UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM
(Mark One)
| Registration statement pursuant to section 12(b) or 12(g) of the Securities Exchange Act of 1934 |
or
| Transition report pursuant to section 13 or 15(d) of the Securities Exchange Act of 1934 |
For the transition period from to
or
| Annual report pursuant to section 13 or 15(d) of the Securities Exchange Act of 1934 |
For the fiscal year ended
or
| Shell company report pursuant to section 13 or 15(d) of the Securities Exchange Act of 1934 |
Date of event requiring this shell company report
Commission file number
(Exact name of Registrant as specified in its charter)
(Jurisdiction of Incorporation or Organization)
Telephone: (91-11) 49409800
(Address and Telephone Number of Principal Executive Offices)
Telephone:
Sugata Sircar, Group Chief Financial Officer
5th Floor, Southern Park, D-II, Saket Place, Saket, New Delhi 110017, India
Telephone: +91-11 49409800, Fax: +91- 11 49409807, e-mail: sugata.sircar@azurepower.com
(Name, Telephone, email and/or Facsimile Number and Address of Company Contact Person)
Securities registered or to be registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading symbol(s) | Name of each exchange on which registered | ||
Securities registered or to be registered pursuant to Section 12(g) of the Act.
None
(Title of Class)
Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act.
None
(Title of Class)
As of March 31,
2022,
Indicate by
check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes
☐
If this annual
report is an annual or transition report, indicate by check mark if the registrant is not required to file reports pursuant to Section 13
or 15(d) of the Securities Exchange Act of 1934. Yes ☐
Indicate by
check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its
internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public
accounting firm that prepared or issued its audit report.
If securities are registered pursuant
to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect
the correction of an error to previously issued financial statements.
Indicate by check mark whether any of those error corrections are restatements that are required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to §240.10D-1(b). ☐
Indicate
by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the
Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file
such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☐
Indicate by
check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405
of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required
to submit such files). Yes ☐
Indicate by check mark whether the registrant is a large, accelerated filer, an accelerated filer or an emerging growth company. See the definitions of “large, accelerated filer”, “accelerated filer” and “emerging growth company” in Rule 12b-2 of the Exchange Act. (Check one):
| Large, accelerated filer ☐ | Non-accelerated filer ☐ | Emerging Growth Company |
If an emerging growth company that prepares its financial statements in accordance with U.S. GAAP, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark which basis of accounting the registrant has used to prepare the financial statements included in this filing:
| International Financial Reporting Standards as issued by the International Accounting Standards Board ☐ | Other ☐ |
If “Other” has been checked in the previous question, indicate by check mark which financial statement item the registrant has elected to follow. Item 17 ☐ Item 18 ☐
If this is an
annual report, indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Securities Exchange Act
of 1934). Yes ☐ No
(APPLICABLE ONLY TO ISSUERS INVOLVED IN BANKRUPTCY PROCEEDINGS DURING THE PAST FIVE YEARS)
Indicate by check mark whether the registrant has filed all documents and reports required to be filed by Sections 12, 13 or 15(d) of the Securities Exchange Act of 1934 subsequent to the distribution of securities under a plan confirmed by a court: Yes ☐ No ☐
| (1) | As of July 13, 2023, the NYSE suspended trading in and announced the delisting of our shares. We are appealing this decision. Refer to “Risk Factors — The New York Stock Exchange (NYSE) has commenced procedures to delist our Company’s shares and our failure to timely file periodic reports with the SEC may result in the delisting of our Company’ shares” section of this document for further details. |
TABLE OF CONTENTS
FORM 20-F CROSS-REFERENCE GUIDE
| Item # | Form 20-F caption | Location in this Report | Page |
| Conventions used in the Annual report | Conventions used in this Annual Report | 5 | |
| Special note regarding FORWARD-LOOKING INFORMATION | Forward-Looking Statements | 7 | |
| 1 | Identity of directors, senior management and advisers | Not applicable | - |
| 2 | Offer statistics and expected timetable | Not applicable | - |
| 3 | Key information | ||
| 3A. [Reserved] | - | ||
| 3B. Capitalization and Indebtedness | Not applicable | - | |
| 3C. Reasons for the Offer and Use of Proceeds | Not applicable | - | |
| 3D. Risk Factors | Risk Factors | 118 | |
| 4 | Information on the Company | ||
| 4A. History and Development of the Company | Business Overview, Company Overview | 8, 14 | |
| 4B. Business Overview | Business Overview, Company Overview, Industry Overview | 8, 14, 18 | |
| 4C. Organizational Structure | Company Overview | 14 | |
| 4D. Property, Plants and Equipment | Overview | 31 | |
| 4A | Unresolved staff comments | Unresolved SEC Staff comments | 138 |
| 5 | Operating and financial review and prospects | ||
| 5A. Operating Results | Results of Operations | 51 | |
| 5B. Liquidity and Capital Resources | Liquidity and Capital Resources | 57 | |
| 5C. Research and Development, Patents and Licenses, etc. | Not applicable | - | |
| 5D. Trend Information | Trend Information | 51 | |
| 5E. Critical Accounting Estimates | Critical Accounting Policies and Estimates | 63 | |
| 6 | Directors, senior management and employees | ||
| 6A. Directors and Senior Management | Management | 72 | |
| 6B. Compensation | Management Compensation | 79 | |
| 6C. Board Practices | Board Practices, Board Committees | 77, 82 | |
| 6D. Employees | Employees | 86 | |
| 6E. Share Ownership | Major Shareholders | 65 | |
| 7 | Major shareholders and related party transactions | ||
| 7A. Major Shareholders | Major Shareholders | 65 | |
| 7B. Related Party Transactions | Related Party Transactions | 66 | |
| 7C. Interest of Experts and Counsel | Not applicable | - | |
| 8 | Financial information | ||
| 8A. Consolidated Statements and Other Financial Information | Financial statements, Legal Proceedings, Distribution | F-1, 118 | |
| 8B. Significant Changes | Significant Changes | 68 | |
| 9 | The offer and listing | ||
| 9A. Offer and Listing Details | Trading Markets | 69 | |
| 9B. Plan of Distribution | Not applicable | - | |
| 9C. Markets | Trading Markets | 69 | |
| 9D. Selling Shareholders | Not applicable | - | |
| 9E. Dilution | Not applicable | - | |
| 9F. Expenses of the Issue | Not applicable | - | |
| 10 | Additional information | ||
| 10A. Share Capital | Bylaws | 121 | |
| 10B. Memorandum and Articles of Association | Bylaws | 121 |
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| 10C. Material Contracts | Material Contracts | 122 | |
| 10D. Exchange Controls | Exchange Controls and Other Limitations Affecting Security Holders | 123 | |
| 10E. Taxation | Taxation | 124 | |
| 10F. Dividends and Paying Agents | Not applicable | - | |
| 10G. Statements by Experts | Not applicable | - | |
| 10H. Documents on Display | Information Filed with Securities Regulators | 136 | |
| 10I. Subsidiary Information | Not applicable | - | |
| 11 | Quantitative and qualitative disclosures about market risk | ||
| 11a. Quantitative information about market risk | Quantitative and Qualitative information about market risk | 128 | |
| 11b. Qualitative information about market risk | Quantitative and Qualitative information about market risk | 128 | |
| 11c. Interim Period | Not applicable | - | |
| 12 | Description of securities other than equity securities | ||
| 12A. Debt Securities | Not applicable | - | |
| 12B. Warrants and Rights | Not applicable | - | |
| 12C. Other Securities | Not applicable | - | |
| 12D. American Depositary Shares | Not applicable | - | |
| 13 | Defaults, dividend arrearages and delinquencies | Liquidity and Capital Resources | 57 |
| 14 | Material modifications to the right of security holders and use of proceeds | Material Modifications to the Rights of Security Holders and Use of Proceeds | 71 |
| 15 | Control and procedures | ||
| 15a. Disclosure Controls and Procedures | Controls and Procedures | 130 | |
| 15b. Management’s Report on Internal Control over Financial Reporting | Controls and Procedures | 130 | |
| 15c. Attestation Report of the Registered Public Accounting Firm | Controls and Procedures | 130 | |
| 15d. Changes in Internal Control over Financial Reporting | Controls and Procedures | 130 | |
| 16 | [Reserved] | ||
| 16A | Audit committee financial expert | Board Committees | 82 |
| 16B | Code of ethics | Whistle-Blower Policy | 133 |
| 16C | Principal accountant fees and services | Principal accountant fees and services | 134 |
| 16D | Exemptions from the listing standards for audit committees | Board Committees; Corporate Governance | 82, 132 |
| 16E | Purchase of equity securities by the issuer and affiliated purchasers | Not applicable | - |
| 16F | Change in registrant’s certifying accountant | Principal Accountant Fees and Services | 134 |
| 16G | Corporate Governance | Corporate Governance | 133 |
| 16H | Mine safety disclosure | Not applicable | - |
| 16I | Disclosures Regarding Foreign Jurisdictions that Prevent Inspections | Not applicable | - |
| 17 | Financial statements | Not applicable | - |
| 18 | Financial statements | Financial statements | F-1 |
| 19 | Exhibits | Exhibits | 139 |
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CONVENTIONS USED IN THIS ANNUAL REPORT
Except where the context requires otherwise and for purposes of this annual report only:
| “Our Company”, “the Company”, “APGL”, or “Azure Power” refers to Azure Power Global Limited on a standalone basis |
| “We”, “us”, “the Group”, “Azure” or “our” refers to Azure Power Global Limited, a company organized under the laws of Mauritius, together with its subsidiaries (including Azure Power Rooftop Private Limited (“AZR”), and Azure Power India Private Limited, or APIPL, its predecessor and current subsidiaries) |
| “ALMM” refers to Approved List of Models & Manufacturers |
| “APDC” refers to Assam Power Distribution Company |
| “APERC” refers to Andhra Pradesh Electricity Regulatory Commission |
| “APTEL” refers to Appellate Tribunal for Electricity |
| “Awarded” refers to the capacity won and for which LOA has been received |
| “APIPL” a company organized under the laws of India, refers to Azure Power India Private Limited |
| “BM” refers to Biomass |
| “BOS’ refers to Balance of System |
| “CAGR” refers to compounded annual growth rate |
| “CDPQ” refers to Caisse de dépôt et placement du Québec |
| “CDPQ Infrastructures” refers to CDPQ Infrastructures Asia Pte Ltd. |
| “CEA” refers to Central Electricity Authority |
| “CEO” refers to Chief Executive Officer |
| “CERC” refers to the Central Electricity Regulatory Commission of India, the state level counterparts of which are referred to as “State Electricity Regulatory Commission”, or “SERC” |
| “Contracted” refers to capacity won and for which PPA has been signed with offtaker |
| “COO” refers to Chief Operating Officer |
| “COP-26” refers to 26th UN Climate Change Conference of the Parties in Glasgow |
| “COVID-19” refers to novel coronavirus disease of 2019 |
| “CPSU” refers to Central Public Sector Undertaking |
| “CSR” refers to Corporate Social Responsibility |
| “CTU” refers to Central Transmission Utility |
| “CUF” refers to Capacity Utilization Factor |
| “Discom” refers to Distribution Company |
| “DSM” refers to Deviation Settlement Mechanism |
| “E&S” refers to Environmental & Social |
| “EPC” refers to Engineering, Procurement and Construction |
| “ERM” refers to Enterprise Risk Management |
| “ESG” refers to Environmental, Social, and Governance |
| “FDI” refers to Foreign Direct Investment |
| “FIFP” refers to Foreign Investment Facilitation Portal |
| “GBC” refers to Global Business Company |
| “GDP” refers to Gross Domestic Product |
| “GEC” refers to Green Energy Corridor |
| “GH/GA” refers to Green Hydrogen/ Green Ammonia |
| “GIB” refers to Great Indian Bustard |
| “GoI” refers to Government of India |
| “GST” refers to Goods and Service Tax |
| “GW” refers to Gigawatt |
| “INR”, “rupees”, or “Indian rupees” refers to the legal currency of India |
| “IREDA” refers to Indian Renewable Energy Development Agency Limited |
| “ISTS” refers to Inter State Transmission System |
| “KERC” refers to Karnataka Electricity Regulatory Commission |
| “LTI” refers to Lost Time Injury |
| “LOA” refers to Letter of Award |
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| “LPSC” refers to Late Payment Surcharge |
| “MNRE” refers to Ministry of New and Renewable Energy, Government of India. |
| “MOP” refers to Ministry of Power, Government of India |
|
“MSEDCL” refers to Maharashtra State Electricity Distribution Co. Limited “MSPA” refers to the Restated Master Share Purchase Agreement between us and Radiance |
| “Mt” refers to million tonnes |
| “MVN” refers to Mega Volt Ampere |
| “MW” refers to Megawatt |
| “NAPCC” refers to National Action Plan on Climate Change |
| “NISE” refers to National Institute of Solar Energy |
| “NIWE” refers to National Institute of Wind Energy |
| “NSM” refers to the Jawaharlal Nehru National Solar Mission. |
| “NTP” refers to National Tariff Policy |
| “NTPC” refers to NTPC Limited |
| “NVVNL” refers to NTPC Vidyut Vyapar Nigam Limited |
| “NYSE” refers to New York Stock Exchange |
| “O&M” refers to Operation and Maintenance |
| “OMERS” refers to OMERS Infrastructure Asia Holdings Pte. Ltd. |
| “PFIC” refers to Passive Foreign Investment Company |
| “PIL” refers to Public Interest Litigation |
| “PLI” refers to Production Linked Incentive |
|
“PPA” refers to Power Purchase Agreement “PSA” refers to Power Sale Agreement |
| “PSERC” refers to Punjab State Electricity Regulatory Commission |
| “PSPCL” refers to Punjab State Power Corporation Limited |
| “PV” refers to Photovoltaic |
| “Radiance” refers to Radiance Renewables Private Limited |
| “RBI” refers to Reserve Bank of India |
| “RPO” refers to Renewable Purchase Obligation |
| “SEC” refers to the U.S. Securities and Exchange Commission |
| “SECI” refers to Solar Energy Corporation of India |
| “U.S. GAAP” refers to the Generally Accepted Accounting Principles in the United States |
| “US$”, “$” or “U.S. dollars” refers to the legal currency of the United States |
| “VGF” refers to Viability Gap Funding |
In this annual report, references to “U.S.” or the “United States” are to the United States of America, its territories and possessions, any State of the United States and the District of Columbia. References to “India” are to the Republic of India, its territories and its possessions. References to “Mauritius” are to the Republic of Mauritius.
Unless otherwise indicated, the consolidated financial statements and related notes included in this annual report have been presented in Indian rupees and prepared in accordance with U.S. GAAP. References to a particular “Fiscal”, “fiscal”, “fiscal year” or “FY” are to our fiscal year ended March 31 of that year, which is typical in our industry and in the jurisdictions in which we operate.
This annual report contains translations of certain Indian rupee amounts into U.S. dollars at specified rates solely for the convenience of the reader. Unless otherwise stated, the translation of Indian rupees into U.S. dollars has been made at INR 75.87 to US$1.00, which is the noon buying rate in New York City for cable transfer in non-U.S. currencies as certified for customs purposes by the Federal Reserve Bank of New York on March 31, 2022. We make no representation that the Indian rupee or U.S. dollar amounts referred to in this annual report could have been converted into U.S. dollars or Indian rupees, as the case may be, at any particular rate or at all.
As used in this annual report, all references to watts (e.g., megawatts, gigawatts, kilowatt hour, terawatt hour, MW, GW, kWh, etc.) refer to measurements of power generated.
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Forward-Looking Statements
This annual report contains forward looking statements about our current expectations and views of future events. All statements, other than statements of historical facts, contained in this annual report, including statements about our strategy, future operations, future financial position, future revenues, projected costs, prospects, plans and future megawatt goals of management, are forward looking statements. These statements relate to events that involve known and unknown risks, uncertainties and other factors, including those listed under “Risk Factors,” which may cause our actual results, performance or achievements to be materially different from any future results, performance or achievements expressed or implied by the forward-looking statements. In some cases, these forward-looking statements can be identified by words or phrases such as “may,” “will,” “expect,” “anticipate,” “aim,” “estimate,” “intend,” “plan,” “believe,” “potential,” “continue,” “is/are likely to” or other similar expressions.
These forward-looking statements are subject to risks, uncertainties and assumptions, some of which are beyond our control. In addition, these forward-looking statements reflect our current views about future events and are not a guarantee of future performance. Actual outcomes may differ materially from the information contained in the forward-looking statements because of a number of factors, including, without limitation, the risk factors set forth in “Risk Factors” and the following:
| ● | the pace of government sponsored auctions and changes in auction rules; | |
| ● | availability of land for projects and transmission capacity installed for evacuation of power generated; | |
| ● | permitting, development and construction of our project pipeline according to schedule; | |
| ● | solar irradiation and wind availability in the regions in which we operate; | |
| ● | adverse change in laws and regulations related to environmental, health and safety; | |
| ● | developments in, or changes to, laws, regulations, governmental policies, incentives, and taxation affecting our operations; | |
| ● | our ability to successfully implement any of our business strategies, including acquiring other companies and sale of our assets; | |
| ● | our ability to enter into PPAs, on acceptable terms, the occurrence of any event that may expose us to certain risks under our PPAs and the willingness and ability of counterparties to our PPAs to fulfill their obligations; | |
| ● | solar power curtailments by state electricity authorities; | |
| the impact of fraud or other misconduct (including bribery) by our employees and former employees; | ||
| ● | material changes in the costs and availability of solar panels, raw materials, capital equipment’s and other equipment and manpower required for our operations; and | |
| ● | other risks and uncertainties, including those listed under the caption “Risk Factors.” |
We caution you that forward-looking statements are not guarantees of future performance and involve risks and uncertainties. Actual results may differ materially from those in forward-looking statements as a result of various factors. These risks and uncertainties include factors relating to (i) economic, political and social issues in the country in which we operate, including factors relating to the coronavirus pandemic outbreak, (ii) the domestic as well as global economy, (iii) financial and capital markets, (iv) Indian government policies and regulation on renewable energy, (v) tax related laws in US, Mauritius and India, and (vi) degree of competition in the renewable energy market in India.
For additional information on risk factors that could cause our actual results to differ from expectations reflected in forward- looking statements, see “Risk Factors”. Forward-looking statements speak only as of the date they are made, and we do not undertake any obligation to update them in light of new information or future developments. All forward-looking statements attributed to us or a person acting on our behalf are expressly qualified in their entirety by this cautionary statement, and you should not place undue reliance on any forward-looking statement. You should read this annual report, the exhibits hereto and other documents we have filed with the SEC completely and with the understanding that our actual future results or performance may be materially different from what we expect.
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I. BUSINESS, COMPANY & INDUSTRY OVERVIEW
A. Business Overview
Azure is one of India’s leading utility scale renewable energy project developers and operators. We build, own, and operate large grid-scale renewable energy projects across India that supply clean energy to India’s power grid. We developed India’s first utility-scale solar power project in 2009 and have since then grown to achieve substantial scale in the Indian renewable industry. Despite the challenges arising from the COVID-19 pandemic, during FY 2022 we commissioned our 600 MW Rajasthan 6 project, which is the largest single site solar project owned and operated by any developer in India.
As of the date of this Form 20-F, our total portfolio stands at 7,311 MW including 86.5 MW of rooftop capacity and excluding 200 MW wind–solar hybrid project earlier won by the Group with Maharashtra State Electricity Distribution Co. Limited1. We had a total operating capacity of 3,041 MW which includes rooftop capacity and Contracted and Awarded capacity of 4,270 MW. Out of total Contracted and Awarded capacity of 4,270 MW, around 700 MW is at early stages of development. A major part of our 4,270 MW project pipeline consists of 4,000 MW allocated by SECI under their manufacturing linked tender, that we won in FY 2020. In FY 2022, we executed PPAs with SECI for 2,983 MW under this manufacturing linked allocation and subsequently, in January 2023 for an additional 50 MW, taking our cumulative SECI manufacturing linked PPA capacity to 3,033 MW. PPAs for the balance capacity of 967 MW under manufacturing linked projects can be signed only after SECI has the power supply agreements for these remaining MW in place. The 3,033 MW of PPA capacity was initially required to be delivered in a phased manner from November 2023 to November 2026. Out of this capacity, 700 MW is presently required to be commissioned from July 2024 to November 2024. The scheduled commissioning timelines for most of this capacity (650 MW) is estimated from the expected CTU Grid Connectivity operationalization date, which in-turn is determined from the anticipated completion dates of the requisite elements of the CTU’s grid transmission/ evacuation system. However, these 4,000 MW manufacturing linked projects are currently challenged under two Public Interest Litigations (PILs), filed in the High Court of Andhra Pradesh in FY 2022 (where we are not a party), challenging various aspects of the manufacturing linked tender. For further information, see “Legal Proceedings” and see “Operating and Financial Review and Prospects - Projects under execution”. In FY 2023, we also executed PPAs with SECI for our first 150 MW solar-wind hybrid project, and for our first wind project of 120 MW. The presently estimated scheduled commissioning timelines for these projects are December 2024 (for the 120 MW wind project), and May 2025 (for the 150 MW solar-wind hybrid project). These timelines are estimated on the basis of anticipated dates of regulatory approvals and anticipated completion dates of the requisite elements of the grid’s transmission/evacuation system.
Our operational power plants are spread over 12 Indian states. Out of total operational capacity, some 90% of our plants are in high irradiation zones like Rajasthan, Gujarat, Maharashtra, and Andhra Pradesh. Below are outlines of our utility scale operational portfolio as of the date of this Form 20-F.
1 This project was cancelled on March 10, 2023, pursuant to withdrawal of the Group’s appeal before the Appellate Tribunal for Electricity. Appeal was filed to challenge Maharashtra Electricity Regulatory Commission’s order, that rejected the adoption of the auction discovered tariff of INR 2.62 per unit and instead gave the Group an option to reduce the tariff to INR 2.49 per unit.
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We sell renewable power under long term PPAs, typically 25 years in duration,2 at a fixed tariff. The quality of our offtake customers is fundamental to our business and more than 85% of our PPAs are signed with top rated central government owned intermediaries such as SECI and NTPC, providing predictable and consistent revenues and cash flows. Further, according to a report published by MOP in April 2023, among the state government owned Discoms that we have large capacities contracted with, Gujarat is rated A+, Punjab & Assam are A rated, while the three Discoms of Karnataka (CHESCOM, GESCOM and HESCOM) are B rated, and Maharashtra Discom is rated B-. Our counterparty exposure for the commissioned capacity is set out below:
In addition to total operating capacity of 3,041 MW, we have Contracted and Awarded capacity of approximately 4,270 MW, bringing our total portfolio size to over 7,311 MW. During FY 2022, we generated 4,551 million units of clean and green electricity for the Indian power grid. We expanded beyond solar power in FY 2022 by winning our first wind and solar-wind hybrid power projects. Our goal is to remain a leader in the renewable energy market in India. All our operating assets are currently solar, but we intend to add wind as well as storage assets over time, to complement our clean generation capacity.
Our business success is driven by:
| 1. | Predictability: Our projects are developed under long-term electricity supply contracts i.e., PPAs, which provide predictability of revenue for our operations. |
| 2. | Sustainability: 100% of our electricity generated by us is clean and is generated from renewable sources. We estimate that Azure’s renewable power generation helped to avoid the production of approximately 5 million tons of CO2e in FY 2023 and 19.5 million tons -equivalent since inception. |
| 3. | Dependability: We aim to be a reliable developer that executes its pipeline on time and within budget. |
| 4. | Competitive Pricing: Our in-house technical expertise in design and engineering, project execution and operation and maintenance, together with our ability to finance at better pricing from both domestic and global sources, enables us to achieve competitive tariffs and deliver our target project returns. |
| 5. | Community Support: Our CSR and community programs are integral to our strategy. We build long-term community relationships, hire from local communities, purchase or lease land with few alternative uses, and seek to support local economic and social development. |
2 Except for one 10 MW project in Uttar Pradesh with Uttar Pradesh Power Corporation Limited, which is subject to a 12 year PPA.
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Our Competitive Advantage
We believe that Azure has developed durable competitive advantages from a range of factors, including:
| (i) | Pioneer: Being a leader in renewable energy industry is fundamental to Azure. We have been early adopters of proven technologies, such as bi-facial modules, trackers, and robotic dry cleaning. Our track record in project financing and refinancing includes the issue of Green Bonds at the lowest rates in India’s renewable industry. |
| (ii) | Strong customer portfolio: More than 85% of our signed PPAs are with central government owned intermediaries like SECI and NTPC. This means that our offtake profile is strong with an industry leading portfolio receivable cycle and the least possible disruptions to revenue collections. |
| (iii) | Superior execution capabilities: We have developed in-house capabilities for the full cycle of our business to enhance our insight, increase our speed and lower our costs. This includes land and site development, design and engineering, and innovation in construction techniques. Because of our execution capabilities, we have been able to increase our operational capacity from 55 MW as of March 31, 2014 to 3,041 MW as of the date of this Form 20-F. |
| (iv) | Focus on efficiency and productivity: We have deployed monitoring drone at our project sites for thermal inspection of plants. All our plants are connected to Centralized Monitoring System which record and monitor our plant performance on real time basis as well as maintenance data on a daily, weekly and monthly basis. Being an early mover in the Indian solar industry we have inhouse expertise to manage substations from small to large voltage of up to 400kV, which is second highest voltage level available in India. |
| (v) | Access to capital: Capital is one of the most important resources in our business, and we believe that strong backing from our large shareholders is a critical advantage. This strong sponsorship and our solid track record supports us in the credit markets, demonstrated by the refinancing of our first Green Bond in FY 2022. Refer to “Risk Factors - Any downgrade of our credit rating may result in increase in interest cost or may trigger covenant defaults under our loan agreements” and “Certain Factors affecting our Results” for further discussion of rating updates. |
| (vi) | Focus on ESG standards: At Azure, our efforts are focused on integrating sustainability with our business strategy and day to day operation of the company. A framework has been developed to link the executive compensation to its ESG performance by developing an organizational level scorecard. ESG risks have been integrated into our Enterprise Risk Management (ERM) framework and we are a signatory to the United Nations Global Compact’s Ten Principles. As a pivotal partner in India’s transition to clean journey, we are taking measures to monitor and improve our environmental performance rolling out initiatives like deployment of robotic cleaning to reduce our dependence on ground water, planting trees across sites to enhance our natural capital and tracking and reducing our greenhouse gas emissions. For last 5 years, Azure has been validated as “carbon neutral” for its scope 1 and 2 emissions. The Company has institutionalized an EV Policy to replace our fossil-based vehicles to EVs in an effort to reduce its dependence on fossil fuel. As part of effort to reduce our scope 1 emissions, we have rolled out a robust EV policy to move away from fossil-based vehicle and have taken a commitment to enhance natural capital by planting 50 trees per MW for all project we install in future. We are ISO 140001 (Env.), 45001 (Safety) and SA8001 (Social accountability) certified company. We are strictly governed by key policies including our anti-bribery and corruption policy, whistle blower policy, code of business conduct and ethics and corporate social responsibility. We were awarded the Apex India CSR Excellence Award 2021, Greentech effective safety culture award 2021 in recognition of our safety initiatives. In October 2022, we won the prestigious Golden Peacock Award for Sustainability for 2022. |
| (vii) | Innovation: We have adopted world class technology and systems to deliver sustainable value in our business. To study new technologies and the interplay between various elements of renewable power generation, we setup a test laboratory in the state of Rajasthan in 2021. This facility is aimed at improving construction processes and testing new technologies before they are mainstreamed in our projects. We have developed design and execution technologies for module mounting structure and electrical connections to suit projects located even in challenging environments. Technologies recently deployed at scale include automated robotic cleaning in over 1,178 MW projects at different sites, use of drone for predictive and rapid maintenance identification and improving revenue by reducing electrical mismatch & import energy. |
Our Business Strategy
India is our focus market. During Fiscal 2022, India was the third largest electricity producer and the fourth-largest
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energy consumer in the world. It is a global pacesetter in terms of renewable energy capacity additions and is on track to become one of the world’s largest markets for clean energy technologies. India has set ambitious climate change and energy transition targets, including Net-Zero carbon emissions by 2070, growth of non-fossil fuel energy capacity to 500 GW by 2030 and to achieve energy independence by 2047. The GOI’s support for the sector, macro factors such as increased electrification and rapid urbanization are expected to result in India representing a significant share in the global renewable energy market across technologies like solar and wind. For more information, see “Industry Overview”.
We believe we are well positioned to benefit from the expanding renewable energy market in India. We expect to continue to invest in the capabilities that we believe give us an edge in an increasingly competitive market. These include:
| ● | In-house expertise in competitive bidding, design, construction, and operation of renewable energy assets to world class standards of quality and cost; |
| ● | Deep engagement in the evolving Indian renewable energy ecosystem with policy makers, regulators and customers at central and state levels; |
| ● | Leadership in raising and deploying both equity and debt capital, including project and climate financing; |
| ● | Insight into and early deployment of evolving technologies, including solar generation, construction techniques, and digital and automated optimization and grid interface; and |
| ● | Strong and effective governance including corporate responsibility and community engagement. |
Our strategic priorities are:
| ● | To execute our pipeline while managing risk and delivering targeted investment returns; | |
| ● | To bid for and win renewable energy auctions in India focused on solar, wind, storage, and their hybrid solutions with a bidding strategy that conforms to our risk-return profile; | |
| ● | To maintain world class standards of safety, reliability and efficiency at our plants using leading digital and automated tools; | |
| ● | To build capabilities to address a more demanding utility grid environment led by higher renewable energy penetration. In addition to existing solar capabilities, we plan to increase our non-solar generation, especially wind and storage; and | |
| ● | To develop business beyond the core utility business by partnering with large energy users for their requirements by providing reliable renewable energy. |
To execute our pipeline of projects
Delivering on our pipeline in a timely and efficient manner – within acceptable risk and return parameters – is our key strategic priority. We have signed PPAs for approximately 3,303 MW of our pipeline and have signed LOAs for another 967 MW. Whilst most of the pipeline is in solar, we have started early-stage development on wind projects and wind solar hybrid projects. We continue to identify project sites with good renewable energy resource potential, connectivity to the grid, and favorable on-ground working ecosystem.
Bid for and win renewable energy auctions in India in line with our risk and return profile
The ambitious targets set by the GoI, combined with climate change commitments being announced by Indian corporates, are expected to substantially increase the demand for clean energy. India offers tremendous potential in solar and wind power, which should be the fastest growing sources of energy in the next decade and beyond. We will continue to bid in a disciplined manner to win projects at an acceptable rate of return and include Power Purchase Agreements (PPAs) with high grade offtake. The PPAs signed by the company are typically for 25 years duration and considering the long tenor of these contracts, it’s important to ensure that the counterparties to such agreements are organizations with robust business model and strong operational cashflows to service their PPA obligations. Based on the above, Azure only selects bidding opportunities that it believes minimize the risks, ensure bankability of our projects, and have a high probability of generating the expected cash-flows.
Maintain world class standards of safety, reliability and efficiency at our plants including using digital and automated tools
We are a fully integrated renewable energy company undertaking development, construction, ownership, operation, and maintenance of renewable energy plants. New technologies, including digital and automation, will help optimize output and reduce cost, while better serving the grid requirement for firmer and more predictable power. We have rolled out multiple initiatives aimed at enhancing safety, efficiency and process improvements which include advanced automated robotic cleaning
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technologies for photovoltaic modules, drones for monitoring, centralized digital platform for asset performance monitoring, predictive analytics etc. We will continue to deploy technologies and innovations that help us deliver world class operating performance and simultaneously optimize the asset life.
Build capabilities in non-solar generation especially in wind, and in storage, to address a more demanding utility grid environment
As the share of renewable energy increases in the energy mix, the challenges to integrate Renewable Energy in the grid will increase due to their variable nature of generation. We expect that there will be an increasing focus to improve power system flexibility and reduce the intermittency associated with renewable power. The Indian wind energy profile complements India’s solar generation profile. Thus, we expect that wind energy, solar-wind hybrids and energy storage solutions will be increasingly deployed for a predictable and flatter renewable energy generation profile and grid stability. On similar lines, we expect that utility customers will increase their share of renewable energy consumption but will increasingly demand more predictable and continuous power. This will require integration of solar, wind and storage technologies. In line with the evolving requirements of the market, we will continue to strengthen our capability to deliver firm and dispatchable renewable power to our customers by leveraging solar, wind and storage technologies.
Develop business beyond the core utility business by partnering with large energy users for their requirements for reliable green energy
With an increasing focus on decarbonization and sustainability, there is a significant and growing demand for renewable energy from commercial and industrial customers. We aim to partner with large energy consumers across segments to meet their requirements for reliable and affordable green energy. We will look for opportunities to displace their brown energy consumption with green power through various techno-commercial offerings tailored to specific customer needs. Such displacement would target not only the power requirements of our partners but also the grey fuel usage for various heating, cooling and other process driven energy requirements.
We will continue to evaluate new technologies such as Green Hydrogen which present an opportunity to implement large scale renewable energy projects in a sustainable manner. We intend to identify such opportunities which integrate with our business strategy, add value to our existing portfolio and would leverage our core strength of building efficient renewable energy projects.
Project Implementation
We have inhouse design, engineering, project execution, operations and maintenance capabilities. We remain one of the pioneers in executing and delivering renewable projects in India, demonstrated by our early adoption of proven technologies like bi-facial modules, trackers, and robotic dry cleaning. We aim to operate our plants to world-class standards of safety, reliability and efficiency using leading digital and automated tools with predictive and rapid response abilities.
Many of our projects are in zones with high irradiation and/or strong winds. We position our power plants to optimize generating efficiency, proximity to customers, and local government support. The typical timeline available under a PPA for commissioning a power project is approximately 18-24 months. The following diagram illustrates the key activities under life cycle of a typical project.
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We procure major components such as solar modules and inverters directly from multiple manufacturers with industry standard warranty and guarantee terms. Our supply chain team are developing strategic relationships with a range of key suppliers of critical equipment and components both in India and globally. We select our suppliers based on quality, technology provided, expected cost, reliability, warranty coverage, ease of installation and other ancillary costs.
The price of components for our solar power plants have declined over the longer time horizon as manufacturers lower their cost of production via technological improvement and economies of scale. However, in the second half of FY 2022, we experienced challenges in receipt and pricing of material from suppliers, primarily due to price increases of raw materials and disruptions to trade flows due to COVID-19 shutdowns in source markets and the imposition of customs duties. We have responded to these supply headwinds by deepening our strategic partnerships with key suppliers like for modules we entered into an agreement with Premier Energies Group (“Premier Group”) and First Solar, Inc. subsequent to the end of FY 2022. We agreed to invest INR 1,000 million (US$13.2 million) in Premier Group, one of India’s leading manufacturers of solar PV cells and modules and also signed a Module Supply Agreement (“MSA”) for supply of modules up to 600 MW capacity per annum over next 4 years. Under the MSA, we have a right to procure modules of up to 600 MW per annum, with a minimum commitment given to off-take 300 MW per annum, subject to agreed exemptions. With First Solar, we entered into an agreement for 600 MW (DC) of high-performance, advanced thin film photovoltaic (PV) solar modules.
We also signed a Master Supply Agreement with Siemens Gamesa Renewable Power Private Limited (“Siemens Gamesa”) to supply 96 units of onshore wind turbines that will cater to an overall capacity of approximately 346 MW of wind projects. The turbine supply was expected to commence during Q2 calendar year 2023 but it is now tentatively planned to commence in Q2 calendar year 2024 as the timelines for the project are under review.
Once a project is constructed and grid-connected, it produces recurring revenue. Our project operating expenses are relatively lower than conventional power plants, with most cash flow servicing the capital costs of the project or contributing to our growth capital requirements including corporate overhead. Because plant operating margins are relatively stable, our growth and financial success depend on effective management of our expenses and the development of new projects. Also refer to the section entitled “Operating and Financial Review and Prospects” for further details.
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B. Company Overview
Azure Power Global Limited is a publicly traded limited liability company incorporated in Mauritius We are an Indian renewable energy developer and independent renewable power producer, and our entire operations are currently in India. Our green bonds are listed on the Singapore Exchange (SGX) with the first solar green bond from India listed in 2017. As such we are subject to regulation in four jurisdictions: the United States of America where Azure Power shares are registered with the SEC; Mauritius, where Azure Power is incorporated; Singapore, where our Bonds are traded; and India, where we operate.
Our shares are listed on the New York Stock Exchange (NYSE). On July 13, 2023, the NYSE suspended trading in our equity shares and commenced delisting proceedings. For further information, see “Risk Factors - The New York Stock Exchange (NYSE) has commenced procedures to delist our Company’s shares and our failure to timely file periodic reports with the SEC may result in the delisting of our Company’ shares”.
Our Company’s registered office is located at c/o AAA Global Services Ltd., 4th Floor, Iconebene, Rue De L’institut, Ebene, 80817, Mauritius with principal executive offices located at: 5th Floor, Southern Park, D-II, Saket Place, Saket, New Delhi – 110017, India. Our telephone number at our principal executive office’s location is +91 (11) 4940 9800 and our principal website address is http://www.azurepower.com. Unless expressly indicated, the information contained on our website is not incorporated by reference in this Annual Report. Reports, proxy, information statements and other information regarding Azure Power can be accessed via the SEC website at http://www.sec.gov/Edgar. Our Company’s agent for service of process in the United States is CT Corporation System, located at 28 Liberty Street, New York, NY 10005.
Organizational Structure
The following diagram illustrates our corporate structure as of the date of this 20-F:
* In April 2021, we entered into a sales contract with Radiance Renewables Private Limited (“Radiance”) to sell certain subsidiaries having an operating capacity of 153 MW for INR 5,350 million (US$70.5 million), subject to certain purchase price adjustments. Out of the identified rooftop portfolio of 153 MW, the Company has already transferred 17.3 MW to Radiance, 33.2 MW will be transferred to Radiance after refinancing of the RG-II bonds and 16 MW will be transferred to Radiance post March 31, 2024. Hence, we have not considered these rooftop portfolios of 66.5 MW for reporting under its total portfolio as at year end. Further, the Company is in discussion with Radiance to mutually terminate the transfer in shareholding of the remaining un-transferred 86.5 MW portfolio to Radiance, and the same shall be subject to modification of the Amended Rooftop Sale Agreement, Hence, portfolio of 86.5 MW have been considered for reporting under total portfolio as at year end.
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Our Sustainability Initiatives and ESG Focus
Sustainability is at the core of our business. We are focused on integrating sustainability across business, building a culture focused on sustainability, sustainability reporting and ESG ratings. Our leadership is evident in the ratings received by
us. We have rated as a “low risk” company with a score of 15.8 by Morningstar Sustainalytics; MSCI has given us a rating of “AA” indicating Azure’s resilience to long term ESG risks.
As a socially and environmentally conscious company, we are committed to protecting our environment and creating a safe and health workplace. To meet these objectives, we have implemented our Environmental and Social Management framework (ESMG). The framework acts as a guideline through which we plan and undertake activities to meet our HSE commitments and helps us to assess our environmental and social performance against established international guidelines such as the International Finance Corporation (“IFC”) Performance Standards and World Bank Equator Principles and governance standards. We continue to operate our plants to the highest standards of safety. We have defined targets for monitoring the continual improvement in our safety performance. In Fiscal 2023, a contract worker had a fatal accident at one of our solar energy project sites in Rajasthan, following which we have strengthened our awareness and training programmes for employees and contractual workers.
We estimate that Azure’s renewable power generation helped to avoid the production of approximately 5 million tons of CO2e in FY 2023 and 19.5 million tons -equivalent since inception. We strongly believe that commitment to high standards of corporate responsibility is both the right way to do business but also an enabler of our business.
During Fiscal 2022, we rolled out various initiatives to address United Nations Sustainable Development Goals (SDG). As one of country’s pivotal clean energy partner, we at Azure are helping India’s to achieve its Net Zero target, thereby contributing to achieving the goals of SDG 13 (Climate Action). As part of our community development initiatives, we are actively working towards improving the quality of infrastructure in schools around our sites, thereby contributing towards achieving the goals of SDG 4 (Quality Education), development of village infrastructure, thereby contributing towards advancement of SDG 1 (No Poverty) and SDG 6 (Clean Water and Sanitation).
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ESG Updates
Environmental
As a pure play renewable energy company, we are working towards clean energy transition and contributing to India met its Net zero target.
Climate change: We estimate that Azure’s renewable power generation helped to avoid the production of approximately 5 million tons of CO2e in FY 2023 and 19.5 million tons -equivalent since inception. We have been validated to be carbon neutral for 5th consecutive year for our scope 1 and 2 emissions. Our actions to reduce Scope 1 emissions include implementation of an Electric Vehicle policy that will phase out all fossil fuel-based vehicles by 2030.
Water Security: We reduced our water consumption per MWh from 122 L/ MWh in FY 2018 to 15 L/ MWh in FY 2023. We recognize that the water required for cleaning our solar modules may result in adverse environmental impact. We are installing robotic dry-cleaning systems at all our project sites to eliminate the requirement for water which has helped to save approximately 1 million kilo liters of water Additionally, we are installing ground water recharge structures across our sites to offset our water consumption.
Natural capital enhancement: We are committed to planting 50 tree saplings per MW installed at all our future projects. in FY 2023, we planted 30,000 trees around our sites.
Social
Community engagement: Through our community engagement initiatives, Azure is committed to improving the quality of life by making a positive economic and social contribution to the communities living in and around its sites. In Fiscal 2022, we won the prestigious Apex India CSR Excellence award 2021. In FY 2023, we commissioned an Impact Evaluation of our CSR activities carried out during FY 2022.
Occupational Health and Safety: Our foremost priority is the health and safety of our staff and contractors at project sites as well as our corporate office. Our target is zero harm for everyone from our operations. We continue to promote safety awareness and best practices among all employees and contractors. We obtained ISO 45001 (Occupational Health and Safety) certification, won the Greentech Effective Safety Culture Award 2021 and Grow Care India Occupational Health and Safety award 2021. We undertook a safety culture survey in September 2022 which saw voluntary participation of 50% of our employees. The survey concluded that the company is performing better than its peers in matter of safety. The internal validation corroborates external validation in form of multiple safety awards as received by the company.
Labor and working condition: We look to monitor the social and compliance performance of our key contractors and suppliers. We have obtained Social Accountability 8000 certification to assure appropriate labor and working conditions associated with our projects.
Governance
We are committed to the high standards of corporate governance and continue to improve our processes and practices.
Board Membership: Our Board currently consists of nine members, two of whom are women. All Board members are Non-Executive; five are Independent Non-Executives and four are Non-Executive nominees of shareholders (three of CDPQ and one of OMERS).
There have been changes in the membership of the Board in FY 2022 and thereafter. In September 2021, Mr. Barney Rush, Chairman, stepped down and was replaced by Mr. Richard Alan Rosling as Chairman. In March 2022, Ms. Christine McNamara joined the Board and became the Chair of the Audit and Risk Committee. She stepped down from her position on June 26, 2023 for personal reasons. The Company appointed Mr. Richard Payette as a new independent non-executive director
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on July 1, 2023 and he was also appointed as the Chair of the Audit and Risk Committee. Mr. Payette brings four decades of experience in the management of global companies and in accounting, audit and governance areas.
In April 2022, our previous Managing Director and CEO, Mr. Ranjit Gupta, resigned.
In May 2022, Ms. Delphine Voeltzel joined the Board as a director and Nominee of OMERS. At the end of May 2022, Arno Harris left the Board after more than six years of service. In October 2022, Mr. Sugata Sircar joined the Board as an Independent Director and member of the Audit & Risk committee. Mr. Sugata is a chartered accountant with 32 years of experience in energy and automation, chemicals, textiles, tires, fast moving consumer goods and city gas distribution. Mr. Sircar stepped down from his role as independent director of the Company on April 30, 2023 to become our Group CFO.
In February 2023, Mr. Jean-François Boisvenu joined the Board as an Independent Non-executive Director. Mr. Boisvenu has more than 25 years of experience in corporate and commercial law matters, with expertise in international banking transactions, lending and debt capital markets transactions and financial institutions regulation. In March 2023, Mrs. Yung Oy Pin Lun Leung left the Board after more than three years of service. She was replaced by Mr. Gowtamsingh Dabee. Mr. Dabee has over 25 years of experience as a professional accountant in public practice and industry in Mauritius, Africa, and the Middle East.
On October 11, 2023, Mr. Alan Rosling resigned as Chairman of the Board and as a director of the Company and APIPL. On October 12, 2023, the Company announced that Mr. M.S Unnikrishnan became the Chairman of the Board of the Company.
For further information, see “Management and Employees – Management”.
Board Committees: In recent months, the Board has completed a review of the Terms of Reference, Charters and membership of its Committees. The Audit Committee is now the Audit and Risk Committee, taking responsibility for our new ERM system. The CSR Committee is now the Sustainability and CSR Committee and has a broader mandate to ensure our ESG and CSR performance is world class and supports our goals, ethos, and operating strategy.
For further information, see “Management and Employees – Board Committees”.
Executive Committees: There are two executive committees which are formed by the Board as follows:
| (i) | Ethics Committee – To review and investigate reported whistleblower complaints. Members of the Ethics Committee include the CEO and GCFO. The Ethics Committee is chaired by the Head of Legal and reports to the ARC. |
| (ii) | Executive Risk Committee – To develop, implement and monitor the Enterprise Risk Management framework. CFO and CEO are the members of this committee. |
For further information, see “Management and Employees – Board Committees”.
Leadership: On April 26, 2022, we announced that the Board had accepted the resignations of our previous CEO & Managing Director, Mr. Ranjit Gupta, and COO, Mr. Murali Subramanian. Mr. Harsh Shah joined the Company as CEO on July 1, 2022 but subsequently resigned on August 29, 2022. Thereafter, Mr. Rupesh Agarwal became Acting CEO of the Company on Mr. Shah’s resignation. In November 2022, Mr. R. Narasimhan Iyer joined as Chief Operating Officer of the Company. On April 30, 2023, Mr. Sugata Sircar resigned from his position as non-executive Independent Director and member of the Company’s Audit & Risk Committee and Capital Committee and on May 1, 2023, joined as Group CFO and Executive Director, Finance of the Company’s subsidiary, APIPL. In July 2023, Mr. Sunil Gupta was appointed as the CEO of the group and as Managing Director of the Company’s subsidiary, APIPL. For more information, see “Risk Factors – The loss of our senior management or key employees may adversely affect our ability to conduct our business”.
For further information, see “Management and Employees – Management”.
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C. Industry Overview
Renewable energy represents a significant and growing industry in India. At the 26th meeting of Conference of the Parties COP-26 climate summit in Glasgow, the Prime Minister of India increased the country’s renewable energy target to 500 GWs by 2030, which would represent 50% of the country’s energy requirements. Beyond that, the Prime Minister committed India to net carbon neutrality by 2070. India’s Nationally Determined Commitments were further tightened at COP-27 in Egypt.
An efficient, resilient, and financially robust power sector is essential for the growth of the Indian economy. Renewable sources of power are cleaner, faster to build and more cost-effective than most traditional sources of power. India’s rapidly growing economy requires significant investment in additional power capacity. India is already one of the largest renewable energy markets globally.
Renewable energy has strong government support and the government has designed policies, programs, and a liberal environment to attract domestic and foreign investment to the sector. Initially, the National Solar Mission (NSM) was launched in 2010 as a part of India’s National Action Plan on Climate Change (NAPCC) with a view to deploy 20 GWs of solar capacity by FY 2022. In 2015, the targets were revised to 175 GWs by 2022. India has now committed to achieve about 50 percent cumulative electric power installed capacity from non-fossil fuel-based energy resources by 2030.
The Indian renewable energy sector is the fourth most attractive renewable energy market in the world, with total installed capacity of renewable power of 131 GWs as of August 2023. India has witnessed one of the fastest growth rates in renewable energy capacity among all large economies, with renewable energy capacity growing from 35.5 GWs in March 2014 to 131 GWs in August 2023, a 269% increase. India’s total electricity installed capacity stood at 424 GWs as of August 31, 2023.
Total Installed Capacity (As of August 31, 2023)
| Category | Installed Generation Capacity (in MW) | % Share in Total | ||||||
| Coal | 206,195 | 48.60 | ||||||
| Lignite | 6,620 | 1.56 | ||||||
| Gas | 25,038 | 5.90 | ||||||
| Diesel | 589 | 0.14 | ||||||
| Total Fossil Fuel (A) | 238,442 | 56.20 | ||||||
| Hydro | 46,850 | 11.04 | ||||||
| Wind | 44,089 | 10.39 | ||||||
| Solar | 71,610 | 16.88 | ||||||
| BM Power/Cogen | 10,261 | 2.42 | ||||||
| Waste to Energy | 570 | 0.13 | ||||||
| Small Hydro Power | 4,982 | 1.18 | ||||||
| Nuclear | 7,480 | 1.76 | ||||||
| Total Non-Fossil Fuel (B) | 185,842 | 43.80 | ||||||
| Total Installed Capacity | 424,284 | 100 | ||||||
Power Consumption
There is huge potential for power demand to grow in India. The country is among the fastest growing large economies, already ranked fifth globally in terms of total GDP. Over the ten year period up to June 2023, electricity consumption and peak demand in India grew at a CAGR of 3.6% and 5.7%, respectively. Annual per capita power consumption in India has also grown significantly from 0.8 MWh in FY 2011 to 1.3 MWh in 2021-22, although it is still among the lowest in the world. According to the International Energy Agency, the annual per capita electricity consumption of India is around 21.7% that of China, which had per capita electricity consumption of 5.98 MWh, and around 9.9% of the United States, which had per capita electricity consumption of 13.07 MWh.
Solar Energy Potential
National Institute of Solar Energy (NISE), an autonomous research and development institution under the MNRE, assesses the country’s solar potential at approximately 748 GWs, assuming 3% of the waste land area could be covered by Solar PV modules. Solar energy has taken a central place in India’s NAPCC with the NSM as one of the key Missions. The GOI have launched various schemes under the NSM to boost generation of solar power in the country, most importantly
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procurement of solar power by SECI, but also including initiatives such as Solar Park Scheme, Viability Gap Funding (“VGF”) Schemes, CPSU Scheme, Defence Scheme, Canal bank & Canal top Scheme, Bundling Scheme and Grid Connected Solar Rooftop Scheme.
In addition, policies to promote and enable renewable energy have included a Renewable Purchase Obligation (RPO) on certain industries, the waiver of ISTS charges and losses for inter-state sale of solar and wind power, “must run” status, guidelines for procurement of solar power though tariff based competitive bidding process, standards for deployment of solar photovoltaic systems and devices, provision of roof top solar and guidelines for development of smart cities, amendments in building by-laws for mandatory provision of roof top solar for new construction or higher floor area ratio, infrastructure status for solar projects, tax free solar bonds, and providing long tenor loans from multi-lateral agencies.
Solar power capacity in India increased from 2.6 GWs in March 2014 to 71.61 GWs as of August 2023. Refer below for solar installed capacity as of August 2023 for states with highest irradiation:
Wind Energy Potential
In recent years wind power generation capacity in India has increased significantly. Through the National Institute of Wind Energy (NIWE), the GOI installed over 800 wind-monitoring stations across the country and issued wind potential maps at 50 meters, 80 meters, 100 meters and 120 meters above ground level. The recent assessment indicates a gross wind power potential of 302 GWs in the country at 100 meters and 695.50 GWs at 120 meters above ground level. Most of this potential exists in seven states: Gujarat, Telangana, Maharashtra, Tamil Nadu, Madhya Pradesh, Karnataka and Andhra Pradesh.
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D. Regulatory Matters
Due to the industry and geographic diversity of our projects, our operations are subject to a variety of rules and regulations. Set forth below is a brief overview of the principal laws and regulations currently governing the businesses of our Indian subsidiaries. The laws and regulations set out below are not exhaustive and are only intended to provide general information to the investors and are neither designed nor intended to be a substitute for professional legal advice.
(i) Central Government – Policies and Regulations:
Electricity Act, 2003
The Electricity Act, 2003, as amended (“Electricity Act”) is the central legislation which covers, among others, generation, transmission, distribution, trading and use of electricity. It governs the establishment, operation and maintenance of any electricity generating company and prescribes technical standards in relation to the connectivity of generating companies with the grid. As per provisions of the Electricity Act, generating companies are required to establish, operate and maintain generating stations, sub-stations and dedicated transmission lines. Further, the generating companies may supply electricity to any licensee or even directly to consumers, subject to obtaining open access to the transmission and distribution systems and payment of transmission charges, including wheeling charges and any other open access charges, as may be determined by the concerned electricity regulatory commission. In terms of the Electricity Act, open access means the non-discriminatory provision for the use of transmission lines or distribution system or associated facilities with such lines or system, by any licensee or consumer or a person engaged in generation in accordance with the regulations specified by the relevant electricity regulatory commission.
In accordance with Section 7 of the Electricity Act, a generating company may establish, operate and maintain a generating station without obtaining a license under the Electricity Act if it complies with the technical standards relating to connectivity with the grid prescribed under clause (b) of Section 73 of the Electricity Act.
Under the Electricity Act, the State Electricity Regulatory Commissions, (“SERCs”) are required to promote co-generation and generation of electricity from renewable sources of energy and sale of electricity to any person from sources other than the incumbent distribution licensee under the provisions of open access. The Electricity Act further requires the SERCs to specify, for the purchase of electricity from renewable sources, as a percentage of the total consumption of electricity within the area of a distribution licensee, which has been implemented in the form of renewable purchase obligations, (“RPOs”).
Additionally, the Electricity Rules, 2005, as amended (“Electricity Rules”) also prescribe a regulatory framework for developing captive generating plants. Pursuant to the Electricity Rules, a power plant shall qualify as a captive power plant only if not less than 26% of ownership is held by captive users and not less than 51% of the aggregate electricity generated in such plant, determined on an annual basis, is consumed for captive use. In case of a generating station owned by a company formed as a special purpose vehicle, the electricity required to be consumed by captive users is to be determined with reference to such unit or units identified for captive use and not with reference to the generating station as a whole, and equity shares to be held by the captive users must not be less than 26% of the proportionate equity interest of the company related to the generating unit or units identified as the captive generating plant.
The Ministry of Power introduced the Electricity Act (Amendment) Bill, 2020 (“2020 Amendment Bill”) to amend the Electricity Act to promote the generation of electricity from renewable sources of energy. The Ministry of Power also introduced Electricity (Rights to Consumers) Rules, 2020, as amended (“2020 Electricity Rules”) to empower consumers of electricity and confer rights upon the consumers to be entitled to reliable services and quality electricity. The 2020 Electricity Rules introduced, inter alia, installation of smart or pre -payment meter. Further, the Rules intend to ensure the availability of 24x7 power to all the consumers with some exceptions for lower hours that the relevant State Electricity Regulatory Commission may specify for certain categories of consumers and introduces robust grievance redressal mechanism to be introduced by the distribution licensees.
The Ministry of Power introduced the Electricity (Amendment) Bill, 2022 (“2022 Amendment Bill”) which seeks to, among others, facilitate (i) development of the hydro sector in the country; and (ii) the use of distribution networks by all licensees under provisions of non-discriminatory open access with the objective of enabling competition, enhancing efficiency of distribution licensees for improving services to consumers and ensuring sustainability of the power sector. The 2022 Amendment Bill added that RPO should not be below a minimum percentage of the total consumption of electricity in the area
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of a distribution licensee, prescribed by the central government. Failure to meet RPO requirements will be punishable with a penalty ranging between Rs. 0.25 and Rs. 0.35 per kilowatt-hour for the shortfall in the first year of default and between Rs. 0.35 and Rs. 0.50 per kilowatt-hour for the shortfall continuing after the first year of default. The Ministry of Power has also issued the Electricity (Amendment) Rules, 2022 to determine that the surcharge imposed by the state commission shall not exceed 20% of average cost of supply, timely recovery of power purchase costs by distribution licensee, resource adequacy, energy storage system, and implementation of a uniform renewable energy tariff for central pool.
Tariff Determination
Under the Electricity Act, the appropriate commission is empowered to determine the tariff for the supply of electricity by a generating company to a distribution licensee. The appropriate electricity regulatory commission is guided by certain principles while determining the tariff applicable to power generating companies which include, among other things, principles and methodologies specified by the CERC for tariff determination, safeguarding consumer interest and other multiyear tariff principles laid down by the implementation of the National Electricity Policy (“NEP”) the Tariff Policy and the National Tariff Policy of India, 2016 (“NTP 2016”); and, tariff may also be determined through the transparent process of bidding in accordance with the guidelines issued by the Government of India.
National Tariff Policy, 2016
The Government of India notified the Tariff Policy on January 6, 2006 (“Tariff Policy 2006”) under Section 3 of the Electricity Act, to ensure availability of electricity to consumers at reasonable and competitive rates, financial viability of the sector and to attract investment, promote transparency, consistency and predictability in regulatory approaches across jurisdictions and minimize perceptions of regulatory risks and promote competition and to guide CERC and the SERCs in discharging their functions. The Tariff Policy 2006 has now been replaced with the NTP 2016.
In exercise of the powers conferred under Section 3 of the Electricity Act, 2003, the Government of India has issued the revised tariff policy to be applicable from January 28, 2016. The objectives of NTP 2016, among others, include:
| 1. | ensuring financial viability of the power sector and attract investments; |
| 2. | ensuring availability of electricity to consumers at reasonable and competitive rates; |
| 3. | promoting generation of electricity from renewable sources; and |
| 4. | promoting hydroelectric power generation. |
The NTP 2016 has removed the ambiguity on applicability of the RPOs on co-generation as it has been clarified that co- generation from sources other than renewable sources shall not be excluded from the applicability of the RPO. NTP 2016 specifies that an existing coal or lignite based generating station may choose to add additional renewable energy capacity and generation from such renewable energy capacity may be bundled with its thermal generation for the purpose of sale. In case an obligated entity procures such bundled power, then the SERCs will consider the obligated entity to have met the RPO to the extent of power bought from such renewable energy generating stations.
Further, to encourage faster capacity addition based on solar and wind energy sources, the Ministry of Power on November 23, 2021 waived the inter-state transmission charges for solar, wind, hydro pumped storage plant (“PSP”) and battery energy storage system projects (“BESS”) commissioned up to June 30, 2025. Such waiver shall be applicable for a period of 25 years for solar, wind and hydro PSP, or for a period of 12 years for BESS, or for a period subsequently notified for future projects by the GoI, from the date of commissioning of the power plant. The waiver shall be allowed for inter-state transmission charges only, and not losses. Such power plants shall be required to meet the following criteria, among others: (a) solar and wind energy generation consumed or sold through competitive bidding, power exchange, or through bilateral agreement; (b) electricity from solar and/or wind sources used by PSP and BESS subject to at least 51% of electricity requirement for pumping of water in PSP and charging of battery in BESS is met by use of electricity generated from wind and/or solar power plants; (c) electricity generated/supplied from such PSP and BESS power plants as mentioned above in (b); (d) for trading of electricity generated/supplied from solar, wind and sources mentioned in (a) to (c) above in green term ahead market and green day ahead market up to June 30, 2025; (e) for green hydrogen plants commissioned up to June 30, 2025 i.e. hydrogen generated using the electricity produced from solar and wind energy and sources mentioned in (a) to (c) above. This waiver shall be applicable for a period of 8 years from the date of commissioning of such hydrogen plant.
Guidelines for Tariff Based Competitive Bidding Process for Procurement of Wind and Solar Power
The Ministry of Power has issued guidelines on August 3, 2017 and December 8, 2017, as amended, for procurement
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of solar and wind power, respectively, through tariff based competitive bidding process (“Competitive Bidding Guidelines”). The Competitive Bidding Guidelines aim to enable the distribution licensees to procure solar and wind power at competitive rates in a cost-effective manner. These Guidelines have been issued under the provisions of Section 63 of the Electricity Act for long term procurement of electricity, determined through the competitive bidding process, by the procurers, the distribution licensees, or the authorized representatives(s), or an intermediary procurer from grid-connected Solar PV Power Projects or grid-connected Wind Power Projects having capacity of 5 MW and above or 5 MW and above for intra-state projects 50 MW and above for inter-state projects, respectively. The Competitive Bidding Guidelines were further supplemented when the Ministry of Power issued guidelines on August 26, 2022 with the aim of promoting cheaper renewable energy sources replacing costlier thermal power and to promote RPO of distribution licensees.
Guidelines for Tariff Based Competitive Bidding Process for Procurement of Power from Grid Connected Wind Solar Hybrid Projects
The Ministry of New and Renewable Energy has issued guidelines on October 14, 2020 (“Competitive Bidding Guidelines”), as amended, for ensuring availability of renewable energy to DISCOMs at competitive rates. The objective for the Competitive Bidding Guidelines is to provide a framework for procurement of electricity from interstate transmission system grid connected wind- solar hybrid power projects through a transparent process of bidding. These Competitive Bidding Guidelines have been issued under the provisions of Section 63 of the Electricity Act, 2003. The individual minimum capacity of projects allowed is 50 MW at one site and a single bidder cannot bid for less than 50 MW. Further, the rated power capacity of one resource (wind or solar) shall be at least 33% of the total contracted capacity. The SECI will be the nodal agency for implementation of these Competitive Bidding Guidelines. The bidders may obtain fiscal and financial incentives available for such projects as per prevailing conditions and rules, and the same may be disclosed by the SECI in the request for selection document.
Guidelines for Tariff Based Competitive Bidding Process for Procurement of Round-The Clock Power from Grid Connected Renewable Energy Power Projects, complemented with Power from any other source or storage.
The Ministry of Power has issued guidelines on July 22, 2020 as amended on November 3, 2020, February 5, 2021, February 3, 2022 and August 26, 2022 to enable procurement of round-the-clock power by distribution companies from grid- connected renewable energy power projects, complemented with power from any source or storage, through tariff based competitive bidding process, and to facilitate addition to renewable energy capacity and fulfillment of renewable power obligation requirements of distribution companies. Pursuant to these guidelines, the renewable energy component generated under this program is eligible for renewable purchase obligation compliance. Further, the amendment dated February 5, 2021 has made it mandatory to include force majeure clauses in the PPAs as per the industry standards. The amendment dated August 26, 2022 provided, among other things, that: (i) the provisions for change in law shall be construed in accordance with the Electricity (Timely Recovery of Costs due to Change in Law) Rules, 2021 notified by the Ministry of Power on October 22, 2021; and (ii) in case of project components being located at multiple locations, if one of such components (wind or solar PV) is ready for injection of power into the grid but the remaining component is unable to be commissioned, then the generator will be allowed for commissioning of such component which is ready outside the ambit of PPA, with first right of refusal for such power vested with the end procurer. Subsequent to refusal of such power by the end procurer, the right of refusal shall vest with the intermediary procurer. In case the procurer/intermediary procurer decides to buy such discrete component(s) power outside the PPA, such power shall be purchased at 50% of the PPA Tariff/weighted average levelized tariff for the applicable contract year.
Central Electricity Regulatory Commission (Terms and Conditions of Tariff Determination from Renewable Energy Sources) Regulations, 2020
CERC notified the Central Electricity Regulatory Commission (Terms and Conditions of Tariff Determination from Renewable Energy Sources) Regulations, 2020, or the “Tariff Regulations 2020,” on June 23, 2020. These regulations came into force from July 1, 2020 and shall remain effective until March 31, 2023, unless reviewed earlier or extended by CERC. Under the Tariff Regulations 2020, CERC has specified certain parameters for determination of tariff for new sources of renewable energy such as floating solar project, renewable hybrid energy project and renewable energy project with storage in addition to those covered in past tariff regulations. In case of renewable energy projects for which generic tariff has to be determined as per these regulations, it will be done through a tariff order at least one month before the commencement of the year for each year of the control period, which is from July 2020 to March 2023. The other tariff, which is project specific, shall be determined by the CERC on a case to case basis for, among others, solar PV power projects, floating solar projects, solar thermal power projects, wind power projects, renewable hybrid energy projects and renewable energy with storage projects.
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National Electricity Policy, 2005
The Indian Government notified the National Electricity Policy, as amended (“NEP”) on February 12, 2005, under Section 3 of the Electricity Act. The key objectives of the NEP, amongst other things are, stipulating guidelines for accelerated development of the power sector, providing supply of electricity to all areas and protecting interests of consumers and other stakeholders, keeping in view availability of energy resources, technology available to exploit these resources, economics of generation using different resources and energy security issues.
Further, NEP emphasizes the need to promote generation of electricity based on non-conventional sources of energy. The NEP provides that SERCs should specify appropriate tariffs to promote renewable energy (until renewable energy power projects relying on non-conventional technologies can compete within the competitive bidding system). SERCs are required to specify percentages of the total consumption of electricity in the area of a distribution licensee that progressively increase the share of electricity generated from renewable sources. Furthermore, the NEP provides that such purchase of electricity by distribution companies should be through competitive bidding.
The Government of India has released draft of National Electricity Policy, 2021 and sought comments from the stakeholders. Once implemented, the draft National Electricity Policy aims at achieving the following objectives, among others: (a) promotion of clean and sustainable generation of electricity; (b) development of adequate and efficient transmission systems; (c) revitalization of DISCOMs; (d) development of efficient markets for electricity; (e) supply of reliable and quality power in line with specified standards in an efficient manner; (f) move towards light- touch regulation; and (g) promotion of manufacturing goods and services in India in the generation, transmission and distribution segments of the power sector under the Make in India initiative and Atmanirbhar Bharat Abhiyan (self-reliance scheme).
Central Electricity Regulatory Commission (Indian Electricity Grid Code) Regulations, 2010 (“Grid Code”)
The CERC in these regulations, as amended from time to time, has laid down the rules, guidelines, and standards to be followed for planning, developing, maintaining and operating the power systems, in the most secure, reliable, economic and efficient manner. These regulations have been amended to require the wind and solar power generators to forecast and schedule their power generation on a day ahead basis. Further, the Grid Code provides a “must-run” status to all solar and wind power plants and exempts such power plants from “merit order dispatch” principles. The schedule by wind and solar generators which are regional entities may be revised by giving advance notice to the relevant regional load dispatch centre.
Guidelines for Development of Onshore Wind Power Projects, 2016 (“MNRE Guidelines”)
The Ministry of New and Renewable Energy (“MNR”) initially issued guidelines for orderly growth of the wind power sector, which were subsequently revised from time to time. These guidelines aim to facilitate the development of wind power projects in an efficient and cost-effective manner.
Revised Guidelines for Wind Power Projects (“Wind Power Guidelines”)
To ensure quality of wind farm projects and equipment, MNRE introduced the Wind Power Guidelines which were revised and addressed to the erstwhile State Electricity Boards, state nodal agencies and financial institutions such as Indian Renewable Energy Development Agency Limited (“IREDA”). The Wind Power Guidelines provide for, inter alia, proper planning, selection of quality equipment and implementation, performance and monitoring of wind power projects.
Renewable Purchase Obligations
The Electricity Act promotes the development of renewable sources of energy by requiring the SERCs to ensure grid connectivity and the sale of electricity generated from renewable sources. In addition, the Electricity Act and the Tariff Policy require the SERCs to specify, for the purchase of electricity from renewable sources, a percentage of the total consumption of electricity within the area of a distribution licensee, which are known as RPOs. RPOs are required to be met by obligated entities (distribution licensees, captive power plants and open access consumers) by purchasing renewable energy, either by renewable energy power producers such as the Group, or by purchasing renewable energy certificates (“RECs”). In the event of default by an obligated entity in any fiscal year, the SERC may direct the obligated entity to pay a penalty or to deposit an amount determined by the relevant SERC, into a fund to be utilized for, among others, the purchase of RECs.
Generation Based Incentive Scheme (“GBI Scheme”)
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To encourage generation from wind energy projects, MNRE notified the GBI Scheme for grid connected wind power projects on December 17, 2009 which is currently applicable to the wind power projects which were commissioned and registered under the GBI Scheme during period commencing from the date of the aforementioned notification and up to March 2017. GBIs under the GBI Scheme are available for the wind power projects selling electricity to the grid and captive wind power projects but exclude wind power projects that undertake third-party sales. Only those wind power projects which sell electricity at the tariff announced by SERCs and/or state governments are eligible for benefits under the GBI Scheme. The objective of the GBI Scheme is to (i) broaden the investor base; (ii) incentivize actual generation with the help of generation/outcome based incentives; and (iii) facilitating entry of large independent power producers and foreign direct investment in the Indian wind power sector. Under the GBI Scheme, generation-based incentives are available for a minimum period of four years and maximum period of 10 years.
Ujwal Discom Assurance Yojana (“UDAY”)
UDAY is a scheme formulated by the Ministry of Power, Government of India, pursuant to an Office Memorandum dated November 20, 2015. It provides for the financial turnaround and revival of Power Distribution companies, (“DISCOMs”). The scheme is applicable only to state-owned DISCOMs including combined generation, transmission, and distribution undertakings.
The various state governments, their respective DISCOMs and the Government of India have entered into agreements which stipulate responsibilities of the entities towards achieving the operational and financial milestones under the scheme. One of the features of this scheme is that the States have agreed to take over 75% of the debt of the DISCOMs as of September 30, 2015 over a period of two years–50% of the DISCOM debt in 2015-16 and 25% in 2016-17 as per the mechanism provided for in the scheme.
National Solar Mission (“NSM”)
NSM was approved by the Government of India on November 19, 2009 and launched on January 11, 2010. The target for solar deployment was enhanced to 100 GW of solar power in India by 2022. The target principally comprises 40 GW rooftop solar power projects and 60 GW large and medium scale grid connected solar power projects. In addition, the Government of India on March 22, 2017 sanctioned the implementation of a scheme to enhance the capacity of solar parks from 20,000 MW to 40,000 MW for setting up at least 50 solar parks each with a capacity of 500 MW and above by 2019-2020, which was further extended to 2021-2022.
Central Electricity Regulatory Commission (Open Access in Inter-State Transmission) Regulations, 2008 (“CERC Open Access Regulations”)
The CERC Open Access Regulations, as amended from time to time, for inter- state transmission provide for a framework which not only facilitates traditional bilateral transactions (negotiated directly or through electricity traders), but also caters to collective transactions discovered in a power exchange through anonymous, simultaneous competitive bidding by sellers and buyers. Applicable to short term open access transactions up to one month at a time, the emphasis of the CERC Open Access Regulations is on scheduling rather than reservation to ensure that the request of an open access customer is included in the dispatch schedules released by RLDCs. Further, certain types of transmission services by payment of transmission charges (to be levied in Rupees per MWh) shall be available to open access customers based on the type of transactions, i.e., bilateral or collective. In addition to transmission charges, certain operating charges shall also be levied. The CERC Open Access Regulations enable entities connected to inter-state transmission as well as intra-state transmission and distribution systems to purchase power from a source other than the incumbent distribution licensee situated outside the relevant State. The CERC Open Access Regulations were last amended in December 2019, establishing procedures for scheduling of transactions in the real-time market.
Central Electricity Regulatory Commission (Grant of Connectivity, Long-term Access and Medium-term Open Access in inter-State Transmission and related matters) Regulations, 2009 (“CERC Connectivity & Access Regulations”)
The CERC Connectivity & Access Regulations, as amended from time to time, provide a framework for granting connectivity, medium and long-term access to the inter-state transmission system (“ISTS”) Any power generating station, including a captive generating plant or a bulk consumer, is authorized to seek connectivity, medium and long-term access to the ISTS in accordance with the provisions made under these Regulations. CERC Connectivity & Access Regulations identifies Central Transmission Utility (“CTU”) as the nodal agency for grant of connectivity. With respect to medium and long-term
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access to ISTS, CTU is mandated to frame procedures concurrent to the CERC Connectivity & Access Regulations covering all the aspects as envisaged in the CERC Connectivity & Access Regulations in detail. For grant of connectivity, wind and solar based projects are treated differently by CERC Connectivity & Access Regulations, as a separate set of procedures is framed for wind and solar projects safeguarding the interests of renewable energy projects and the transmission system owner.
Central Electricity Regulatory Commission (Sharing of Inter-State Transmission Charges and Losses) Regulations, 2020 (“CERC Transmission Charges Regulations 2020”)
The CERC Transmission Charges Regulations 2020, as amended on February 7, 2023, provides a framework for sharing of charges among the entities for using the ISTS network. As per the CERC Transmission Charges Regulations 2020, transmission charges and losses for the use of ISTS are not applicable for solar power-based projects whose useful life has been commissioned during the period from July 1, 2011 to June 30, 2023 and for wind power-based projects whose useful life has been commissioned during the period from July 1, 2017 to June 30, 2023. The CERC Transmission Charges Regulations 2020 has come into force from November 1, 2020 and has superseded the CERC Transmission Charges Regulations 2010. The CERC Transmission Charges Regulations 2020 accorded ISTS transmission charges waiver to wind, solar and hydro projects as follows:
| ● | REGS or RHGS based on wind or solar sources or hydro PSP ESS which have declared commercial operation up to June 30, 2025 shall be considered for waiver of transmission charges. for a period of 25 years from date of COD; |
| ● | Battery ESS charged with REGS or RHGS based on wind or solar sources which have declared commercial operation up to June 30, 2025 shall be considered for waiver of transmission charges for a period of 12 years from date of COD; |
| ● | Hydro generating station where: (a) PPAs are signed on or after December 1, 2022 but on or before June 30, 2025; and (b) construction work is awarded on or before June 30, 2025 shall be considered for waiver of transmission charges under the CERC Transmission Charges Regulations 2020, for a period of 18 years from the date of COD of the hydro generating station post June 30, 2025; and |
| ● | ISTS charges shall be levied in a staggered manner with annual increments of 25% post June 30, 2025. |
Central Electricity Regulatory Commission (Deviation settlement Mechanism and related matters) Regulations, 2022 (“F&S Regulations”)
The CERC in these regulations, as amended from time to time, has laid down rules guidelines and standards for maintaining grid discipline and grid security as envisaged under the Grid Code through the commercial mechanism for Deviation Settlement through withdrawal and injection of electricity by the users of the grid including wind and solar based plants connected to an interstate transmission network. The wind and solar generators connected to interstate transmission networks are required to provide a daily 15 minutes’ time block wise generation schedule. The schedule may be revised by giving advance notice to the relevant Regional Load Despatch Centre. Any deviations between actual generation with respect to the schedule generation in the 15-minute time block is liable to attract commercial charges as per the formula prescribed in the F&S Regulations.
Electricity (Timely Recovery of Costs due to Change in Law) Rules, 2021 (“Change in Law Rules”)
The Change in Law Rules, provide the mechanism for adjustment and recovery of monthly tariff or charges upon the occurrence of a change in law (such as change in any domestic tax including duty, levy, cess, or charges as specified under the Change in Law Rules), for the compensation of the affected party to restore such affected party to the same economic position as if such change in law had not occurred. Change in law, as per the Change in Law Rules, unless otherwise defined in the relevant agreement means, any enactment or amendment or repeal of any law, made after the determination of tariff under the Electricity Act, 2003, leading to corresponding changes in the cost requiring change in tariff. Where the relevant agreement does not lay down a formula for calculation of the amount of the impact of a change in law to be adjusted and recovered, such impact shall be calculated in accordance with the formula provided in the Change in Law Rules, which is based on, among other things, the estimated monthly electricity generation, contracted capacity of the power plant as per the agreement, normative plant load factor and capacity utilization factor. The generating company or transmission licensee shall, within thirty days of the coming into effect of the recovery of impact of change in law, furnish all relevant documents along with the details of calculation for adjustment of the amount of the impact in the monthly tariff or charges to the appropriate commission, which shall verify the calculation and adjust the amount of impact within 60 days from the date of receipt of the relevant documents. After such adjustment, the generating company or transmission licensee, as the case may be, shall adjust the monthly tariff or charges annually based on actual amount recovered, to ensure that the payment to the affected party is not more than the yearly annuity amount. The Ministry of Power, pursuant to its circular dated February 21, 2022, clarified that this Change in Law
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Rules will be applicable on the events occurred on or after the date of notification of this Change in Law Rules.
Electricity (Promotion of Generation of Electricity from Must-Run Power Plant) Rules, 2021 (“Must-Run Rules”)
Under the Must-Run Rules, a wind, solar, wind-solar hybrid or hydro power plant (in cases where water levels could lead to flooding risk) or a power plant from any other sources, as may be established from time to time by the relevant governmental authority, that has entered into an agreement to sell electricity to any person is a ‘must-run power plant’. A must-run power plant is not subject to reduction or regulation of generation or supply of electricity on account of merit order dispatch or any other commercial consideration, except in the event of technical constraint in the electricity grid or for reasons of security of the electricity grid. In the event of reduced demand by a procurer from a must-run power plant, compensation is payable by the procurer to the must -run power plant at the rates specified in the agreement for purchase or supply of electricity. In the event of any technical constraint in the electricity grid or for reasons of security of the electricity grid, where the procurer notifies the must-run power plant in advance of a reduction, the must-run power plant will sell the electricity not utilized by the procurer on the open market. The amount realized by such must-run power plant from such sale of electricity on the open market, after deducting actual expenses paid for the sale on the open market, if any, shall reduce the compensation payable by the procurer. Amounts owed pursuant to the foregoing will be paid by the procurer on a monthly basis with any offset payment paid by the must-run power plant to the procurer within one month of the close of the fiscal year.
Electricity (Late Payment Surcharge) Rules, 2022 (“LPS Rules 2022”)
The LPS Rules 2022 were notified by the Ministry of Power on June 3, 2022. The LPS Rules 2022 are applicable for payments to be made in pursuance of power purchase agreements, power supply agreements and transmission service agreements, where tariff is determined under the Electricity Act, 2003, including such agreements which become effective before the LPS Rules 2022 came into force. The LPS Rules 2022 provide that late payment surcharge, that is, the charges payable by a distribution company to a generating company or electricity trader for power procured from it, or by a user of a transmission system to a transmission licensee on account of delay in payment of monthly charges beyond the due date, shall be payable on the payment outstanding after the due date at the base rate of late payment surcharge applicable for the period for the first month of default. The rate of late payment surcharge for the successive months of default shall increase by 0.5% for every month of delay provided that the late payment surcharge shall not be more than 3 percent higher than the base rate at any time and shall not be higher than the rate specified in the agreement for purchase or transmission of power. All payments by a distribution licensee to a generating company or a trading licensee for power procured from it or by a user of a transmission system to a transmission licensee shall be first adjusted towards late payment surcharge and thereafter, towards monthly charges, starting from the longest overdue bill. LPS Rules 2022 also provides for regulation of access to power in case of non-payment of dues within the specified time period. The over-dues of the prior period, i.e., up to June 3, 2022, shall be liquidated through equated monthly installments as per the provision of the LPS Rules 2022.
Electricity (Promoting Renewable Energy Through Green Energy Open Access) Rules, 2022 (“Green Energy Open Access Rules 2022”)
The Ministry of Power notified the Green Energy Open Access Rules 2022 on June 6, 2022 with the objective of ensuring access to affordable, reliable, sustainable and green energy. The reduction of the open access transaction limit from 1 MW to 100 kW and appropriate provisions for cross-subsidy surcharge, additional surcharge, and standby charge is expected to incentivize consumer access to green energy at reasonable rates.
Central Electricity Regulatory Commission (Connectivity and General Network Access to the inter-State Transmission System) Regulations, 2022 (“GNA Regulations”)
The CERC issued the GNA Regulations on June 7, 2022, which, when fully implemented, will replace CERC regulations form 2009. The GNA Regulations provide electricity generators with general network access, allowing them to connect to and distribute power through the inter-state transmission system without designating the location of the offtaker. The GNA Regulations also contemplate grant of temporary GNA (T-GNA), which provides an open access right to an eligible buying entity for a duration of up to 11 months.
Ministry of Environment - E-Waste (Management) Rules, 2022
These rules apply to every manufacturer, producer refurbishes dismantler and recycler involved in manufacture, sale, transfer, purchase, refurbishing, dismantling, recycling and processing of e- waste or electrical and electronic equipment, including Solar panels/cells, solar Photovoltaic panels/cells/modules under (ii) Consumer Electrical and Electronics and
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Photovoltaic.
This rule requires every manufacturer and producer of solar photo-voltaic modules or panels or cells to also:
| ● | Store solar photo-voltaic modules or panels or cells waste generated up to the year 2034 - 2035 as per the guidelines laid down by the CPCB in this regard; |
| ● | Ensure that the processing of the waste other than solar photo-voltaic modules or panels or cells; |
| ● | Ensure that the inventory of solar photo-voltaic modules or panels or cells shall be put in place distinctly on portal; and |
| ● | Comply with standard operating procedure and guidelines laid down by CPCB. |
Ministry of Environment, Forest and Climate Change - Plastic Waste Management Rules, 2016
These rules apply to every waste generator, local body, village body, manufacturer, importers and producer. The rules do not apply to the export oriented units or units in special economic zones, notified by the Central Government, manufacturing their products against an order for export only.
The waste generator must take steps to minimize generation of plastic waste and segregate plastic waste at source in accordance with the Solid Waste Management Rules, 2000; not litter plastic waste and ensure segregated storage of waste at source; and handover segregated waste to the relevant local body or agencies appointed by them or registered waste pickers’, registered recyclers or waste collection agencies.
Renewable energy certificates (“RECs”)
The CERC notified the Central Electricity Regulatory Commission (Terms and Conditions for Recognition and Issuance of Renewable Energy Certificate for Renewable Energy Generation) Regulations, 2010 (“REC Regulations”) on January 14, 2010 and the same was amended on September 29, 2010, July 10, 2013, December 30, 2014 and March 28, 2016. The REC Regulations aim at the development of markets for power from non-conventional energy sources by issuance of transferable and saleable credit certificates. The REC Regulations facilitate fungibility and inter-state transaction of renewable energy with least cost and technicality involved. The CERC has nominated the National Load Dispatch Centre as the central agency to perform certain functions, including, inter alia, registration of eligible entities, issuance of certificates, maintaining and settling accounts in respect of certificates, acting as repository of transactions in certificates and such other functions incidental to the implementation of REC mechanism as may be assigned by the CERC. The REC mechanism provides a market-based instrument which can be traded freely and provides means for fulfillment of RPOs by the distribution utilities/consumers.
Central Electricity Regulatory Commission (Terms and Conditions for Renewable Energy Certificates for Renewable Energy Generation) Regulations, 2022
According to the new regulations, renewable energy generating stations, captive generating stations based on renewable energy sources, distribution licensees, and open access consumers are now eligible to issue renewable energy certificates (RECs).
The national load despatch center (NLDC) has been designated the agency to implement these regulations. REC Regulations stipulated the details of Grant of accreditation, Issuance, Exchange, Redemption, Denomination, Pricing and Validity for certificates. CERC has also introduced certificate multiplier for renewable energy generating station, Hydro, municipal solid waste, non- fossil fuel-based cogeneration and biomass and biofuel. Certificate once assigned to a renewable energy generating station, the certificate multiplier will remain valid for 15 years.
National Wind-Solar Hybrid Policy (“Hybrid Policy”)
MNRE announced the Hybrid Policy on May 14, 2018, with an aim to encourage renewable power generation and promote new projects as well as hybridization of the existing wind and solar projects. The policy was amended on August 13, 2018. The main objective of the Hybrid Policy is to provide a framework for promotion of large grid connected wind-solar photovoltaic hybrid systems for optimal and efficient utilization of transmission infrastructure and land, reducing the variability in renewable power generation and achieving better grid stability.
The implementation of wind solar hybrid systems will be/was on the basis of different configurations and use of technology. The Hybrid Policy mandates the Central Electricity Authority and the CERC to formulate necessary standards and
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regulations for wind-solar hybrid systems.
Guidelines for Tariff Based Competitive Bidding Process for procurement of power from Grid Connected Wind Solar Hybrid Projects, 2020 (“Hybrid Projects Guidelines”)
Pursuant to the Hybrid Policy, a scheme was introduced on May 25, 2018 for setting up of 2500 MW of wind-solar hybrid power projects at a tariff discovered through competitive bidding. The Hybrid Projects Guidelines dated October 14, 2020, as amended, issued by MNRE provides a framework for procurement of electricity from ISTS grid connected wind-solar hybrid power projects and facilitates transparency and fairness in procurement processes. Further, power purchase agreements, (“PPAs”) entered into pursuant to these guidelines shall not have a term lesser than 25 years from the COD. These Guidelines have been issued under the provisions of Section 63 of the Electricity Act for long term procurement of electricity, determined through the competitive bidding process, by the procurers, the distribution licensees or an intermediary procurer from Inter State Transmission State grid-connected wind-solar hybrid power projects having individual size of 50 MW and above at one site with minimum bid capacity of 50 MW. The Hybrid Projects Guidelines as amended on March 9, 2022 and November 2, 2022 provide that where the distribution licensee, authorizes any agency to carry out the tendering/bidding process on its behalf then the agency will be responsible for fulfilling all the obligations imposed on the procurer during the bidding phase, in accordance with these Guidelines.
Approved Models and Manufacturers of Solar Photovoltics Modules (Requirements for Compulsory Registration) order 2019 (“ALMM Order”)
The GoI has introduced a list of approved module suppliers who will be eligible to supply modules to project developers selected to develop solar projects in government projects, government assisted projects, projects under government schemes and programs, open access, net-metering projects, installed in the country, including specified projects set up for sale of electricity to the government. The Ministry of New and Renewable Energy on March 10, 2023 stated that the projects commissioned by March 31, 2024 will be exempted from the requirement of procuring solar photovoltaic modules from the list of approved module suppliers.
Integrated Day Ahead Market
Pursuant to a notification dated March 24, 2021, the Ministry of Power, India, an integrated day-ahead market (“Integrated DAM”), is expected to be launched at the power exchanges with separate price formation for power generated from renewable energy and conventional power. According to this notification, the proposed market structure should allow the buyer to meet the RPO target by dire power from the exchange. The notification is proposed to be implemented by June 30, 2021.
Amendments to the guidelines for tariff-based competitive bidding process for procurement of Round-The-Clock (RTC) power from grid-connected renewable energy (RE) power projects, complemented with power from any other source or storage
The amendments were notified by the Government of India in February 2022 and provide that the bidding evaluation parameter will be the weighted average levelized tariff per unit supply of RTC power. The bidder will be selected on the basis of the lowest weighted average levelized tariff. If the allocated quantum of power to the bidder is less than the total quantum of power to be contracted, capacity allocation will be on the basis of the bidder’s capacity to fill the tendered capacity until it is exhausted. This compares to the previous system wherein the remaining qualifying bidders (except the lowest cost bidder) were asked to match the tariff of the lowest cost bidder.
Guidelines for Procurement and Utilization of Battery Energy Storage Systems as part of Generation, Transmission and Distribution Assets, along with Ancillary Services
The guidelines were notified by the Government of India in March 2022 and aim to facilitate the procurement of battery storage systems to be utilized either in combination with renewable energy or as a standalone asset. These guidelines will also play a critical role in achieving the nation’s renewable energy and decarbonization goals. Business opportunities identified by the Ministry of Power in this space include BESS coupled with RE and with transmission infrastructure and storage for distribution and ancillary services.
Revised Scheme for Flexibility in Generation of Thermal/Hydro Power Stations through Bundling with Renewable Energy and Storage Power
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A revised scheme was notified by the Government of India in April 2022. The revisions provide flexibility in generation and scheduling of power from thermal/hydro plants through bundling with renewable energy. This reduces the cost of power and helps distribution companies to meet renewable purchase obligations for distribution licensees to meet a certain minimum quantity of their power requirement from renewable sources.
Guidelines for Encouraging Competition in Development of Transmission Projects and Tariff based Competitive-bidding Guidelines for Transmission Service, 2021
The MoP and the GoI issued the Guidelines for Encouraging Competition in Development of Transmission Projects (“CDTP Guidelines”) and the Tariff based Competitive-bidding Guidelines for Transmission Service on August 10, 2021 (“TBCB Guidelines”), framed under the provisions of Section 63 of the Electricity Act in order to facilitate the smooth and rapid development of transmission capacity in the country as envisaged in the NEP and the NTP such that inter-state/intra-state transmission projects, other than those exempted by the GoI are implemented through tariff based competitive bidding. The CDTP Guidelines provides for the preparation of a) perspective plan for fifteen years, b) short term plan for five years, both collectively being a part of the National Electricity Plan by the Central Electricity Authority and c) a network plan prepared by the Central Transmission Utility based upon the National Electricity Plan prepared in accordance with the NEP which will be reviewed and updated as and when required but not later than once a year. Information will be made available to the stakeholders regarding new projects and the respective technical and other specifications for the purpose of project formulation and for enabling competitive bidding to take place. In addition, the selection of developers for identified projects would be through tariff based competitive bidding through e-reverse bidding for transmission services according to the TBCB Guidelines. Additionally, the nodal agency shall appoint an independent engineer during the construction phase in accordance with the framework prescribed in the CDTP Guidelines.
The TBCB Guidelines apply to the procurement of transmission services for the transmission of electricity through tariff-based competitive bidding. The TBCB Guidelines aim at facilitating competition through wider participation in providing transmission services and tariff determination through a process of tariff-based bidding.
The TBCB Guidelines provide that a Bid Process Coordinator (“BPC”) would be responsible for conducting the bid process for the procurement of the required transmission services for inter-state and intra-state transmission projects to be implemented under the tariff-based competitive bidding process prescribed. For the procurement of transmission services, the BPC shall adopt a single stage two envelope tender process featuring the requirement of a request for proposal with the preparation of bid documents as per the prescribed requirements. The initial price offer submitted online with the request for proposal will be evaluated based on annual transmission charged for all components covered under the package as quoted by the bidder. The bidders will undertake in the prescribed e-reverse bidding process with the minimum of two qualified bidders.
On selection of the bidder and issue of letter of intent from the BPC, the selected bidder shall execute the share purchase agreement to acquire the special purpose vehicle created for the project to become the transmission service provider in accordance with the bid made and consequently execute the transmission service agreement in accordance with the TBCB Guidelines. The transmission service provider shall accordingly be required to make an application for the grant of a transmission license to the appropriate commission within five working days from the date of execution of the share purchase agreement for the acquisition of the special purpose vehicle.
(ii) Environmental Laws
The Central Pollution Control Board of India (“CPCB”) a statutory organization established in 1974 under the Ministry of Environment, Forest and Climate Change (“MoEF&CC”) is responsible for setting the standards for maintenance of clean air and water and providing technical services to the MoEF&CC.
CPCB has classified industrial sectors under the red, orange, green and white categories. The newly introduced white category pertains to those industrial sectors which are practically non-polluting, including solar power generation through photovoltaic cells, wind power projects of all capacities and mini hydroelectric power. In relation to the white category of industries, only intimation to the relevant State Pollution Control Board is required, and there is no requirement to obtain a consent to operate within this category. However, to the extent they are applicable to the entities prescribed under the relevant legislation, the pollution control laws in India must be adhered to.
Solar PV Cell manufacturing plant is covered under the red category and there is a requirement to obtain consent to
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operate in this category.
National Action Plan on Climate Change
The National Action Plan on Climate Change, or the “NAPCC,” issued by the Government of India in 2008 has recommended that the national renewable energy generation standard be set at 5% of total grid purchase and that it be increased by 1% each year for ten (10) years, with the option for the SERCs to set higher minimum percentages than 5%, to ensure that by 2020, 15% of the total power capacity is generated from renewable energy sources. NAPCC also recommends imposition of penalty under the Electricity Act in case of utilities falling short to meet their RPOs.
National Wind Mission
In order to boost electricity generation from on-shore and off-shore wind sources, ensure certainty for stakeholders and capacity building, the MNRE has formulated the National Wind Mission, which provides for, inter alia, single window clearance for wind energy projects, land allocation mechanisms, tariff and financing mechanisms.
Green Hydrogen Policy
In January 2023, the Ministry of New and Renewable Energy Green Hydrogen Mission was notified to produce 5 MMT of Green Hydrogen per annum by 2030, with potential to reach 10 MMT per annum. The Mission will support replacement of fossil fuels and fossil fuel based feedstocks with renewable fuels and feedstocks based on Green Hydrogen. This will include replacement of hydrogen produced from fossil fuel sources with Green Hydrogen in ammonia production and petroleum refining, blending Green Hydrogen in city gas distribution systems, production of steel with Green Hydrogen, and use of Green Hydrogen-derived synthetic fuels (including Green Ammonia, and Green Methanol) to replace fossil fuels in various sectors including mobility, shipping, and aviation. The Mission also aims to make India a leader in technology and manufacturing of electrolysers and other enabling technologies for Green Hydrogen.
Energy Conservation (Amendment) Bill, 2022
The Energy Conservation (Amendment) Bill, 2022 was passed in December 2022, with the intention of encouraging the use of biofuels, green hydrogen and other renewable energy sources, as well as promoting the trading of carbon credits.
The bill includes the following key provisions:
| 1. | Mandating minimum use of non-fossil fuel sources for industries (mining, steel, cement, textile, chemicals and petrochemicals) and commercial buildings. |
| 2. | Enabling government authorities to specify a system for trading carbon credits and for carbon markets. |
| 3. | Enhancing the scope and coverage of the Energy Conservation Building Code |
Measures to promote Hydropower:
In March 2019, the Government of India issued measures to promote hydropower including:
| 1. | Declaring Large Hydropower Projects (>25 MW) as renewable energy. |
| 2. | Rationalizing hydropower tariff. |
| 3. | Budgetary support for flood moderation and Storage Hydro Electric Projects (HEPs). |
| 4. | Budgetary Support for enabling infrastructure. |
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II. OPERATING AND FINANCIAL REVIEW AND PROSPECTS
The following discussion of our business, financial condition and results of operations should be read in conjunction with our consolidated financial statements and the related notes included elsewhere in this annual report. This discussion contains forward-looking statements and involves numerous risks and uncertainties, including, but not limited to, those described in “Risk Factors” and elsewhere in this annual report. Actual results could differ materially from those contained in any forward-looking statements.
A. Overview
We are committed to remain a leader and pioneer of the renewable energy market in India. We sell renewable power to our customers in India on long term fixed price contracts, in many cases at prices at or below prevailing alternatives for our customers. Our financial strategy is to build our renewable energy assets with the most efficient cost of capital available to us. Since we have engineering, procurement and construction as well as O&M capabilities in-house, we retain the value creation at all stages of development and operation. Through value engineering, operational performance monitoring and efficient financial strategy, we are able to deliver cost-effective energy to our customers.
We recognize revenue monthly, from renewable energy sold to our customers on a per kilowatt hour basis for the electricity supplied by our renewable power plants. We sell renewable energy based on terms in Power Purchase Agreements or “PPAs”.
The energy output of our plants is dependent in part on the quantum of solar irradiation at plant locations. As a result, our revenue is impacted by seasonal patterns such as shorter daylight hours in winters as well as daily and annual fluctuation in insolation. Typically, our plant load factor, or “PLF”, from operational solar power plants is lowest in the third quarter and highest in the first quarter of any given fiscal year (which ends on March 31).
A significant portion of the cost of our solar power plants consists of solar photovoltaic panels (or solar modules as they are called generally), inverters and other plant equipment. Other less significant costs include the cost of land or leasehold land costs, and installation costs. Our cost of operations primarily consists of expenses pertaining to operations, maintenance and insurance of our solar power plants. These expenses include payroll and related costs for plant maintenance staff, plant maintenance, insurance and, if applicable, lease costs. The cost of financing is a significant element in the overall cost of development and operations.
Under U.S. GAAP, we depreciate the capital cost of solar power plants over the estimated useful life of 25-35 years. We typically fund our projects through a mix of project finance and sponsor equity. Our project financing agreements typically restrict the ability of our project subsidiaries to distribute funds to us unless specific financial thresholds are met on specified dates. Some of our project finance borrowings are denominated in U.S. dollars, while we seek to hedge, fluctuations in the U.S. dollar exchange rate, any unhedged foreign currency exchange exposure can adversely impact our profitability. We seek to finance longer term and at fixed rates, but some of our borrowings have variable interest rates and changes in such rates may lead to an adverse effect on our overall cost of capital.
We use certain financial and non-financial non-U.S. GAAP measures to provide a comparison of our performance. The non-financial metrics include electricity generation, PLF, MW operating, MW Contracted & Awarded and MW Operating, Contracted & Awarded. We also use certain non-U.S. GAAP financial metrices such as Cost per MW operating, portfolio revenue run-rate, Adjusted EBITDA and Cash Flow to Equity to provide a comparison of our financial results. We use non-financial metrics that are commonly used in the industry to help users compare us with our peers and better demonstrate growth in terms of our current capacity, as well as our future capacity. We understand that non-U.S. GAAP measures helps investors compare our performance period over period and assess how we have improved productivity in reducing the cost of building a plant through cost per megawatt as well as measure the output of the plants through PLFs. The non-financial metrics are used by analysts and investors in arriving at a fair valuation of the Company by projecting future revenue as well as predicting the results of the company.
We classify a financial measure as being a non-U.S. GAAP financial measure if that financial measure excludes or includes amounts, or is subject to adjustments that have the effect of excluding or including amounts, that are not included or excluded in the most directly comparable measure calculated and presented in accordance with U.S. GAAP as in effect from time to time in the United States in our statements of operations, balance sheets or statements of cash flows. The non-U.S. GAAP financial measures are supplemental measures that are not required by, or are not presented in accordance with, U.S.
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GAAP. Non-U.S. GAAP financial measures do not include operating, other statistical measures or ratios calculated using exclusively financial measures calculated in accordance with U.S. GAAP. Moreover, the way we calculate the non-U.S. GAAP financial measures may differ from that of other companies reporting measures with similar names, which may limit these measures’ usefulness as a comparative measure.
Certain Factors affecting our Results
Late filing of this Form 20-F and NYSE delisting
We did not file our annual report on Form 20-F for fiscal 2022 (the “2022 Form 20-F”) and Fiscal 2023 including interim filings by the timelines required under SEC rules. In accordance with SEC rules, we are now unable to file new Form F-3 registration statements (including shelf registration statements) until such time we have timely filed all required SEC reports for 12 calendar months.
The NYSE suspended trading of our shares on July 13, 2023 due to our failure to timely file our periodic reports, including 2022 Form 20-F, in violation of their listing rules. We are appealing the NYSE’s decision, but, if our appeal is unsuccessful, our shares will be delisted, and no further trading on the NYSE will be possible. Consequently, our shares are only available to trade on the over-the-counter (or OTC) “expert” market, where quotations only will be directly available to broker dealers and professional investors (not to retail investors).
See “Risk Factors - The New York Stock Exchange (NYSE) has commenced procedures to delist our Company’s shares and our failure to timely file periodic reports with the SEC may result in the delisting of our Company’ shares.”
Cashflow and Liquidity Position:
Our expansion plans in Fiscal 2024, if consummated, will require additional financing. We expect to incur substantial capital expenditure as well as operating and financial expenses, and, if so, our cash reserves and cash flow from operations may be insufficient to meet our planned obligations. Our ability to obtain additional financing on favorable terms, if at all, will depend on several factors, including our future results of operations, financial condition and cash flows, the amount and terms of existing indebtedness, general market conditions and market conditions for financing activities and the economic, political and other conditions in the markets where we operate. Our ability to raise financing on acceptable terms also depends on our credit ratings and may also be affected by the failure to deliver audited consolidated financial statements and the financial statements of subsidiaries and restricted borrowing groups in accordance with financing documents. We can make no assurances that we will be able to raise additional financing on acceptable terms in a timely manner or at all. Failure to obtain additional financing on acceptable terms and in a timely manner could adversely affect our business, results of operations, financial condition and cash flows. See “Risk Factors – Our cash reserves and cash flows may be insufficient to meet our working capital requirements and expansion plans absent further financing. Accordingly, our failure to obtain additional financing on acceptable terms and in a timely manner could materially and adversely affect our financial condition.”
Defaults under our Loan Agreements:
Timely submission of financial statements of the Group, our subsidiaries and/or our subsidiary restricted groups is a key covenant in most of our financing agreements. Due to our inability to meet these covenants to date in respect of Fiscal 2022 and Fiscal 2023 (and interim periods therein), we secured extensions from our lenders in respect of these covenants until June 30, 2023 and July 15, 2023 (in one case). We have requested each of the applicable lenders for a further extensions until October 31, 2023, for submission of our financial statements for Fiscal 2022, and until December 31, 2023, for submission of our financial statements for Fiscal 2023.
While we received the requested extensions from several lenders, we have not yet received the requested extensions from lenders representing INR 14,089 million (US$ 185.7 million) of our external indebtedness. In this regard, our auditors have provided in their audit report that these “events raise a substantial doubt about the Company’s ability to continue as a going concern.” See “Consolidated Financial Statements - Report of Independent Registered Public Accounting Firm” on page F-2.
The Company is currently under discussions with its lenders to obtain the requisite extensions and expects to receive them in due course. The lenders who have not granted such extensions have rights under the respective financing agreements to take actions including (but not limited to) acceleration of the repayment of all or some of the indebtedness owed to them and/or security enforcement under the terms of the applicable financing agreements. Any such actions by lenders also could result in cross-defaults or cross-accelerations of other indebtedness and could materially and adversely affect our business, results of operations, financial condition and cash flows.
In addition, due to our inability to meet these information covenants to date, some of our lenders have started charging us penalty interest rates. In addition, in some of our borrowing facilities, the lenders have also revised the rate of interest upward due to delay in Fiscal 2022 audited financial statements and our downgrade in credit ratings. These penal rates of interest and higher rates of interest have increased our finance costs for the projects to which these loans relate. While the penal interest
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may cease to be charged upon finalization and submission of the delayed financial statements, the rate of interests which have been revised upwards may not be reverted to pervious levels, and, therefore, may result in continued higher cost of funds for our debt borrowings for these projects.
Credit Rating Downgrades:
Most of our external borrowings are required to be rated by accredited credit rating agencies. In Fiscal 2023 and Fiscal 2024, the rating agencies Fitch Ratings, Moody’s Investor Service, CRISIL and Care Ratings have each downgraded or announced a review of credit ratings with negative implications of the credit ratings of one or more of our subsidiaries. Downgrades in our credit ratings and other factors have led to interest rate increases in respect of some of our certain of our borrowings which has increased our financing costs and other similar interest rate increases are possible.
The table below sets forth our ratings and downgrades in Fiscal 2023 and Fiscal 2024 with respect to various borrowings.
| Borrower or Borrower Group | Borrowing | Rating Agency | Downgrade Action |
| Azure Power India Private Limited | Long term & Short term | CRISIL | On December 23, 2022, long term downgraded to A+ (from AA-) and short term downgraded to A1 (from A1+) |
| On May 29, 2023 long term downgraded to A (from A+) | |||
| On July 11, 2023, long term downgraded to BBB+ (from A) and short term downgraded to A2 (from A1). | |||
| Azure Power India Private Limited | Long term & Short term | CARE | On December 27, 2022, long-term to A+ (from AA-) |
| On May 15, 2023, long-term downgraded to A (from A+) and short term downgraded to A1 (from A1+) | |||
| On July 15, 2023, long-term downgraded to BBB+ (from A) and short term downgraded to A2 (from A1). | |||
| Azure Power Maple Private Limited | Long Term | CRISIL | On December 23, 2022, long term downgraded to A (from A+) |
| On May 29, 2023 long term downgraded to A- (from A) | |||
| On July 11, 2023, long term downgraded to BBB+ (from A-) | |||
| Azure Power Forty Three Private Limited | Long Term | CRISIL | On December 23, 2022, long term downgraded to A+ (from AA-) |
| On May 29, 2023 long term downgraded to A (from A+) | |||
| On July 11, 2023, long term downgraded to BBB+ (from A) | |||
| Azure Power Forty Private Limited | Long Term | CRISIL | On December 23, 2022, long term downgraded to A (from A+) |
| On May 29, 2023 long term downgraded to A- (from A) | |||
| On July 11, 2023, long term downgraded to BBB+ (from A-) | |||
| Azure Power Forty Private Limited | Long Term | CARE | On Feb 13, 2023 long term downgraded to A- (from A) |
| On July 18, 2023, long term downgraded to BBB (from A-) | |||
| Azure Solar Private Limited | Long Term | CARE | On July 18, 2022, long term downgraded to A (from AA-) |
| Azure Power (Rajasthan) Private Limited | Long Term | CARE | On July 18, 2022, long term downgraded to A (from AA-) |
| Azure Power Jupiter Private Limited | Long Term | CARE | On July 18, 2022, long term downgraded to A (from AA-) |
| Restricted Group - II | Long Term | Fitch | On January 16, 2023, long term downgraded to BB- (from BB) |
| On June 26, 2023, long term downgraded to B (from BB-) |
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| Restricted Group – II | Long Term | Moody’s | On January 16, 2023, long term downgraded to Ba2 (from Ba1) |
| On May 29, 2023, long term downgraded to Ba3 (from Ba2) | |||
| On July 14, 2023, long term downgraded to B1 (from Ba3) and withdrawn | |||
| Restricted Group - III | Long Term | Fitch | On January 16, 2023, long term downgraded to BB (from BB+) |
| On June 26, 2023, long term downgraded to B (from BB) | |||
| Restricted Group - III | Long Term | Moody’s | On January 16, 2023, long term downgraded to Ba3 (from Ba2) |
| On May 29, 2023, long term downgraded to B1 (from Ba3) | |||
| On July 14, 2023, long term downgraded to B2 (from B1) and withdrawn |
Our rated borrowing as set forth in the table above, remain on negative credit outlook by each of the respective credit rating agencies, and, accordingly, further ratings downgrades could be announced by such agencies at any time.
See “Risk Factors - Any downgrade of our credit rating may result in increase in interest cost or may trigger covenant defaults under our loan agreements.”
Whistle-blower Allegations and Special Committee Investigation:
We have conducted investigations into whistle-blower claims and learned of other allegations in June, July, and October 2021 against certain directors, officers and employees and former officers and directors of the Company.
In June and July 2021, we received whistle-blower complaints alleging corrupt conduct in acquisition of land, improper use of political connections, special treatment of certain employees, payment of kickbacks, and improper conduct by our sales team (this specific allegation was later determined to be a hoax). Our Ethics Committee, supervised by the Board’s Audit and Risk Committee and with the support of outside counsel and forensic accounting professionals, conducted a fulsome investigation into these allegations and found none to be substantiated. We nonetheless implemented enhancements to our compliance program recommended by our advisors after the investigations had concluded.
In addition, on October 1, 2021, the Enforcement Directorate of India filed a Prosecution Complaint with a special court in New Delhi in respect of an earlier Enforcement Case Information Report. Our former Group Chief Financial Officer and current Chief Financial Officer of our subsidiary APIPL, Mr. Pawan Kumar Agrawal, is one of the individuals named and charged with the commission of offences under Sections 3 and 4 of the Prevention of Money Laundering Act, 2002 of India in relation to Mr. Agrawal’s prior employment. The relevant transactions that are the subject of the complaint predated Mr. Agrawal’s tenure as an employee and as Chief Financial Officer of the Company, and the criminal charges are not directed at, and do not concern, the Company or its subsidiaries. We will continue to monitor the proceedings as Mr. Agrawal defends the charges made against him.
We have conducted investigations into whistle-blower claims and other allegations against certain directors, officers and employees and former officers and directors of the Company. We have reported the allegations and our findings to the SEC and the Department of Justice and continue to cooperate with these authorities.
In May 2022, we received a whistle-blower complaint that alleged health and safety lapses, procedural irregularities, misconduct by certain employees, improper payments and false statements relating to one of our projects belonging to a project subsidiary. Following extensive investigation by the Ethics Committee, supervised by the Board’s Audit and Risk Committee and by external counsel and forensic professionals, we identified evidence of manipulation and misrepresentation of project data by some employees at that project site. Weak controls over payments to a vendor and failures to provide accurate information both internally and externally were found, but no direct evidence that any improper payment was made to any government official was identified. Further, in Fiscal 2023, we reported to SECI that this project had (i) shortfalls in generation and (ii) that it failed to timely complete and commission the requisite contractually required capacity. On January 3, 2023 and January 4, 2023, SECI advised us, inter alia, that the project may be liable for damages and penalties for shortfalls in generation
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and for not commissioning the full capacity required under its PPA in a timely manner.
In September 2022, we received an additional whistle-blower complaint containing similar allegations of misconduct as the May 2022 complaint, as well as allegations of misconduct related to joint ventures and land acquisition, allegations of our failure to be transparent with the market and advisors and other allegations. The Ethics Committee, supervised by the Board’s Audit and Risk Committee, with the support of external counsel and forensic accounting professionals, investigated these September 2022 allegations. The investigation of the September 2022 complaint identified significant control issues in the process of acquiring land and land use rights in relation to one of our projects. The investigation concluded that third party land aggregators may have been involved in improper payments but no improper transfer of money by the Group was identified. We have made an adjustment (de-capitalization) in the books of accounts of INR 135 million (US$ 1.8 million) on estimate, as a prudent measure in the given project. Further, we have reviewed the entire amount paid to land aggregators in other projects to identify any similar issue and after an assessment a further adjustment (decapitalisation) aggregating to INR 118 million (US$ 1.6 million) has been made in the books of account on estimate, as a prudent measure, though no improper payments by the Group could be identified.
We also identified potential misrepresentations made by former executives to the Board in July 2021 regarding an asset purchase transaction for the development of a wind project. In addition, it appears our former executive officers may have circumvented internal policies in connection with the approval of another transaction related to another wind project. We were not able to identify any evidence of improper payments related to either of these transactions. Considering the observations regarding the transactions, we have reassessed the valuation of the asset purchase and related government orders and did not find any adjustment that needed to be made in the books of account.
Our investigation did not substantiate other portions of this September 2022 whistle-blower complaint.
As part of our investigations of the May 2022 and September 2022 whistle-blower complaints, we also widened our review to include a review of projects commissioned in Fiscal 2022 and Fiscal 2023 to ensure that similar weaknesses were not present. As part of our investigations, we identified inconsistencies in project data in certain of our projects, but we identified no improper payments made in connection with these projects.
We have taken a range of actions due to these findings, and the employees involved in the misconduct are no longer associated with us. In accordance with the recommendations of the Ethics Committee, the Board’s Audit and Risk Committee and their legal and forensic advisors, we are implementing remedial measures in both project control and monitoring. Further, we reported the findings from its investigations of the May 2022 and September 2022 whistle-blower complaints to the SEC and the U.S. Department of Justice, and we continue to cooperate with these authorities.
In addition, a Special Committee of the Board of Directors (the “Special Committee”) was convened in August 2022 to review certain material projects and contracts over a three-year period for anti-corruption and related compliance issues. Independent outside counsel and forensic advisors were engaged to support the Special Committee. The Special Committee’s investigation has identified evidence that former executives were involved in an apparent scheme with persons outside the Company to make improper payments in relation to a project but no related improper payments or transfers by the Group have been identified. The Special Committee’s review and its findings could impact our decision-making in connection with such projects. We have disclosed the details of the Special Committee’s investigation to the SEC and the U.S. Department of Justice, and we continue to cooperate with those agencies.
Our Group including our subsidiaries with respect to affected projects could be exposed to liabilities under the relevant contractual and tender documents (including levy of damages and liquidated damages, reduction of PPA tariffs and/or short closure of capacity), administrative actions (including the risk of PPA cancellation, risk of being debarred from SECI’s future contracts, withdrawal or nullification of commissioning certificates and/or revocation of commissioning extensions) and penalties from customers and other civil liabilities, all of which could adversely impact the revenue, profitability and capitalization of the affected projects. In addition, fines and/or penalties by regulatory authorities (including by the SEC, the U.S. Department of Justice and applicable Indian regulatory authorities) could be imposed on us. Any such fines or penalties could materially and adversely affect our business, results of operations, financial condition and cash flows in future periods. In addition, we could be exposed to future litigation in connection with any findings of fraud, corruption, or other misconduct by our employees and former employees and executives.
For further information on the liabilities associated with the May 2022 and September 2022 whistle-blower complaints and the Special Committee investigation, see “Our Consolidated Financial Statements as of, and for the year ended,
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March 31, 2022, Note 27 – Whistle-blower Allegations and Special Committee Investigations”.
Projects under execution:
In Fiscal 2023, the economics of projects currently under execution by us, have deteriorated given geo-political constraints and inflation in the supply chain, particularly in module prices, higher interest rates and a strong U.S. dollar.
We are conducting an ongoing review of our projects under contract to consider their commercial and economic viability. We also have reviewed our projects including those under review by the Special Committee with respect to improper payment allegations and related compliance issues. For more information, see below “- We have conducted investigations into whistle-blower claims and other allegations against certain directors, officers and employees and former officers and directors of the Company. We have reported the allegations and our findings to the SEC and the Department of Justice and continue to cooperate with these authorities.”
In respect of our 2,333 MW projects in the state of Andhra Pradesh as part of its awarded 4,000 MW manufacturing linked projects, two Public Interest Litigations (“PILs”) were filed in the High Court of Andhra Pradesh in Fiscal 2022, challenging various aspects of the manufacturing linked tender and seeking to quash the Andhra Pradesh Regulator’s approval for procurement of capacity tied up by Andhra Pradesh Discoms with SECI pursuant to the tender. The tariff adoption for the capacities by the Central Electricity Regulatory Commission is subject to the outcome of the PILs. We are not a party to the PILs, and the PILs currently are pending adjudication. As a result of these PILs and because the tariffs have been conditioned on the outcome of the PILs, we have not initiated project execution including land acquisition and procurement. Given uncertainties, we initiated discussions with SECI regarding the 2,333 MW projects and have requested that SECI work with us toward a resolution of the matter through reallocation of the capacity to another state, termination of the PPAs or other resolution. In a letter received in August 2023, SECI has requested that we comply with the provisions of our PPA with SECI. We continue to engage with SECI on this matter and look toward a fair resolution. If were unable to resolve the matter with SECI, we could face claims under our PPA with SECI, which could materially and adversely affect our business and subject us to damages or other liabilities that could adversely affect our results of operations and financial condition in future periods.
We continue to consider and manage all of our projects under execution in view of these developments.
General and administrative expenses (excluding Stock Appreciation Right (SAR) expenses):
The consolidated general and administrative expenses (excluding SAR expenses) in Fiscal 2022 were higher than our consolidated general and administrative expenses (excluding SAR expenses) in Fiscal 2021 primarily due to higher legal and accounting costs related to whistle-blower and other investigations and legal costs related to defending various litigation matters. See “Whistle-blower Allegations and Special Committee Investigation” above. While we expect that such higher costs will adversely affect our operating results and cashflow in Fiscal 2023, we expect our SARs expenses to be lower than Fiscal 2022.
Operational update on Assam project:
In May 2022, portion of our 25 MW Assam project (Region 4) was severely affected by floods and other climatic hazards and was not operation from May 2022 to February 2023. The cost of restoration work was approx. INR 210 million (US$ 2.8 million) and total admissible insurance claim was INR 392 million (US$ 5.2 million) including business interruption. We consider these events to be a force majeure under the PPA. We formally informed the force majeure event to offtaker i.e. Assam Power Distribution Company Limited (“APDCL”) vide our letter dated May 17, 2022. There is no formal acceptance of force majeure from APDCL, however, there is no penalty imposed for this period due to non-availability of plant.
Rooftop Portfolio and Radiance:
In April 2021, the Company has entered into an agreement with Radiance to sell certain subsidiaries (the “Rooftop Subsidiaries”) with an operating capacity of 153 MW (the “Rooftop Portfolio”) for INR 5,350 million, subject to certain
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purchase price adjustments (the “Rooftop Sale Agreement”). Pursuant to the Rooftop Sale Agreement, Radiance was to acquire 100% of the equity ownership of the Rooftop Subsidiaries owned by the Group. The Company had recognized an impairment loss in relation to the Rooftop Subsidiaries aggregating to INR 3,255 million during the year ended March 31, 2021.
As on September 30, 2023, we received aggregate sale proceeds of INR 1,412 million (excluding working capital support reimbursed by Radiance), and we had transferred 66.5 MWs out of the total portfolio of 153 MWs. Out of this 66.5 MW, 33.2 MWs were from RG-II entities, for which we transferred a 48.6% shareholding to Radiance pursuant to the terms of the Green Bond Indentures, and the remaining 51.4% will be transferred to Radiance only after refinancing of the RG-II bonds. In August 2021, post refinancing of 5.5% Senior Notes and repayment of loan relating to one of a rooftop project of 10 MW, the restriction on transfer of shareholding was released. For another 16 MWs, which is the Delhi Jal Board rooftop project, a 49% shareholding was transferred to Radiance and the remaining 51% will be transferred in 2024 after compliance with equity lock-in conditions under the applicable PPA. The transfer of ownership of these portfolios is not anticipated to occur within 12 months due to these restrictions.
Further, subsequent to year end, Company has transferred 100% shareholding in relation to 2.5 MW operating capacity.
The Company is in discussion with Radiance to mutually terminate the transfer in shareholding of the remaining un-transferred 86.5 MW portfolio to Radiance, and the same shall be subject to modification of the Amended Rooftop Sale Agreement.
COVID-19
In Fiscal 2021 and Fiscal 2022, COVID-19 and related lockdowns, especially in China, impacted our supply of components and raw materials for our projects. Our contracts with our suppliers and contractors all contain provisions for force majeure. In Fiscal 2021 and Fiscal 2022, due to the impact of COVID -19 related lockdowns in India and other parts of the world some of our suppliers issued force majeure notices to us requesting a suitable time extension for delivery.
During Fiscal 2021, under the MNRE’s direction, lockdowns due to COVID-19 were treated as force majeure events and blanket time-extension of 5 months were provided to all renewable energy projects. During the second wave of the COVID-19 pandemic in India at the start of Fiscal 2022, MNRE through its notifications dated May 12, 2021 and June 29, 2021, granted a further time-extension of 2.5 months (corresponding to the period from April 1, 2021 to June 15, 2021), for projects having their scheduled commissioning date (SCOD) on or after April 1, 2021, provided such time-extensions are not used as a ground for claiming termination of a PPA or for claiming any increase in the project cost. MNRE through its notification dated September 15, 2021, further clarified that the time-extension given for 2.5 months is an out-of-contract concession and can be claimed by renewable energy project developers and EPC contractors, provided that they do not claim any increase in project cost on account of this 2.5 months’ time extension. Subsequently, MNRE through its notification dated November 3, 2021 clarified that, change-in-law event shall continue to be governed by the provisions of the governing PPA and as decided by the appropriate commission. Further, MNRE though another notification, dated November 3, 2021, empowered its Dispute Resolution Committee to consider any additional time extension requirement in exceptional circumstances on account of disruptions into supply of imported solar PV modules and make a recommendation to MNRE on a case-to-case basis.
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Key Operating Metrics
Megawatts Operating and Megawatts Contracted & Awarded
We measure the rated capacity of our plants in megawatts. Rated capacity is the expected maximum output that a power plant can produce without exceeding its design limits. We believe that tracking the growth in aggregate megawatt rated capacity is a measure of the growth rate of our business.
Megawatts Operating represents the aggregate cumulative megawatt rated capacity of solar power plants that are commissioned and operational as of the reporting date.
Megawatts Contracted & Awarded represents the aggregate megawatt rated capacity of renewable power plants which include (i) PPAs signed with customers, and (ii) capacity won and allotted in auctions and where LOAs have been received but does not include the commissioned and operational capacity as of the reporting date.
The following table represents the megawatts Operating and megawatts Contracted & Awarded, which together are also called our total Portfolio, as of the end of the respective periods presented:
| As of March 31, | ||||||||||||
| 2020 | 2021* | 2022**# | ||||||||||
| Megawatts Operating | 1,808 | 1,990 | 2,752 | |||||||||
| Megawatts Contracted & Awarded | 5,307 | 4,965 | 4,759 | |||||||||
| Megawatts Operating, Contracted & Awarded | 7,115 | 6,955 | 7,511 | |||||||||
| * | In Fiscal Year 2021, we identified certain subsidiaries to sell off on a going concern basis, which currently form part of our Rooftop business. Out of this identified portfolio, during the current year in April 2021, we executed a contract with Radiance to sell certain subsidiaries having an operating capacity of 153 MW. Hence, we have not considered this rooftop portfolio capacity for reporting under total portfolio as at year end. |
| ** |
Out of the identified rooftop portfolio of 153 MW, the Company has already transferred 17.3 MW to Radiance, 33.2 MW will be transferred to Radiance after refinancing of the RG-II bonds and 16 MW will be transferred to Radiance post March 31, 2024. Hence, we have not considered these rooftop portfolios of 66.5 MW for reporting under its total portfolio as at year end. The Company is in discussion with Radiance to mutually terminate the transfer in shareholding of the remaining un-transferred 86.5 MW portfolio to Radiance, and the same shall be subject to modification of the Amended Rooftop Sale Agreement. Hence, portfolio of 86.5 MW have been considered for reporting under total portfolio as at year end. |
| # | Adjusted for inconsistencies in MWs reported as identified by the Group through its review of 2022 whistle-blower allegations. See “Whistle-blower Allegations and Special Committee Investigation” section for details. |
As of March 31, 2023, the Company had operating capacity of 3,041 megawatts and we do not expect commissioning of any further projects during Fiscal Year 2023-24. Therefore, we expect to have megawatts operating of 3,041 MW by March 31, 2024.
Plant Load Factor (“PLF”)
Plant load factor, or PLF, is the ratio of the actual output of all our power plants, including rooftop portfolio, over the reporting period to their potential output if it were possible for them to operate at full rated capacity. The PLF is not the same as the availability factor. Our power plants have high availability, that is, when the sun is shining our plants are almost always able to produce electricity. The variability in our PLF is a result of seasonality, weather, air pollution, rotation of the earth, equipment efficiency losses, breakdown of our transmission system and grid unavailability. We compute PLF on the basis of PPA capacity in AC or alternate current, which is generally lower than the actual installed capacity in DC or direct current.
We track PLF as a measure of the performance of our power plants. It indicates effective utilization of resources and validates our value engineering and operations research. Higher PLF at a plant indicates increased electricity generation. Monitoring PLF on real time allows us to respond rapidly to potential generation anomalies. PLF in AC was 21.6% for Fiscal Year 2022 compared with 20.9% for FY 2021, higher primarily due to greater optimization in our new plants and by adding additional DC capacity to our existing facilities.
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Fiscal Year Ended March 31, | ||||||||||||
| 2020 | 2021 | 2022 | ||||||||||
| Plant Load Factor (AC) (%) | 19.5 | 20.9 | 21.6 | |||||||||
Electricity Generation
Electricity generation represents the actual amount of power generated by our power plants including rooftop portfolio over the reporting period. This is a measure of the periodic performance of our power plants.
Fiscal Year Ended March 31, | ||||||||||||
| 2020 | 2021 | 2022 | ||||||||||
| Electricity Generation (kilowatt hours in millions) | 2,870 | 3,495 | 4,551 | |||||||||
Summary of Operating Metrics
| Key metrics | Unit of Measurement | Fiscal 2020 | Fiscal 2021 | Fiscal 2022 | ||||||||||
| Electricity generation | kWh in millions | 2,870 | 3,495 | 4,551 | ||||||||||
| Plant load factor | % | 19.5 | 20.9 | 21.6 | ||||||||||
| MW Operating | MW | 1,808 | 1,990 | 2,752 | ||||||||||
| MW Contracted & Awarded | MW | 5,307 | 4,965 | 4,759 | ||||||||||
| MW Operating, Contracted & Awarded | MW | 7,115 | 6,955 | 7,511 | ||||||||||
Key Financial Metrics
Adjusted EBITDA
Adjusted EBITDA is a non-U.S. GAAP financial measure. We present Adjusted EBITDA as a supplemental measure of our performance. This measurement is not recognized in accordance with U.S. GAAP and should not be viewed as an alternative to U.S. GAAP measures of performance. The presentation of Adjusted EBITDA should not be construed as an inference that our future results will be unaffected by unusual or non-recurring items.
We define Adjusted EBITDA as net loss/(income) plus (a) income tax expense/(benefit), (b) interest expense, net, (c) depreciation and amortization (d) loss/(gain) on foreign currency exchange (net) I other expense/(income) and (f) Impairment loss. We believe Adjusted EBITDA is useful to investors in assessing our ongoing financial performance and provides improved comparability between periods through the exclusion of certain items that management believes are not indicative of our operational profitability and that may obscure underlying business results and trends.
Adjusted EBITDA is also used by securities analysts, lenders and others in their evaluation of different companies because it excludes certain items that can vary widely across different industries or among companies within the same industry. For example, interest expense can be highly dependent on a company’s capital structure, debt levels and credit ratings. Therefore, the impact of interest expense on earnings can vary significantly among companies. In addition, the tax positions of companies can vary because of their differing abilities to take advantage of tax benefits and because of the tax policies of the various jurisdictions in which they operate. As a result, effective tax rates and tax expense can vary considerably among companies.
Adjusted EBITDA has limitations as an analytical tool, and one should not consider it in isolation or as a substitute for analysis of our results as reported under U.S. GAAP. Some of these limitations include:
| ● | it does not reflect cash expenditures or future requirements for capital expenditures or contractual commitments or foreign exchange gain/loss; |
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| ● | it does not reflect changes in, or cash requirements for, working capital; | |
| ● | it does not reflect significant interest expense or the cash requirements necessary to service interest or principal payments on our outstanding debt; | |
| ● | it does not reflect payments made or future requirements for income taxes; and | |
| ● | although depreciation, amortization and impairment are non-cash charges, the assets being depreciated and amortized will often have to be replaced or paid in the future and Adjusted EBITDA does not reflect cash requirements for such replacements or payments. |
Investors are encouraged to evaluate each adjustment and the reasons we consider it appropriate for supplemental analysis.
The following table presents a reconciliation of net (loss)/profit to Adjusted EBITDA:
| Fiscal Year Ended March 31, | ||||||||||||||||
| 2020 | 2021 | 2022 | ||||||||||||||
| INR | INR | INR | US$ | |||||||||||||
| (in millions) | ||||||||||||||||
| Net loss | (2,337 | ) | (4,201 | ) | (2,126 | ) | (27.8 | ) | ||||||||
| Income tax expense | 489 | 296 | 1,316 | 17.3 | ||||||||||||
| Interest expense, net | 7,962 | 8,410 | 11,930 | 157.2 | ||||||||||||
| Other (income)/expense, net | (96 | ) | 18 | 3 | 0.0 | |||||||||||
| Depreciation and amortization | 2,860 | 3,202 | 3,667 | 48.3 | ||||||||||||
| Impairment loss/(reversal) | — | 3,255 | (80 | ) | (1.1 | ) | ||||||||||
| Loss/(gain) on foreign currency exchange (net) | 512 | 7 | (33 | ) | (0.4 | ) | ||||||||||
| Adjusted EBITDA | 9,390 | 10,987 | 14,677 | 193.5 | ||||||||||||
| (1) | Translation of balances in the financial information table above from INR into US$, as of and for Fiscal Year 2022, are solely for the convenience of the readers and were calculated at the rate of US$1.00 = INR 75.87, the noon buying rate in New York City for cable transfers in non-U.S. currencies, as certified for customs purposes by the Federal Reserve Bank of New York on March 31, 2022. No representation is made that the INR amounts could have been, or could be, converted, realized or settled into US$ at that rate on March 31, 2022, or at any other rate. |
Project Cost per Megawatt Operating
Project cost per megawatt operating consists of the total project cost including solar photovoltaic panels, inverters, balance of plant equipment, freehold land or leasehold land, capitalizable financing costs, and installation costs incurred for installing one megawatt of DC capacity during the reporting period. A reduction in project cost per megawatt helps reduce the cost of power and thereby improves our ability to win new projects.
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| Fiscal Year Ended March 31, | ||||||||||||
| 2021 | 2022 | |||||||||||
| INR | INR | US$ | ||||||||||
| (in millions) | ||||||||||||
| Including Safeguard Duty: | ||||||||||||
| Cost per MW (AC) | 42.9 | 43.1 | 0.57 | |||||||||
| Cost per MW (DC) | 28.8 | 33.5 | 0.44 | |||||||||
| Excluding Safeguard Duty: | ||||||||||||
| Cost per MW (AC) | 40.1 | 42.4 | 0.56 | |||||||||
| Cost per MW (DC) | 26.1 | 32.9 | 0.43 | |||||||||
Cost per MW has increased in current year as compared to previous year primarily on account of increase in module prices.
Cash Flow to Equity (“Cfe”)
Cash Flow to Equity is a Non- U.S.GAAP financial measure. We present Cfe as a supplemental measure of our performance. This measurement is not recognized in accordance with U.S. GAAP and should not be viewed as an alternative to U.S. GAAP measures of performance. The presentation of Cfe should not be construed as an inference that our future results will be unaffected by unusual or non-recurring items.
We believe U.S. GAAP metrics, such as net income (loss) and cash from operating activities, do not provide the same level of visibility into the performance and prospects of our operating business as a result of the long-term capital-intensive nature of our businesses, non-cash depreciation and amortization cash used for debt servicing as well as investments and costs related to the growth of our business.
Our business owns high-value, long-lived assets capable of generating substantial Cash Flow to Equity over time. We define Cfe as profit before tax (the most comparable U.S. GAAP metric), adjusted for net cash provided for used/in operating activities, other than changes in operating assets and liabilities, income and deferred taxes and amortization of hedging costs; less: cash paid for income taxes, debt amortization and maintenance capital expenditure.
We believe that changes in operating assets and liabilities is cyclical for cash flow generation of our assets, due to high growth environment. Furthermore, to reflect the actual cash outflows for income tax, we deduct income and deferred taxes computed under U.S. GAAP presented in our consolidated financial statements and instead include the actual cash tax outflow during the period, are considered as part of tax expense.
We believe that external consumers of our financial statements, including investors and research analysts, use Cfe both to assess Azure’s performance and as an indicator of its success in generating an attractive risk-adjusted total return, assess the value of the business and the platform. This has been a widely used metric by analysts to value our business, and hence we believe this will help potential investors in analyzing the cash generation from our operating assets.
We have disclosed Cfe for our operational assets on a consolidated basis, which is not the cash from operations on a consolidated basis. We believe Cfe supplements U.S. GAAP results to provide a more complete understanding of the financial and operating performance of our businesses than would not otherwise be achieved using U.S. GAAP results alone. Cfe should be used as a supplemental measure and not in lieu of our financial results reported under U.S. GAAP.
We have categorized the Cfe into “Operational Assets” and “Others”, as defined below, so that users of our financial statements are able to understand the Cash generation from our operational assets.
We define our “Operational Assets”, as the projects which had commenced operations on or before March 31, 2022. –The operational assets represent the MW operating as on the date.
We define “Others” as (i) the project SPV’s which are under construction, or under development – as provided in the Power Purchase Agreement table in this Form 20-F, (ii) “corporate” which includes our three Mauritius entities, (iii) other projects not covered under operational assets, and (iv) other entities under the group which are newly incorporated.
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We define “debt amortization” as the current portion of long-term debt which has been repaid during the period as part of debt repayment obligations, excluding the debt which has been repaid before maturity or refinanced. It does not include the amortization of debt financing costs or interest paid during the period.
Other items from the Statement of Cash Flows include most of the items that reconcile “Net (loss) gain” and “Changes in operating assets and liabilities” from the Statement of Cash Flows, other than deferred taxes, non-cash employee benefit and amortization of hedging costs.
Following is the Cfe statement for the periods March 2021 and 2022:
|
For the twelve months ended March 31, 2021 |
For the twelve months ended March 31, 2022 |
|||||||||||||||||||||||||||
| Unaudited | Unaudited | |||||||||||||||||||||||||||
| Total | Other | Operating | Total | Other | Operating | Operating | ||||||||||||||||||||||
| INR | INR | INR | INR | INR | INR | US$ | ||||||||||||||||||||||
| Revenue from customers | 15,236 | - | 15,236 | 18,341 | - | 18,341 | 241.7 | |||||||||||||||||||||
| Cost of operations | 1,261 | - | 1,261 | 1,597 | - | 1,597 | 21.0 | |||||||||||||||||||||
| General and administrative | 2,988 | 2,159 | 829 | 2,067 | 1,288 | 779 | 10.3 | |||||||||||||||||||||
| Depreciation and amortization | 3,202 | 36 | 3,166 | 3,667 | 28 | 3,639 | 48.0 | |||||||||||||||||||||
| Impairment loss/(reversal) | 3,255 | - | 3,255 | (80 | ) | - | (80 | ) | (1.1 | ) | ||||||||||||||||||
| Operating income/(loss) | 4,530 | (2,195 | ) | 6,725 | 11,090 | (1,316 | ) | 12,406 | 163.5 | |||||||||||||||||||
| Interest expense, net | 8,410 | 1,024 | 7,386 | 11,930 | 6,498 | 5,432 | 71.6 | |||||||||||||||||||||
| Other expense, net | 18 | - | 18 | 3 | 1 | 2 | (0.0 | ) | ||||||||||||||||||||
| Loss/(gain) on foreign currency exchange, net | 7 | 3 | 4 | (33 | ) | 17 | (50 | ) | (0.7 | ) | ||||||||||||||||||
| Profit/(Loss) before income tax | (3,905 | ) | (3,222 | ) | (683 | ) | (810 | ) | (7,832 | ) | 7,022 | 92.6 | ||||||||||||||||
| Add: Depreciation and amortization | 3,202 | 36 | 3,166 | 3,667 | 28 | 3,639 | 48.0 | |||||||||||||||||||||
| Add: Impairment loss | 3,255 | - | 3,255 | (80 | ) | - | (80 | ) | (1.1 | ) | ||||||||||||||||||
| Add: Loss/(gain) on foreign currency exchange, net | 7 | 3 | 4 | (33 | ) | 17 | (50 | ) | (0.7 | ) | ||||||||||||||||||
| Add: Amortization of debt financing costs | 369 | 74 | 295 | 1,107 | 140 | 967 | 12.7 | |||||||||||||||||||||
| Add: Other items from Statement of Cash Flows(1) | 1,840 | 1,062 | 778 | 1,796 | 10 | 1,786 | 23.5 | |||||||||||||||||||||
| Less: Cash paid for income taxes | (488 | ) | (43 | ) | (445 | ) | (644 | ) | (516 | ) | (128 | ) | (1.7 | ) | ||||||||||||||
| Less: Debt amortization(2) | (698 | ) | - | (698 | ) | (1,591 | ) | - | (1,591 | ) | (21.0 | ) | ||||||||||||||||
| Cfe | 3,582 | (4) | (2,090 | ) | 5,672 | 3,412 | (8,153 | ) | 11,565 | 152.3 | ||||||||||||||||||
| (1) |
Other items from the Statement of Cash Flows: For the year ended March 31, 2021 and March 31, 2022 respectively, Other items include: loss on disposal of property plant and equipment of INR 32 million and INR 167 million (US$2.2 million), share based compensation of INR 1,001 million and reversal of INR 295 million (US$3.9 million), non-cash rent expense of INR 169 million and INR 354 million (US$4.7 million), allowance for doubtful debts of INR 294 million and reversal of INR 97 million (US$1.3 million), loan repayment charges of INR 257 million and INR 1,608 million (US$21.2 million) and Assets Retirement Obligation (ARO) accretion of INR 42 million and INR 46 million (US$0.6 million).
|
| (2) |
Debt Amortization: Repayments of term and other loans during the year ended March 31, 2022, was INR 90,022 million (US$1,186.5 million) (refer to the Statement of Cash Flows) which includes INR 88,431 million (US$1,165.5 million) related to refinancing of loans, extinguishment, repayment of debt and payments for hedge and have been excluded to determine debt amortization of INR 1,591 million (US$21.0 million). Repayments of term and other loans during the year ended March 31, 2021, was INR 10,563 million (refer to the Statement of Cash Flows) which includes INR 9,865 million related to refinancing of loans or early repayment of debt before maturity and have been excluded to determine debt amortization of INR 698 million.
|
| (3) |
Classification of Maintenance capital expenditures and Growth capital expenditures: All our capital expenditures are considered Growth Capital Expenditures. In broad terms, we expense all expenditures in the current period that would primarily maintain our businesses at current levels of operations, capability, profitability or cash flow in operations and maintenance and therefore there are no Maintenance Capital Expenditures. Growth capital expenditures primarily provide new or enhanced levels of operations, capability, profitability or cash flows. |
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| (4) | Reconciliation of total Cfe to U.S. GAAP cash from Operating Activities: |
|
For the year ended March 31, 2021 |
For the year ended March 31, 2022 |
|||||||
| Cfe (Non-U.S. GAAP) | 3,582 | 3,412 | ||||||
| Items included in U.S. GAAP Cash from Operating Activities but not considered in Cfe: | ||||||||
| Change in current assets and liabilities as per statement of cash flows | (838 | ) | (1,455 | ) | ||||
| Current income taxes | (625 | ) | (859 | ) | ||||
| Prepaid lease payments and employee benefits | (246 | ) | (312 | ) | ||||
| Amortization of hedging costs | 1,918 | 1,576 | ||||||
| Items included in Cfe but not considered in U.S. GAAP Cash Flow from Operating Activities: | ||||||||
| Debt amortization | 698 | 1,591 | ||||||
| Cash taxes paid | 488 | 644 | ||||||
| Cash from Operating Activities (U.S. GAAP) | 4,977 | 4,597 | ||||||
Summary of key financial metrices
The following are the key metrics used to evaluate our business performance:
| Key metrics | Unit of Measurement | Fiscal 2020 | Fiscal 2021 | Fiscal 2022 | ||||||||||
| Revenue (1) | INR in millions | 12,958 | 15,236 | 18,341 | ||||||||||
| Revenue (2) | US$ in millions | 171.9 | 208.3 | 241.7 | ||||||||||
| Cost per MW Operating (3) | INR in millions | 35.5 | 28.8 | 33.5 | ||||||||||
| Adjusted EBITDA | INR in millions | 9,390 | 10,987 | 14,677 | ||||||||||
| Cfe | INR in millions | 1,860 | 3,582 | 3,412 | ||||||||||
| (1) | Revenue consists of revenue from the sale of power, including other revenue items related to generation from renewable power. |
| (2) | Translation of balances from INR into US$, as of and for Fiscal Year 2022 are solely for the convenience of the readers and were calculated at the rate of US$1.00 = INR 75.87, the noon buying rate in New York City for cable transfers in non-U.S. currencies, as certified for customs purposes by the Federal Reserve Bank of New York on March 31, 2022. No representation is made that the INR amounts could have been, or could be, converted, realized or settled into US$ at that rate on March 31, 2022, or at any other rate. |
| (3) | Installation per MW of DC capacity and includes INR 0.6 million (US$0.01 million) per MW operating of safe-guard duties which we expect to recover. |
Critical Accounting Policies and Estimates
Our consolidated financial statements are prepared in accordance with U.S. GAAP. We have identified certain accounting policies that we believe are the most critical to the presentation of our consolidated financial information over a period of time. These accounting policies may require our management to take decisions on subjective and/or complex matters relating to reported amounts of assets, liabilities, revenue, costs, expenses and related disclosures. These would further lead us to estimate the effect of matters that may inherently be uncertain.
The judgment on such estimates and underlying assumptions is based on our experience, historical trends, understanding of the business, industry and various other factors that we believe are reasonable under the circumstances. These form the basis of our judgment on matters that may not be apparent from other available sources of information. In many instances changes in the accounting estimates are likely to occur from period-to-period. Actual results may differ from the
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estimates. The future financial statement presentation, financial condition, results of operations and cash flows may be affected to the extent that the actual results differ materially from our estimates.
Our significant accounting policies are summarized in Note 2—Summary of Significant Accounting Policies in our consolidated financial statements included in this annual report.
Components of Results of Operations
Operating Revenue
We recognize revenue on PPAs when the power plant generates power, and it is supplied to the customer in accordance with the respective PPA. Revenue is recognized in each period based on the volume of electricity supplied to the customer at the price stated in the PPA, once the energy kilowatts are supplied and collectability is reasonably assured. The energy kilowatts we supplied are validated by the customer prior to billing and recognition of revenue.
Where PPAs include scheduled price changes, revenue is recognized by applying the average rate to the energy output estimated over the term of the PPA. We estimate the total kilowatt hour units expected to be generated annually during the tenure of PPA using budgeted PLFs, rated capacity of the project and annual estimated decrease in rated capability of solar panels. The contractual rates are applied to this annual estimate to determine the total estimated revenue over the term of the PPA. We then use the total estimated revenue and the total estimated kilowatt hours to compute the average rate used to record revenue on the actual energy output supplied. We compare the actual energy supplied to the estimate of the energy expected to be generated over the remaining term of the PPA on a periodic basis, but at least annually. Based on this evaluation, we reassess the energy output estimated over the remaining term of the PPA and adjust the revenue recognized and deferred to date. Through March 31, 2022, the adjustments have not been significant, and the difference between the actual billing and revenue recognized is recorded as deferred revenue.
Cost of Operations (Exclusive of Depreciation and Amortization)
Cost of operations primarily consists of expenses pertaining to operations and maintenance of our solar power plants. These expenses include payroll and related costs for maintenance staff, plant maintenance, insurance, and, if applicable, lease costs.
General and Administrative Expenses
Our general and administrative expenses include payroll and related costs for corporate, finance and other support staff, including bonus and share based compensation expense, professional fees and other corporate expenses. We anticipate that we will incur additional general and administrative costs, including headcount and expansion related costs, to support the growth in our business as well as additional costs of being a public reporting company.
Depreciation and Amortization
Depreciation and Amortization expense are recognized using the straight-line method over the estimated useful life of our solar power plants and other assets. Leasehold improvements related to solar power plants are amortized over the shorter of the lease term or the underlying period of the PPA for that particular solar power plant. Leasehold improvements related to office facilities are amortized over the shorter of the lease period or the estimated useful life. Freehold land is not depreciated. Construction in progress is not depreciated until such projects are commissioned.
Impairment loss/(reversal)
Impairment loss/(reversal) relates to our non-core solar rooftop portfolio, for which we entered into an agreement for sale during April 2021.
Interest Expense, Net
Interest expense, net consists of interest incurred on term loans for projects under our fixed and variable rate financing arrangements including interest expense and cost of hedging foreign currency risk on the Green Bonds, and interest expense on non-convertible debentures. Interest cost also includes the cost of swaps and option contracts entered to mitigate the foreign exchange risk for solar green bond transactions. We have designated the swaps and option contracts as a cash flow hedge and are tested for effectiveness on a quarterly basis or as determined at the time of designation of hedge. Interest expense also include bank fees and other borrowing costs, which are typically amortized over the life of the loan using the effective interest rate method. Interest expense is presented net of capitalized financing costs and interest income earned from bank deposits.
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Interest incurred in connection with a project that has been commissioned is expensed while interest incurred prior to commissioning is capitalized.
Other expense/(income)
Other expense/(income) primarily consists of mutual fund income net of certain expense.
Gain/Loss on Foreign Currency Exchange (Net)
We are exposed to movements in currency exchange rates, particularly to changes in exchange rates between U.S. dollars and Indian rupees. While our functional currency is the U.S. dollar, the functional currency of APIPL is Indian rupees and a portion of APIPL’s borrowings from financial institutions are denominated in U.S. dollars. Foreign exchange gain/loss includes the unrealized and realized gain/loss from foreign currency fluctuations on our non-functional currency denominated borrowings.
We also enter into foreign currency option contracts to mitigate and manage the risk of changes in foreign exchange rates on our borrowings denominated in currencies other than our functional currency. Some of these hedges do not qualify as cash flow hedges under Accounting Standards Codification, or “ASC”, Topic 815, “Derivatives and Hedging.” Changes in the fair value of these option contracts are recognized in the consolidated statements of operations and are included in loss on foreign currency exchange.
Income Tax Expense/(Income)
Our income tax expense/ (income) consists of current and deferred income tax as per applicable jurisdictions in Mauritius, India and the United States. Income tax for our current and prior periods is measured at the amount expected to be recovered from or paid to taxation authorities based on our taxable income or loss for that period.
Deferred income taxes and changes in related valuation allowance, if any, reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. We use the asset and liability method in accounting for income taxes. Under this method, deferred income tax assets and liabilities are determined based on the difference between financial reporting and tax bases of assets and liabilities and are measured using the enacted tax rates and laws that will be in effect when the differences are expected to reverse.
The tax rates on reversal of temporary differences might be different from the tax rates used for creation of the respective deferred tax assets/liabilities.
As of March 31, 2021, and 2022, we had net deferred tax assets of INR 1,748 million and INR 1,920 million (US$ 25.3 million), respectively, and net deferred tax liabilities of INR 2,046 million and INR 1,936 million (US$ 25.5 million), respectively.
We apply a two-step approach to recognize and measure uncertainty in income taxes in accordance with ASC Topic 740. The first step is to evaluate the tax position for recognition by determining if the weight of available evidence indicates that it is more likely than not that the position will be sustained on audit, including resolution of related appeals or litigation processes, if any. The second step is to measure the tax benefit as the largest amount, which is more than 50% likely of being realized upon ultimate settlement. We re-evaluate these uncertain tax positions on an annual basis. This evaluation is based on factors including changes in facts or circumstances, changes in tax law and effectively settled issues under tax-audit. Such a change in recognition or measurement could result in the recognition of a tax benefit or an additional charge to the tax provision in the relevant period. As of March 31, 2021, and 2022, we did not have any material uncertain tax positions.
We establish valuation allowances against our deferred tax assets when it is more likely than not that all or a portion of a deferred tax asset will not be realized. The valuation allowance as on March 31, 2021 and 2022 were INR 1,088 million and INR 2,281 million (US$30.1 million), respectively.
A portion of our Indian operations qualifies for tax holiday related to their operating income attributable to undertakings, as defined, in operating solar power plants under section 80-IA of the Indian Income Tax Act, 1961. This holiday is available for a period of ten consecutive years out of fifteen years beginning from the year in which the undertaking first generates power (referred to as the Tax Holiday period), however, the exemption is available only to the projects completed on or before March 31, 2017. We assess the election of the Tax Holiday period on an annual basis for each of our undertakings. We believe these undertakings will generate higher taxable profits due to lower interest cost as debt balances are paid down in the later years of operations and therefore, we plan to defer the Tax Holiday election to later years in order to maximize the
45
benefits. As of March 31, 2022, we are claiming tax holiday benefits for twelve of our subsidiaries. Deferred tax assets are recognized to the extent probable of realization outside the anticipated Tax Holiday period. For example, if we choose years six through 15 as the tax holiday period, we recognize deferred tax assets only to the extent that they will be realized either in years one through five or from year 16 onwards. As a result, all temporary differences do not result in creation of a deferred tax asset or liability.
Under certain of our subsidiaries, which are not eligible for deduction under section 80IA of the Income Tax Act, we had opted for the reduced corporate tax rate of 22% as per the provision of the Taxation Laws (Amendment) Act, 2019.
APIPL and AZR provide EPC and related support services to other group subsidiaries and as a result incur income taxes on profits from the services provided. The services provided to the group subsidiaries are in the nature of capitalizable costs and are therefore capitalized as part of property, plant and equipment in the standalone financial statements of such subsidiaries. However, these capitalized costs are eliminated for the purposes of the consolidated financial statements. The costs capitalized in the standalone financial statements are however eligible for income tax deductions in the tax records of the respective group subsidiaries. We started recording Deferred Tax Asset on the intra-entity transfer of assets pursuant to ASU 2016-16, from April 1, 2017. We assess that the probability of realizing the benefit on an annual basis and its recognition is limited to the extent probable of realization outside of the anticipated Tax Holiday period. Our estimate is that such benefit is limited to approximately 30% to 55% of the tax expense incurred by APIPL and the subsidiary. As a result, while all the profits on inter-company transactions are eliminated during consolidation, it does not result in a complete reversal of tax expense on such inter-company transactions. Accordingly, while we may not be profitable, we report income tax expense / benefit that may fluctuate from period to period. Further, EPC services by APIPL to other group subsidiaries were provided up-till financial year ended March 31, 2020 only. Now all subsidiaries are managing these EPC services by themselves with dedicated team of field-service engineers, technicians and other employees.
Contracts Designated as Cashflow Hedges for Solar Green Bonds
We issued U.S. dollar denominated 3.575% Solar Green Bonds in August 2021 and 5.65% Solar Green Bonds in September, 2019 (together the “Green Bonds”), listed on the Singapore Exchange Limited. We used the proceeds from the Green Bonds to repay project level debt of certain projects in India, in the form of intercompany Non-Convertible Debentures (“NCD”) and External Commercial Borrowings (“ECBs”) denominated in INR. We hedged the exchange rate risk on the proceeds invested from the Green Bonds through cross currency swap for payment of coupons and through call spread option contracts for repayment of principal (collectively, “option contracts”). We have designated these option contracts as a cashflow hedge. We expect that these option contracts mitigate the exchange rate risk associated with the forecasted transaction for semi-annual repayment of coupon and principal and also for repayment of the principal balance at the end of five years.
The cashflow from the underlying agreement match the terms of a hedge such as—notional amount, maturity of the option contracts, mitigation of exchange rate risk, and there are no significant changes in the counter party risk, hence they are designated as a cashflow hedge in accordance with ASC Topic 815— Derivatives and Hedging. Fair value of the hedge at the time of inception of the contract was nil and the cost of the hedge is recorded as an expense over the period of the contract on a straight-line basis. Changes in fair value of the option contracts designated as cash flow hedge are recorded in Other Comprehensive Income/(Loss), net of tax, until the hedge transactions occur. We evaluate hedge effectiveness of cash flow hedges at the time a contract is entered into as well as on a quarterly basis. We test the effectiveness of the hedge relationship on a quarterly basis and the hedge was effective as of March 31, 2022.
We used the derivatives option pricing model based on the principles of the Black-Scholes model to determine the fair value of the foreign exchange option contracts. We classify the fair value of these foreign exchange option contracts as Level 2 because the inputs used in the valuation model are observable in active markets over the term of the respective contracts. Fair value of the hypothetical derivative is computed based on the above inputs from Bloomberg or other reputed banks.
46
| As of March 31, 2021 (in millions) | ||||||||||||||||
Notional Amount | Current Liabilities (Fair value) | Other Assets (Fair value) | Other Assets (Fair value) | |||||||||||||
| (US$) | (INR) | (INR) | (US$) | |||||||||||||
| Foreign currency option contracts | 849.7 | — | 5,766 | 78.8 | ||||||||||||
| As of March 31, 2022 (in millions) | ||||||||||||||||
Notional Amount | Current Liabilities (Fair value) | Other Assets (Fair value) | Other Assets (Fair value) | |||||||||||||
| (US$) | (INR) | (INR) | (US$) | |||||||||||||
| Foreign currency option contracts | 753.9 | (1,735 | ) | 2,647 | 34.9 | |||||||||||
Property, Plants and Equipment
Our Company’s principal executive offices are located at 5th Floor, Southern Park, D-II, Saket Place, Saket, New Delhi 110017, India and occupy approximately 20,550 square feet of space. Our power projects are located primarily on land leased from the state governments and third parties and freehold land purchased from private individuals and entities. Further, we source the land required for construction of plants under the land lease arrangement or procure at the required locations of the plant. Our land lease arrangements range typically from 25 to 35 years, but our PPAs are generally for a term of 25 years. We believe that our facilities are in good condition and generally suitable and adequate for our needs in the foreseeable future. However, we will continue to seek additional space as needed to satisfy our growth.
Internal Control over Financial Reporting
We availed the exemptions afforded to us as an Emerging Growth Company pursuant to the Jumpstart Our Business Startups Act of 2012, or the JOBS Act untill FY 2021. The Company completed its fifth anniversary from the first sale of common equity shares during FY 2022, and as such the exemptions available to us as an Emerging Growth Company are no longer available to us. We now comply with all reporting requirements as applicable to other public companies that are foreign private issuers including the requirement to comply with the auditor attestation requirements of Section 404 of the Sarbanes-Oxley Act and accordingly included as part of the financial statements.
Power Purchase Agreements
The material terms of the PPAs we have entered into and bids we have won as of the date of this Form 20-F for our utility scale projects are summarized in the following table.
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Project Names |
Commercial Operation Date (1) |
PPA Capacity (MW) |
DC Capacity (MW) |
Tariff (INR / kWh) |
(6) | Offtaker | Duration of PPA in Years |
||||||||||||||
| Utility | |||||||||||||||||||||
| Operational | |||||||||||||||||||||
| Gujarat 1.1 | Q2 2011 | 5 | 5 | 15.00 | (2) | Gujarat Urja Vikas Nigam Limited | 25 | ||||||||||||||
| Gujarat 1.2 | Q4 2011 | 5 | 5 | 15.00 | (2) | Gujarat Urja Vikas Nigam Limited | 25 | ||||||||||||||
| Punjab 1 | Q4 2009 | 2 | 2 | 17.91 | NTPC Vidyut Vyapar Nigam Limited | 25 | |||||||||||||||
| Rajasthan 1 | Q4 2011 | 5 | 5 | 11.94 | NTPC Vidyut Vyapar Nigam Limited | 25 | |||||||||||||||
| Rajasthan 2.1 | Q1 2013 | 20 | 22 | 8.21 | NTPC Vidyut Vyapar Nigam Limited | 25 | |||||||||||||||
| Rajasthan 2.2 | Q1 2013 | 15 | 18 | 8.21 | NTPC Vidyut Vyapar Nigam Limited | 25 | |||||||||||||||
| Punjab 2.1 | Q3 2014 | 15 | 15 | 7.67 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Punjab 2.2 | Q4 2014 | 15 | 15 | 7.97 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Punjab 2.3 | Q4 2014 | 4 | 4 | 8.28 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Karnataka 1 | Q1 2015 | 10 | 10 | 7.47 | Bangalore Electricity Supply Company Limited | 25 | |||||||||||||||
| Uttar Pradesh 1 | Q1 2015 | 10 | 12 | 8.99 | Uttar Pradesh Power Corporation Limited | 12 | |||||||||||||||
| Rajasthan 3.1 | Q2 2015 | 20 | 23 | 5.45 | (3) | Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Rajasthan 3.2 | Q2 2015 | 40 | 43 | 5.45 | (3) | Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Rajasthan 3.3 | Q2 2015 | 40 | 41 | 5.45 | (3) | Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Chhattisgarh 1.1 | Q2 2015 | 10 | 10 | 6.44 | Chhattisgarh State Power Distribution Company Limited | 25 | |||||||||||||||
| Chhattisgarh 1.2 | Q2 2015 | 10 | 10 | 6.45 | Chhattisgarh State Power Distribution Company Limited | 25 | |||||||||||||||
| Chhattisgarh 1.3 | Q3 2015 | 10 | 10 | 6.46 | Chhattisgarh State Power Distribution Company Limited | 25 | |||||||||||||||
| Rajasthan 4 | Q4 2015 | 5 | 6 | 5.45 | (3) |
Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Delhi 1.1 | Q4 2015 | 2 | 2 | 5.43 |
(3) |
Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Karnataka 2 | Q1 2016 | 10 | 12 | 6.66 | Bangalore Electricity Supply Company Limited | 25 | |||||||||||||||
| Andhra Pradesh 1 (4) | Q1 2016 | 50 | 54 | 6.63 |
(2) |
Southern Power Distribution Company of Andhra Pradesh Limited |
25 | ||||||||||||||
| Punjab 3.1 | Q1 2016 | 24 | 25 | 7.19 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Punjab 3.2 | Q1 2016 | 4 | 4 | 7.33 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Bihar 1 | Q3 2016 | 10 | 11 | 8.39 | North & South Bihar Power Distribution Company Limited | 25 | |||||||||||||||
| Punjab 4.1 | Q4 2016 | 50 | 52 | 5.62 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Punjab 4.2 | Q4 2016 | 50 | 52 | 5.63 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Punjab 4.3 | Q4 2016 | 50 | 52 | 5.64 | Punjab State Power Corporation Limited | 25 | |||||||||||||||
| Karnataka 3.1 | Q1 2017 | 50 | 54 | 6.51 | Chamundeshwari Electricity Supply Company Limited | 25 | |||||||||||||||
| Karnataka 3.2 | Q1 2017 | 40 | 42 | 6.51 | Hubli Electricity Supply Company Limited | 25 | |||||||||||||||
| Karnataka 3.3 | Q1 2017 | 40 | 42 | 6.51 | Gulbarga Electricity Supply Company Limited | 25 | |||||||||||||||
| Maharashtra 1.1 | Q1 2017 | 2 | 2 | 5.50 | (3) | Ordinance Factory, Bhandara | 25 | ||||||||||||||
| Maharashtra 1.2 | Q1 2017 | 5 | 6 | 5.31 | Ordinance Factory, Ambajhari | 25 | |||||||||||||||
| Andhra Pradesh 2 (5) | Q2 2017 | 100 | 130 | 5.12 | NTPC Limited | 25 | |||||||||||||||
| Uttar Pradesh 2 | Q2-Q3 2017 | 50 | 59 | 4.78 | NTPC Limited | 25 | |||||||||||||||
| Telangana 1 | Q1 2018 | 100 | 128 | 4.67 | NTPC Limited | 25 | |||||||||||||||
| Uttar Pradesh 3 | Q2 2018 | 40 | 51 | 4.43 | (3) | Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Andhra Pradesh 3 | Q2 2018 | 50 | 59 | 4.43 | (3) | Solar Energy Corporation of India Limited | 25 | ||||||||||||||
| Gujarat 2 | Q4 2018 – Q1 2019 | 260 | 363 | 2.67 | Gujarat Urja Vikas Nigam Limited | 25 | |||||||||||||||
| Karnataka 4.1 | Q1 2019 | 50 | 75 | 2.93 | Bangalore Electricity Supply Company | 25 | |||||||||||||||
| Karnataka 4.2 | Q1 2019 | 50 | 75 | 2.93 | Hubli Electricity Supply Company Limited | 25 | |||||||||||||||
| Rajasthan 5 | Q2-Q3 2019 | 200 | 262 | 2.48 | Solar Energy Corporation of India Limited | 25 | |||||||||||||||
| Maharashtra 3 | Q3 2019 | 130 | 195 | 2.72 | Maharashtra State Electricity Distribution Company Limited | 25 | |||||||||||||||
| Assam 1 | Q3 2020-Q1 2022 | 90 | 135 | 3.34 | Assam Power Distribution Company | 25 | |||||||||||||||
| Rajasthan 6 | Q4 2020- Q1 2022 | 600 | 893 | 2.53 | Solar Energy Corporation of India Limited | 25 | |||||||||||||||
| Rajasthan 8 | Q4 2021- Q1 2022 | 300 | 417 | 2.58 | Solar Energy Corporation of India Limited | 25 | |||||||||||||||
| Rajasthan 9 | Q1-Q3 2022 | 300 | 385 | 2.54 | Solar Energy Corporation of India Limited | 25 | |||||||||||||||
| Others (8) | Q1 2018-Q4 2019 | 7 | 10 | 3.36 | (4) | Various | 25 | ||||||||||||||
| Operational Capacity Rooftop | 2013- Q1 2020 | 86 | 86 | Various | Various | 25 | |||||||||||||||
| Total Operational Capacity | 3,041 | 3,485 | |||||||||||||||||||
| Under
Construction / Contracted/ Awarded |
|||||||||||||||||||||
| 4 GW Project 1 | 700 | (7) | 2.54 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
| 4 GW Project 1 | 2,333 | (7) | 2.42 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
| 4 GW Project 1 | 300 |
(7) | 2.54 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
| 4 GW Project 1 | 667 |
(7) | 2.42 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
| SECI Hybrid | 150 | (9) | 2.35 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
| SECI WIND | 120 | (9) | 2.70 | Solar Energy Corporation of India Limited | 25 | ||||||||||||||||
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| Total Contracted & Awarded Capacity – Utility | 4,270 | ||||||||||||||||||||
| Total Portfolio* | 7,311 |
Notes:
| (1) | Refers to the applicable quarter of the calendar year in which commercial operations commenced or are scheduled to commence based on AC capacity. |
| (2) | Current tariff, subject to escalation. Please also see “—Tariff structure” |
| (3) | Projects are supported by VGF, in addition to the tariff. Please also see “—VGF for projects” |
| (4) | Levelized tariff; includes capital incentive. |
| (5) | Projects under accelerated depreciation per the Indian Income tax regulation. |
| (6) | In the case of projects with more than one PPA, tariff is calculated as the weighted average of the PPAs for such project. |
| (7) |
LOA received. PPA signed for 3,033 MW and for 967 MW yet to be signed. For more information, see “Operating And Financial Review And Prospects – Projects under execution” |
| (8) | Others include projects with Hindustan Aeronautics Limited (HAL), Decathlon and other offtakers. |
| (9) | PPA for 150 MW solar-wind hybrid signed on July 15, 2022 and PPA for 120 MW for wind project signed on August 31, 2022 (119 MW) and November 28, 2022 (1 MW). |
| * | In FY 2021, we entered into a sales contract with Radiance Renewables Private Limited (“Radiance”) to sell certain subsidiaries having an operating capacity of 153 MW for INR 5,350 million (US$70.5 million), subject to certain purchase price adjustments. Out of the identified rooftop portfolio of 153 MW, the Company has already transferred 17.3 MW to Radiance, 33.2 MW will be transferred to Radiance after refinancing of the RG-II bonds and 16 MW will be transferred to Radiance post March 31, 2024. Hence, we have not considered these rooftop portfolios of 66.5 MW for reporting under its total portfolio as at year end. Further, the Company is in discussion with Radiance to mutually terminate the transfer in shareholding of the remaining un-transferred 86.5 MW portfolio to Radiance, and the same shall be subject to modification of the Amended Rooftop Sale Agreement. Hence, portfolio of 86.5 MW have been considered for reporting under total portfolio as at year end. |
Our PPAs typically require that certain conditions be met including, among others, that we have obtained all necessary consents and permits, financing arrangements have been made and an agreement has been entered into to provide for the transmission of power. Furthermore, the PPAs contain customary termination provisions and negative and affirmative covenants, including the provision of performance bank guarantees and minimum guarantees of power to be sold and restrictions on changing the controlling shareholder of the project subsidiaries.
Megawatts Allotted or Won at Auction
During Fiscal Year 2020, we won a bid for 2,000 MW manufacturing linked project with SECI and also elected to exercise a greenshoe option for an additional 2,000 MW as per auction guidelines. During Fiscal Year 2020, we received a Letter of Award (“LOA”) for the 2,000 MW project and also received a LOA for the greenshoe option for 2,000 MW, during Fiscal Year 2021.
During Fiscal Year 2022, we signed PPAs with SECI for 650 MW at a fixed tariff of INR 2.54 per kWh and for 2,333 MW at a fixed tariff of INR 2.42 per kWh respectively for supply power for 25 years, as a part of the 4,000 MW manufacturing linked projects. However, 2,333 MW out of 4,000 MW manufacturing linked projects are being challenged under a Public Interest litigation filed before the Hon’ble High Court of Andhra Pradesh.
We executed a PPA with SECI for our 150 MW solar-wind hybrid project on July 15, 2022, PPA with SECI for our 120 MW wind project on August 31, 2022 (for 119 MW) and on November 28, 2022 (for 1 MW) and PPA for additional 50 MW under manufacturing linked projects on January 5, 2023. We also received a LOA on December 14, 2021 for 200 MW solar-wind hybrid project from Maharashtra State Electricity Distribution Co. Limited (MSEDCL), however, this project was cancelled on March 10, 2023, pursuant to withdrawal of the Group’s appeal before the Appellate Tribunal for Electricity. Appeal was filed to challenge Maharashtra Electricity Regulatory Commission’s order, that rejected the adoption of the auction discovered tariff of INR 2.62 per unit and instead gave the Group an option to reduce the tariff to INR 2.49 per unit.
We will continue our discussions with SECI towards signing PPAs for the balance capacity of 967 MW for which LOAs have been received.
For further information, see “Legal Proceedings” and “Operating And Financial Review And Prospects – Projects
49
under execution”.
Tariff structure
The tariff for Gujarat 1.1 and Gujarat 1.2 is INR 15.0 per kWh for the first 12 years and INR 5.0 per kWh for remainder of the contract term. The tariff for Andhra Pradesh 1 is INR 5.89 per kWh for first year, increasing by 3% each year from the second year to the tenth year and thereafter with the same tariff as that in year ten for the remainder of the 25-year term. All other projects have a fixed rate structure.
Viability Gap Funding (VGF) for projects
We won and implemented few projects under the erstwhile VGF scheme by MNRE. The VGF for Rajasthan 3.1 project is INR 23.0 million per MW, for Rajasthan 3.2 it is INR 22.0 million per MW, for Rajasthan 3.3 it is INR 13.0 million per MW and Rajasthan 4 it is INR 12.9 million per MW. The VGF for Andhra Pradesh 3 project is INR 7.4 million per MW. The VGF for Maharashtra 1 project is INR 0.9 million per MW. The VGF for Uttar Pradesh 3 is INR 8.0 million per MW. The VGF for Delhi 1 is INR 4.6 million per MW.
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B. Results of Operations
The following section illustrates our results of operations for the years ended March 31, 2020, 2021 and 2022 and includes a discussion and analysis of our performance, financial condition and results of operations.
| 2020 | 2021 | 2022 | 2022 | |||||||||||||
| Consolidated Statement of Operations data: | (INR) | (INR) | (INR) | (US$) (a) | ||||||||||||
| Operating revenues: | ||||||||||||||||
| Revenue from customers (1) | 12,958 | 15,236 | 18,341 | 241.7 | ||||||||||||
| Operating costs and expenses: | ||||||||||||||||
| Cost of operations (exclusive of depreciation and amortization shown separately below) (2) | 1,146 | 1,261 | 1,597 | 21.0 | ||||||||||||
| General and administrative (3) | 2,422 | 2,988 | 2,067 | 27.2 | ||||||||||||
| Depreciation and amortization (4) | 2,860 | 3,202 | 3,667 | 48.3 | ||||||||||||
| Impairment loss/(reversal)(5) | — | 3,255 | (80 | ) | (1.1 | ) | ||||||||||
| Total operating costs and expenses: | 6,428 | 10,706 | 7,251 | 95.4 | ||||||||||||
| Operating income | 6,530 | 4,530 | 11,090 | 146.3 | ||||||||||||
| Other expense, net: | ||||||||||||||||
| Interest expense, net (6) | 7,962 | 8,410 | 11,930 | 157.2 | ||||||||||||
| Other (income)/expenses (7) | (96 | ) | 18 | 3 | 0.0 | |||||||||||
| Loss/(gain) on foreign currency exchange, net (8) | 512 | 7 | (33 | ) | (0.4 | ) | ||||||||||
| Total other expenses, net | 8,378 | 8,435 | 11,900 | 156.8 | ||||||||||||
| Loss before income tax | (1,848 | ) | (3,905 | ) | (810 | ) | (10.5 | ) | ||||||||
| Income tax expense (9) | (489 | ) | (296 | ) | (1,316 | ) | (17.3 | ) | ||||||||
| Net loss | (2,337 | ) | (4,201 | ) | (2,126 | ) | (27.8 | ) | ||||||||
| Less: Net profit/ (loss) attributable to non-controlling interest | (68 | ) | 5 | (22 | ) | (0.3 | ) | |||||||||
| Net profit / (loss) attributable to APGL equity shareholders | (2,269 | ) | (4,206 | ) | (2,104 | ) | (27.5 | ) | ||||||||
| Net profit / (loss) per share attributable to APGL equity stockholders | ||||||||||||||||
| Basic | (52.71 | ) | (87.66 | ) | (41.36 | ) | (0.55 | ) | ||||||||
| Diluted | (52.71 | ) | (87.66 | ) | (41.36 | ) | (0.55 | ) | ||||||||
| Shares used in computing basic and diluted per share amounts: | ||||||||||||||||
| Weighted average shares | ||||||||||||||||
| Basic | 43,048,026 | 47,979,581 | 50,876,360 | 50,876,360 | ||||||||||||
| Diluted | 43,048,026 | 47,979,581 | 50,876,360 | 50,876,360 | ||||||||||||
| (a) | Azure Power Global Limited’s functional currency is the U.S. dollar and reporting currency is the Indian rupee. Solely for the convenience of the reader, we have translated the financial information for Fiscal Year 2022. The rate used for this translation is INR 75.87 to US$1.00, which is the noon buying rate in New York City for cable transfer in non-U.S. dollar currencies as certified for customs purposes by the Federal Reserve Bank of New York as of March 31, 2022, which is the last available rate in the period of reported financial statements. No representation is made that the Indian rupee amounts could have been, or could be, converted, realized or settled into U.S. dollars at that rate. |
Fiscal Year 2022 Compared to Fiscal Year 2021
(1) Operating Revenue
Operating revenues during Fiscal Year 2022 increased by INR 3,105 million, or 20.4%, to INR 18,341 million (US$241.7 million) compared to Fiscal Year 2021. The principal reasons for the increase in revenue during Fiscal Year 2022 was the incremental revenue from projects that commenced operations at various dates during Fiscal Year 2021 and Fiscal Year 2022. These include Rajasthan 6 and Assam 1 solar power projects, part of which commenced operation during FY 2021 and contributed incremental operating revenue of INR 2,223 million, and INR 207 million, respectively, in Fiscal Year 2022. In addition, Rajasthan 8 and Rajasthan 9 projects commenced their operations during FY 2022 and contributed incremental operating revenue of INR 296 million and INR 53 million respectively. Further, there was an additional revenue of INR 617
51
million from sale of carbon credits, which is partially offset by decrease in revenue from existing projects, due to lower insolation and other matters.
(2) Cost of Operations (Exclusive of Depreciation and Amortization)
Cost of operations during Fiscal Year 2022 increased by INR 336 million, or 26.6%, to INR 1,597 million (US$21.0 million), compared to Fiscal Year 2021, and remained consistent at 8% - 9% of revenue recognized during the respective periods in both years.
The net increase was primarily due to an increase in plant maintenance cost related to newly operational projects and partial commissioned projects during Fiscal Year 2021.
(3) General and Administrative Expenses
General and administrative expenses during Fiscal Year 2022, decreased by INR 921 million, or 30.8%, to INR 2,067 million (US$27.2 million) compared to Fiscal Year 2021. The decrease was primarily due to reversal of stock appreciation rights (SARs) expense of INR 373 million (US$4.9 million) on account of management transition compared to an expense of INR 1,319 million in year ended March 31, 2021, partially offset by increase in expense due to liquidation charges of INR 548 million (US$7.2 million) on account of termination of joint venture agreement with M/s Waaree Energies Limited (also refer to Note 10 “Investment in equity investee” in our consolidated financial statements for details). Further, a adjustment (decapitalisation) aggregating INR 253 million (US$ 3.3 million) has been made in books of account as impact of Whistle blower based on certain benchmarking reports.
(4) Depreciation and Amortization
Depreciation and amortization expenses during Fiscal Year 2022 increased by INR 465 million, or 14.5%, to INR 3,667 million (US$48.3 million) compared to Fiscal Year 2021. The principal reason for the increase in depreciation was the full year effect of projects commissioned during Fiscal Year 2021, primarily the Rajasthan 6 project contributing an incremental depreciation expense of INR 441 million in current year. Further, there was incremental depreciation on projects commissioned during Fiscal Year 2022, which included Rajasthan 8 and Rajasthan 9, amounting to INR 87 million and INR 11 million respectively.
(5) Impairment loss/(reversal)
We recognized an reversal of impairment loss of INR 80 million (US$1.1 million) during the year ended March 31, 2022, primarily due to 86.5 MW rooftop portfolio re-classified from asset held for sale to respective balance sheet captions in the consolidated balance sheet as at March 31, 2022.
(6) Interest Expense, Net
Net interest expense during Fiscal Year 2022 increased by INR 3,520 million, or 41.9%, to INR 11,930 million (US$157.2 million) compared to Fiscal Year 2021. The increase of INR 1,192 million (US$15.7 million) is primarily due to non-recurring charges for refinancing of 5.5% Solar Green bonds and other project loans and increase of INR 1,206 million (US$15.9 million) is on borrowings related to projects commissioned after year ended March 31, 2021. Further, increase of INR 1,169 million (US$ 15.4 million) is on account of loss on cancellation of hedged instruments.
(7) Other Expense
Other expenses during Fiscal Year 2022 decreased by INR 15 million to INR 3 million (US$0.0 million) as compared to Fiscal Year 2021.
(8) Gain on Foreign Currency Exchange
The foreign exchange gain during Fiscal Year 2022 increased by INR 40 million to INR 33 million (US$0.4 million) compared to FY 2021.
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(9) Income Tax Expense
Income tax expense increased during Fiscal Year 2022 by INR 1,020 million to an income tax expense of INR 1,316 million (US$17.3 million) compared to Fiscal Year 2021, the details of which are summarized below.
| Year ended March 31, (in millions) | ||||||||||||||||
| 2020 | 2021 | 2022 | 2022 | |||||||||||||
| INR | INR | INR | US$ | |||||||||||||
| Current tax expense | 120 | 242 | 485 | 6.4 | * | |||||||||||
| Withholding Tax on interest on restricted group debt | 258 | 383 | 367 | 4.8 | ||||||||||||
| Deferred income tax (benefit)/expense | 111 | (330 | ) | 464 | 6.1 | |||||||||||
| Total | 489 | 296 | 1,316 | 17.3 | ||||||||||||
| * | Current tax on profit before tax. Current tax includes INR 42 million (US$0.6 million) for tax adjustment relating to earlier years. |
We pay taxes on taxable profits at the individual entity level, in accordance with the tax rates in the relevant jurisdictions. While at the consolidated level, we remain unprofitable, certain Indian and non-Indian subsidiaries at the individual entity level have previously generated taxable profits. These taxable profits result from services provided by these entities to other subsidiaries and are taxed at the applicable tax rates in the jurisdiction of the entity providing the services. These inter-company transactions and profits are eliminated during consolidation, while the related income tax expense is not eliminated. We started recording deferred tax asset on the intra-entity transfer of assets pursuant to ASU 2016-16, from April 1, 2017. Subsequent thereto, there was a decrease in tax expense, which is primarily attributable to adoption of a new accounting standard on “intra-entity transfer of assets”, resulting in recognition of deferred tax asset on the income taxes paid on the intra entity transfer of assets to the extent these are expected to be realized by the subsidiary outside of the tax holiday period. Furthermore, a portion of our Indian operations qualifies for a tax holiday related to their operating income attributable to undertakings, as defined, in operating solar power plants under section 80-IA of the Indian Income Tax Act, 1961. This holiday is available for a period of ten consecutive years out of 15 years beginning from the year in which the undertaking first generates power (referred to as the tax holiday period); however, the exemption is available only to the projects completed on or before March 31, 2017. We anticipate that we will claim the aforesaid deduction in the last ten years out of 15 years beginning with the year in which we generate power and when we have taxable income. Accordingly, our current operations are taxable at the normally applicable tax rates. Due to the tax holiday period, a substantial portion of the temporary differences between the book and tax basis of our assets and liabilities do not have any tax consequences as they are expected to reverse within the tax holiday period.
The total income tax expense for Fiscal Year 2022 was INR 1,316 million, which increased by INR 1,020 million compared to Fiscal Year 2021.
The current tax expense (other than impact of tax adjustment relating to earlier years) for Fiscal Year 2022 increased by INR 201 million compared to Fiscal Year 2021 primarily on account of (i) increase in the taxable income of the entities that are outside Tax holiday period; (ii) increase in the book profits under various SPVs resulting increase in Minimum Alternate Tax; and (iii) increase in the Other Income (primarily interest income) of entities utilizing the 80-IA exemption, as the benefit of the tax holiday period is not available for such other income items.
The withholding tax on interest on restricted group debt relates to the tax on intercompany interest on Solar Green Bond entities for which the tax credit is not available under Mauritius tax laws. The withholding tax amount for FY 2022, has decreased by INR 16 million compared to Fiscal Year 2021 primarily due to refinancing of 5.5% Solar Green bonds during the previous year ended March 31, 2022.
During Fiscal Year 2022, we recorded a deferred tax expense of INR 464 million (after considering valuation allowance primarily relating to unabsorbed depreciation and business losses of entities availing 80-IA exemption), whereas for Fiscal Year 2021, we recorded a deferred tax benefit of INR 330 million.
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Our tax expenses are further described in Note 13—Income Taxes to our consolidated financial statements included in this annual report.
Fiscal Year 2021 Compared to Fiscal Year 2020
Operating Revenue
Operating revenues during FY 2021 increased by INR 2,278 million, or 17.6%, to INR 15,236 million (US$208.3 million) compared to FY 2020. The principal reasons for the increase in revenue during FY 2021 was the incremental revenue from projects that commenced operations at various dates during FY 2020 and FY 2021. These include Rajasthan 5 and Maharashtra 3 solar power projects, which commenced operation during FY 2020 and contributed incremental operating revenue of INR 312 million, and INR 617 million, respectively, in FY 2021. In addition, Rajasthan 6 and Assam 1 projects commenced their operations during FY 2021 and contributed incremental operating revenue of INR 335 million and INR 63 million respectively. Further, there was an additional revenue of INR 381 million for the recovery of Safe-Guard Duties and Goods and Service Tax under the change in law provision of our PPAs for four of our projects. The remaining increase in revenue was from existing projects, including repowering.
Cost of Operations (Exclusive of Depreciation and Amortization)
Cost of operations during FY 2021 increased by INR 115 million, or 10.0%, to INR 1,261 million (US$17.2 million), compared to FY 2020, and remained consistent at 8% - 9% of revenue recognized during the respective periods in both years.
The net increase was primarily due to an increase in plant maintenance cost related to newly operational projects and partial commissioned projects during the previous FY 2020, partially offset by lower module cleaning and other operation and maintenance activities due to COVID-19.
General and Administrative Expenses
General and administrative expenses during FY 2021 increased by INR 566 million, or 23.4%, to INR 2,988 million (US$40.9 million) compared to FY 2020. The higher General and administrative expenses was primarily due to an increase in stock appreciation rights (SARs) expense of INR 1,150 million compared to the year ended March 31, 2020, partially offset by absence of management transition expense of INR 323 million, absence of interest charges on the safeguard duty on the import of modules of INR 125 million and lower other cost due to cost reductions initiatives in travel, professional and other administrative expenses.
Depreciation and Amortization
Depreciation and amortization expenses during FY 2021 increased by INR 342 million, or 12.0%, to INR 3,202 million (US$43.8 million) compared to FY 2020. The principal reason for the increase in depreciation was the full year effect of projects that commenced operations on various dates during FY 2020. Plants which were commissioned commercial operation during part of FY 2020, which primarily includes Rajasthan 5 and Maharashtra 3 solar power projects contributing an incremental depreciation expense of INR 41 million and INR 87 million, respectively, in FY 2021. Further, there is incremental depreciation on projects commissioned during FY 2021, which includes the Rajasthan 6 and Assam 1 amounting to INR 103 million and INR 19 million respectively.
Impairment loss
We have reported an impairment loss during FY 2021 of INR 3,255 million (US$44.5 million) primarily relating to the planned disposal of our rooftop projects and other identified assets.
Interest Expense, Net
Net interest expense during FY 2021 increased by INR 448 million, or 5.6 %, to INR 8,410 million (US$114.8 million) compared to FY 2020. The increase was primarily due to incremental interest expense (net) of INR 753 million on borrowing related to new projects, refinancing of existing loans during current year causing an increase of INR 257 million, partially offset
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by prior year charges that did not repeat, comprising INR 385 million of prepayment charges to settle existing loans from the proceeds from the issuance of a solar green bond, INR 124 million related to the extinguishment of a debt facility, and INR 96 million relating to the refinancing of a loan.
Other Expenses/(Income)
Other expenses/(income) during FY 2021 increased by INR 114 million to INR 18 million (US$0.2 million) as compared to FY 2020. The lower income is primarily on account of lower investment in mutual funds due to lower free cash available during the year ended March 31, 2021.
Loss on Foreign Currency Exchange
The foreign exchange loss during FY 2021 decreased by INR 505 million to a loss of INR 7 million (US$0.1 million) compared to FY 2020. During the current FY, we refinanced a foreign currency loan of INR 3,099 million (US$42.4 million) into an INR denominated loan, which had reduced the impact of Gain /Loss on Foreign Currency Exchange.
Income Tax Expense/(Benefit)
Income tax expense decreased during FY 2021 by INR 193 million to INR 296 million (US$4.0 million), compared to FY 2020, the details of which are summarized below.
| Year ended March 31, (in millions) | ||||||||||||||||
| 2019 | 2020 | 2021 | 2021 | |||||||||||||
| INR | INR | INR | US$ | |||||||||||||
| Current tax expense | 128 | 120 | 242 | 3.3 | * | |||||||||||
| Withholding Tax on interest on restricted group debt | 192 | 258 | 383 | 5.2 | ||||||||||||
| Deferred income tax (benefit)/expense | (167 | ) | 111 | (330 | ) | (4.5 | ) | |||||||||
| Total | 153 | 489 | 296 | 4.0 | ||||||||||||
| * | Current tax on profit before tax. |
The total income tax expense for FY 2021 was INR 296 million, which decreased by INR 193 million compared to FY 2020.
The current tax expense for FY 2021 increased by INR 122 million compared to FY 2020 primarily on account of (i) increase in the taxable income of the entities that are outside Tax holiday period; and (ii) increase in the Other Income (primarily interest income) of entities utilizing the 80-IA exemption, as the benefit of the tax holiday period is not available for such other income items.
The withholding tax on interest on restricted group debt relates to the tax on intercompany interest on Solar Green Bond entities for which the Tax credit is not available under Mauritius tax laws. Amount for FY 2021 has increased by INR 125 million compared to FY 2020 primarily due to the reason that during the previous year withholding tax on our 5.65% Solar Green Bond was booked for part of the year as these bonds were issued in September 2019, whereas in the current year withholding tax is recognized for the full year for these bonds.
During FY 2021, we recorded a deferred tax benefit of INR 329 million (after considering valuation allowance of INR 269 million relating to the impairment loss related to the rooftop entities we are disposing of), whereas for FY 2020, we recorded a deferred tax expense of INR 111 million. The deferred tax benefit in the current year is primarily due to an increase in deferred tax asset of INR 280 million from the inter-company margin on projects under capital work in progress (including, but not limited to Rajasthan 6, Rajasthan 8 and Rajasthan 9) and the remaining increase is due to movement in other temporary timing difference between the book and tax basis of our assets and liabilities.
Our tax expenses are further described in Note 13—Income Taxes to our consolidated financial statements included in this annual report.
Trend Information
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Other than as disclosed elsewhere in this annual report, we are not aware of any trends, uncertainties, demands, commitments or events since March 31, 2022, that are reasonably likely to have a material adverse effect on our net revenues, income, profitability, liquidity or capital resources, or that caused the disclosed financial information to be not necessarily indicative of future operating results or financial conditions.
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C. Liquidity and Capital Resources
We currently do not generate adequate cash from operations to fund corporate expenses and to finance our growth. Our subsidiaries provide various support services to other group subsidiaries and charge amounts in the form of management fees for the services provided. Restrictions on the ability of our subsidiaries to pay us cash dividends as a result of certain regulatory and contractual restrictions may make it impracticable to use such dividends as a means of funding the expenses of Azure Power Global Limited. For a further discussion on our ability to issue and receive dividends, see “Financial Statements”
Our principal liquidity requirements are to finance current operations, service our debt and support our growth in India. We plan to continue to use capital to finance the construction of renewable power plants. Historically, our operations largely relied on equity and project-level long term borrowings, proceeds from issuance of compulsorily convertible preferred shares and compulsorily convertible debentures, and internally generated cash flows to meet capital expenditure requirements. As a normal part of our business and 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 electricity sales, increased expenses or other events may cause us to seek additional debt or 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, additional covenants and operating restrictions. Future financings could result in the dilution of our existing shareholding. In addition, any of the items discussed in detail under “Risk Factors” elsewhere in this annual report may also significantly impact our liquidity.
Liquidity Position
As of March 31, 2022, our liquid assets totaled INR 18,796 million (US$247.7 million), which was comprised of cash and cash equivalents. In addition, we have INR 3,784 million (US$49.9 million) of short-term restricted cash as of March 31, 2022 that generally gets utilized for capital expenditures. As of March 31, 2022, we carried cash and cash equivalent of INR 17,636 million (US$ 232.5 million) held by our foreign subsidiaries, which are not readily available to Azure Power Global Limited.
We also have commitments from financial institutions that we can draw upon in the future upon the achievement of specific funding criteria. As of March 31, 2022, we have such undrawn commitments excluding rooftop projects amounting to INR 5,980 million (US$78.8 million) under project-level financing arrangements.
We are subject to business and operational risks that could adversely affect our cash flows. A material decrease in our cash flows would likely produce a corresponding adverse effect on our borrowing capacity.
Sources of Liquidity
Our ability to meet our debt service obligations and other capital requirements will depend on our future operating performance which, in turn, will be subject to general economic, financial, business, competitive, legislative, regulatory and other conditions, many of which are beyond our control. Our financing arrangements as of March 31, 2022 consisted of project- level financing arrangements and other borrowings.
Project-level Financing Arrangements
Our borrowings include project-specific financing arrangements collateralized by the underlying power plants. The table below summarizes certain terms of our project-level financing arrangements as of March 31, 2022:
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| Outstanding principal Amount (in millions) | Type of | Maturity | ||||||||||||
| Name of project | INR | US$ | Interest | Currency | Date (1) | |||||||||
| Andhra Pradesh 1 | 2414 | 31.8 | Fixed | INR | 2026 | |||||||||
| Bihar 1 | 422 | 5.6 | Fixed | INR | 2026 | |||||||||
| Gujarat 1 | 893 | 11.8 | Fixed | INR | 2026 | |||||||||
| Karnataka 1 | 720 | 9.5 | Fixed | INR | 2026 | |||||||||
| Karnataka 3.1 | 2,115 | 27.9 | Fixed | INR | 2026 | |||||||||
| Karnataka 3.2 | 1,723 | 22.7 | Fixed | INR | 2026 | |||||||||
| Karnataka 3.3 | 2,704 | 35.6 | Fixed | INR | 2026 | |||||||||
| Punjab 1 | 312 | 4.1 | Fixed | INR | 2026 | |||||||||
| Punjab 2 | 1,866 | 24.6 | Fixed | INR | 2026 | |||||||||
| Punjab 4 | 5,332 | 70.3 | Fixed | INR | 2026 | |||||||||
| Rajasthan 3.1 | 1,142 | 15.1 | Fixed | INR | 2026 | |||||||||
| Rajasthan 3.2 | 1,263 | 16.6 | Fixed | INR | 2026 | |||||||||
| Rajasthan 3.3 | 2,237 | 29.5 | Fixed | INR | 2026 | |||||||||
| Rajasthan 4 | 227 | 3.0 | Fixed | INR | 2026 | |||||||||
| Telangana 1 | 4,841 | 63.8 | Fixed | INR | 2026 | |||||||||
| Uttar Pradesh 1 | 340 | 4.5 | Fixed | INR | 2026 | |||||||||
| Gujarat 2 | 9,188 | 121.1 | Fixed | INR | 2024 | |||||||||
| Maharashtra 3 | 5,238 | 69.0 | Fixed | INR | 2024 | |||||||||
| Karnataka 4 | 3,934 | 51.9 | Fixed | INR | 2024 | |||||||||
| Maharashtra 1.1 & 1.2 | 325 | 4.3 | Fixed | INR | 2024 | |||||||||
| Uttar Pradesh 3 | 1,778 | 23.4 | Fixed | INR | 2024 | |||||||||
| Andhra Pradesh 3 | 2,179 | 28.7 | Fixed | INR | 2024 | |||||||||
| Punjab 3.1 and 3.2 | 1,219 | 16.1 | Fixed | INR | 2024 | |||||||||
| Chhattisgarh 1.1,1.2 & 1.3 | 1,520 | 20.0 | Floating | INR | 2036 | |||||||||
| Rajasthan 1 | 406 | 5.4 | Fixed | INR | 2031 | |||||||||
| Rajasthan 2 | 2,424 | 31.9 | Fixed | INR | 2033 | |||||||||
| Karnataka 2 | 367 | 4.8 | Floating | INR | 2034 | |||||||||
| Andhra Pradesh 2 | 5,070 | 66.8 | Floating | INR | 2036 | |||||||||
| Uttar Pradesh 2 | 2,103 | 27.7 | Floating | INR | 2037 | |||||||||
| Rajasthan 5 | 5,655 | 74.5 | Floating | INR | 2039 | |||||||||
| Rajasthan 8 | 11,932 | 157.3 | Floating | US$ | 2026 | |||||||||
| Rajasthan 9 | 8,454 | 111.4 | Mixed | INR/US$ | 2022-2041 | |||||||||
| Assam 1 | 3,600 | 47.4 | Floating | INR | 2042 | |||||||||
| Rajasthan 6 | 21,090 | 278.0 | Floating | INR | 2042 | |||||||||
| Rooftop Projects (4) | 2,959 | 39.0 | Mixed | INR/US$ | 2022-2032 | |||||||||
| Total Amount | 117,992 | (2), (3) | 1,555.1 | |||||||||||
| (1) | This represents the last repayment period. These loans are repayable on a quarterly or semi-annual or on bullet payment basis. For repayment by period of the above-mentioned loans, refer to contractual obligation and commercial commitments. |
| (2) | This amount is presented in the financials as, net of ancillary cost of borrowing of INR 1,194 million (US$15.7 million). |
| (3) | Further, non-project level debt of INR 12,058 million (US$158.9 million) are excluded from the above table. The non-project level debt balance includes INR 4,058 million (US$53.5 million) of foreign exchange impact on project debt against which the company has taken a hedge and also include INR 1,118 million (US$14.7 million) loan taken from minority shareholder in rooftop entities which forms part of the group. |
| (4) | Rooftop Projects includes Delhi Rooftop 4, Gujarat rooftop, Punjab Rooftop 2, Railway 1 and SECI 50. |
Our outstanding project-level borrowings have been secured by certain movable and immovable properties, including property, plant and equipment, as well as a pledge of the shares of the project-level SPVs.
The financing agreements governing our project-level borrowings contain financial and other restrictive covenants that limit our project subsidiaries’ ability to make distributions to us unless certain specific conditions are met, including the satisfaction of certain financial ratios. Certain rooftop project entities of the Group, which are held for the sale, were not in compliance with the financial covenants related to this borrowing and had obtained suitable waivers for the non-compliance prior to the issuance of these financial statements. See also Note 12 to the consolidated financial statements.
Uses of Liquidity
Our principal requirements for liquidity and capital resources can be categorized into investment for developing power plants and debt service obligations. Generally, once operational, our power generation assets do not require significant capital expenditures to maintain their operating performance and our working capital is sufficient to meet the operations. For principal and interest payments on our debt outstanding as of March 31, 2022, refer to the section entitled “Contractual Obligations”.
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Capital Expenditures
As of March 31, 2022, we operated 47 utility scale projects with a combined rated capacity of 2,666 MW. As of such date, we were also constructing projects with a combined rated capacity of 247 MW.
All our capital expenditures are considered Growth Capital Expenditures. In broad terms, we expense all expenditures in the current period that would primarily maintain our businesses at current levels of operations, capability, profitability or cash flow in operations and maintenance and therefore there are no Maintenance Capital Expenditures. Growth capital expenditures primarily provide new or enhanced levels of operations, capability, profitability or cash flows.
Our capital expenditure requirements consist of:
| (i) | Expansion capital expenditures for new projects; |
| (ii) | Working capital spent for building a pipeline of projects for the coming year(s); and |
| (iii) | Replacement capex for running plant. |
Expansion capital expenditures also include interest expense associated with borrowings used to fund expansion during the construction phase of the projects.
Our capital expenditure amounted to INR 18,321 million, INR 18,909 million and INR 40,869 million (US$538.7 million) for FY 2020, FY 2021 and FY 2022 respectively. Our capital expenditure during the current year was primarily for construction of Assam 1, Rajasthan 6, Rajasthan 8 and Rajasthan 9.
Cash Flow Discussion
We also use traditional measures of cash flow, including net cash provided by operating activities, net cash used in investing activities and net cash provided by financing activities, as well as cash available for distribution to evaluate our periodic cash flow results.
Cash and cash equivalents include cash on hand, demand deposits with banks, term deposits and all other highly liquid investments purchased with an original maturity of three months or less at the date of acquisition and that are readily convertible to cash. It does not include restricted cash which consists of cash balances restricted as to withdrawal or usage and relate to cash used to collateralize bank letters of credit supporting the purchase of equipment for solar power plants, bank guarantees issued in relation to the construction of the solar power plants within the timelines stipulated in PPAs and for certain debt service reserves required under our loan agreements.
Fiscal Year 2022 Compared to Fiscal Year 2021
The following table reflects the changes in cash flows for the comparative periods:
| 2021 | 2022 | 2022 | Change | |||||||||||||
| INR | INR | US$ | INR | |||||||||||||
| (Millions) | ||||||||||||||||
| Cash flow data | ||||||||||||||||
| Net cash provided by operating activities | 4,977 | 4,597 | 60.6 | (380 | ) | |||||||||||
| Net cash used in investing activities | (18,919 | ) | (39,427 | ) | (519.7 | ) | (20.508 | ) | ||||||||
| Net cash provided by financing activities | 15,092 | 41,940 | 552.8 | 26,848 | ||||||||||||
Operating Activities
During Fiscal Year 2022, we generated INR 4,597 million (US$ 60.6 million) of cash from operating activities. This cash generated from operating activities primarily is a result of net loss of INR 2,126 million during FY 2022 added with non-cash items including a derivative instrument of INR 1,576 million, depreciation and amortization of INR 3,667 million, reversal of Impairment loss of INR 80 million, deferred income taxes of INR 457 million, amortization of debt financing cost of INR 1,107 million and prepayment penalty on refinancing of loans of INR 1,608 million, offset by reversal of share based
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compensation of INR 295 million. In addition to this there is impact of working capital changes, including INR 1,018 million due to increase in other liabilities, increase in deferred revenue of INR 3,184 million, increase in accounts payable of INR 347 million, offset by decrease in interest payable of INR 520 million, INR 1,057 million increase in trade receivables and increase in prepaid and other assets by INR 4,427 million.
During FY 2021, we generated INR 4,977 million (US$68.3 million) of cash from operating activities. This cash generated from operating activities primarily resulted from a net loss during FY 2021 of INR 4,201 million increased by non-cash items including a derivative instrument of INR 1,918 million, depreciation and amortization of INR 3,202 million, Impairment loss of INR 3,255 million, allowance for doubtful accounts of INR 294 million and share based compensation of INR 1,001 million, offset by deferred income taxes of INR 329 million, in addition to changes in working capital including, a INR 61 million decrease in other liabilities, an INR 224 million increase in deferred revenue, a INR 20 million decrease in prepaid expenses and other current assets, a INR 112 million decrease in other assets primarily resulting from prepaid income taxes and interest receivable on term deposits and INR 83 million decrease in interest payable offset by an INR 874 million increase in accounts receivable.
Investing Activities
During FY 2022, we utilized INR 39,427 million (US$519.7 million) in our investing activities. This cash outflow was primarily due to INR 40,869 million (US$538.7 million) incurred to purchase property, plant and equipment primarily related to the construction of our Rajasthan 6, Rajasthan 8, Rajasthan 9 and Assam 1 projects and investment in equity investee amounting to INR 94 million (US$ 1.2 million). This cash outflow has been offset by proceeds from disposal of subsidiaries for INR 1,557 million (US$ 20.5 million).
During FY 2021, we utilized INR 18,919 million (US$258.9 million) in our investing activities. This cash outflow was primarily due to INR 18,909 million (US$258.8 million) incurred to purchase property, plant and equipment primarily related to the construction of our following projects Rajasthan 6 and Assam 1.
Financing Activities
During FY 2022, we generated INR 41,940 million (US$ 552.8 million) from financing activities. This cash inflow was primarily due to net proceeds of INR 18,622 million (US$245.4 million) from issuance of equity share under right issues, net loan proceeds of INR 31,710 million (US$ 418.0 million) for our Rajasthan 6, Rajasthan 8, Rajasthan 9 and additional loans on refinancing of existing projects, offset by lower loan draw down on account of refinancing of Green Bonds amounting to INR 6,784 million (US$89.4 million) and INR 1,608 million (US$21.2 million) on account of prepayment charges paid on refinancing of loans.
During FY 2021, we generated INR 15,092 million (US$206.2 million) from financing activities. This cash inflow was primarily due to new loan proceeds of INR 25,510 million (US$348.7 million) for our Assam 1, Rajasthan 6, Rajasthan 2, Rajasthan 5 and Karnataka 2 projects and certain rooftop solar power plants, offset by repayment of term loan amounting to INR 10,563 million (US$144.5 million), which includes INR 2,279 million (US$31.2 million) paid towards hedging costs for Green Bonds and import of goods and a INR 257 million (US$3.5 million) decrease due to loan prepayment charges.
Fiscal Year 2021 Compared to Fiscal Year 2020
The following table reflects the changes in cash flows for the comparative periods:
| For fiscal year ended March 31, | ||||||||||||||||
| 2020 | 2021 | Change | ||||||||||||||
| INR | INR | US$ | INR | |||||||||||||
| (In millions) | ||||||||||||||||
| Cash flow data | ||||||||||||||||
| Net cash provided by operating activities | 3,678 | 4,977 | 68.3 | 1,299 | ||||||||||||
| Net cash used in investing activities | (18,256 | ) | (18,919 | ) | (258.9 | ) | (663 | ) | ||||||||
| Net cash provided by financing activities | 16,146 | 15,092 | 206.2 | (1,054 | ) | |||||||||||
Operating Activities
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During FY 2021, we generated INR 4,977 million (US$68.3 million) of cash from operating activities. This cash generated from operating activities primarily resulted from a net loss during FY 2021 of INR 4,201 million increased by non-cash items including a derivative instrument of INR 1,918 million, depreciation and amortization of INR 3,202 million, Impairment loss of INR 3,255 million, allowance for doubtful accounts of INR 294 million and share based compensation of INR 1,001 million, offset by deferred income taxes of INR 329 million, in addition to changes in working capital including, a INR 61 million decrease in other liabilities, an INR 224 million increase in deferred revenue, a INR 20 million decrease in prepaid expenses and other current assets, a INR 112 million decrease in other assets primarily resulting from prepaid income taxes and interest receivable on term deposits and INR 83 million decrease in interest payable offset by an INR 874 million increase in accounts receivable.
During FY 2020, we generated INR 3,678 million (US$49.2 million) of cash from operating activities. This cash generated from operating activities primarily resulted from a net loss during FY 2020 of INR 2,337 million increased by non-cash items including a derivative instrument of INR 1,428 million, depreciation and amortization of INR 2,860 million, allowance for doubtful accounts of INR 303 million and deferred income taxes of INR 149 million, offset by realized gain on investments of INR 108 million, in addition to changes in working capital including, an INR 164 million increase in other liabilities, an INR 340 million increase in deferred revenue, an INR 247 million decrease in prepaid expenses and other current assets, an INR 335 million increase in other assets primarily resulting from prepaid income taxes and interest receivable on term deposits and INR 699 million increase in interest payable offset by an INR 1,390 million increase in accounts receivable.
Investing Activities
During FY 2021, we utilized INR 18,919 million (US$258.9 million) in our investing activities. This cash outflow was primarily due to INR 18,909 million (US$258.8 million) incurred to purchase property, plant and equipment primarily related to the construction of our following projects Rajasthan 6 and Assam 1.
During FY 2020, we utilized INR 18,256 million (US$242.7 million) in our investing activities. This cash outflow was primarily due to INR 18,321 million (US$243.0 million) incurred to purchase property, plant and equipment primarily related to the construction of our following projects Assam 1, Rajasthan 6, Rajasthan 5, Maharashtra 3, Gujarat 2 and Karnataka 4.1 and 4.2, offset by a net sale of INR 108 million (US$1.4 million) of available-for-sale current investments.
Financing Activities
During FY 2021, we generated INR 15,092 million (US$206.2 million) from financing activities. This cash inflow was primarily due to new loan proceeds of INR 25,510 million (US$348.7 million) for our Assam 1, Rajasthan 6, Rajasthan 2, Rajasthan 5 and Karnataka 2 projects and certain rooftop solar power plants, offset by repayment of term loan amounting to INR 10,563 million (US$144.5 million), which includes INR 2,279 million (US$31.2 million) paid towards hedging costs for Green Bonds and import of goods and a INR 257 million (US$3.5 million) decrease due to loan prepayment charges.
During FY 2020, we generated INR 16,146 million (US$214.3 million) from financing activities. This cash inflow was primarily due to issuance of Green Bonds for INR 24,400 million (US$323.7 million), new loan proceeds of INR 19,538 million (US$259.2 million) for our Uttar Pradesh 3, Andhra Pradesh 3 and Karnataka 4 projects and certain rooftop solar power plants and private placement for issuance of 6,493,506 equity shares at US$11.55 per share to Caisse de depot et placement du Quebec, from which we raised INR 5,317 million (US$70.5 million) offset by repayment of term loan amounting to INR 32,827 million (US$435.4 million), which includes INR 1,058 million (US$14.0 million) paid towards hedging costs for Green Bonds and an INR 282 million (US$3.7 million) decrease due to loan prepayment charges.
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D. Off-Balance Sheet Arrangements
The terms of our PPAs provide for the annual delivery of a minimum amount of electricity at fixed prices. Under the terms of the PPAs, we have issued irrevocable performance bank guarantees. These in total amount to INR 7,730 and INR 5,179 million (US$68.3 million) as of March 31, 2021 and 2022, respectively.
As of March 31, 2021 and 2022, the Company has irrevocable performance bank guarantees aggregating to INR 5,366 million and INR 2,320 million (US$30.6 million) respectively, in relation to under construction projects. Further, bank guarantees of INR 516 million and INR 1,517 million (US$20.0 million) as of March 31, 2021 and 2022 respectively are in relation to commissioned projects as per respective PPAs and other project requirements.
Bank guarantees amounting to INR 906 million and INR 458 million (US$6.0 million) as of March 31, 2021 and 2022, respectively, have been issued to meet Debt-Service Reserve Account (DSRA) requirements for outstanding loans.
We have also obtained guarantees from financial institutions as a part of the bidding process for establishing solar projects amounting to INR 932 million and INR 873 million (US$11.5 million) as of March 31, 2021 and 2022 respectively. We have given term deposits as collateral for those guarantees which are classified as restricted cash on the consolidated balance sheet.
Further, INR 10 million and INR 11 million (US$0.1 million) bank guarantee as of March 31, 2021 and 2022 respectively, are towards other commitments. The funds released from maturity/settlement of existing bank guarantees can be used for future operational activities.
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E. Contractual Obligations
We have contractual obligations and other commercial commitments that represent prospective cash requirements. The following table summarizes our outstanding contractual obligations and commercial commitments as of March 31, 2022.
| Payment due by Period | ||||||||||||||||||||
Under 1 year | 1-3 Years | 3-5 Years | Over 5 years | Total | ||||||||||||||||
| (INR in millions) | ||||||||||||||||||||
| Contractual cash obligations | ||||||||||||||||||||
| Long-term debt (principal) (1) | 7,480 | 41,173 | 39,766 | 34,521 | 122,940 | |||||||||||||||
| Long-term debt (interest) (2) | 7,617 | 13,628 | 7,583 | 17,586 | 46,414 | |||||||||||||||
| Operating lease obligations | 313 | 652 | 690 | 11913 | 13,567 | |||||||||||||||
| Purchase obligations (3) | 2,857 | — | — | — | 2,857 | |||||||||||||||
| Asset retirement obligations | — | — | — | 902 | 902 | |||||||||||||||
| Total contractual obligations | 18,267 | 55,453 | 48,039 | 64,922 | 186,680 | |||||||||||||||
| Total contractual obligations (US$) | 240.8 | 730.9 | 633.2 | 855.7 | 2,460.6 | |||||||||||||||
| (1) | The long-term debt includes project secured term loans and, other secured bank loans. The long-term debt (principal) obligations for foreign currency denominated project borrowings have been converted to Indian rupees using the closing exchange rate as of March 31, 2022 as per Reserve Bank of India. |
| (2) | Interest on long-term debt is calculated based on the outstanding balance of the debt at the prevailing interest rate for the corresponding periods. |
| (3) | Consists of asset purchase commitment for construction of solar power plants. |
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F. Critical Accounting Policies and Estimates
In December 2019, the FASB issued ASU 2019-12, Simplifying the Accounting for Income Taxes (“ASU 2019-12”). This ASU eliminates certain exceptions to the general principles in ASC 740, Income Taxes and adds guidance to reduce complexity in accounting for income taxes. The ASU eliminates, inter alia, the general methodology for calculating income taxes in an interim period when a year-to-date loss exceeds the anticipated loss for the year. The ASU requires that an entity reflect the effect of an enacted change in tax laws or rates in the annual effective tax rate computation in the interim period that includes the enactment date. ASU 2019-12 is effective for the annual periods beginning after December 15, 2020, including interim periods within those fiscal years. During FY 2022, we applied ASU 2019-12 and noted that the impact of adoption of this guidance did not have a material effect on our consolidated financial statements.
In March 2020, the Financial Accounting Standards Board issued ASU No. 2020-04, “Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting (“ASU 2020-04”).” ASU 2020-04 provides temporary optional expedients and exceptions to the guidance in U.S. GAAP on contract modifications and hedge accounting to ease the financial reporting burdens related to the expected market transition from the London Interbank Offered Rate (LIBOR) and other interbank offered rates to alternative reference rates. In January 2021, the FASB issued Accounting Standard Update (“ASU”) 2021-01 (Topic 848), which amends and clarifies the existing accounting standard issued in March 2020 (“ASU”) 2020-04 for Reference Rate Reform. Reference rates such as LIBOR, are widely used in a broad range of financial instruments and other agreements. The ASU permits entities to elect certain optional expedients and exceptions when accounting for derivative contracts and certain hedging relationships affected by changes in the interest rates used for discounting cash flows, for computing variation margin settlements, and for calculating price alignment interest in connection with reference rate reform activities under way in global financial markets (the “discounting transition”). The ASU 2020-04 is effective for adoption at any time between March 12, 2020 and December 31, 2022, for all entities and the ASU 2021-01 is effective for all entities as of January 7, 2021 through December 31, 2022. As of March 31, 2022, we have not made any contract modifications to replace the reference rate in any of its agreements and will continue to evaluate the effects of this standard on its consolidated financial position, results of operations, and cash flows.
Other recent accounting pronouncements issued by the FASB (including its Emerging Issues Task Force) and the SEC did not or are not believed by management to have a material impact on our present or future financial statements.
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III. SHARE OWNERSHIP AND TRADING
A. Major Shareholders
The following table sets forth certain information with respect to the beneficial ownership of our Company’s equity shares as of October 10, 2023 by each of our directors and executive officers, by all of our directors and executive officers as a group and by each person known to us to own beneficially more than 5% of the equity shares.
As used in this table, beneficial ownership means the sole or shared power to vote or direct the voting or to dispose of or direct the sale of any security. A person is deemed to be the beneficial owner of securities that can be acquired within 60 days upon the exercise of any option, warrant or right as of October 10, 2023. Equity shares subject to options, warrants or rights that are currently exercisable or exercisable within 60 days are deemed outstanding for computing the ownership percentage of the person holding the options, warrants or rights, but are not deemed outstanding for computing the ownership percentage of any other person. The amounts and percentages are based on 64,161,490 equity shares outstanding as of the date of this table:
| Name | Number shares beneficially owned | % | ||||||
| Directors and Executive Officers: | ||||||||
| Panicker Unnikrishnan Mangalath Sukumara | - | - | ||||||
| Cyril Sebastien Dominique Cabanes | - | - | ||||||
| Deepak Malhotra | - | - | ||||||
| Muhammad Khalid Peyrye1 | - | - | ||||||
| Supriya Prakash Sen | 402 | * | 2 | |||||
| Jean-François Boisvenu | - | - | ||||||
| Delphine Voeltzel | - | - | ||||||
| Gowtamsingh Dabee | - | - | ||||||
| Richard Payette | - | - | ||||||
| Sugata Sircar | - | - | ||||||
| Sunil Gupta | - | - | ||||||
| Pawan Kumar Agrawal | 92,044 | 0.14 | % | |||||
| R Narasimhan Iyer | - | - | ||||||
| Vijay Kumar Wadhwani | - | - | ||||||
| Shweta Srivastava | - | - | ||||||
| All Directors and Executive Officers as a Group | 92,446 | 0.14 | % | |||||
| 5% or Greater Shareholders: | ||||||||
| CDPQ Infrastructures Asia Pte Ltd.3 | 34,258,963 | 53.4 | % | |||||
| OMERS4 | 13,759,647 | 21.4 | % | |||||
Shareholders’ Agreement
The Company did not have any changes to its shareholders agreement. The shareholders agreement is attached as exhibit no. 4.3, 4,4 and 4.5.
| 1 | Mr. Peyrye’s business address is c/o AAA Global Services Ltd., 4th Floor, Iconebene, Rue De L’institut, Ebene, 80817, Mauritius. | |
| 2 | Less than 0.01% |
| 3 | CDPQ Infrastructures Asia Pte Ltd., a company organized and existing under the laws of Singapore, is a wholly-owned subsidiary of the Caisse de dépôt et placement du Québec, a body constituted by the Act Respecting the Caisse De Dépôt Et Placement Du Québec. The principal address of the Caisse de dépôt et placement du Québec is 1000, Place Jean-Paul-Riopelle, Montréal, Québec, H2Z 2B3. | |
| 4 | During the Fiscal Year 2022, OMERS Infrastructure Asia Holdings Pte. Ltd. (“OMERS”), has acquired the entire stake of 19.4% in the Company, previously held by International Finance Corporation and IFC GIF Investment Company. |
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B. Related Party Transactions
We believe that the terms of our related party transactions are comparable to the terms we could obtain from independent third parties. Our Company’s related party transactions are subject to the review and approval of the audit and risk committee of our Company’s Board of Directors. Our Company’s audit and risk committee will consider whether the transaction is to be conducted on an arm’s-length basis and whether the services can be procured from an independent third party. The charter of our audit and risk committee as adopted by our Company’s Board of Directors provides that we may not enter into any related-party transaction unless and until it has been approved by the audit and risk committee. Refer “Note 20. Related Party Disclosures” of the Notes to Consolidated Financial Statements for details of transactions with related parties.
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C. Distribution
The Company has never declared or paid dividends, nor does the Company have any present plan to pay any cash dividends on our equity shares in the foreseeable future. The Company currently intends to retain its available funds and any future earnings to operate and expand its business.
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D. Significant Changes
Except as disclosed elsewhere in this annual report, we have not experienced any significant changes since the date of the annual financial statements included in this annual report. See “Certain Factors affecting our Results”.
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E. Trading Markets
The Company’s equity shares have been listed on the NYSE since October 12, 2016 under the symbol “AZRE.” On July 13, 2023, the NYSE suspended trading in our equity shares and commenced delisting proceedings as a result of our failure to timely file with the SEC our annual report on Form 20-F for the period ended March 31, 2022 and our semi-annual report on Form 6-K for the period ended September 30, 2022. On July 26, 2023, we submitted an appeal of this decision. We await the hearing of the Company’s appeal before the NYSE. Although we are appealing the NYSE’s attempt to delist our equity shares, our equity shares are currently suspended from trading on the NYSE and will remain suspended during the delisting proceedings. See “Risk Factors – The New York Stock Exchange (NYSE) has commenced procedures to delist our Company’s shares and our failure to timely file periodic reports with the SEC may result in the delisting of our Company’ shares”.
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F. Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Azure did not engage in any share repurchases during Fiscal Year 2022.
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G. Material Modifications to the Rights of Security Holders and Use of Proceeds
Material modifications to the rights of the security holders
There have been no material modifications to the rights of securities holders.
Use of proceeds
In January 2022, we completed a rights offering of 15,828,917 new equity shares to raise up to US$250 million. Each right entitles the holder to purchase 0.3275 equity shares at the subscription price of US$15.79 per whole equity share. HSBC Securities (USA) Inc. and Roth Capital Partners, LLC acted as our dealer managers in connection with the rights offering. The offering by our Company resulted in aggregate gross proceeds before expenses of US$250 million and incurred an underwriter’s commission and other expenses of US$2.9 million. As on March 31, 2022, out of the net equity proceeds, US$100 million was utilized against repayment of corporate debts and US$26.4 million was utilized to pay off certain borrowings. The balance of the proceeds are being utilized for purchase of renewable assets and other operational expenses.
During November – December 2019, we completed a US$75 million private placement. An aggregate 6,493,506 shares were sold by us in the offering at a price of US$11.55 per share to CDPQ Infrastructures. The offering by our Company resulted in aggregate gross proceeds before expenses of US$75.0 million. We have used the net proceeds to fund capital expenditures for projects.
During October – November 2018, our Company completed our follow-on to our public offering of our Company’s equity shares pursuant to a Registration Statement on Form F-3, as amended (File No. 333-227164), which became effective on September 10, 2018. Credit Suisse Securities (USA) LLC., Barclays Capital Inc., and HSBC Securities (USA) Inc., acted as managing underwriters for the issue. An aggregate of 14,915,542 shares (including 115,542 shares exercised by underwriters subsequent to our offering) were sold by our Company in the offering at a price of US$12.50 per share. The initial offering by our Company resulted in aggregate gross proceeds before expenses of US$186.4 million and incurred an underwriter’s commission and other expenses of US$1.3 million. Our Company has used US$182.0 million of the net proceeds to purchase equity shares of our subsidiary APIPL and Azure Power Rooftop Private Limited, as outlined in the registration statement and prospectus.
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IV. MANAGEMENT AND EMPLOYEES
A. Management
Board of Directors
Our Board of Directors (the “Board”) sets policies for our business and monitors the implementation of those policies by our executive officers. Our Board has nine directors. Our Board has in-depth experience in the renewable energy industry and corporate finance and is globally respected in energy, finance, and public policy. All Board directors are non-executive; five are Independent Non-Executives and four are Non-Executive nominees of shareholders (three of CDPQ and one of OMERS). The following table presents certain information concerning the current board of directors as of October 10, 2023.
| Name of Directors | Age | Position | ||
| Panicker Unnikrishnan Mangalath Sukumara | 63 | Chairman of the Board of Directors1 | ||
| Muhammad Khalid Peyrye | 45 | Director | ||
| Supriya Prakash Sen | 58 | Director | ||
| Jean-François Boisvenu | 57 | Director (from February 8, 2023) | ||
| Cyril Sebastien Dominique Cabanes | 49 | Director | ||
| Deepak Malhotra | 44 | Director | ||
| Delphine Voeltzel | 39 | Director (from May 11, 2022) | ||
| Gowtamsingh Dabee | 56 | Director (from March 30, 2023) | ||
| Richard Payette | 63 | Director (from July 01,2023) | ||
| Richard Alan Rosling | 61 | Chairman of the Board of Directors1 (from October 1, 2021 to October 11, 2023) | ||
| Arno Lockheart Harris | 54 | Director (until May 31, 2022) | ||
| Ranjit Gupta | 53 | Chief Executive Officer/Managing Director (until April 26, 2022) | ||
| Barney S. Rush | 72 | Chairman of the Board of Directors (until September 30, 2021) | ||
| Sugata Sircar | 59 | Director (from October 1, 2022 until April 30, 2023) | ||
| Christine Ann McNamara | 64 | Director (from March 1, 2022 until June 26, 2023) | ||
| Yung Oy Pin Lun Leung | 57 | Director (until March 16, 2023) |
1 On October 11, 2023, Mr. Alan Rosling resigned as Chairman of the Board and as a director of the Company and APIPL. On October 12, 2023, the Company announced that Panicker Unnikrishnan Mangalath became the Chairman of the Board of the Company.
Below is a summary of the business experience, activities and areas of expertise of our current directors.
| Name and Designation | Experience and areas of expertise | ||||
|
Panicker Unnikrishnan Mangalath Sukumara | ◾ | Over 30 years of experience in the energy and environmental sector. Asia Innovator of the Year by CNBC Asia, one of the best CEOs in India by Grant Thorton, and India Innovator of the Year by CNBC India.
| ||
| Chairman and Non-Executive Director | ◾ | Managing Director and CEO of Thermax Ltd. | |||
| ◾ | Actively involved with various industry bodies to help in policy making and technology development for India.
| ||||
| ◾ | He holds a Bachelor of Engineering (Mechanical) from Visveswaraiya NIT, Nagpur and has completed an Advanced Management Program from Harvard Business School.
| ||||
| ◾ | Nominated to the Board by CDPQ. | ||||
|
|
Muhammad Khalid Peyrye | ◾ | One of our resident directors in Mauritius. | ||
| Independent Director | ◾ | Heads the Corporate Secretarial and Administrative cluster of AAA Global Services Ltd. | |||
| ◾ | Previously was a Money Laundering and Compliance officer for a leading financial services company. | ||||
|
|
Supriya Prakash Sen
Independent Director |
◾ | Over 30 years of experience in banking, private equity, capital markets and multilateral funding and investment as well as significant involvement in sustainability initiatives globally and in India.
| ||
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| ◾ | She was Senior Advisor at McKinsey and a strategy consultant for clients in South East Asia, South Asia and China. | ||||
| ◾ | Worked on differentiated funding models for enabling private investment in green infrastructure. | ||||
| ◾ | She holds MBA from IIM, Calcutta and also holds executive development programs in strategic innovation, public policy and governance. | ||||
|
|
Jean-François Boisvenu Independent Director |
◾ | More than 25 years of extensive experience in corporate and commercial law matters, with particular expertise in international banking transactions, lending and debt capital markets transactions and financial institutions regulation. | ||
| ◾ | He is a partner at Eversheds Sutherland (Mauritius), prior to that, he was Group Head Legal at AfrAsia Bank Limited and worked at BLC Robert. | ||||
| ◾ | Before moving to Mauritius in 2009, he was a partner at the Canadian law firm McCarthy Tétrault (Banking and Insolvency Department). Mr. Boisvenu is a Member of the Quebec Bar (Canada) and a Registered Foreign Lawyer in Mauritius. | ||||
| ◾ | He holds degrees in Law from University of Montreal and Quebec Bar School (Canada) and a bachelor’s degree in Applied Economics from École des Hautes Études Commerciales de Montréal. | ||||
|
|
Cyril Sebastien | ● | Vice President, Head of Infrastructure Transactions, Asia-Pacific at CDPQ. | ||
| Dominique Cabanes | ● | More than 20 years of experience across all facets of infrastructure transactions including acquisitions, financing and fundraising. | |||
| Non-Executive Director |
●
● |
He holds a Masters from ESCP-Europe and an MBA from Drexel University. Nominated to the Board by CDPQ. | |||
|
|
Deepak Malhotra | ● | Managing Director, Infrastructure, India at CDPQ. | ||
Non-Executive Director |
● | More than 20 years of experience. He previously worked at International Finance Corporation, World Bank, at a leading credit agency in India and in the Merchant Navy. | |||
|
●
● |
He holds a Bachelor’s Degree from Delhi University and an MBA from Vanderbilt University. Nominated to the Board by CDPQ. | ||||
|
|
Delphine Voeltzel | ● | She has 13 years of professional experience in the infrastructure sector across Europe and Asia and is leading OMERS Infrastructure’s investment efforts in Asia | ||
| Non-Executive Director | ● | Presently, she is serving as Managing Director at OMERS Infrastructure. | |||
| ● | Responsible for originating and executing new transactions in Asia and managing the existing investment portfolio for OMERS Infrastructure. |
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| ● | She holds a Master of Science in Management from HEC Paris School of Management. | ||||
| ● | Nominated to the Board by OMERS. | ||||
|
|
Gowtamsingh Dabee | ● | He has over 25 years of experience as a professional accountant in public practice and industry in Mauritius, Africa, and the Middle East. | ||
| Independent Director | ● | Presently he is a Partner of GD Riches Chartered Accountants and is an auditor, public accountant, and insolvency practitioner in Mauritius. | |||
| ● | Prior to that, he served as the CFO and Company Secretary of a multinational corporation in Mauritius where he was instrumental in implementing SOX internal control systems for the group subsidiaries. | ||||
| ● | Also worked with the representative office of Andersen Worldwide in Mauritius and the Arthur Andersen Office in Dubai. | ||||
| ● | He is an Associate Member of the Institute of Chartered Accountants in England and Wales (ICAEW) and a Fellow of Chartered Association of Certified Accountant (FCCA). He holds an MBA from Surrey Business School, University of Surrey, UK, and an Advanced Diploma in International Tax from the Chartered Institute of Taxation UK (CIOT). | ||||
| ● | He is a registered insolvency practitioner in Mauritius and a member of INSOL. | ||||
|
|
Richard Payette | ● | He is a business leader with over four decades of experience in management of global companies and accounting and audit matters. | ||
| Independent Director | ● | His area of expertise includes organisational transformation, international market development, finance, audit, governance, and risk management. | |||
| ● | He currently serves as a director of Export Development Canada (EDC), Canada’s export credit agency wholly owned by the Government of Canada and the Canadian Public Accountability Board (CPAB), a regulatory body charged with overseeing audits of Canadian reporting issuers. | ||||
| ● | He earlier served as Chair of the boards of the Canadian Chamber of Commerce and Fédération de Chambres de Commerce du Québec. | ||||
| ● | From 2016 until 2020, he served as President and CEO Québec of Manulife and was the CEO for the Americas region at BDO International between 2010 and 2015. | ||||
| ● | He worked with Raymond Chabot Grant Thornton since 1982 until 2009, lastly as the President and CEO. He is also a member of the advisory boards of Lemay and LexRockAI. | ||||
| ● | He is a Fellow of the Chartered Professional Accountants of Canada and holds an ESG Certification and designation. |
Executive Officers
The executive officers are responsible for the management of the company under the governance of the Board of Directors. All our executive offices are experienced in their domains. The following table lists our current executive officers.
| Name of Executive Officers |