% stake in Rioglass, a supplier of spare parts and services to the solar industry, increasing its stake from 15% to 57.5% and gaining control over the business under IFRS 10, Consolidated Financial Statements. The purchase price paid was $8.6 million, and the Company paid an additional $3.7 million (deductible from the final payment) for an option to acquire the remaining 42.5% under the same conditions until September 2021. On July 22, 2021, the Company exercised the option paying an additional $4.8 million, becoming the sole shareholder of the entity. Rioglass is included within the Renewable energy sector and the EMEA geography. The acquisition of Rioglass has been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations.


On April 7, 2021, the Company closed the acquisition of Coso, a 135 MW renewable asset in California. The purchase price paid was $130 million. Atlantica has control over Coso under IFRS 10, Consolidated Financial Statements and its acquisition had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Coso is included within the Renewable energy sector and the North America geography.



On May 14, 2021, the Company closed the acquisition of Calgary District Heating, a district heating asset of approximately 55 MWt in Canada. The purchase price paid was approximately $22.9 million. The acquisition had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Calgary District Heating is included within the Efficient natural gas and heat sector and the North America geography.
28

On August 6, 2021, the Company closed the acquisition of Italy PV 1 and Italy PV 2, two solar PV plants in Italy with a combined capacity of 3.7 MW for a total equity investment of $9 million. The acquisition had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. These assets are included within the Renewable energy sector and the EMEA geography.



On November 25, 2021, the Company closed the acquisition of La Sierpe, a 20 MW solar PV plant in Colombia for a total equity investment of approximately $23.5 million. The acquisition had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. La Sierpe is included within the Renewable energy sector and the South America geography.
On December 14, 2021, the Company closed the acquisition of Italy PV 3, a 2.5 MW solar asset in Italy for a total equity investment of approximately $4 million. The acquisition had been accounted for in these Consolidated Condensed Interim Financial Statements in accordance with IFRS 3, Business Combinations. Italy PV 3 is included within the Renewable Energy sector and the EMEA geography.

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

   
Business combinations
for the year ended December 31, 2021
  
    Coso     Other
    Total
 
Contracted concessional assets
     383,153
       159,575
       542,728
  
Deferred tax asset
     -
       4,410
       4,410
  
Other non-current assets     11,024
       1,943
       12,967
  
Cash & cash equivalents
     6,363
       14,649
       21,012
  
Other current assets
     14,378
       46,632
       61,010
  
Non-current Project debt
     (248,544
 )
     (39,808
 )
     (288,352
 )
Current Project debt
     (13,415
 )
     (25,366
 )
     (38,781
 )
Deferred tax liabilities
     -
       (4,910
 )
     (4,910
 )
Other current and non-current liabilities
     (22,959
 )
     (64,922
 )
     (87,881
 )
Non-controlling interests
     -
       (8,287
 )
     (8,287
 )
Total net assets acquired at fair value
     130,000
       83,916
       213,916
  
Asset acquisition – purchase price paid
     (130,000
 )
     (80,868
 )
     (210,868
 )
Fair value of previously held 15% stake in Rioglass
     -
       (3,048
 )
     (3,048
 )
Net result of business combinations
     -
       -
       -
  

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



The amount of revenue contributed by the acquisitions performed during 2021 to the Consolidated Financial Statements of the Company for the year 2021 was $163.5 million, and the amount of profit after tax was $0.8 million. Had the acquisitions been consolidated from January 1, 2021, the consolidated statement of comprehensive income would have included additional revenue of $17.7 million and additional profit after tax of $3.3 million.


The provisional period for the purchase price allocation of Coso, Calgary, Chile PV 2 and Rioglass closed during the six-month period ended June 30, 2022 and did not result in significant adjustments to the initial amounts recognized.

29
 Note 6. - Contracted concessional assets
Contracted concessional assets correspond to the assets of the Company recorded as intangible or financial assets in accordance with IFRIC 12, property plant and equipment in accordance with IAS 16, intangible assets in accordance with IAS 38 and financial asset in accordance with IFRS 16.
The detail of contracted concessional assets included in the heading ‘Contracted concessional assets’ as of June 30, 2022 and December 31, 2021 is as follows:

   
Financial
assets under
IFRIC 12
    
Financial
assets under
IFRS 16
    
Intangible
assets under
IFRIC 12
    
Intangible
assets under
IFRS 16
(Lessee)
    
Property,
plant and equipment under
IAS 16 and
other
intangible
assets under
IAS 38
    
Balance as of
June 30,
2022
  
   
($ in thousands)
  
Contracted concessional assets cost
    
841,790
      
3,023
      
8,881,929
      
89,067
      
930,800
      
10,746,609
  
Amortization and impairment
    
(75,440
)
    
-
      
(2,846,410
)
    
(15,322
)
    
(164,485
)
    
(3,101,657
)
Total
    
766,350
      
3,023
      
6,035,519
      
73,745
      
766,315
      
7,644,952
  

   
Financial
assets under
IFRIC 12
    
Financial
assets under
IFRS 16
    
Intangible
assets under
IFRIC 12
    
Intangible
assets under
IFRS 16
(Lessee)
    
Property,
plant and equipment under
IAS 16 and
other
intangible
assets under
IAS 38
    
Balance as of December
31, 2021
  
   
($ in thousands)
  
Contracted concessional assets cost
    
874,525
      
2,843
      
9,202,539
      
82,818
      
856,410
      
11,019,135
  
Amortization and impairment
    
(62,889
)
    
-
      
(2,769,345
)
    
(14,105
)
    
(151,228
)
    
(2,997,567
)
Total
    
811,636
      
2,843
      
6,433,194
      
68,713
      
705,182
      
8,021,568
  

The decrease in the contracted concessional assets cost is primarily due to the lower value of the Euro denominated assets since the exchange rate of the Euro decreased against the U.S. dollar since December 31, 2021.

No losses from impairment of contracted concessional assets, excluding the change in the provision for expected credit losses under IFRS 9, Financial instruments, were recorded during the six-month periods ended June 30, 2022 and 2021. The impairment provision based on the expected credit losses on contracted concessional financial assets increased by $13 million in the six-month period ended June 30, 2022 (decrease of $20 million in the six-month period ended June 30, 2021), primarily in ACT.

30
Note 7. - Investments carried under the equity method
The table below shows the breakdown of the investments held in associates as of June 30, 2022 and December 31, 2021:

   
Balance as of
June 30,
2022
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
2007 Vento II, LLC     190,753       195,952  
Windlectric Inc
    
28,304
      
41,911
  
Myah Bahr Honaine, S.P.A.
    
39,845
      
38,922
  
Pemcorp SAPI de CV
    
14,395
      
15,358
  
Pectonex, R.F. Proprietary Limited
    
1,450
      
1,495
  
Evacuación Valdecaballeros, S.L.
    
792
      
923
  
ABY Infraestructuras S.L.U.
    
32
      
21
  
Total
    
275,572
      
294,581
  

2007 Vento II, LLC, is the holding company of a 596 MW portfolio of wind assets (“Vento II”) in the U.S., 49% owned by Atlantica since June 16, 2021, and accounted for under the equity method in these Consolidated Condensed Interim Financial Statements (Note 1).

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

Myah Bahr Honaine, S.P.A., the project entity, is 51% owned by Geida Tlemcen, S.L., which is accounted for using the equity method in these Consolidated Condensed Interim Financial Statements. Geida Tlemcen, S.L. is 50% owned by Atlantica.
Pemcorp SAPI de CV, Monterrey´s project entity, is 100% owned by Arroyo Netherlands II B.V., which is accounted for under the equity method in these Consolidated Condensed Interim Financial Statements. Arroyo Netherlands II B.V. is 30% owned by Atlantica.

The decrease in investments carried under the equity method as of June 30, 2022, is primarily due to the distributions received by AYES Canada from Amherst Island Partnership for $12.8 million. A significant portion of the distributions received from Amherst are distributed by the Company to its partner in this project (Note 13). The decrease in the investment in Vento II is due to the distributions received from this asset by the Company for $21.7 million, partially offset by the share of profit in Vento II for the six-month period ended June 30, 2022 for $16.5 million.

31
Note 8. - Financial investments
The detail of Non-current and Current financial investments as of June 30, 2022 and December 31, 2021 is as follows:

   
Balance as of
June 30,
2022
    
Balance as of
December 31,
2021
  
   
($ in thousands)
  
Fair Value through OCI (Investment in Ten West link)
    
15,959
      
14,459
  
Derivative assets (Note 9)
    
48,374
      
10,807
  
Other receivable accounts at amortized cost
    
71,380
      
71,342
  
Total non-current financial investments
    
135,713
      
96,608
  
Contracted concessional financial assets
    
178,801
      
188,912
  
Derivative assets (Note 9)
    
3,928
      
2,153
  
Other receivable accounts at amortized cost
    
6,075
      
16,314
  
Total current financial investments
    
188,804
      
207,379
  

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

Note 9. - Derivative financial instruments
The breakdowns of the fair value amount of the derivative financial instruments as of June 30, 2022 and December 31, 2021 are as follows:

   
Balance as of June 30, 2022
    
Balance as of December 31, 2021
  
   
($ in thousands)
  
   
Assets
    
Liabilities
    
Assets
    
Liabilities
  
Interest rate cash flow hedge
    
47,006
      
80,260
      
9,550
      
206,763
  
Foreign exchange derivatives instruments
    
5,296
      
-
      
3,410
      
-
  
Notes conversion option (Note 14)
    
-
      
13,246
      
-
      
16,690
  
Total
    
52,302
      
93,506
      
12,960
      
223,453
  

The derivatives are primarily interest rate cash flow hedges. All are classified as non-current assets or non-current liabilities, as they hedge long-term financing agreements.
The net amount of the fair value of interest rate derivatives designated as cash flow hedges transferred to the consolidated condensed income statement is a loss of $23.4 million for the six-month period ended June 30, 2022 (loss of $30.4 million for the six-month period ended June 30, 2021).
The after-tax results accumulated in equity in connection with derivatives designated as cash flow hedges as of June 30, 2022 and December 31, 2021 amount to a profit of $274,643 thousand and $171,272 thousand, respectively.

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

Finally, the conversion option of the Green Exchangeable Notes issued in July 2020 (Note 14) is recorded as a derivative with a negative fair value (liability) of $13 million as of June 30, 2022 ($17 million as of December 31, 2021).

32
Note 10. - Fair value of financial instruments
Financial instruments measured at fair value are classified based on the nature of the inputs used for the calculation of fair value:
●
Level 1: Inputs are quoted prices in active markets for identical assets or liabilities.

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

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

As of June 30, 2022, all the financial instruments measured at fair value correspond to derivatives and have been classified as Level 2, except for the investments held in Ten West Link, which has been classified as Level 3.

Note 11. - Related parties
The related parties of the Company are primarily Algonquin Power & Utilities Corp. (“Algonquin”) and its subsidiaries, non-controlling interests (Note 13), entities accounted for under the equity method (Note 7), as well as the Directors and the Senior Management of the Company.
Details of balances with related parties as of June 30, 2022 and December 31, 2021 are as follows:

   
Balance as of
June 30,
    
Balance as of
December 31,
  
   
($ in thousands)
  
   
2022
    
2021
  
             
Credit receivables (current)
    
9,065
      
19,387
  
Credit receivables (non-current)
    
17,006
      
15,768
  
Total receivables from related parties
    
26,071
      
35,155
  
                 
Credit payables (current)
    
11,406
      
9,494
  
Credit payables (non-current)
    
-
      
5
  
Total payables to related parties
    
11,406
      
9,499
  
Current credit receivables as of June 30, 2022 primarily include a dividend to be collected from Amherst Island Partnership for $5.5 million ($6.3 million as of December 31, 2021). Current credit receivables as of December 31, 2021 included the short-term portion of the loan to Arroyo Netherland II B.V., the holding company of Pemcorp SAPI de CV., Monterrey´s project entity (Note 7), of which $8.2 million was collected in the first quarter of 2022.

Non-current credit receivables as of June 30, 2022 and December 31, 2021 correspond to the long-term portion of the loan to Arroyo Netherland II B.V.

Current credit payables primarily include the dividend to be paid by AYES Canada to Algonquin for $5.4 million as of June 30, 2022 ($6.1 million as of December 31, 2021).
The transactions carried out by entities included in these Consolidated Condensed Interim Financial Statements with related parties, for the six-month periods ended June 30, 2022 and 2021 have been as follows:

 
For the six-month period ended
June 30,
  
 
2022
  
2021
  
 
($ in thousands)
  
Financial income
    
682
      
1,029
  
Financial expenses
    
(126
)
    
(62
)

Note 12. - Trade and other receivables
Trade and other receivables as of June 30, 2022 and December 31, 2021, consist of the following:

   
Balance as of
June 30,
    
Balance as of
December 31,
  
   
2022
    
2021
  
   
($ in thousands)
  
Trade receivables
    
209,402
      
227,343
  
Tax receivables
    
50,092
      
59,350
  
Prepayments
    
22,932
      
9,342
  
Other accounts receivable
    
6,418
      
11,108
  
Total
    
288,844
      
307,143
  

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

As of June 30, 2022, and December 31, 2021, the fair value of trade and other receivables accounts does not differ significantly from its carrying value.

34
Note 13. - Equity
As of June 30, 2022, the share capital of the Company amounts to $11,524,167 represented by 115,241,671 ordinary shares fully subscribed and disbursed with a nominal value of $0.10 each, all in the same class and series. Each share grants one voting right.
Algonquin owns 42.5% of the shares of the Company and is its largest shareholder as of June 30, 2022. Algonquin’s voting rights and rights to appoint directors are limited to 41.5% and the difference between Algonquin´s ownership and 41.5% will vote replicating non-Algonquin’s shareholders’ vote.
On December 11, 2020 the Company closed an underwritten public offering of 5,069,200 ordinary shares, including 661,200 ordinary shares sold pursuant to the full exercise of the underwriters’ over-allotment option, at a price of $33 per new share. Gross proceeds were approximately $167 million. Given that the offering was issued through a subsidiary in Jersey, which became wholly owned by the Company at closing, and subsequently liquidated, the premium on issuance was credited to a merger reserve account (Capital reserves), net of issuance costs, for $161 million. Additionally, Algonquin committed to purchase 4,020,860 ordinary shares in a private placement in order to maintain its previous equity ownership of 44.2% in the Company. The private placement closed on January 7, 2021. Gross proceeds were approximately $133 million  ($131 million net of issuance costs).

During the first quarter of 2021, the Company changed the accounting treatment applied to its existing long-term incentive plans granted to employees from cash-settled to equity-settled in accordance with IFRS 2, Share-based Payment, as a result of incentives being settled in shares. The liability recognized for the rights vested by the employees under such plans at the date of this change, was reclassified to equity within the line “Accumulated deficit” for approximately $9 million. The settlement in shares was approved by the Board of Directors on February 26, 2021, and the Company issued 141,482 new shares to its employees up to December 31, 2021, to settle a portion of these plans. In the six-month period ended June 30, 2022, the Company issued 222,803 new shares under such incentive plans.

On August 3, 2021, the Company established an “at-the-market program” and entered into a distribution agreement with J.P. Morgan Securities LLC, as sales agent, under which the Company may offer and sell from time to time up to $150 million of its ordinary shares. The Company also entered into an agreement with Algonquin pursuant to which the Company has offered Algonquin the right but not the obligation, on a quarterly basis, to purchase a number of ordinary shares to maintain its percentage interest in Atlantica at the average price of the shares sold under the distribution agreement in the previous quarter (the “ATM Plan Letter Agreement”). On February 28, 2022, the Company established a new “at-the-market program” and entered into a distribution agreement with BofA Securities, MUFG and RBC Capital Markets, as its sales agents, under which the Company may offer and sell from time to time up to $150 million of its ordinary shares. Upon entry into the distribution agreement, the Company terminated its prior “at-the-market program” established on August 3, 2021 and the related distribution agreement dated such date, entered into with J.P. Morgan Securities LLC. During the first semester of 2022 the Company sold 2,615,895 shares (1,613,079 shares during the year 2021) at an average market price of $33.45 ($38.43 in 2021) pursuant to its distribution agreement, representing net proceeds of $86 million ($61 million in 2021). Pursuant to the ATM Plan Letter Agreement, the Company delivers a notice to Algonquin quarterly in order for them to exercise their rights thereunder.

Atlantica´s reserves as of June 30, 2022 are made up of share premium account and capital reserves.

Other reserves primarily include the change in fair value of cash flow hedges and its tax effect.
Accumulated currency translation differences primarily include the result of translating the financial statements of subsidiaries prepared in a foreign currency into the presentation currency of the Company, the U.S. dollar.
Accumulated deficit primarily includes results attributable to Atlantica.
Non-controlling interests fully relate to interests held by JGC in Solacor 1 and Solacor 2, by Idae in Seville PV, by Itochu Corporation in Solaben 2 and Solaben 3, by Algerian Energy Company, SPA and Sacyr Agua S.L. in Skikda, by Algerian Energy Company, SPA in Tenes, by Industrial Development Corporation of South Africa (IDC) and Kaxu Community Trust in Kaxu, by Algonquin Power Co. in AYES Canada, and by partners of the Company in the Chilean renewable energy platform in Chile PV 1 and Chile PV 2.
35
On February 25, 2022, the Board of Directors declared a dividend of $0.44 per share corresponding to the fourth quarter of 2021. The dividend was paid on March 25, 2022 for a total amount of $49.7 million.

On May 5, 2022, the Board of Directors declared a dividend of $0.44 per share corresponding to the first quarter of 2022. The dividend was paid on June 15, 2022 for a total amount of $50.3 million.

In addition, the Company declared dividends to non-controlling interests, primarily to Algonquin (interests in Amherst through AYES Canada, see Note 7) for $12.5 million in the six-month period ended June 30, 2022 ($8.7 million in the six-month period ended June 30, 2021)
As of June 30, 2022, there was no treasury stock and there have been no transactions with treasury stock during the period then ended.

Note 14. - Corporate debt
The breakdown of corporate debt as of June 30, 2022 and December 31, 2021 is as follows:

   
Balance as of
June 30,
    
Balance as of
December 31,
  
   
2022
    
2021
  
   
($ in thousands)
  
Non-current
    
971,586
      
995,190
  
Current
    
28,505
      
27,881
  
Total Corporate Debt
    
1,000,091
      
1,023,071
  

On July 20, 2017, the Company signed a credit facility (the “2017 Credit Facility”) for up to €10 million ($10.4 million), which is available in euros or U.S. dollars. Amounts drawn down accrue interest at a rate per year equal to EURIBOR plus 2% or LIBOR plus 2%, depending on the currency, with a floor of 0% on the LIBOR and EURIBOR. As of June 30, 2022, $9.4 million has been drawn down ($8.2 million as of December 31, 2021). As of December 31, 2021, the credit facility maturity was July 1, 2023. On July 1, 2022, the maturity has been extended to July 1, 2024.

On May 10, 2018, the Company entered into the Revolving Credit Facility for $215 million with a syndicate of banks. Amounts drawn down accrue interest at a rate per year equal to (A) for Eurodollar rate loans, Term SOFR, plus a Term SOFR Adjustment equal to 0.10% per annum, plus a percentage determined by reference to the leverage ratio of the Company, ranging between 1.60% and 2.25% and (B) for base rate loans, the highest of (i) the rate per annum equal to the weighted average of the rates on overnight U.S. Federal funds transactions with members of the U.S. Federal Reserve System arranged by U.S. Federal funds brokers on such day plus ½ of 1.00%, (ii) the U.S. prime rate and (iii) Term SOFR plus 1.00%, in any case, plus a percentage determined by reference to the leverage ratio of the Company, ranging between 0.60% and 1.00%. Letters of credit may be issued using up to $100 million of the Revolving Credit Facility. During 2019, the amount of the Revolving Credit Facility increased from $215 million to $425 million. In the first quarter of 2021, the Company increased the amount of the Revolving Credit Facility from $425 million to $450 million. On May 5, 2022, the maturity was extended to December 31, 2024. During the first semester of 2022, $10 million were drawn down. On June 30, 2022, the Company issued letters of credit for $21.5 million ($10 million as of December 31, 2021). As of June 30, 2022, therefore, $418.5 million of the Revolving Credit Facility were available ($440 million as of December 31, 2021).
36
On April 30, 2019, the Company entered into the Note Issuance Facility 2019, a senior unsecured note facility with a group of funds managed by Westbourne Capital as purchasers of the notes issued thereunder for a total amount of €268 million ($280 million), with maturity date on April 30, 2025. Interest accrued at a rate per annum equaled to the sum of 3-month EURIBOR plus 4.50%. The interest rate on the Note Issuance Facility 2019 was fully hedged by an interest rate swap resulting in the Company paying a net fixed interest rate of 4.24%. The Note Issuance Facility 2019 was fully repaid on June 4, 2021, and subsequently delisted from the Official List of The International Stock Exchange.
On October 8, 2019, the Company filed a euro commercial paper program (the “Commercial Paper”) with the Alternative Fixed Income Market (MARF) in Spain. The program had an original maturity of twelve months and has been extended twice, for annual periods. The program allows Atlantica to issue short term notes over the next twelve months for up to €50 million ($52 million), with such notes having a tenor of up to two years. As of June 30, 2022, the Company had €22.8 million ($23.8 million) issued and outstanding under the program at an average cost of 0.39% (€21.5 million, or $22.4 million, as of December 31, 2021).
On April 1, 2020, the Company closed the secured 2020 Green Private Placement for €290 million ($303 million). The private placement accrues interest at an annual 1.96% interest rate, payable quarterly and has a June 2026 maturity.
On July 8, 2020, the Company entered into the Note Issuance Facility 2020, a senior unsecured financing with a group of funds managed by Westbourne Capital as purchasers of the notes issued thereunder for a total amount of $146 million which is denominated in euros (€140 million). The Note Issuance Facility 2020 was issued on August 12, 2020, accrues annual interest of 5.25%, payable quarterly and has a maturity of seven years from the closing date.
On July 17, 2020, the Company issued the Green Exchangeable Notes for $100 million in aggregate principal amount of 4.00% convertible bonds due in 2025. On July 29, 2020, the Company closed an additional $15 million aggregate principal amount of the Green Exchangeable Notes. The notes mature on July 15, 2025 and bear interest at a rate of 4.00% per annum. The initial exchange rate of the notes is 29.1070 ordinary shares per $1,000 principal amount of notes, which is equivalent to an initial exchange price of $34.36 per ordinary share. Noteholders may exchange their notes at their option at any time prior to the close of business on the scheduled trading day immediately preceding April 15, 2025, only during certain periods and upon satisfaction of certain conditions. On or after April 15, 2025, noteholders may exchange their notes at any time. Upon exchange, the notes may be settled, at the election of the Company, into Atlantica ordinary shares, cash or a combination thereof. The exchange rate is subject to adjustment upon the occurrence of certain events.
As per IAS 32, “Financial Instruments: Presentation”, the conversion option of the Green Exchangeable Notes is an embedded derivative classified within the line “Derivative liabilities” of these Consolidated Condensed Interim Financial Statements (Note 9). It was initially valued at the transaction date for $10 million, and prospective changes to its fair value are accounted for directly through the profit and loss statement. The principal element of the Green Exchangeable Notes, classified within the line “Corporate debt” of these Consolidated Condensed Interim Financial Statements, is initially valued as the difference between the consideration received from the holders of the instrument and the value of the embedded derivative, and thereafter, at amortized cost using the effective interest method as per IFRS 9, Financial Instruments.
On December 4, 2020, the Company entered into a loan with a bank for €5 million ($5.2 million). This loan accrues interest at a rate per year equal to 2.50%. The maturity date is December 4, 2025.

37
On May 18, 2021, the Company issued the Green Senior Notes due in 2028 in an aggregate principal amount of $400 million. The notes mature on May 15, 2028 and bear interest at a rate of 4.125% per annum payable on June 15 and December 15 of each year, commencing December 15, 2021.

On January 31, 2022, the Company entered into a loan with a bank for €5 million ($5.2 million). This loan accrues interest at a rate per year equal to 1.90%. The maturity date is January 31, 2026.  

The repayment schedule for the corporate debt as of June 30, 2022 is as follows:

   
Remainder
of 2022
    
Between
January
and
June
2023
    
Between
July
and
December
2023
    
2024
    
2025
    
2026
    
Subsequent
years
    
Total
  
   
($ in thousands)
  
2017 Credit Facility
    
2
      
-
      
9,398
      
-
      
-
      
-
      
-
      
9,400
  
Revolving Credit Facility
     -       -       -       8,947       -       -       -       8,947  
Commercial Paper
    
23,791
      
-
      
-
      
-
      
-
      
-
      
-
      
23,791
  
2020 Green Private Placement    
346
      
-
      
-
      
-
      
-
      
300,463
       -      
300,809
  
Note Issuance Facility 2020
    
-
      
-
      
-
      
-
      
-
      
-
      
143,394
      
143,394
  
Green Exchangeable Notes
    
2,082
      
-
      
-
      
-
      
105,636
      
-
      
-
      
107,718
  
Green Senior Notes
    
963
      
-
      
-
      
-
      
-
      
-
      
394,608
      
395,571
  
Other bank loans
     683       637       2,383       3,045       3,044       669       -       10,461  
Total
    
27,868
      
637
      
11,781
      
11,992
      
108,680
      
301,132
      
538,002
      
1,000,091
  

The repayment schedule for the corporate debt as of December 31, 2021 was as follows:

   
2022
    
2023
    
2024
    
2025
    
2026
    
Subsequent
years
    
Total
  
2017 Credit Facility
    
5
      
8,199
      
-
      
-
      
-
      
-
      
8,204
  
Commercial Paper
    
24,422
      
-
      
-
      
-
      
-
      
-
      
24,422
  
2020 Green Private Placement
    
359
      
-
      
-
      
-
      
327,081
      
-
      
327,440
  
Note Issuance Facility 2020
    
-
      
-
      
-
      
-
      
-
      
155,814
      
155,814
  
Green Exchangeable Notes
    
2,121
      
-
      
-
      
104,289
      
-
      
-
      
106,410
  
Green Senior Note
    
963
      
-
      
-
      
-
      
-
      
394,155
      
395,118
  
Other bank loans
     11       1,895       1,895       1,862       -       -       5,663  
Total
    
27,881
      
10,094
      
1,895
      
106,151
      
327,081
      
549,969
      
1,023,071
  

Note 15. - Project debt
This note shows the project debt linked to the contracted concessional assets included in Note 6 of these Consolidated Condensed Interim Financial Statements.
Project debt is generally used to finance contracted assets, exclusively using as guarantee the assets and cash flows of the company or group of companies carrying out the activities financed. In addition, the cash of the Company´s projects include funds held to satisfy the customary requirements of certain non-recourse debt agreements and other restricted cash for an amount of $227 million as of June 30, 2022 ($254 million as of December 31, 2021).
38
The breakdown of project debt for both non-current and current liabilities as of June 30, 2022 and December 31, 2021 is as follows:

   
Balance as of
June 30,
    
Balance as of
December 31,
  
   
2022
    
2021
  
   
($ in thousands)
  
Non-current
    
4,390,459
      
4,387,674
  
Current
    
345,041
      
648,519
  
Total Project debt
    
4,735,500
      
5,036,193
  

The decrease in total project debt is primarily due to:

-
the repayment of project debt for the period in accordance with the financing arrangements; and
-
the lower value of debt denominated in Euros given the depreciation of the Euro against the U.S. dollar since December 31, 2021.

As of December 31, 2021, Kaxu total debt was presented as current in the Consolidated Condensed Interim Financial Statements of the Company, for an amount of $314 million, in accordance with International Accounting Standards 1 (“IAS 1”), “Presentation of Financial Statements”, as a result of the existence of a theoretical event of default under the Kaxu project finance agreement. As of June 30, 2022, the Company has again an unconditional right to defer the settlement of the debt for at least twelve months, and therefore the debt previously presented as current in these Consolidated Condensed Interim Financial Statements has been reclassified as non-current in accordance with the financing agreements (Note 1).

The repayment schedule for project debt in accordance with the financing arrangements as of June 30, 2022, is as follows and is consistent with the projected cash flows of the related projects:

Remainder of 2022
                                            
Interest
payment
    
Nominal
repayment
    
Between
January
and
June 2023
    
Between
July
and
December 2023
    
2024
    
2025
    
2026
    
Subsequent years
   
Total
  
($ in thousands)
  
 
16,688
      
200,718
      
127,635
      
209,351
      
353,583
      
473,217
      
394,734
      
2,959,574
       4,735,500
  

The repayment schedule for project debt in accordance with the financing arrangements and assuming there would be no acceleration of the Kaxu debt repayment as of December 31, 2021, was as follows and was consistent with the projected cash flows of the related projects:

2022
    
2023
    
2024
    
2025
    
2026
    
Subsequent years
   
Total
  
Interest
payment
    
Nominal
repayment
                                      
 
18,017
      
317,388
      
355,956
      
369,528
      
498,712
      
411,514
      
3,065,078
      
5,036,193
  

39
Note 16. - Grants and other liabilities

   
Balance as of
June 30,
    
Balance as of
December 31,
  
    2022
     2021  
   
($ in thousands)
  
Grants
    
940,975
      
970,557
  
Other Liabilities
    
311,374
      
293,187
  
Grants and other non-current liabilities
    
1,252,349
      
1,263,744
  

As of June 30, 2022, the amount recorded in Grants primarily corresponds to the ITC Grant awarded by the U.S. Department of the Treasury to Solana and Mojave for a total amount of $626 million ($642 million as of December 31, 2021). The amount recorded in Grants as a liability is progressively recorded as other income over the useful life of the asset.

The remaining balance of the “Grants” account corresponds to loans with interest rates below market rates for Solana and Mojave for a total amount of $313 million as of June 30, 2022 ($326 million as of December 31, 2021). Loans with the Federal Financing Bank guaranteed by the Department of Energy for these projects bear interest at a rate below market rates for these types of projects and terms. The difference between proceeds received from these loans and its fair value, is initially recorded as “Grants” in the consolidated statement of financial position, and subsequently recorded progressively in “Other operating income”.
Total amount of income for these two types of grants for Solana and Mojave is $29.3 million and $29.4 million for the six-month periods ended June 30, 2022 and 2021, respectively (Note 20).
Other liabilities mainly include:

-
$61 million of lease liabilities ($59 million as of December 31, 2021);
-
$123 million of dismantling provision ($125 million as of December 31, 2021); and
-
$80 million of provision related to the current high market prices in Spain at which the solar assets in Spain invoiced electricity up to June 30, 2022 ($75 million as of December 31, 2021), as a result of a negative adjustment to the regulated revenues expected to be recorded progressively over the remaining regulatory life of the solar assets of the Company, as a compensation.

Note 17. - Trade payables and other current liabilities
Trade payables and other current liabilities as of June 30, 2022 and December 31, 2021 are as follows:

   
Balance as of
June 30,
    
Balance as of
December 31,
  
   
2022
     2021  
   
($ in thousands)
  
Trade accounts payable
    
106,309
      
79,052
  
Down payments from clients
    
641
      
542
  
Other accounts payable
    
47,721
      
34,313
  
Total
    
154,671
      
113,907
  

Trade accounts payable mainly relate to the operation and maintenance of the plants.
Nominal values of trade payables and other current liabilities are considered to be approximately equal to fair values and the effect of discounting them is not significant.

40
Note 18. - Income Tax
The effective tax rate for the periods presented has been established based on management’s best estimates, taking into account the tax treatment of permanent differences and tax credits.
For the six-month period ended June 30, 2022, income tax amounted to a $6,050 thousand expense with respect to a profit before income tax of $16,848 thousand. In the six-month period ended June 30, 2021, income tax amounted to a $33,128 thousand expense with respect to a profit before income tax of $37,614 thousand. The effective tax rate differs from the nominal tax rate mainly due to unrecognized tax loss carryforwards and permanent tax differences in some jurisdictions.

Note 19. - Financial expense, net
Financial income and expense
The following table sets forth financial income and expenses for the six-month periods ended June 30, 2022 and 2021:

   
For the six-month period ended June 30,
  

 
2022
    
2021
  
Financial income
  
($ in thousands)
  
Interest income from loans and credits
    
699
      
1,027
  
Interest rate gains on derivatives: cash flow hedges
    
921
      
205
  
Total
    
1,620
      
1,232
  

   
For the six-month period ended June 30,
  

 
2022
    
2021
  
Financial expense
 
($ in thousands)
  
Interest on loans and notes     (140,616 )     (158,882 )
Interest rates losses derivatives: cash flow hedges
     (23,737 )     (30,642 )
Total
    
(164,353
)
    
(189,524
)

Interest on loans and notes primarily include interest on corporate and project debt.
Losses from interest rate derivatives designated as cash flow hedges primarily correspond to transfers from equity to financial expense when the hedged item impacts the consolidated income statement.
Net exchange differences
Net exchange differences primarily correspond to realized and unrealized exchange gains and losses on transactions in foreign currencies as part of the normal course of business of the Company.
41
Other financial income and expenses
The following table sets out Other financial income and expenses for the six-month periods ended June 30, 2022, and 2021:

   
 For the six-month period ended June 30,
  
Other financial income / (expenses)
  
2022
    
2021
  
   
($ in thousands)
  
Other financial income
    
11,241
      
21,434
  
Other financial losses
    
(11,624
)
    
(8,133
)
Total
    
(383
)
    
13,301
  

Other financial income in the six-month period ended June 30, 2022, include $5.6 million of income for non-monetary change to the fair value of derivatives of Kaxu for which hedge accounting is not applied ($5.7 million for the six-month period ended June 30, 2021), and $3.4 million income ($8.0 million income for the six-month period ended June 30, 2021) further to the change in the fair value of the conversion option of the Green Exchangeable Notes since December 2021 (Note 14). Residual items primarily relate to interest on deposits and loans, including non-monetary changes to the amortized cost of such loans.
Other financial losses primarily include guarantees and letters of credit, other bank fees and other minor financial expenses.

Note 20.- Other operating income and expenses
The table below shows the detail of Other operating income and expenses for the six-month periods ended June 30, 2022, and 2021:

Other operating income
  
For the six-month period ended June 30,
  
   
2022
    
2021
  
   
($ in thousands)
  
Grants (Note 16)
    
29,661
      
29,625
  
Insurance proceeds and other
    
6,375
      
10,645
  
Total
    
36,036
      
40,270
  


Other operating expenses
  
For the six-month period ended June 30,
  
   
2022
    
2021
  
   
($ in thousands)
  
Raw materials and consumables used
    
(9,315
)
    
(44,785
)
Leases and fees
    
(5,646
)
    
(3,808
)
Operation and maintenance
    
(76,853
)
    
(77,672
)
Independent professional services
    
(19,676
)
    
(18,222
)
Supplies
    
(27,573
)
    
(14,385
)
Insurance
    
(23,683
)
    
(21,932
)
Levies and duties
    
(8,700
)
    
(22,299
)
Other expenses
    
(7,650
)
    
(12,689
)
Total
    
(179,096
)
    
(215,792
)

The decrease in Other operating expenses in 2022 is primarily due to a specific non-recurrent solar project of Rioglass which ended in October 2021, which mainly explains the decrease in Raw materials and consumables used in 2022.

42
Note 21. - Earnings per share
Basic earnings per share have been calculated by dividing the profit/(loss) attributable to equity holders of the Company by the average number of outstanding shares.
Diluted earnings per share for the six-month period ended June 30, 2022 have been calculated considering the potential issuance of 3,347,305 shares on the settlement of the Green Exchangeable Notes (Note 14) and the potential issuance of 879,197 shares to Algonquin under the agreement signed on August 3, 2021, according to which Algonquin has the option, on a quarterly basis, to subscribe such number of shares to maintain its percentage in Atlantica in relation to the use of the ATM program (Note 13). Diluted earnings per share for the six-month period ended June 30, 2021 was calculated considering the potential issuance of 3,347,305 shares on the settlement of the Green Exchangeable Notes.

 Item  
For the six-month period ended June 30,
 
   
2022
    
2021
  
   
($ in thousands)
  
Profit/(loss) attributable to Atlantica
    
4,070
   
(6,829
)
Average number of ordinary shares outstanding (thousands) - basic
    
113,541
      
110,594
  
Average number of ordinary shares outstanding (thousands) - diluted
    
117,665
      
113,941
  
Earnings per share for the period (U.S. dollar per share) - basic
    
0.04
   
(0.06
)
Earnings per share for the period (U.S. dollar per share) - diluted
    
0.03
   
(0.06
)

Note 22. - Subsequent events

On August 2, 2022, the Board of Directors of the Company approved a dividend of $0.445 per share, which is expected to be paid on September 15, 2022.

43
Item 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
 
The following discussion and analysis should be read together with, and is qualified in its entirety by reference to, our Consolidated Condensed Interim Financial Statements and our Annual Consolidated Financial Statements prepared in accordance with IFRS as issued by the IASB and other disclosures including the disclosures under “Part II, Item 1.A.—Risk Factors” of this quarterly report and “Part I, Item 3.D.—Risk Factors” in our Annual Report. The following discussion contains forward-looking statements that reflect our plans, estimates and beliefs, which are based on assumptions we believe to be reasonable. Our actual results could differ materially from those discussed in such forward-looking statements. The results shown here are not necessarily indicative of the results expected in any future period. Please see our Annual Report for additional discussion of various factors affecting our results of operations.
 
Overview
 
We are a sustainable infrastructure company with a majority of our business in renewable energy. Our purpose is to support the transition towards a more sustainable world by investing in and managing sustainable infrastructure, while creating long-term value for our investors and the rest of our stakeholders. In 2021, our renewable sector represented 77% of our revenue, with solar energy representing 69%. We complement our portfolio of renewable assets with storage, efficient natural gas and heat and transmission infrastructure assets, as enablers of the transition towards a clean energy mix. We also hold water assets, a relevant sector for sustainable development.
 
As of the date of this quarterly report, we own or have an interest in a portfolio of diversified assets, both in terms of business sector and geographic footprint. Our portfolio consists of 40 assets with 2,048 MW of aggregate renewable energy installed generation capacity (of which approximately 72% is solar), 343 MW of efficient natural gas-fired power generation capacity, 55 MWt of district heating capacity, 1,229 miles of transmission lines and 17.5 M ft3 per day of water desalination.
 
We currently own and manage operating facilities in North America (United States, Canada and Mexico), South America (Peru, Chile, Colombia and Uruguay) and EMEA (Spain, Italy, Algeria and South Africa). Our assets generally have contracted or regulated revenue. As of December 31, 2021, our assets had a weighted average remaining contract life of approximately 15 years.
 
Our objective is to pay a consistent and growing cash dividend to shareholders that is sustainable on a long-term basis. We expect to distribute a significant percentage of our cash available for distribution as cash dividends and we will seek to increase such cash dividends over time through organic growth, investments in new assets and acquisitions.
 
Recent Investments and Acquisitions
 
•
In April 2021, we closed the acquisition of Coso, a 135 MW geothermal plant in the United States, with 18-year average contract life PPAs in place. The equity investment was $130 million, which was paid in April 2021. In addition, on July 15, 2021, we repaid $40 million of project debt.
 
•
In May 2021, we closed the acquisition of Calgary District Heating, a district heating asset in Canada, for a total equity investment of $22.9 million. The asset has availability-based revenue with inflation indexation and 20 years of weighted average contract life at the time of the acquisition.
 
•
In June 2021, we closed the acquisition of a 49% interest in Vento II, a 596 MW wind portfolio in the United States for a total equity investment of $198.3 million. EDP Renewables owns the remaining 51%.
 
44
The assets have PPAs with investment grade off-takers with a five-year average remaining contract life at the time of the investment.
 
•
In August 2021, we closed the acquisition of Italy PV 1 and Italy PV 2, two solar PV plants in Italy with a combined capacity of 3.7 MW for a total equity investment of $9 million. In December 2021, we closed the acquisition of Italy PV 3, a 2.5 MW solar portfolio in Italy for a total equity investment of $4 million. These assets have regulated revenues under a feed in tariff until 2030, 2031 and 2032, respectively.
 
•
In November 2021, we closed the acquisition of La Sierpe, a 20 MW solar PV plant in Colombia for a total equity investment of $23.5 million. The asset was acquired under our Liberty GES ROFO Agreement.
 
•
In 2021, we acquired in two stages the 85% equity interest in Rioglass that we did not previously own for a total investment of $17.1 million, resulting in a 100% ownership. Rioglass is a supplier of spare parts and services in the solar industry and we gained control over the asset in January 2021.
 
•
In January 2022, we closed the acquisition of Chile TL4, a 63-mile transmission line and 2 substations in Chile for a total equity investment of $39 million. We expect to make an expansion of the line no later than in 2023, which would represent an additional investment of approximately $8 million. The asset has fully contracted revenues in U.S. dollars, with inflation escalation and a 50-year contract life. The off-takers are several mini-hydro plants that receive contracted or regulated payments.
 
•
In April 2022, we closed the acquisition of Italy PV 4, a 3.6 MW solar portfolio in Italy for a total equity investment of $3.7 million. The asset has regulated revenues under a feed in tariff until 2031.
 
•
In May 2022, together with our partner, we closed a 7.5-year PPA extension for Monterrey with our current off-takers. The extension will involve an investment that is expected to be financed with cash available at the asset level. The main objective of the investment is to achieve improvements in the asset to provide, among other things, additional battery capacity and improve the electric power redundancy. The PPA, which is denominated in U.S. dollars, has now 24 years remaining.
 
•
In July 2022 we closed a 12-year transmission service agreement denominated in U.S. that will allow us to build a substation and a 2.4 mile transmission line connected to our ATN transmission line and serving a new mine in Peru. The substation is expected to enter in operation in 2024 and the investment is expected to be approximately $12 million.
 
•
In addition, we currently have three assets under construction:
 

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

 -
La Tolua and Tierra Linda are two solar PV assets in Colombia with a combined capacity of 30 MW. Each plant has a 15-year PPA in local currency indexed to local inflation with Synermin, the largest independent electricity wholesaler in Colombia.
 
45
Recent Developments
 
•
Regulation in Spain. As expected, the Administration in Spain has recently approved measures to adjust the regulated revenue component for renewable energy plants, following the increase since mid-2021 in the billings of these plants for the sale of electricity in the market. On March 30, 2022, the Royal Decree Law 6/2022 was published, adopting urgent measures in response to the economic and social consequences of the war in Ukraine. This Royal Decree Law contains a bundle of measures in diverse fields, including those targeted at containing the sharp rise in the prices of gas and electricity. It includes temporary changes to the detailed regulated components of revenue received by our solar assets in Spain, which are applicable from January 1, 2022.
 
The proposed remuneration parameters for the year 2022 were published on May 12, 2022, and, although they are still subject to comments and final publication, we do not expect significant changes. As a result, we have recorded our revenue for the first half of 2022 following these new parameters. In addition, on May 14, 2022, the Royal Decree Law 10/2022 was published, including additional details on the changes to the regulated components of revenue. The main changes are:
 

 −
The statutory half-period of three years from 2020 to 2022 has been split into two statutory half-periods (1) from January 1, 2020 until December 31 2021 and (2) calendar year 2022. As a result, the fixed monthly payment based on installed capacity (Remuneration on Investment or Rinv) for calendar year 2022 is being revised. The proposed Rinv is detailed in the table below.
 

 −
The electricity market price assumed by the regulation for calendar year 2022 was changed from €48.82 per MWh to an expected price of €121.9 per MWh. As a result, the variable payment based on net electricity produced (Remuneration on operation or Ro), is also being adjusted. The proposed Ro for the year 2022 is zero €/MWh reflecting the fact that market prices for the power sold in the market are significantly higher.
 
The proposed remuneration parameters applicable to our plants for 2022 are as follows, as preliminarily published on May 12, 2022:
 
 
Useful Life
Return on
Investment
2022 (euros/MW)
Remuneration
on Operation
2022 (euros/GWh)
Maximum
Hours
Minimum
Hours
Operating
Threshold
Solaben 2
25 years
390,452
0
2,008
1,205
703
Solaben 3
25 years
390,452
0
2,008
1,205
703
Solacor 1
25 years
390,452
0
2,008
1,205
703
Solacor 2
25 years
390,452
0
2,008
1,205
703
PS 10
25 years
543,185
0
1,840
1,104
644
PS 20
25 years
401,296
0
1,840
1,104
644
Helioenergy 1
25 years
385,012
0
2,008
1,205
703
Helioenergy 2
25 years
385,012
0
2,008
1,205
703
Helios 1
25 years
398,496
0
2,008
1,205
703
Helios 2
25 years
398,496
0
2,008
1,205
703
Solnova 1
25 years
404,290
0
2,008
1,205
703
Solnova 3
25 years
404,290
0
2,008
1,205
703
Solnova 4
25 years
404,290
0
2,008
1,205
703
Solaben 1
25 years
395,303
0
2,008
1,205
703
Solaben 6
25 years
395,303
0
2,008
1,205
703
Seville PV
30 years
696,405
0
2,041
1,225
714
 
46

 −
For the three-year half period starting on January 1, 2023 and ending on December 31, 2025, the adjustment for electricity price deviations in the preceding statutory half period will be progressively modified to take into account a mix of actual market prices and future market prices.
 
Given that our solar assets in Spain are regulated and are entitled to receive a defined reasonable rate of return, we do not expect any impact from the changes in the regulatory remuneration parameters in the revenue expected to be received in the long-term. For the year 2022, as a result of these changes, revenue from return on investment will be reduced by €5.6 million and revenue from Return on Operation will be reduced by €42.7 million. These effects are expected to be more than offset by significantly higher revenue from sales of electricity at market prices. We do not expect a significant impact from these changes in the regulatory remuneration parameters with respect to our expectations at the end of 2021.
 
In order to obtain the right to receive the Return on Investment, the plants need to achieve a minimum production threshold. In recent months, some of our assets have been subject to significant technical curtailment, which had happened very occasionally in the past. If this curtailment continued in the upcoming months, these assets may not reach the minimum production necessary to obtain the Return on Investment, which may have a material negative effect on our financial condition, results of operations and cash flows.
 
•
Potential electric reform in Mexico. On April 17, 2022, the House of Representatives in Mexico rejected a constitutional amendment proposal submitted by the Mexican President aimed at approving a reform to the Electricity Industry Law and granting the state-owned Federal Electricity Commission priority over private sector companies. Although the Mexican President has stated that he does not intend to re-submit a modified amendment proposal for approval again, at this point we cannot guarantee that he will not pursue other relevant changes to the electricity sector in Mexico, since this has been an important component of his political agenda.

•
Changes in tax regulations. Italy has recently enacted an extraordinary and temporary tax on extraordinary profits obtained by companies operating in the energy sector (including electricity and oil and gas) due to current high prices and calculated by comparing certain 2022 metrics versus 2021. The tax would only be paid if those extraordinary profits are higher than a certain threshold. We do not expect this tax to affect our assets and profits due to this threshold. In addition, the government of Spain has recently announced a new temporary levy which is expected to be in force during the fiscal years 2023 and 2024, and to be applicable to revenues obtained in fiscal years 2022 and 2023 by large operators of the electric and oil and gas sectors with revenue in Spain exceeding €1,000 million. The levy is not expected to be applicable to our assets in Spain since we are out of the proposed scope.
 
•
Arizona Corporation Commission. In August 2021, the Arizona Corporation Commission (“ACC”) held a hearing related to different aspects of Arizona Public Service’s electricity supply during which the ACC Chairwoman raised the possibility to retroactively examine Solana’s PPA prudency. This proceeding was ultimately resolved at a July 13, 2022, hearing of the ACC in which the ACC formally approved a resolution to take no action in respect of the Solana PPA.
 
•
New director. On August 2, 2022, our board of directors appointed Mr. Edward C. Hall as independent director. Mr. Hall is an active independent director and advisor with 35 years of experience in all facets of the electricity industry. Mr. Hall brings a deep understanding of electricity markets, power generation technologies, utility operations and commercial structuring. Mr. Hall serves as Chairman of Cypress Creek Renewables, Vice Chairman of Japan Wind Development Company and as a Director of Wellesley Municipal Light. Mr. Hall spent 25 years of his career with AES Corporation, where he was a member of the AES Executive Leadership Team and served as Chief Operating Officer of global generation. Mr. Hall has previously served on the boards of General Cable, Globeleq, TerraForm Power and Green Conversion Systems. Mr. Hall earned a B.S. in Mechanical Engineering from Tufts University and M.S. in Finance and Technology Innovation from the MIT Sloan School of Management
 
47
•
Dividend. On August 2, 2022, our board of directors approved a dividend of $0.445 per share. The dividend is expected to be paid on September 15, 2022, to shareholders of record as of August 31, 2022.
 
Potential implications of Abengoa developments
 
In 2021, Abengoa performed operation and maintenance (O&M) services for assets that represented approximately 47% of our consolidated revenue for that year. In February 2022, we started to perform the O&M services in Kaxu from an Atlantica subsidiary after reaching an agreement with Abengoa to transition such services. In addition, following the expiration of two O&M agreements, we reached a global agreement for the O&M services of the assets in Spain. As a result of this agreement, Atlantica replaced Abengoa as a service provider for three of our assets in Spain: Solaben 2&3, Solaben 1&6 and Helioenergy 1&2. After this replacement, Abengoa currently provides services for assets representing around 20% of our 2021 consolidated revenue.

On February 22, 2021, Abengoa, S.A., which is the holding company of subsidiaries performing O&M services for those assets, filed for insolvency proceedings in Spain. In addition, on July 28, 2022, the subsidiary in Spain performing the O&M services at some of our plants filed for insolvency proceedings. During the insolvency period, we expect the O&M services to continue to be provided as usual, but no assurance can be provided that that will be the case. The O&M contracts in Spain include the possibility for Atlantica to terminate the agreements by the end of 2024 and before under certain circumstances.

For these assets in respect of which O&M services are provided by Abengoa as of August 3, 2022, we cannot guarantee that Abengoa and/or its subcontractors will be able to continue performing the services or at the same level of service as they did in the past (or at all) or under the same terms and conditions, or at the same prices. If Abengoa cannot continue performing current services at the same prices, we may need to renegotiate contracts, to internalize the service, engage with other suppliers at higher prices or change the scope of those O&M contracts. This may have a material adverse effect on our business, financial condition, results of operations and cash flows.

In addition, the project financing arrangement for Kaxu contained a cross-default provision related to Abengoa S.A.’s insolvency filing. In September 2021, we obtained a waiver for such cross-default which became effective on March 31, 2022, following the transfer of the employees performing the O&M in Kaxu from an Abengoa subsidiary to an Atlantica subsidiary and other conditions. The Kaxu project debt was reclassified to non-current as of that date.

There may be unanticipated consequences of Abengoa S.A. insolvency filings and potential liquidation process, Abengoa Abenewco1, S.A. and certain of its subsidiaries pre-insolvency filings or potential insolvency filings, further restructurings by Abengoa or ongoing bankruptcy proceedings by Abengoa’s subsidiaries that we have not yet identified. There are uncertainties as to how any further bankruptcy proceedings would be resolved and how our current O&M agreements or other relationships with Abengoa would be affected following the initiation or resolution of any such proceedings.
 
48
In addition, in Mexico, Abengoa was the owner of a plant that shares certain infrastructure and has certain back-to-back obligations with ACT. ACT is required to deliver an equipment to Pemex which has been recently donated and delivered to ACT by such plant. If we are unable to comply with these obligations, it may result in a material adverse effect on ACT and on our business, financial conditions, results of operations and cash flows. According to public information, the plant mentioned above is currently controlled by a third party.
 
Prior to the completion of our initial public offering in 2014, we and many of our assets were part of Abengoa. In addition, many of our senior executives have previously worked for Abengoa. Abengoa’s current and prior restructuring processes, and the events and circumstances that led to them, are currently the subject of various legal proceedings and investigations and may in the future become the subject of additional proceedings. To the extent that allegations are made in any such proceedings that involve us, our assets, our dealings with Abengoa or our employees, such proceedings may have a material adverse effect on our business, financial condition, results of operations and cash flows, as well as on our reputation and employees. We refer to “Part I. Item 3.D.—Risk Factors—Risks Related to Our Relationship with Algonquin and Abengoa” in our Annual Report for further discussion of potential implications of the Abengoa situation.
 
Factors Affecting the Comparability of Our Results of Operations
 
Acquisitions and non-recurrent projects
 
The results of operations of Coso, Calgary District Heating, Italy PV 1, Italy PV 2, La Sierpe, Italy PV 3, Chile TL4 and Italy PV 4 have been fully consolidated since April 2021, May 2021, August 2021 for Italy PV 1 and Italy PV 2, November 2021, December 2021, January 2022 and April 2022, respectively. Vento II has been recorded under the equity method since June 2021. These acquisitions represent additional revenue for $31.7 million and additional Adjusted EBITDA of $36.2 million in the first half of 2022 when compared to the first half of 2021.
 
In addition, the results of operations of Rioglass have been fully consolidated since January 2021. In the first half of 2021, most of Rioglass operating results relate to a specific solar project which ended in October 2021, and which represented $58.0 million in revenue and $1.1 million in Adjusted EBITDA, included in our EMEA and Renewable energy segments for the first half of 2021 and which are non-recurrent.
 
Impairment
 
IFRS 9 requires impairment provisions to be based on expected credit losses on financial assets rather than on actual credit losses. For the first half of 2022 we recorded an expected credit loss impairment provision at ACT for $10.5 million which is reflected in the line item “Depreciation, amortization, and impairment charges” following a worsening in its client's credit risk metrics. For the six-month period ended June 30, 2021 we had recorded a $19.4 million reversal of the expected credit loss impairment provision in ACT.
 
Electricity market prices
 
In addition to regulated revenue, our solar assets in Spain receive revenue from the sale of electricity at market prices. Electricity prices have increased significantly since mid-2021 and revenue from the sale of electricity at current market prices represented $84.7 million in the first half of 2022 compared to $39.6 million in the first half of 2021, resulting in higher short-term cash collections. Regulated revenues are revised periodically to reflect, among other things, the difference between expected and actual market prices if the difference is higher than a pre-defined threshold. Current higher market prices in Spain will therefore cause lower regulated revenue to be received progressively over the remaining regulatory life of our solar assets. As a result, we increased our provision by $17.7 million in the first half of 2022 which lowered revenue in this geography with no cash impact on the current period, compared to a provision of $11 million in the first half of 2021. On March 30, 2022, the Royal Decree Law 6/2022 introduced certain temporary changes to the detailed regulated components of revenue received by our solar assets in Spain, which are applicable from January 1, 2022, the details of which are still subject to comments and publication. Considering the proposed remuneration parameters published, revenue from the sale of electricity at market prices plus Remuneration on operation (Ro) plus market price provision was $67.0 million in the first half of 2022, compared to $54.4 million in the first half of 2021 (see “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations— Recent Developments”).
 
49
Significant Trends Affecting Results of Operations
 
Acquisitions
 
If the acquisitions recently closed perform as expected, we expect these assets to positively impact our results of operations in 2022 and upcoming years.
 
Solar, wind and geothermal resources
 
The availability of solar, wind and geothermal resources affects the financial performance of our renewable assets, which may impact our overall financial performance. Due to the variable nature of solar, wind and geothermal resources, we cannot predict future availabilities or potential variances from expected performance levels from quarter to quarter. Based on the extent to which the solar, wind and geothermal resources are not available at expected levels, this could have a negative impact on our results of operations.
 
Capital markets conditions
 
The capital markets in general are subject to volatility that is unrelated to the operating performance of companies. Our growth strategy depends on our ability to close acquisitions, which often requires access to debt and equity financing to complete these acquisitions. Volatility in capital markets may affect our ability to access this capital through debt or equity financings.
 
Exchange rates
 
Our functional currency is the U.S. dollar, as most of our revenue and expenses are denominated or linked to U.S. dollars. All our companies located in North America, with the exception of Calgary, with revenue in Canadian dollars, and most of our companies in South America have their revenue and financing contracts signed in or indexed totally or partially to U.S. dollars. Our solar power plants in Europe have their revenue and expenses denominated in euros, Kaxu, our solar plant in South Africa, has its revenue and expenses denominated in South African rand and La Sierpe our solar plant in Colombia has its revenue and expenses denominated in Colombian pesos. Project financing is typically denominated in the same currency as that of the contracted revenue agreement. This policy seeks to ensure that the main revenue and expenses streams in foreign companies are denominated in the same currency, limiting our risk of foreign exchange differences in our financial results.
 
Our strategy is to hedge cash distributions from our assets in Europe. We hedge the exchange rate for the distributions in euros after deducting euro-denominated interest payments and euro-denominated general and administrative expenses. Through currency options, we have hedged 100% of our euro-denominated net exposure for the next 12 months and 75% of our euro-denominated net exposure for the following 12 months. We expect to continue with this hedging strategy on a rolling basis.
 
50
Although we hedge cash-flows in euros, fluctuations in the value of the euro in relation to the U.S. dollar may affect our operating results. For example, revenue in euro-denominated companies could decrease when translated to U.S. dollars at the average foreign exchange rate solely due to a decrease in the average foreign exchange rate, in spite of revenue in the original currency being stable. Fluctuations in the value of South African rand and Colombian peso with respect to the U.S. dollar may also affect our operating results. Apart from the impact of these translation differences, the exposure of our income statement to fluctuations of foreign currencies is limited, as the financing of projects is typically denominated in the same currency as that of the contracted revenue agreements.
 
In our discussion of operating results, we have included foreign exchange impacts in our revenue by providing constant currency revenue growth. The constant currency presentation is not a measure recognized under IFRS and excludes the impact of fluctuations in foreign currency exchange rates. We believe providing constant currency information provides valuable supplemental information regarding our results of operations. We calculate constant currency amounts by converting our current period local currency revenue using the prior period foreign currency average exchange rates and comparing these adjusted amounts to our prior period reported results. This calculation may differ from similarly titled measures used by others and, accordingly, the constant currency presentation is not meant to substitute recorded amounts presented in conformity with IFRS as issued by the IASB, nor should such amounts be considered in isolation.
 
Impacts associated with fluctuations in foreign currency are discussed in more detail under “Item 3—Quantitative and Qualitative Disclosure about Market Risk—Foreign exchange risk”.
 
Interest rates
 
We incur significant indebtedness at the corporate and asset level. The interest rate risk arises mainly from indebtedness at variable interest rates. To mitigate interest rate risk, we primarily use long-term interest rate swaps and interest rate options which, in exchange for a fee, offer protection against a rise in interest rates. As of June 30, 2022, approximately 93% of our project debt and close to 100% of our corporate debt either has fixed interest rates or has been hedged with swaps or caps. Nevertheless, our results of operations can be affected by changes in interest rates with respect to the unhedged portion of our indebtedness that bears interest at floating rates, which typically bear a spread over EURIBOR, LIBOR, SOFR or over the alternative rates replacing these.
 
Electricity market prices
 
In addition to regulated revenue, our solar assets in Spain receive revenue from the sale of electricity at market prices. Regulated revenues are revised every three years to reflect the difference between expected and actual market prices if the difference is higher than a pre-defined threshold. Given that since mid-2021 electricity prices in Spain have been, and may continue to be, significantly higher than expected, it will cause lower regulated revenue over the remaining regulatory life of our solar assets. On March 30, 2022, the Royal Decree Law 6/2022 introduced certain temporary changes to the detailed regulated components of revenue received by our solar assets in Spain, which is applicable from January 1, 2022. In addition, the proposed remuneration parameters for the year 2022 were published on May 12, 2022. These parameters, already take into account the current high electricity prices and is applicable from January 1, 2022. The remuneration parameters will be subsequently reviewed in the next semi-regulatory period, starting on January 1, 2023.
 
51
Key Financial Measures
 
We regularly review a number of financial measurements and operating metrics to evaluate our performance, measure our growth and make strategic decisions. In addition to traditional IFRS performance measures, such as total revenue, we also consider Adjusted EBITDA.
 
Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). 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.
 
Our management believes Adjusted EBITDA is useful to investors and other users of our financial statements in evaluating our operating performance because it provides them with an additional tool to compare business performance across companies and across periods. EBITDA is widely used by investors to measure a company’s operating performance without regard to items such as interest expense, taxes, depreciation and amortization, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired. Adjusted EBITDA is widely used by other companies in our industry.
 
The non-GAAP financial measures including Adjusted EBITDA may not be comparable to other similarly titled measures of other companies and has limitations as analytical tools and should not be considered in isolation or as a substitute for analysis of our operating results as reported under IFRS as issued by the IASB. Non-GAAP financial measures and ratios are not measurements of our performance or liquidity under IFRS as issued by the IASB and should not be considered as alternatives to operating profit or profit for the period or any other performance measures derived in accordance with IFRS as issued by the IASB or any other generally accepted accounting principles or as alternatives to cash flow from operating, investing or financing activities. Adjusted EBITDA excludes the impact of cash costs of financing activities and taxes, and the effects of changes in operating working capital balances, and therefore are not necessarily indicative of operating profit or cash flow from operations as determined under IFRS GAAP.
 
Our revenue and Adjusted EBITDA by geography and business sector for the six-month periods ended June 30, 2022 and 2021 are set forth in the following tables:
 
Revenue by geography
 
   
Six-month period ended June 30,
  
Revenue by geography
  
2022
    
2021
  
   
$ in
millions
    
% of
revenue
    
$ in
millions
    
% of
revenue
  
North America
  
$
199.3
      
35.9
%
  
$
178.8
      
29.3
%
South America
    
78.3
      
14.1
%
    
78.4
      
12.8
%
EMEA
    
277.7
      
50.0
%
    
354.0
      
57.9
%
Total revenue
  
$
555.3
      
100
%
  
$
611.2
      
100
%
 
52
Revenue by business sector
 
   
Six-month period ended June 30,
  
Revenue by business sector
  
2022
    
2021
  
   
$ in
millions
    
% of
revenue
    
$ in
millions
    
% of
revenue
  
Renewable energy
  
$
420.3
      
75.7
%
  
$
471.6
      
77.1
%
Efficient natural gas & heat
    
53.4
      
9.6
%
    
58.5
      
9.6
%
Transmission lines
    
54.9
      
9.9
%
    
53.6
      
8.8
%
Water
    
26.7
      
4.8
%
    
27.5
      
4.5
%
Total revenue
  
$
555.3
      
100
%
  
$
611.2
      
100
%

Adjusted EBITDA by geography
   
Six-month period ended June 30,
  
Adjusted EBITDA by geography
  
2022
    
2021
  
   
$ in
millions
    
Adjusted
EBITDA
Margin (2)
    
$ in
millions
    
Adjusted
EBITDA
Margin (2)
  
North America
  
$
161.2
      
80.8
%
  
$
134.9
      
75.4
%
South America
    
58.8
      
75.1
%
    
60.2
      
76.8
%
EMEA
    
182.3
      
65.6
%
    
209.1
      
59.0
%
Total Adjusted EBITDA(1)
  
$
402.3
      
72.4
%
  
$
404.2
      
66.1
%
 
Adjusted EBITDA by business sector
 
   
Six-month period ended June 30,
  
Adjusted EBITDA by business sector
  
2022
    
2021
  
   
$ in
millions
    
Adjusted
EBITDA
Margin (2)
    
$ in
millions
    
Adjusted
EBITDA
Margin (2)
  
Renewable energy
  
$
296.8
      
70.6
%
  
$
295.0
      
62.6
%
Efficient natural gas & heat
    
44.0
      
82.4
%
    
47.2
      
80.7
%
Transmission lines
    
43.2
      
78.7
%
    
42.5
      
79.3
%
Water
    
18.3
      
68.5
%
    
19.5
      
70.9
%
Total Adjusted EBITDA(1)
  
$
402.3
      
72.4
%
  
$
404.2
      
66.1
%
Note:
(1)
Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.
(2)
Adjusted EBITDA Margin is calculated as Adjusted EBITDA for each segment based on geography and business sector divided by revenue for each segment based on geography and business sector.

53
Reconciliation of profit/(loss) for the period to Adjusted EBITDA
 
The following table sets forth a reconciliation of Adjusted EBITDA to our net cash generated by or used in operating activities:
 
   
For the six-month
period ended June 30,
  
   
2022
    
2021
  
   
($ in millions)
  
Profit /(Loss) attributable to the company
  
$
4.1
    
$
(6.8
)
Profit attributable to non-controlling interests
    
6.7
      
11.3
  
Income tax
    
6.1
      
33.1
  
Financial expense, net
    
155.8
      
172.8
  
Depreciation, amortization and impairment charges
    
217.8
      
188.9
  
Depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro rata of our equity ownership)
    
11.9
      
4.9
  
Adjusted EBITDA
  
$
402.3
    
$
404.2
  

Reconciliation of net cash generated by operating activities to Adjusted EBITDA

   
For the six-month
period ended June
30,
  
   
2022
    
2021
  
   
($ in millions)
  
Net cash flow provided by operating activities
  
$
264.1
    
$
246.3
  
Net interest /taxes paid
    
129.3
      
163.7
  
Variations in working capital
    
2.3
      
(9.4
)
Non-monetary items
    
(21.4
)
    
(1.8
)
Share of profit/(loss) of associates carried under the equity method, depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership) and other
    
28.0
      
5.4
  
Adjusted EBITDA
  
$
402.3
    
$
404.2
  

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

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

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

 •
Availability in the case of our Efficient natural gas and heat assets, Transmission lines and Water assets also provides information on the performance of the assets. In these business segments revenues are based on availability, which is the time during which the asset was available to our client totally or partially divided by contracted availability or budgeted availability, as applicable.
 
54
Key Performance Indicators
 
   
Volume sold and availability levels
As of and for the six-month period ended June 30,
  
Key performance indicator
  
2022
    
2021
  
Renewable energy
            
MW in operation(1)
    
2,048
      
2,018
  
GWh produced(2)
    
2,647
      
1,984
  
Efficient natural gas & heat
                
MW in operation(3)
    
398
      
398
  
GWh produced(4)
    
1,251
      
1,043
  
Availability (%)
    
100.1
%
    
99.4
%
Transmission lines
                
Miles in operation
    
1,229
      
1,166
  
Availability (%)
    
99.9
%
    
99.9
%
Water
                
Mft3 in operation(1)
    
17.5
      
17.5
  
Availability (%)
    
102.2
%
    
99.7
%
Notes:
(1)
Represents total installed capacity in assets owned or consolidated for the six-month period ended June 30, 2022 and 2021, respectively, regardless of our percentage of ownership in each of the assets except for Vento II for which we have included our 49% interest.
(2)
Includes 49% of Vento II wind portfolio production since its acquisition. Includes curtailment in wind assets for which we receive compensation
(3)
Includes 43 MW corresponding to our 30% share in Monterrey and 55MWt corresponding to Calgary District Heating.
(4)
GWh produced includes 30% of the production from Monterrey.
 
Production in the renewable business sector increased by 33.5% in the first half of 2022, compared to the same period of the previous year. The increase was largely due to the contribution from the recently acquired renewable assets Coso, Vento II, Italy PV 1, Italy PV 2, Italy PV 3, Italy PV 4 and La Sierpe bringing approximately 751.4 GWh of additional electricity generation.
 
In our solar assets in the U.S. solar radiation was higher than in the first half of 2021 and production increased at Mojave. This effect was offset by lower production at Solana due to the scheduled improvements in the storage system, which are expected to continue throughout 2022. With this, solar production remained in line with the first half of 2021, showing a 0.5% decrease compared to the same period in the previous year. In our wind assets in the U.S., wind resource was in line with expectations in the first half of the 2022.
 
In Chile, production at our PV assets was lower compared to the same period of the previous year as a result of curtailments. In our wind assets in Uruguay, production decreased by 12.4% mainly due to lower wind resource in the second quarter of 2022 compared to the same period of the previous year.
 
In Spain, production at our solar assets decreased by 8.9% in the first half of 2022, compared to the same period of the previous year. Although solar radiation was better in the first half of 2022, some of our assets experienced significant technical curtailments during the second quarter of 2022. In Kaxu, production decreased slightly as a result of lower radiation.
 
55
Efficient natural gas and heat availability and production levels during the six-month period ended June 30, 2022 were higher than in the same period of the previous year due to the scheduled maintenance stops performed in the first quarter of 2021 and to higher demand from our off-taker in the first half of 2022 compared to the same period of 2021.
 
In Water, availability during the six-month period ended June 30, 2022 was higher than in the same period of the previous year, with very good performance in all the assets. Our transmission lines, where revenue is also based on availability, continue to achieve high availability levels.
 
Results of Operations
 
The table below illustrates our results of operations for the six-month periods ended June 30, 2022 and 2021.
 
   
Six -month period ended June 30,
    
   
2022
    
2021
    
% Changes
    
   
($ in millions)
           
Revenue
  
$
555.3
      
611.2
      
(9.1
)
%
Other operating income
    
36.0
      
40.3
      
(10.7
)
%
Employee benefit expenses
    
(40.1
)
    
(39.0
)
    
2.8
  
%
Depreciation, amortization, and impairment charges
    
(217.8
)
    
(188.9
)
    
15.3
  
%
Other operating expenses
    
(179.1
)
    
(215.8
)
    
(17.0
)
%
Operating profit
  
$
154.3
      
207.8
      
(25.7
)
%
                           
Financial income
    
1.6
      
1.2
      
33.3
  
%
Financial expense
    
(164.4
)
    
(189.5
)
    
(13.2
)
%
Net exchange differences
    
7.3
      
2.2
      
231.8
  
%
Other financial income/(expense), net
    
(0.4
)
    
13.3
      
(103.0
)
%
Financial expense, net
  
$
(155.8
)
    
(172.8
)
    
(9.8
)
%
                              
Share of profit of associates carried under the equity method
    
18.3
      
2.6
      
603.8
  
%
Profit/ (loss) before income tax
  
$
16.8
      
37.6
      
(55.3
)
%
                                
Income tax
    
(6.1
)
    
(33.1
)
    
(81.6
)
%
Profit for the period
  
$
10.8
      
4.5
      
140.0
  
%
Profit attributable to non-controlling interests
    
(6.7
)
    
(11.3
)
    
(40.7
)
%
Profit/(loss) for the period attributable to the company
  
$
4.1
      
(6.8
)
    
160.3
  
%
Weighted average number of ordinary shares outstanding - basic
    
113.5
      
110.6
          
Weighted average number of ordinary shares outstanding - diluted
    
117.7
      
113.9
            
Basic earnings per share (U.S. dollar per share)
    
0.04
      
(0.06
)
          
Diluted earnings per share (U.S. dollar per share)
    
0.03
      
(0.06
)
          
Dividend paid per share(1)
    
0.88
      
0.85
            
Note:
(1)
On February 25, 2022 and May 5, 2022, our board of directors approved a dividend of $0.44 per share for each of the fourth quarter of 2021 and the first quarter of 2022, which were paid on March 25, 2022 and June 15, 2022, respectively. On February 26, 2021, and May 4, 2021, our board of directors approved a dividend of $0.42 and $0.43 per share corresponding to the fourth quarter of 2020 and to the first quarter of 2021, which were paid on March 22, 2021, and June 15, 2021, respectively.

56
Comparison of the Six-Month Periods Ended June 30, 2022 and 2021.
 
The significant variances or variances of the significant components of the results of operations are discussed in the following section.
 
Revenue
 
Revenue decreased to $555.3 million for the six-month period ended June 30, 2022, which represents a decrease of 9.1% compared to $611.2 million for the six-month period ended June 30, 2021. On a constant currency basis, revenue for the six-month period ended June 30, 2022, was $579.3 million, which represents a decrease of 5.2% compared to the six-month period ended June 30, 2021. Additionally, on a constant currency basis and excluding the Rioglass non-recurrent solar project accounted for in the first half of 2021 revenue increased by 4.7% for the six-month period ended June 30, 2022.
 
This increase (on a constant currency basis and excluding the Rioglass non-recurrent solar project) was mainly due to the contribution of the recently acquired and consolidated assets which represent a total of $31.7 million of additional revenue in the first half of 2022 compared to the first half of 2021. In addition, revenue increased at our solar assets in the U.S. and in Spain in spite of lower production during the period primarily due to higher electricity prices net of its corresponding accounting provision (see “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Factors Affecting our Results of Operations—Electricity market prices). These effects were partially offset by a decrease in revenue at ACT mainly due to lower revenue in the portion of the tariff related to operation and maintenance services, driven by lower operation and maintenance costs for the six-month period ended June 30, 2022, compared to the same period of the previous year.
 
Other operating income
 
The following table sets forth our other operating income for the six-month periods ended June 30, 2022 and 2021:
 
   
Six-month period ended June 30,
  
Other operating income
  
2022
    
2021
  
   
($ in millions)
  
Grants
  
$
29.7
    
$
29.6
  
Insurance proceeds and other
    
6.4
      
10.7
  
Total
  
$
36.0
    
$
40.3
  
 
Other operating income decreased by 10.7% to $36.0 million for the six-month period ended June 30, 2022, compared to $40.3 million for the period ended June 30, 2021.
 
“Grants” represent the financial support provided by the U.S. Department of the Treasury to Solana and Mojave and consist of an ITC Cash Grant and an implicit grant related to the below market interest rates of the project loans with the Federal Financing Bank. Grants were stable for the six-month period ended June 30, 2022 compared to same period of the previous year.
 
“Insurance proceeds and other” for the six-month period ended June 30, 2021 included $6.8 million in profit resulting from the purchase of a long-term operation and maintenance account payable at a discounted price, compared to a $0.8 million in profit in the same period of 2022, which is the main reason for the decrease.
 
57
Employee benefit expenses

Employee benefit expenses increased by 2.8% to $40.1 million for the for the six-month period ended June 30, 2022, compared to $39.0 million for the six-month period ended June 30, 2021. The increase was mainly due to the consolidation of Coso and the internalization of the operation and maintenance services at Kaxu. The increase was partially offset by a decrease in the number of employees at Rioglass once the non-recurrent solar project previously mentioned was completed.
 
Depreciation, amortization and impairment charges
 
Depreciation, amortization and impairment charges increased by 15.3% to $217.8 million for the six-month period ended June 30, 2022, compared to $188.9 million for the six-month period ended June 30, 2022, mainly due to an increase of the expected credit loss impairment provision at ACT. IFRS 9 requires impairment provisions to be based on the expected credit loss of the financial assets in addition to actual credit losses. ACT recorded a credit loss impairment provision of $10.5 million for the six-month period ended June 30, 2022, while for the six-month period ended June 30, 2021, there was a reversal of the expected credit loss provision of $19.4 million. Depreciation, amortization and impairment charges also increased due to the consolidation of recent acquisitions.
 
Other operating expenses
 
The following table sets forth our other operating expenses for the six-month periods ended June 30, 2022 and 2021:
 
   
Six-month period ended June 30,
  
Other operating expenses
  
2022
    
2021
  
   
$ in
millions
    
% of
revenue
    
$ in
millions
    
% of
revenue
  
Leases and fees
  
$
5.6
      
1.0
%
  
$
3.8
      
0.6
%
Operation and maintenance
    
76.9
      
13.8
%
    
77.7
      
12.7
%
Independent professional services
    
19.7
      
3.5
%
    
18.2
      
3.0
%
Supplies
    
27.6
      
5.0
%
    
14.4
      
2.4
%
Insurance
    
23.7
      
4.3
%
    
21.9
      
3.6
%
Levies and duties
    
8.7
      
1.6
%
    
22.3
      
3.6
%
Other expenses
    
7.6
      
1.4
%
    
12.7
      
2.1
%
Raw materials
    
9.3
      
1.7
%
    
44.8
      
7.3
%
Total
  
$
179.1
      
32.3
%
  
$
215.8
      
35.3
%
 
Other operating expenses decreased by 17.0% to $179.1 million for the six-month period ended June 30, 2022, compared to $215.8 million for the six-month period ended June 30, 2021, mainly due to lower raw material costs corresponding to the aforementioned Rioglass non-recurrent solar project which ended in October 2021.
 
Other operating expenses also decreased due to lower levies and duties. In the third quarter of 2021, the government in Spain granted an exemption for the 7% electricity sales tax in our assets in Spain until December 2022, which reduced our costs in the first half of 2022 compared to the same period of the previous year.
 
On the other hand, the cost of supplies increased mainly because a portion of our supply costs are related to the electricity market prices, which have increased since mid-2021.
 
In addition, our operation and maintenance costs remained stable, since the increase caused by recent acquisitions was offset by lower operation and maintenance costs in ACT.
 
58
Operating profit
 
As a result of the above-mentioned factors, operating profit decreased by 25.7% to $154.3 million for the six-month period ended June 30, 2022, compared with $207.8 million for the six-month periods ended June 30, 2021.
 
Financial income and financial expense
 
   
Six-month period ended June 30,
  
Financial income and financial expense
  
2022
    
2021
  
   
($ in millions)
  
Financial income
  
$
1.6
    
$
1.2
  
Financial expense
    
(164.4
)
    
(189.5
)
Net exchange differences
    
7.3
      
2.2
  
Other financial income/(expense), net
    
(0.4
)
    
13.3
  
Financial expense, net
  
$
(155.8
)
  
$
(172.8
)
 
Financial expense
 
The following table sets forth our financial expense for the six-month periods ended June 30, 2022, and 2021:
 
   
For the six-month period ended June 30,
  
Financial expense
  
2022
    
2021
  
   
($ in millions)
  
Interest on loans and notes
  
$
(140.6
)
  
$
(158.9
)
Interest rates losses derivatives: cash flow hedges
    
(23.8
)
    
(30.6
)
Total
  
$
(164.4
)
  
$
(189.5
)
 
Financial expense decreased by 13.2% to $164.4 million for the six-month period ended June 30, 2022, compared to $189.5 million for the six-month period ended June 30, 2021.
 
“Interest on loans and notes” expense decreased mainly because the six-month period ended June 30, 2021, included costs related to the prepayment of the Note Issuance Facility 2019 in May 2021 and the decrease in interest in our assets as we progressively repay our project debt.
 
Under “Interest rate losses on derivatives designated as cash flow hedges” we record transfers from equity to financial expense when the hedged item impacts profit and loss. The decrease was mainly due to lower losses in swaps hedging loans indexed to EURIBOR and LIBOR primarily due to lower notional amounts, as we progressively repay our project debt, and to an increase in the reference rates EURIBOR and LIBOR in the first half of 2022 compared to the same period of the previous year.
 
Net exchange differences
 
Net exchange differences increased to $7.3 million in the first half or 2022 compared to $2.2 million income in the same period of the previous year. The increase was mainly due to the change in fair value of caps hedging our cash flows in Euros, resulting from the appreciation of the US dollar against the Euro.
 
59
Other financial income/(expense), net

   
Six-month period ended June 30,
  
Other financial income /(expense), net
  
2022
    
2021
  
   
($ in millions)
  
Other financial income
  
$
11.2
    
$
21.4
  
Other financial expense
    
(11.6
)
    
(8.1
)
Total
  
$
(0.4
)
  
$
13.3
  
 
Other financial income/(expense), net decreased to a net expense of $0.4 million for the six-month period ended June 30, 2022, compared to a net income of $13.3 million for the six-month period ended June 30, 2021.
 
The decrease of other financial income for the six-month period ended June 30, 2022, was mainly due to a lower income related to the mark-to-market of the derivative liability embedded in the Green Exchangeable Notes.
 
Other financial expense includes expenses for guarantees and letters of credit, wire transfers, other bank fees and other minor financial expenses. The increase is primarily due the contribution of the recently acquired assets.
 
Share of profit of associates carried under the equity method
 
Share of profit of associates carried under the equity method increased to $18.3 million for the six-month period ended June 30, 2022, compared to $2.6 million for the six-month period ended June 30, 2021 primarily due to the contribution of Vento II.
 
Profit/(loss) before income tax
 
As a result of the previously mentioned factors, we reported a loss before income tax of $16.8 million for the six-month period ended June 30, 2022, compared to a profit before income tax of $37.6 million for the six-month period ended June 30, 2021.
 
Income tax
 
The effective tax rate for the periods presented has been established based on management’s best estimates. For the six-month period ended June 30, 2022, income tax amounted to an expense of $6.1 million, with a profit before income tax of $16.8 million. For the six-month period ended June 30, 2021, income tax amounted to an expense of $33.1 million, with a profit before income tax of $37.6 million. The effective tax rate differs from the nominal tax rate mainly due to unrecognized tax losses carryforwards and permanent tax differences in some jurisdictions.
 
Profit attributable to non-controlling interests
 
Profit attributable to non-controlling interests was $6.7 million for the six-month period ended June 30, 2022, compared to $11.3 million for the six-month period ended June 30, 2021. Profit attributable to non-controlling interests corresponds to the portion attributable to our partners in the assets that we consolidate (Kaxu, Skikda, Solaben 2 & 3, Solacor 1 & 2, Seville PV, Chile PV 1, Chile PV 2 and Tenes). The decrease is mainly due to losses in our PV assets in Chile which were primarily caused by technical curtailment and lower electricity market prices.
 
60
Profit/(loss) attributable to the parent company

As a result of the previously mentioned factors, profit attributable to the parent company was $4.1 million for the six-month period ended June 30, 2022, compared to a loss of $6.8 million for the six-month period ended June 30, 2021.
 
Segment Reporting
 
We organize our business into the following three geographies where the contracted assets and concessions are located: North America, South America and EMEA. In addition, we have identified four business sectors based on the type of activity: Renewable energy, Efficient natural gas and heat, Transmission and Water. We report our results in accordance with both criteria.
 
Revenue and Adjusted EBITDA by geography
 
The following table sets forth our revenue, Adjusted EBITDA and volumes for the six-month periods ended June 30, 2022 and 2021, by geographic region:
 
Revenue by geography
 
   
Six-month period ended June 30,
  
Revenue by geography
  
2022
    
2021
  
   
$ in
millions
    
%
of revenue
    
$ in
millions
    
%
of revenue
  
North America
  
$
199.3
      
35.9
%
  
$
178.8
      
29.3
%
South America
    
78.3
      
14.1
%
    
78.4
      
12.8
%
EMEA
    
277.7
      
50.0
%
    
354.0
      
57.9
%
Total revenue
  
$
555.3
      
100
%
  
$
611.2
      
100
%

   
Six-month period ended June 30,
  
Adjusted EBITDA by geography
  
2022
    
2021
  
   
$ in
millions
    
Adjusted
EBITDA
Margin (2)
    
$ in
millions
    
Adjusted
EBITDA
Margin (2)
  
North America
  
$
161.2
      
80.8
%
  
$
134.9
      
75.4
%
South America
    
58.8
      
75.1
%
    
60.2
      
76.8
%
EMEA
    
182.3
      
65.6
%
    
209.1
      
59.0
%
Total Adjusted EBITDA(1)
  
$
402.3
      
72.4
%
  
$
404.2
      
66.1
%
Note:
(1)
Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.

61
   
Volume produced/availability
  
   
Six- Month period ended June 30,
  
Volume by geography
  
2022
    
2021
  
       
North America (GWh) (1)
    
2,961
      
2,034
  
North America availability(2)
    
100.1
%
    
99.4
%
South America (GWh) (3)
    
333
      
346
  
South America availability(2)
    
99.9
%
    
99.9
%
EMEA (GWh)
    
604
      
646
  
EMEA availability
    
102.2
%
    
99.7
%
Note:
(1)
GWh produced includes 30% of the production from Monterrey and our 49% of Vento II wind portfolio production since its acquisition.
(2)
Availability includes only those assets that have revenue based on availability.
(3)
Includes curtailment production in wind assets for which we receive compensation.
 
North America
 
Revenue increased by 11.5% to $199.3 million for the six-month period ended June 30, 2022, compared to $178.8 million for the six-month period ended June 30, 2021. The increase was mainly due to the contribution from the recently acquired assets, Coso and Calgary. Revenue also increased at our solar assets in North America, mainly due to higher production at Mojave driven by higher solar radiation. The increase was partially offset by lower revenue at ACT mainly due to lower revenue in the portion of the tariff related to operation and maintenance services, driven by lower operation and maintenance costs for the six-month period ended June 30, 2022.
 
Adjusted EBITDA increased by 19.5% to $161.2 million for the six-month period ended June 30, 2022, compared to $134.9 million for the six-month period ended June 30, 2021 mainly due to the contribution of the recently acquired assets Coso, Calgary and Vento II. This effect was partially offset by lower Adjusted EBITDA at ACT. Adjusted EBITDA margin increased to 80.8% for the six-month period ended June 30, 2022, compared to 75.4% for the six-month period ended June 30, 2021, mainly due to the contribution from Vento II.
 
South America
 
Revenue and Adjusted EBITDA remained stable at $78.3 million and $58.8 million respectively for the six-month period ended June 30, 2022, compared to $78.4 million and $60.2 million for the six-month period ended June 30, 2021. Revenue and Adjusted EBITDA decreased at our wind assets in Uruguay, mainly due to lower wind resource in the second quarter of 2022 and in our PV assets in Chile mainly driven by curtailment in the first quarter of 2022 and lower market prices in Chile. The decrease in revenue and Adjusted EBITDA was partially offset by the contribution from the assets recently acquired La Sierpe and Chile TL4.
 
Adjusted EBITDA margin decreased slightly to 75.1% for the six-month period ended June 30, 2022, compared to 76.8% for the six-month period ended June 30, 2021 mainly due to lower Adjusted EBITDA margins at our wind assets in Uruguay and PV assets in Chile.
 
EMEA
 
Revenue decreased to $277.7 million for the six-month period ended June 30, 2022, which represents a decrease of 21.6% compared to $354.0 million for the six-month period ended June 30, 2021. On a constant currency basis, revenue for the six-month period ended June 30, 2022, was $301.6 million, which represents a decrease of 14.8% compared to the six-month period ended June 30, 2021. Additionally, on a constant currency basis and excluding the non-recurrent solar project accounted for in the first half of 2021 revenue for the six-month period ended June 30, 2022 increased by 1.9%.
 
62
Revenue increased (on a constant currency basis and excluding the non-recurrent solar project) mainly due to the contribution of the recently acquired assets in Italy. Revenue also increased at our solar assets in Spain in spite of lower production, primarily thanks to higher electricity prices net of its corresponding accounting provision (see “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Factors Affecting our Results of Operations—Electricity market prices”). The increase in revenue was also due to higher revenue from Kaxu in spite of lower production primarily due to the indexation of our PPA to local inflation.
 
Adjusted EBITDA decreased to $182.3 million for the six-month period ended June 30, 2022, which represents a decrease of 12.8% compared to $209.1 million for the six-month period ended June 30, 2021. On a constant currency basis, Adjusted EBITDA for the six-month period ended June 30, 2022, was $197.8 million which represents a decrease of 5.4% compared to the six-month period ended June 30, 2021. Additionally, on a constant currency basis and excluding the non-recurrent solar project accounted for in the first half of 2021 Adjusted EBITDA for the six-month period ended June 30, 2022 decreased by 5.0%. This decrease was mainly due to lower Adjusted EBITDA at our solar assets in Spain resulting from the non-recurrent $6.8 million profit recorded in 2021 in “Other operating income” and to higher operating costs, mostly related to higher supplies, as previously mentioned. This decrease was partially offset by the contribution of the recently acquired assets in Italy. Adjusted EBITDA margin increased to 65.6% for the six-month period ended June 30, 2022, compared to 59.0% for the six-month period ended June 30, 2021 mainly due to the non-recurrent solar project previously mentioned, causing lower margin in the first half of 2021.
 
Revenue and Adjusted EBITDA by business sector
 
The following table sets forth our revenue, Adjusted EBITDA and volumes for the six-month periods ended June 30, 2022 and 2021, by business sector:
 
   
Six-month period ended June 30,
  
Revenue by business sector
  
2022
    
2021
  
   
$ in
millions
    
% of
revenue
    
$ in
millions
    
% of
revenue
  
Renewable energy
  
$
420.3
      
75.7
%
  
$
471.6
      
77.2
%
Efficient natural gas & heat
    
53.4
      
9.6
%
    
58.5
      
9.6
%
Transmission lines
    
54.9
      
9.9
%
    
53.6
      
8.8
%
Water
    
26.7
      
4.8
%
    
27.5
      
4.5
%
Total revenue
  
$
555.3
      
100
%
  
$
611.2
      
100
%

63
   
Six-month period ended June 30,
  
   
2022
    
2021
  
   
$ in
millions
    
Adjusted
EBITDA
Margin (2)
    
$ in
millions
    
Adjusted
EBITDA
Margin (2)
  
Renewable energy
  
$
296.8
      
70.6
%
  
$
295.0
      
62.6
%
Efficient natural gas & heat
    
44.0
      
82.4
%
    
47.2
      
80.7
%
Transmission lines
    
43.2
      
78.7
%
    
42.5
      
79.3
%
Water
    
18.3
      
68.5
%
    
19.5
      
70.9
%
Total Adjusted EBITDA(1)
  
$
402.3
      
72.4
%
  
$
404.2
      
66.1
%
Note:
(1)
Adjusted EBITDA is calculated as profit/(loss) for the period attributable to the parent company, after adding back loss/(profit) attributable to non-controlling interest, income tax expense, financial expense (net), depreciation, amortization and impairment charges of entities included in the Consolidated Condensed Interim Financial Statements and depreciation and amortization, financial expense and income tax expense of unconsolidated affiliates (pro-rata of our equity ownership). Adjusted EBITDA is not a measure of performance under IFRS as issued by the IASB and you should not consider Adjusted EBITDA as an alternative to operating income or profits or as a measure of our operating performance, cash flows from operating, investing and financing activities or as a measure of our ability to meet our cash needs or any other measures of performance under generally accepted accounting principles. We believe that Adjusted EBITDA is a useful indicator of our ability to incur and service our indebtedness and can assist securities analysts, investors and other parties to evaluate us. Adjusted EBITDA and similar measures are used by different companies for different purposes and are often calculated in ways that reflect the circumstances of those companies. Adjusted EBITDA may not be indicative of our historical operating results, nor is it meant to be predictive of potential future results. See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Key Financial Measures”.

Volume by business sector

   
Volume produced/availability
  
   
six-month period ended June 30,
  
Volume by business sector
  
2022
    
2021
  
Renewable energy (GWh) (1)
    
2,648
      
1,984
  
Efficient natural gas & heat (GWh) (2)
    
1,251
      
1,043
  
Efficient natural gas & heat availability
    
100.1
%
    
99.4
%
Transmission availability
    
99.9
%
    
99.9
%
Water availability
    
102.2
%
    
99.7
%
Note:
(1)
Includes curtailment production in wind assets for which we receive compensation. Includes our 49% of Vento II wind portfolio production since its acquisition.
(2)
GWh produced includes 30% of the production from Monterrey.
 
Renewable energy
 
Revenue decreased to $420.3 million for the six-month period ended June 30, 2022, which represents a decrease of 10.9% compared to $471.6 million for the six-month period ended June 30, 2021. On a constant currency basis, revenue for the six-month period ended June 30, 2022, was $444.3 million, which represents a decrease of 5.8% compared to the six-month period ended June 30, 2021. Additionally, on a constant currency basis and excluding the non-recurrent solar project accounted for in the first quarter of 2021 revenue for the six-month period ended June 30, 2022 increased by 7.4%. The increase in revenue was primarily due to the contribution from the recently acquired assets Coso, La Sierpe and our PV assets in Italy. Revenue also increased at our solar assets in Spain and in Kaxu, as well as at our solar assets in North America. This increase was partially offset by a decrease in revenue at our wind assets in Uruguay and solar assets in Chile as previously described.
 
64
Adjusted EBITDA increased to $296.8 million for the six-month period ended June 30, 2022, which represents an increase of 0.6% compared to $295.0 million for the six-month period ended June 30, 2021. On a constant currency basis, Adjusted EBITDA for the six-month period ended June 30, 2022, was $313.2 million which represents an increase of 6.2% compared to the six-month period ended June 30, 2021. Additionally, on a constant currency basis and excluding the non-recurrent solar project accounted for in the first quarter of 2021 Adjusted EBITDA increased by 6.6%. Adjusted EBITDA increased mainly due to the increase in Revenue and the contribution of Vento II. This increase was partially offset by lower Adjusted EBITDA at our solar assets in Spain due to the $6.8 million profit recorded in “Other operating income” and higher supply costs, as previously described. Adjusted EBITDA margin increased to 70.6% for the six-month period ended June 30, 2022, from 62.6% for the six-month period ended June 30, 2021, mainly due to the contribution from Vento II and to the non-recurrent solar project previously mentioned, causing lower margin in the first half of 2021.
 
Efficient natural gas & heat
 
Revenue decreased by 8.7% to $53.4 million for the six-month period ended June 30, 2022, compared to $58.5 million for the six-month period ended June 30, 2021, while Adjusted EBITDA decreased by 6.8% to $44.0 million for the six-month period ended June 30, 2022, compared to $47.2 million for the six-month period ended June 30, 2021. Revenue decreased at ACT mainly due to lower operation and maintenance costs, since there is a portion of revenue related to operation and maintenance services plus a margin. At ACT, operation and maintenance costs were higher in 2021 as it happens in the quarters preceding any major maintenance works. This decrease was partially offset by the contribution from the recently acquired asset in Calgary. Adjusted EBITDA decreased for the same reasons. Adjusted EBITDA margin increased to 82.4% for the six-month period ended June 30, 2022, from 80.7% for the six-month period ended June 30, 2021 mainly due to lower operation and maintenance costs at ACT.
 
Transmission lines
 
Revenue and Adjusted EBITDA increased slightly to $54.9 million and $43.2 million respectively for the six-month period ended June 30, 2022 compared to $53.6 million and $42.5 million for the six-month period ended June 30, 2021. The increase in revenue and Adjusted EBITDA was mainly due to the contribution of the recently acquired asset in Chile, Chile TL 4. Adjusted EBITDA margin decreased to 78.7% for the six-month period ended June 30, 2022, from 79.4% for the six-month period ended June 30, 2021 mainly due to lower margin at Chile TL 4.
 
Water
 
Revenue remained stable at $26.7 million for the six-month period ended June 30, 2022, compared to $27.5 million for the six-month period ended June 30, 2021. Adjusted EBITDA also remained stable at $18.3 million for the six-month period ended June 30, 2022, compared to $19.5 million for the six-month period ended June 30, 2021.
 
65
Liquidity and Capital Resources
 
Our principal liquidity and capital requirements consist of the following:
 
•
debt service requirements on our existing and future debt;
 
•
cash dividends to investors; and
 
•
investments in new assets and companies and operations (See “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Recent Investments and Acquisitions”).
 
As a normal part of our business, depending on market conditions, we will from time to time consider opportunities to repay, redeem, repurchase or refinance our indebtedness. Changes in our operating plans, lower than anticipated sales, increased expenses, acquisitions or other events may cause us to seek additional debt or equity financing in future periods. There can be no guarantee that financing will be available on acceptable terms or at all. Debt financing, if available, could impose additional cash payment obligations and additional covenants and operating restrictions. In addition, any of the items discussed in detail under “Item 3.D.—Risk Factors” in our Annual Report and other factors may also significantly impact our liquidity.
 
Liquidity position

   
As of
June 30,
2022
    
As of
December 31,
2021
  
   
($ in millions)
  
Corporate Liquidity
            
Cash and cash equivalents at Atlantica Sustainable Infrastructure, plc, excluding subsidiaries
  
$
123.1
    
$
88.3
  
Revolving Credit Facility availability
    
418.5
      
440.0
  
Total Corporate Liquidity(1)
  
$
541.6
    
$
528.3
  
Liquidity at project companies
                
Restricted Cash
    
227.0
      
254.3
  
Non-restricted cash
    
318.1
      
280.1
  
Total cash at project companies
  
$
545.1
    
$
534.4
  
Note:
(1)
Corporate Liquidity means cash and cash equivalents held at Atlantica Sustainable Infrastructure plc as of June 30, 2022, and available revolver capacity as of June 30, 2022.
 
Cash at the project level includes $227.0 million and $254.3 million restricted cash balances as of June 30, 2022 and December 31, 2021, respectively. Restricted cash consists primarily of funds required to meet the requirements of certain project debt arrangements. In the case of Solana, part of the restricted cash is being used and is expected to be used for equipment replacement. As of December 31, 2021, restricted cash also included Kaxu’s cash balance, given that the project financing of this asset was under a theoretical event of default which was resolved as of March 31, 2022 (see “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Potential Implications of Abengoa developments”).
 
Non-restricted cash at project companies includes among others, the cash that is required for day-to-day management of the companies, as well as amounts that are earmarked to be used for debt service in the future.
 
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As of June 30, 2022, we had $10 million of borrowings under the Revolving Credit Facility and $21.5 million of letters of credit were outstanding. As a result, $418.5 million was available under our Revolving Credit Facility. As of December 31, 2021, we had no borrowings, $10 million of letters of credit were outstanding and $440 million was available under our Revolving Credit Facility.
 
Management believes that the Company’s liquidity position, cash flows from operations and availability under its Revolving Credit Facility will be adequate to meet the Company’s financial commitments and debt obligations; growth, operating and maintenance capital expenditures; and dividend distributions to shareholders. Management continues to regularly monitor the Company’s ability to finance the needs of its operating, financing and investing activities within the guidelines of prudent balance sheet management.
 
Credit Ratings
 
Credit rating agencies rate us and part of our debt securities. These ratings are used by the debt markets to evaluate our credit risk. Ratings influence the price paid to issue new debt securities as they indicate to the market our ability to pay principal, interest and dividends.
 
The following table summarizes our credit ratings as of June 30, 2022. The ratings outlook is stable for S&P and Fitch.
 
 
 S&P
Fitch
Atlantica Sustainable Infrastructure Corporate Rating
BB+
BB+
Senior Secured Debt
BBB-
BBB-
Senior Unsecured Debt
BB
BB+
 
Sources of liquidity
 
We expect our ongoing sources of liquidity to include cash on hand, cash generated from our operations, project debt arrangements, corporate debt and the issuance of additional equity securities, as appropriate, and given market conditions. Our financing agreements consist mainly of the project-level financing for our various assets and our corporate debt financings, including our Green Exchangeable Notes, the Note Issuance Facility 2020, the 2020 Green Private Placement, the Green Senior Notes and the Revolving Credit Facility.
 
         
As of
June 30,
2022
    
As of
December 31,
2021
  
   
Maturity
    
($ in millions)
  
Revolving Credit Facility
  
2024
    
$
8.9
      
-
  
Other Facilities(1)
  
2022-2026
      
47.0
      
41.7
  
Green Exchangeable Notes
  
2025
      
105.6
      
104.3
  
2020 Green Private Placement
  
2026
      
300.5
      
327.1
  
Note Issuance Facility 2020
  
2027
      
143.4
      
155.8
  
Green Senior Notes
  
2028
      
394.6
      
394.2
  
Total Corporate Debt(2)
        
$
1,000.1
    
$
1,023.1
  
Total Project Debt
        
$
4,735.5
    
$
5,036.2
  
Note:
(1)
Other facilities include the commercial paper program issued in October 2020, accrued interest payable and other debts.
(2)
Accounting amounts may differ from notional amounts.

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In the first half of 2022 project debt decreased by $300.7 million mainly due to foreign exchange translation differences for $175.8 million, mainly due the depreciation of the Euro against the U.S. dollar, and to the scheduled repayment of our project debt for $149.4 million.
 
A) Corporate debt agreements
 
Green Senior Notes
 
On May 18, 2021, we issued the Green Senior Notes with an aggregate principal amount of $400 million due in 2028. The Green Senior Notes bear interest at a rate of 4.125% per year, payable on June 15 and December 15 of each year, commencing December 15, 2021, and will mature on June 15, 2028.
 
The Green Senior Notes were issued pursuant to an Indenture, dated May 18, 2021, by and among Atlantica as issuer, Atlantica Peru S.A., ACT Holding, S.A. de C.V., Atlantica Infraestructura Sostenible, S.L.U., Atlantica Investments Limited, Atlantica Newco Limited, Atlantica North America LLC, as guarantors, BNY Mellon Corporate Trustee Services Limited, as trustee, The Bank of New York Mellon, London Branch, as paying agent, and The Bank of New York Mellon SA/NV, Dublin Branch, as registrar and transfer agent.
 
Our obligations under the Green Senior Notes rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Note Issuance Facility 2020 and the Green Exchangeable Notes.
 
Green Exchangeable Notes
 
On July 17, 2020, we issued 4.00% Green Exchangeable Notes amounting to an aggregate principal amount of $100 million due in 2025. On July 29, 2020, we issued an additional $15 million aggregate principal amount in Green Exchangeable Notes. The Green Exchangeable Notes are the senior unsecured obligations of Atlantica Jersey, a wholly owned subsidiary of Atlantica, and fully and unconditionally guaranteed by Atlantica on a senior, unsecured basis. The notes mature on July 15, 2025, unless they are repurchased or redeemed earlier by Atlantica or exchanged, and bear interest at a rate of 4.00% per annum.
 
Noteholders may exchange all or any portion of their notes at their option at any time prior to the close of business on the scheduled trading day immediately preceding April 15, 2025, only during certain periods and upon satisfaction of certain conditions. Noteholders may exchange all or any portion of their notes during any calendar quarter if the last reported sale price of Atlantica’s ordinary shares for at least 20 trading days during a period of 30 consecutive trading days, ending on the last trading day of the immediately preceding calendar quarter is greater than 120% of the exchange price on each applicable trading day. On or after April 15, 2025, until the close of business on the second scheduled trading day immediately preceding the maturity date thereof, noteholders may exchange any of their notes at any time, at the option of the noteholder. Upon exchange, the notes may be settled, at our election, into Atlantica ordinary shares, cash or a combination of both. The initial exchange rate of the notes is 29.1070 ordinary shares per $1,000 of the principal amount of notes (which is equivalent to an initial exchange price of $34.36 per ordinary share). The exchange rate is subject to adjustment upon the occurrence of certain events.
 
Our obligations under the Green Exchangeable Notes rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Note Issuance Facility 2020 and the Green Senior Notes.
 
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Note Issuance Facility 2020
 
On July 8, 2020, we entered into the Note Issuance Facility 2020, a senior unsecured euro-denominated financing with a group of funds managed by Westbourne Capital as purchasers of the notes issued thereunder for a total amount of $146 million (€140 million). The notes under the Note Issuance Facility 2020 were issued on August 12, 2020 and are due on August 12, 2027. Interest accrues at a rate per annum equal to the sum of the 3-month EURIBOR plus a margin of 5.25% with a floor of 0% for the EURIBOR. We have entered into a cap at 0% for the EURIBOR with 3.5 years maturity to hedge the variable interest rate risk.
 
Our obligations under the Note Issuance Facility 2020 rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the 2020 Green Private Placement, the Green Exchangeable Notes and the Green Senior Notes. The notes issued under the Note Issuance Facility 2020 are guaranteed on a senior unsecured basis by our subsidiaries Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC.
 
2020 Green Private Placement
 
On March 20, 2020, we entered into a senior secured note purchase agreement with a group of institutional investors as purchasers providing for the 2020 Green Private Placement. The transaction closed on April 1, 2020 and we issued notes for a total principal amount of €290 million ($303 million), maturing on June 20, 2026. Interest accrues at a rate per annum equal to 1.96%. If at any time the rating of these senior secured notes is below investment grade, the interest rate thereon would increase by 100 basis points until such notes are again rated investment grade.
 
Our obligations under the 2020 Green Private Placement rank equal in right of payment with our outstanding obligations under the Revolving Credit Facility, the Note Issuance Facility 2020 and the Green Senior Notes. Our payment obligations under the 2020 Green Private Placement are guaranteed on a senior secured basis by our subsidiaries Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC. The 2020 Green Private Placement is also secured with a pledge over the shares of the subsidiary guarantors, the collateral of which is shared with the lenders under the Revolving Credit Facility.
 
Revolving Credit Facility
 
On May 10, 2018, we entered into a $215 million Revolving Credit Facility with a syndicate of banks. The Revolving Credit Facility was increased by $85 million to $300 million on January 25, 2019 and was further increased by $125 million (to a total limit of $425 million) on August 2, 2019. On March 1, 2021, this facility was further increased by $25 million (to a total limit of $450 million). On May 5, 2022, the maturity of the Revolving Credit Facility was extended to December 31, 2024. Under the Revolving Credit Facility, we are also able to request the issuance of letters of credit, which are subject to a sublimit of $100 million that are included in the aggregate commitments available under the Revolving Credit Facility.
 
Loans under the Revolving Credit Facility accrue interest at a rate per annum equal to: (A) for eurodollar rate loans, Term SOFR, plus a Term SOFR Adjustment equal to 0.10% per annum, plus a percentage determined by reference to our leverage ratio, ranging between 1.60% and 2.25% and (B) for base rate loans, the highest of (i) the rate per annum equal to the weighted average of the rates on overnight U.S. Federal funds transactions with members of the U.S. Federal Reserve System arranged by U.S. federal funds brokers on such day plus ½ of 1.00%, (ii) the prime rate of the administrative agent under the Revolving Credit Facility and (iii) Term SOFR plus 1.00%, in any case, plus a percentage determined by reference to our leverage ratio, ranging between 0.60% and 1.00%.
 
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Our obligations under the Revolving Credit Facility rank equal in right of payment with our outstanding obligations under the 2020 Green Private Placement, the Note Issuance Facility 2020, the Green Exchangeable Notes and the Green Senior Notes. Our payment obligations under the Revolving Credit Facility are guaranteed on a senior secured basis by Atlantica Infraestructura Sostenible, S.L.U., Atlantica Peru, S.A., ACT Holding, S.A. de C.V., Atlantica Investments Limited, Atlantica Newco Limited and Atlantica North America LLC. The Revolving Credit Facility is also secured with a pledge over the shares of the subsidiary guarantors, the collateral of which is shared with the holders of the notes issued under the 2020 Green Private Placement.
 
Other Credit Lines
 
In July 2017, we signed a line of credit with a bank for up to €10.0 million ($10.4 million) which was available in euros or U.S. dollars. Amounts drawn accrue interest at a rate per annum equal to the sum of the 3-month EURIBOR or LIBOR, plus a margin of 2%, with a floor of 0% for the EURIBOR or LIBOR. As of June 30, 2022, we had $9.4 million drawn under this line of credit. On July 1, 2022, the maturity has been extended to July 1, 2024.
 
In December 2020 and January 2022, we also entered into two different loans with banks for €5 million ($5.2 million) each. The maturity dates are December 4, 2025 and January 31, 2026, respectively, and they accrue interest at a rate per annum equal to 2.50% and 1.90%, respectively.
 
Commercial Paper Program
 
On October 8, 2019, we filed a euro commercial paper program with the Alternative Fixed Income Market (MARF) in Spain. The program had an original maturity of twelve months and has been extended twice, for annual periods. The program allows Atlantica to issue short term notes for up to €50 million, with such notes having a tenor of up to two years. As of June 30, 2022, we had €22.8 million ($23.8 million) issued and outstanding under the Commercial Paper Program at an average cost of 0.39%.
 
Covenants, restrictions and events of default
 
The Note Issuance Facility 2020, the 2020 Green Private Placement, the Green Senior Notes and the Revolving Credit Facility contain covenants that limit certain of our and the guarantors’ activities. The Note Issuance Facility 2020, the 2020 Green Private Placement and the Green Exchangeable Notes also contain customary events of default, including a cross-default with respect to our indebtedness, indebtedness of the guarantors thereunder and indebtedness of our material non-recourse subsidiaries (project-subsidiaries) representing more than 25% of our cash available for distribution distributed in the previous four fiscal quarters, which in excess of certain thresholds could trigger a default. Additionally, under the 2020 Green Private Placement, the Revolving Credit Facility and the Note Issuance Facility 2020 we are required to comply with a leverage ratio of our corporate indebtedness excluding non-recourse project debt to our cash available for distribution of 5.00:1.00 (which may be increased under certain conditions to 5.50:1.00 for a limited period in the event we consummate certain acquisitions).
 
B) At-The-Market Program
 
On February 28, 2022, we established an “at-the-market program” and entered into the Distribution Agreement with BofA Securities, Inc., MUFG Securities Americas Inc. and RBC Capital Markets LLC, as our sales agents, under which we may offer and sell from time to time up to $150 million of our ordinary shares, including in “at-the-market” offerings under our shelf registration statement on Form F-3 filed with the SEC on August 3, 2021, and a prospectus supplement that we filed on February 28, 2022. During the first half of 2022, we issued and sold 2,615,895 ordinary shares under such program at an average market price of $33.45 per share pursuant to our Distribution Agreement, representing gross proceeds of $87.5 million and net proceeds of $86.6 million.
 
70
Uses of liquidity and capital requirements
 
Cash dividends to investors
 
We intend to distribute a significant portion of our cash available for distribution to shareholders on an annual basis less all cash expenses including corporate debt service and corporate general and administrative expenses and less reserves for the prudent conduct of our business (including, among other things, dividend shortfall as a result of fluctuations in our cash flows), on an annual basis. We intend to distribute a quarterly dividend to shareholders. Our board of directors may, by resolution, amend the cash dividend policy at any time. The determination of the amount of the cash dividends to be paid to shareholders will be made by our board of directors and will depend upon our financial condition, results of operations, cash flow, long-term prospects and any other matters that our board of directors deem relevant.
 
Our cash available for distribution is likely to fluctuate from quarter to quarter and, in some cases, significantly as a result of the seasonality of our assets, the terms of our financing arrangements, maintenance and outage schedules, among other factors. Accordingly, during quarters in which our projects generate cash available for distribution in excess of the amount necessary for us to pay our stated quarterly dividend, we may reserve a portion of the excess to fund cash distributions in future quarters. During quarters in which we do not generate sufficient cash available for distribution to fund our stated quarterly cash dividend, if our board of directors so determines, we may use retained cash flow from other quarters, and other sources of cash.
 
The latest dividends paid and declared are presented below:
 
Declared
  
Record Date
  
Payment Date
  
$ per share
  
May 4, 2021
  
May 31, 2021
  
June 15, 2021
    
0.43
  
July 30, 2021
  
August 31, 2021
  
September 15, 2021
    
0.43
  
November 9, 2021
  
November 30, 2021
  
December 15, 2021
    
0.435
  
February 25, 2022
  
March 14, 2022
  
March 25, 2022
    
0.44
  
May 5, 2022
  
May 31, 2022
  
June 15, 2022
    
0.44
  
August 3, 2022
  
August 31, 2022
  
September 15, 2022
  
0.445
  
 
Investments and Acquisitions
 
The acquisitions and investments detailed in “Item 2—Management’s Discussion and Analysis of Financial Condition and Results of Operations—Recent Investments and Acquisitions” have been part of the use of our liquidity in 2021 and 2022. In addition, we have made investments in assets which are currently under development or construction. We expect to continue making investments in assets in operation or under construction or development to grow our portfolio.
 
Our uses of liquidity also include debt service and contractual obligations (refer to our Annual Report for further detail).
 
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Cash flow
 
The following table sets forth cash flow data for the six-month periods ended June 30, 2022 and 2021:
 
   
Six-month period ended June 30,
  
   
2022
    
2021
  
   
($ in millions)
  
Gross cash flows from operating activities
            
Profit for the period
  
$
10.8
    
$
4.5
  
Financial expense and non-monetary adjustments
    
384.9
      
396.1
  
Profit for the period adjusted by non-monetary items
  
$
395.7
    
$
400.6
  
                 
Changes in working capital
  
$
(2.3
)
  
$
9.4
  
Net interest and income tax paid
    
(129.3
)
    
(163.7
)
Net cash provided by operating activities
  
$
264.1
    
$
246.3
  
                 
Net cash used in investing activities
  
$
(30.7
)
  
$
(327.0
)
                 
Net cash provided by / used in financing activities
  
$
(167.4
)
  
$
(96.7
)
                 
Net increase in cash and cash equivalents
    
66.0
      
(177.4
)
Cash and cash equivalents at beginning of the period
    
622.7
      
868.5
  
Translation differences in cash or cash equivalents
    
(20.5
)
    
(4.8
)
Cash and cash equivalents at the end of the period
  
$
668.2
    
$
686.3
  
 
Net cash provided by operating activities
 
For the six-month period ended June 30, 2022, net cash provided by operating activities was $264.1 million, a 7.2% increase compared to $246.3 million in the six-month period ended June 30, 2021. The increase was largely due to lower net interest and income tax paid in the first half of 2022 compared to the same period of the previous year. Interest paid typically decrease in each asset as we progressively repay our project debt.
 
Net cash used in investing activities
 
For the six-month period ended June 30, 2022, net cash used in investing activities amounted to $30.7 million and corresponded mainly to $42.0 million paid for acquisitions consisting mainly of Chile TL4 and Italy PV4, investments in assets under construction for $22.1 million and other investments in concessional assets for $10.3 million. These cash outflows were partially offset by $43.8 million of dividends received from associates under the equity method, of which $13.9 million corresponded to Amherst Island Partnership by AYES Canada, most of which were paid to our partner in this project.
 
For the six-month period ended June 30, 2021, net cash used in investing activities amounted to $327.0 million and corresponded mainly to $323.1 million paid for the acquisitions of Vento II, Coso, Calgary, Chile PV2 and Rioglass, investments in assets under construction for $1.6 million and other investments in concessional assets for $16.6 million, mainly corresponding to maintenance capital expenditure and equipment replacements in Solana. These cash outflows were partially offset by $13.2 million of dividends received from Amherst Island Partnership by AYES Canada, most of which were paid to our partner in this project.
 
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Net cash provided by/ (used in) financing activities
 
For the six-month period ended June 30, 2022, net cash used in financing activities amounted to $167.4 million and includes the repayment of principal of our project financing for $156.3 million and dividends paid to shareholders for $99.9 million and non-controlling interests for $16.0 million. These cash outflows were partially offset by the proceeds from the equity raised under the at-the-market programs for a net amount of $86.2 million, net of transaction costs and the net increase in our corporate debt for $18.7 million, corresponding mainly to the net borrowings under our Revolving Credit Facility for $10 million.
 
For the six-month period ended June 30, 2021, net cash used in financing activities amounted to $96.7 million and includes the repayment of principal of our project financing agreements for an amount of $164.4 and $105.8 million of dividends paid to shareholders and non-controlling interests. These cash outflows were partially offset by the proceeds from the equity private placement closed in January 2021 for a net amount of $130.6 million. In addition, in the second quarter of 2021 we prepaid the Note Issuance Facility 2019, a senior unsecured note facility, for $354.2 with the proceeds of the Green Senior Notes, amounting to $394.0 million, which created a net cash inflow of $32.9 million.
 
Item 3.
Quantitative and Qualitative Disclosure about Market Risk
 
Our activities are undertaken through our segments and are exposed to market risk, credit risk and liquidity risk. Risk is managed by our Risk Management and Finance Departments in accordance with mandatory internal management rules. The internal management rules provide written policies for the management of overall risk, as well as for specific areas, such as exchange rate risk, interest rate risk, credit risk, liquidity risk, use of hedging instruments and derivatives and the investment of excess cash.
 
Market risk
 
We are exposed to market risk, such as movement in foreign exchange rates and interest rates. All of these market risks arise in the normal course of business and we do not carry out speculative operations. For the purpose of managing these risks, we use swaps and options on interest rates and foreign exchange rates. None of the derivative contracts signed has an unlimited loss exposure.
 
Foreign exchange risk
 
The main cash flows from our subsidiaries are cash collections arising from long-term contracts with clients and debt payments arising from project finance repayment. Given that financing of the projects is generally denominated in the same currency in which the contract with the client is signed, a natural hedge exists for our main operations.
 
Our functional currency is the U.S. dollar, as most of our revenue and expenses are denominated or linked to U.S. dollars. All our companies located in North America and most of our companies in South America have their revenue and financing contracts signed in, or indexed totally or partially to, U.S. dollars, with the exception of Calgary, with revenue in Canadian dollars. Our solar power plants in Europe have their revenue and expenses denominated in euros, Kaxu, our solar plant in South Africa, has its revenue and expenses denominated in South African rand and La Sierpe, our solar plant in Colombia, has its revenue and expenses denominated in Colombian pesos. Project financing is typically denominated in the same currency as that of the contracted revenue agreement. This policy seeks to ensure that the main revenue and expenses streams in foreign companies are denominated in the same currency, limiting our risk of foreign exchange differences in our financial results.
 
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Our strategy is to hedge cash distributions from our assets in Europe. We hedge the exchange rate for the distributions in euros after deducting euro-denominated interest payments and euro-denominated general and administrative expenses. Through currency options, we have hedged 100% of our euro-denominated net exposure for the next 12 months and 75% of our euro-denominated net exposure for the following 12 months. We expect to continue with this hedging strategy on a rolling basis.
 
Although we hedge cash-flows in euros, fluctuations in the value of the euro in relation to the U.S. dollar may affect our operating results. For example, revenue in euro-denominated companies could decrease when translated to U.S. dollars at the average foreign exchange rate solely due to a decrease in the average foreign exchange rate, in spite of revenue in the original currency being stable. Fluctuations in the value of the South African rand and the Colombian peso with respect to the U.S. dollar may also affect our operating results. Apart from the impact of these translation differences, the exposure of our income statement to fluctuations of foreign currencies is limited, as the financing of projects is typically denominated in the same currency as that of the contracted revenue agreement.
 
Interest rate risk
 
Interest rate risk arises mainly from our financial liabilities at variable interest rate (less than 10% of our total project debt financing). We use interest rate swaps and interest rate options (caps) to mitigate interest rate risk.
 
As a result, the notional amounts hedged as of June 30, 2022, contracted strikes and maturities, depending on the characteristics of the debt on which the interest rate risk is being hedged, are very diverse, including the following:
 
•
Project debt in euro: between 75% and 100% of the notional amount, with hedged maturing until 2038 at an average guaranteed strike interest rates of between 0.00% and 4.87%.
 
•
Project debt in U.S. dollars: between 75% and 100% of the notional amount, with hedges maturing until 2038 and average strike interest rates of between 0.86% and 5.89%.
 
The most significant impact on our Consolidated Condensed Interim Financial Statements related to interest rates corresponds to the potential impact of changes in EURIBOR or LIBOR on the debt with interest rates based on EURIBOR or LIBOR and on derivative positions.
 
In relation to our interest rate swaps positions, an increase in EURIBOR or LIBOR above the contracted fixed interest rate would create an increase in our financial expense which would be positively mitigated by our hedges, reducing our financial expense to our contracted fixed interest rate. However, an increase in EURIBOR or LIBOR that does not exceed the contracted fixed interest rate would not be offset by our derivative position and would result in a net financial loss recognized in our consolidated income statement. Conversely, a decrease in EURIBOR or LIBOR below the contracted fixed interest rate would result in lower interest expense on our variable rate debt, which would be offset by a negative impact from our hedges, increasing our financial expense up to our contracted fixed interest rate, thus likely resulting in a neutral effect.
 
In relation to our interest rate options positions, an increase in EURIBOR or LIBOR above the strike price would result in higher interest expenses, which would be positively mitigated by our hedges, reducing our financial expense to our capped interest rate, whereas a decrease of EURIBOR or LIBOR below the strike price would result in lower interest expenses.
 
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In addition to the above, our results of operations can be affected by changes in interest rates with respect to the unhedged portion of our indebtedness that bears interest at floating rates.
 
In the event that EURIBOR and LIBOR had risen by 25 basis points as of June 30, 2022, with the rest of the variables remaining constant, the effect in the consolidated income statement would have been a loss of $1.8 million and an increase in hedging reserves of $18.5 million. The increase in hedging reserves would be mainly due to an increase in the fair value of interest rate swaps designated as hedges.
 
Credit risk
 
The credit rating of Eskom is currently CCC+ from S&P, Caa1 from Moody’s and B from Fitch. Eskom is the off-taker of our Kaxu solar plant, a state-owned, limited liability company, wholly owned by the government of the Republic of South Africa. Eskom’s payment guarantees to our Kaxu solar plant are underwritten by the South African Department of Energy, under the terms of an implementation agreement. The credit ratings of the Republic of South Africa as of the date of this report are BB-/Ba2/BB- by S&P, Moody’s and Fitch, respectively.
 
In addition, Pemex’s credit rating is currently BBB from S&P, Ba3 from Moody’s and BB- from Fitch. We have been experiencing delays from Pemex in collections since the second half of 2019 which have been significant in certain quarters.
 
In 2019, we also entered into a political risk insurance agreement with the Multinational Investment Guarantee Agency for Kaxu. The insurance provides protection for breach of contract up to $58.0 million in the event the South African Department of Energy does not comply with its obligations as guarantor. We also have a political risk insurance in place for our assets in Algeria up to $38.3 million, including two years dividend coverage. These insurance policies do not cover credit risk.
 
Liquidity risk
 
The objective of our financing and liquidity policy is to ensure that we maintain sufficient funds to meet our financial obligations as they fall due.
 
Project finance borrowing permits us to finance projects through project debt and thereby insulate the rest of our assets from such credit exposure. We incur project finance debt on a project-by-project basis.
 
The repayment profile of each project is established based on the projected cash flow generation of the business.
 
Item 4.
CONTROLS AND PROCEDURES
 
Not Applicable
 
PART II. OTHER INFORMATION
 
Item 1.
Legal Proceedings
 
In 2018, an insurance company covering certain Abengoa obligations in Mexico claimed certain amounts related to a potential loss. Atlantica reached an agreement under which Atlantica’s maximum theoretical exposure would in any case be limited to approximately $35 million, including $2.5 million to be held in an escrow account. In January 2019, the insurance company called on this $2.5 million from the escrow account and Abengoa reimbursed us for this amount. The insurance company could claim additional amounts if they faced new losses after following a process agreed between the parties and, in any case, Atlantica would only make payments if and when the actual loss has been confirmed and after arbitration if the Company initiates it. In the past we had indemnities from Abengoa for certain potential losses, but such indemnities are no longer valid following the insolvency filing by Abengoa S.A. in February 2021.
 
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In addition, during 2021 and 2022, several lawsuits were filed related to the February 2021 winter storm in Texas against among others Electric Reliability Council of Texas (“ERCOT”), two utilities in Texas and more than 230 individual power generators, including Post Oak Wind, LLC, the project company owner of Lone Star I, one of the wind assets in Vento II where we currently have a 49% equity interest. The basis for the lawsuits is that the defendants, among other things, failed to properly prepare for cold weather, including failure to implement measures and equipment to protect against cold weather, and failed to properly conduct their operations before and during the storm.
 
Atlantica is not a party to any other significant legal proceedings Atlantica is party to various administrative and regulatory proceedings that have arisen in the ordinary course of business.
 
While Atlantica does not expect the above noted proceedings, either individually or in combination, to have a material adverse effect on its financial position or results of operations, because of the nature of these proceedings Atlantica is not able to predict their ultimate outcomes, some of which may be unfavorable to Atlantica.
 
Item 1A.
Risk Factors
 
None
 
Item 2.
Unregistered Sales of Equity Securities and Use of Proceeds
 
Recent sales of unregistered securities
 
None.
 
Use of proceeds from the sale of registered securities
 
None.
 
Purchases of equity securities by the issuer and affiliated purchasers
 
None
 
Item 3.
Defaults Upon Senior Securities
 
None.
 
Item 4.
Mine Safety Disclosures
 
Not applicable.
 
Item 5.
Other Information
 
Not Applicable.
 
Item 6
Exhibits
 
Not Applicable.
 
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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

Date: August 3, 2022
   
    
 
ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC
   
   
By:
/s/ Santiago Seage
     
Name:
Santiago Seage
     
Title:
Chief Executive Officer

   
ATLANTICA SUSTAINABLE INFRASTRUCTURE PLC
         


 
By:
/s/ Francisco Martinez-Davis
       
Name:
Francisco Martinez-Davis
       
Title:
Chief Financial Officer


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