HYDRO ONE INC Form 40-F Filed 2023-02-14

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 40-F




☐			REGISTRATION STATEMENT PURSUANT TO SECTION 12 OF THE SECURITIES EXCHANGE ACT OF 1934




☒			ANNUAL REPORT PURSUANT TO SECTION 13(a) OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934





For the fiscal year ended December 31, 2022						Commission File Number 001-36115

Hydro One Inc.

(Exact name of Registrant as specified in its charter)

Ontario, Canada

4911

Not Applicable

(Province or other jurisdiction

of incorporation or organization)

(Primary Standard Industrial

Classification Code Number)

(I.R.S. Employer

Identification Number)

483 Bay Street

South Tower, 8th Floor

Toronto, Ontario M5G 2P5

Canada

(416) 345-5000

(Address and telephone number of Registrant’s principal executive offices)

C T Corporation System

28 Liberty St., New York, NY 10005

(212) 894-8940

(Name, address, (including zip code) and telephone number (including area code)

of agent for service in the United States)

Securities registered or to be registered pursuant to Section 12(b) of the Act:

4.59% Medium-Term Notes due 2043

Title of each class: Medium Term Notes

Name of each exchange on which registered: New York Stock Exchange LLC

Trading Symbol: HYDO43

Securities registered or to be registered pursuant to Section 12(g) of the Act: Not applicable

Securities for which there is a reporting obligation pursuant to Section 15(d) of the Act:

Not applicable

Information filed with this Form:



☒	Annual Information Form	☒	Audited annual financial statements

Number of outstanding shares of each of the issuer’s classes of capital or common stock as of December 31, 2022:


142,239			Common Shares outstanding
0 (Nil)			Series A Preferred Shares
0 (Nil)			Series B Preferred Shares

Indicate by check mark whether the Registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Exchange Act 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	☐	No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted and posted 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 and post such files).



☒	Yes	☐	No

Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 12b-2 of the Exchange Act.

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. ☐

† The term “new or revised financial accounting standard” refers to any update issued by the Financial Accounting Standards Board to its Accounting Standards Codification after April 5, 2012.

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 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). ☐

CONTROLS AND PROCEDURES

Disclosure Controls and Procedures

Disclosure controls and procedures are defined in Rule 13a-15(e) under the U.S. Securities Exchange Act of 1934, as amended (the “Exchange Act”), to mean controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized and reported, within the time periods specified in the United States Securities and Exchange Commission’s (the “Commission”) rules and forms.

At the direction of Hydro One Inc.’s (the “Registrant”) Chief Executive Officer and Chief Financial Officer, management evaluated disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, management concluded that the Registrant’s disclosure controls and procedures were effective as at December 31, 2022.

See the disclosure provided under the heading “Disclosure Controls and Procedures and Internal Control over Financial Reporting” on page 31 of Exhibit 99.3, the Registrant’s Management’s Discussion and Analysis (the “MD&A”) which is incorporated by reference herein.

Management’s Annual Report on Internal Control over Financial Reporting and Attestation Report of the Registered Public Accounting Firm

Management is responsible for establishing and maintaining adequate disclosure controls and procedures and internal control over financial reporting as described in the MD&A. Management evaluated the effectiveness of the design and operation of internal control over financial reporting based on the framework and criteria established in the Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management concluded that the Registrant's internal control over financial reporting was effective as of December 31, 2022.

Internal control, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives and due to its inherent limitations, may not prevent or detect all misrepresentations. Furthermore, the effectiveness of internal control is affected by change and subject to the risk that internal control effectiveness may change over time.

This annual report does not include an attestation report of the Registrant’s registered public accounting firm regarding internal control over financial reporting.

The report of management on our internal control over financial reporting is provided under the heading “Management’s Report” in the Registrant’s audited consolidated financial statements, which is filed as Exhibit 99.2 and is incorporated by reference herein.

Changes in Internal Control Over Financial Reporting

There were no significant changes in the design of the Registrant’s internal control over financial reporting during the year ended December 31, 2022 that have materially affected, or are reasonably likely to materially affect, the operation of the Registrant’s internal control over financial reporting.

IDENTIFICATION OF THE AUDIT COMMITTEE

The Registrant has a separately-designated standing audit committee established in accordance with Section 3(a)(58)(A) of the Exchange Act (the “Audit Committee”). The Audit Committee comprises Stacey Mowbray (Chair), Russel Robertson, Blair Cowper-Smith, Melissa Sonberg, and Mark Podlasly. The board of directors of the Registrant has determined that each member of the Audit Committee is “independent” as defined in the Exchange Act and the New York Stock Exchange’s listing standards applicable to the Registrant. Each of the Audit Committee members has an understanding of the accounting principles used to prepare the Registrant’s financial statements and varied experience as to the general application of such accounting principles, as well as an understanding of the internal controls and procedures necessary for financial reporting.

AUDIT COMMITTEE FINANCIAL EXPERT

The board of directors of the Registrant has determined that it has at least one audit committee financial expert serving on its audit committee. Stacey Mowbray, Mark Podlasly, and Russel Robertson have each been designated as an audit committee financial expert and are each independent, as such term is defined in the New York Stock Exchange’s listing standards applicable to the Registrant. The Commission has indicated that the designation or identification of an audit committee financial expert does not deem that audit committee financial expert an “expert” for any purpose, impose any duties, obligations or liability on such audit committee financial expert that are greater than those imposed on members of the audit committee and board of directors who do not carry this designation or identification, or affect the duties, obligations or liability of any other member of the audit committee or board of directors.

AUDIT COMMITTEE PRE-APPROVAL POLICIES AND PROCEDURES

The charter of the Audit Committee requires that the Audit Committee review and approve all policies and procedures for the pre-approval of services to be rendered by external auditors. All permissible non-audit services to be provided to the Registrant or any of its affiliates by external auditors or any of their affiliates that are not covered by pre-approval policies and procedures approved by the Audit Committee, are subject to pre-approval by the Audit Committee. During the fiscal year ended December 31, 2022, the waiver of pre-approval provisions set forth in the applicable rules of the Commission was not utilized for any services related to Audit-Related Fees, Tax Fees or All Other Fees and the Audit Committee did not approve any such fees subject to the waiver of pre-approval provisions.

PRINCIPAL ACCOUNTANT FEES AND SERVICES

The aggregate fees billed by KPMG LLP to Hydro One Inc. and its subsidiaries in 2022 and 2021 for professional services are presented below (in Canadian dollars):


	Year ended December 31, 2022		Year ended December 31, 2021
Audit Fees(1)	$	1,934,012	$	1,604,867
Audit-Related Fees(2)	$	362,950	$	321,147
Tax Fees(3)	$	18,618	$	21,351
All Other Fees	$	—	$	—
Total	$	2,315,580	$	1,947,365

Notes:

(1)The nature of the services rendered were: audit of annual financial statements of the Registrant and its subsidiaries, statutory and regulatory filings including reporting to the Province and services related to securities offerings.

(2)The nature of services rendered were: translations, audit of the Hydro One Pension Plans, and services reasonably related to the performance of the audit or review of the Registrant’s financial statements that are not reported under Audit Fees.

(3)The nature of services rendered was general tax advice and compliance.

CODE OF ETHICS

The Registrant has adopted a Code of Business Conduct (the “Code”) that applies to all directors, officers and employees of the Registrant, including the Chief Executive Officer and Chief Financial Officer, or persons performing similar functions. A copy of the Code has been posted on the Registrant’s website at https://www.hydroone.com/about/corporate-information/governance. A copy of the Code is available in print to any person, without charge, upon written request to Investor Relations at the executive office address of the Registrant shown above.

OFF BALANCE SHEET ARRANGEMENTS

The disclosure provided under the heading “Other Obligations-Off-Balance Sheet Arrangements” on page 13 of Exhibit 99.3, the MD&A, is incorporated by reference herein.

CONTRACTUAL OBLIGATIONS

The tabular disclosure provided under the heading “Other Obligations-Summary of Contractual Obligations and Other Commercial Commitments” on page 14 of Exhibit 99.3, the MD&A, is incorporated by reference herein.

INTERACTIVE DATA FILE

Concurrent with this filing, the Registrant has submitted to the Commission and posted on its corporate website an Interactive Data File.

MINE SAFETY DISCLOSURE

Not applicable.

DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS

Not applicable.

UNDERTAKING AND CONSENT TO SERVICE OF PROCESS

Undertaking

The Registrant undertakes to make available, in person or by telephone, representatives to respond to inquiries made by the Commission staff, and to furnish promptly, when requested to do so by the Commission staff, information relating to: the securities in relation to which the obligation to file an annual report on Form 40-F arises or transactions in said securities.

Consent to Service of Process

The Registrant has previously filed a Form F-X in connection with the class of securities in relation to which the obligation to file this report arises.

Any change to the name or address of the agent for service of process of the Registrant shall be communicated promptly to the Commission by an amendment to the Form F-X referencing the file number of the Registrant.

SIGNATURES

Pursuant to the requirements of the Exchange Act, the Registrant certifies that it meets all of the requirements for filing on Form 40-F and has duly caused this annual report to be signed on its behalf by the undersigned, thereto duly authorized.

DATED this 14th day of February, 2023.

HYDRO ONE INC.

By:

/s/ David Lebeter

Name: David Lebeter

Title: President and Chief Executive Officer

EXHIBIT INDEX





Exhibit Number						Description

99.1						2022 Annual Information Form dated February 14, 2023 for the fiscal year ended December 31, 2022.

99.2						Consolidated Financial Statements as at December 31, 2022 and December 31, 2021 and for the years then ended, and the accompanying auditors’ report.

99.3						Management’s Discussion and Analysis for the fiscal year ended December 31, 2022.

99.4						Consent of KPMG LLP (KPMG LLP, Toronto, ON, Canada, Auditor Firm ID: 85).

99.5						Certification of Chief Executive Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the U.S. Securities Exchange Act of 1934, as amended.

99.6						Certification of Chief Financial Officer pursuant to Rule 13a-14(a) or 15d-14(a) of the U.S. Securities Exchange Act of 1934, as amended.

99.7						Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

99.8						Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.

101						Interactive Data File (formatted as Inline XBRL).

104						Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

ANNUAL INFORMATION FORM

FOR HYDRO ONE INC.

FOR THE YEAR ENDED DECEMBER 31, 2022

February 14, 2023

TABLE OF CONTENTS


GLOSSARY			1
PRESENTATION OF INFORMATION			6
FORWARD-LOOKING INFORMATION			7
ELECTRICITY INDUSTRY OVERVIEW			11
General Overview			11
Overview of an Electricity System			12
THE ELECTRICITY INDUSTRY IN ONTARIO			13
Regulation of Transmission and Distribution			13
Transmission			15
Distribution			15
Issues Affecting the Electricity Industry Generally			15
Legislative Provisions Specific to Hydro One			18
Elimination of Certain Legislation With Respect to Hydro One			18
Cybersecurity			19
RECENT DEVELOPMENTS AT HYDRO ONE			19
Sustainable Financing Framework			19
Directors and Executive Officers			20
RATE-REGULATED UTILITIES			20
Rate Applications in Ontario			20
CORPORATE STRUCTURE			21
Incorporation and Office			21
Corporate Structure and Subsidiaries			22
GENERAL DEVELOPMENT OF THE BUSINESS			23
Chronological Development of the Business			23
General Development of the Business			26
BUSINESS OF HYDRO ONE			28
Segments			28
Transmission Business Segment			29
Distribution Business Segment			37
Other Segment			42
Indigenous Communities			43
Outsourced Services			43
Employees			44
Health, Safety and Environmental Management			45
Environmental Regulation			45
Insurance			47
Ombudsman			47
RISK FACTORS			47
DIVIDENDS			48
DESCRIPTION OF CAPITAL STRUCTURE			48
General Description of Capital Structure			48
Common Shares			48
Class A Preference Shares			49
Class B Preference Shares			49


CREDIT RATINGS			51
MARKET FOR SECURITIES			53
Prior Sales			53
Trading Price and Volume			53
DIRECTORS AND OFFICERS			53
Directors and Executive Officers			53
Information Regarding Certain Directors and Executive Officers			61
Corporate Cease Trade Orders and Bankruptcies			61
Penalties or Sanctions			62
Conflicts of Interest			62
Indebtedness of Directors and Executive Officers			63
CORPORATE GOVERNANCE			63
INTEREST OF MANAGEMENT AND OTHERS IN MATERIAL TRANSACTIONS			63
Relationships with the Province and Other Parties			64
MATERIAL CONTRACTS			66
LEGAL PROCEEDINGS AND REGULATORY ACTIONS			69
INTEREST OF EXPERTS			70
TRUSTEE AND REGISTRAR			70
ADDITIONAL INFORMATION			70
STATEMENT OF EXECUTIVE COMPENSATION			70

GLOSSARY

When used in this annual information form, the following terms have the meanings set forth below unless expressly indicated otherwise:

“$” or “dollar” means Canadian dollars, unless otherwise indicated.

“2017 Long-Term Energy Plan” has the meaning given to it under “The Electricity Industry in Ontario – Issues Affecting the Electricity Industry Generally – Ontario 2017 Long-Term Energy Plan”.

“2020 Ontario Budget” has the meaning given to it under “The Electricity Industry in Ontario – Issues Affecting the Electricity Industry Generally – 2020 Ontario Budget”.

“2022 MTN Shelf Prospectus” has the meaning given to it under “General Development of the Business – Chronological Development of the Business – 2022 MTN Shelf Prospectus and Related Offerings”.

“ACI” has the meaning given to it under “The Electricity Industry in Ontario – Regulation of Transmission and Distribution – Ontario Energy Board”.

“Annual MD&A” means the management’s discussion and analysis for Hydro One Inc. for the years ended December 31, 2022 and 2021 filed on SEDAR under Hydro One Inc.’s profile at www.sedar.com.

“Approved Banks” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“Auditor General Act” means the Auditor General Act, RSO 1990, c A-35.

“Board” means the Board of Directors of Hydro One Inc.

“Building Broadband Faster Act” means the Building Broadband Faster Act, 2021, S.O. 2021, c. 2, Schedule 1.

“Canadian Energy Regulator Act” means the Canadian Energy Regulator Act, SC 2019, c 28, s 10.

“CCAA” means the Companies’ Creditors Arrangement Act, RSC 1985, c C-36.

“CDM” means conservation and demand management.

“CDOR Rate” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“CEO” means Chief Executive Officer.

“CFO” means Chief Financial Officer.

“Class A Preference Shares” means the Class A Preference Shares in the capital of Hydro One Inc.

“Class A Redemption Date” has the meaning given to it under “Description of Capital Structure – Class A Preference Shares”.

“Class B Dividend Payment Date” has the meaning given to it under “Description of Capital Structure –Class B Preference Shares”.

“Class B Preference Shares” means the Class B Preference Shares in the capital of Hydro One Inc.

“Class B Redemption Date” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“common shares” means the common shares in the capital of Hydro One Inc.

“CSO” has the meaning given to it under “Business of Hydro One – Employees”.

“Custom IR Method” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Transmission Rate Setting”.

“CUSW” has the meaning given to it under “Business of Hydro One – Employees”.

“DBRS” has the meaning given to it under “Credit Ratings”.

“Dealer Agreement” has the meaning given to it under “Material Contracts”.

“Dealers” has the meaning given to it under “Material Contracts”.

“DERs” has the meaning given to it under “The Electricity Industry in Ontario – Regulation of Transmission and Distribution – Ontario Energy Board”.

“DMS” has the meaning given to it under “Business of Hydro One – Distribution Business Segment –Capital Expenditures”.

“Electricity Act” means the Electricity Act, 1998, SO 1998, c 15, Schedule A.

“Electrification and Energy Transition Panel” has the meaning given to it under “The Electricity Industry in Ontario – Issues Affecting the Electricity Industry Generally – Ontario 2017 Long-Term Energy Plan”.

“Energy Statute Law Amendment Act” means the Energy Statute Law Amendment Act, 2016, SO 2016, c 10.

“Energy Transition Roadmap” has the meaning given to it under “The Electricity Industry in Ontario – Regulation of Transmission and Distribution – Ontario Energy Board”.

“Environmental Assessment Act” means the Environmental Assessment Act, RSO 1990, c E-18.

“EPSCA” has the meaning given to it under “Business of Hydro One – Employees”.

“ESG” means environmental, social and governance.

“Executive Compensation Exemptive Relief” has the meaning given to it under “Statement of Executive Compensation”.

“FEI” has the meaning given to it under “The Electricity Industry in Ontario – Regulation of Transmission and Distribution – Ontario Energy Board”.

“Financial Administration Act” means the Financial Administration Act, RSO 1990, c F-12.

“Floating Quarterly Dividend Rate” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“Floating Rate Calculation Date” means November 20, 2017 and each Class B Dividend Payment Date thereafter.

“Framework” has the meaning given to it under “Recent Developments at Hydro One – Sustainable Financing Framework”.

“GAICD” means “Graduate of the Australian Institute of Company Directors”.

“Golf Town” has the meaning given to it under “Directors and Officers – Corporate Cease Trade Orders and Bankruptcies”.

“Governance Agreement” means the governance agreement dated November 5, 2015 between Hydro One Limited and the Province.

“Great Lakes Power” means Great Lakes Power Transmission LP.

“HOSSM” means Hydro One Sault Ste. Marie LP.

“Hydro One” or the “Company” have the meanings given to such terms set out under “Presentation of Information”.

“Hydro One Accountability Act” means the Hydro One Accountability Act, 2018, SO 2018, c 10, Schedule 1.

“Hydro One Inc.” has the meaning given to it under “Presentation of Information”.

“Hydro One Limited” has the meaning given to it under “Presentation of Information”.

“Hydro One Networks” means Hydro One Networks Inc.

“Hydro One Remote Communities” means Hydro One Remote Communities Inc.

“Hydro One Telecom” means Hydro One Telecom Inc., now Acronym Solutions Inc.

“ICD.D” means the “Institute of Corporate Directors, Director” designation.

“IESO” means the Independent Electricity System Operator.

“JRAP” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – Hydro One Networks”.

“kV” means kilovolt.

“kW” means kilowatt.

“Letter Agreement” means the agreement dated July 11, 2018 between Hydro One Limited and the Province.

“management” has the meaning given to it under “Presentation of Information”.

“Market Rules” means the rules made under section 32 of the Electricity Act that are administered by the IESO.

“Minister of Energy” means the Minister of Energy, Northern Development and Mines for the Province

or the Minister of Energy for the Province, as applicable at the relevant time.

“Moody’s” has the meaning given to it under “Credit Ratings”.

“National Energy Board Act” means the National Energy Board Act, RSC 1985, c N-7.

“NERC” means the North American Electric Reliability Corporation.

“Niagara Line” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – Niagara Reinforcement Limited Partnership”.

“NPCC” means the Northeast Power Coordinating Council, Inc.

“NRLP” means – Niagara Reinforcement Limited Partnership.

“NYSE” means the New York Stock Exchange.

“OBCA” means the Business Corporations Act, RSO 1990, c B-16.

“OEB” means the Ontario Energy Board.

“OEFC” means Ontario Electricity Financial Corporation.

“Ontario” or the “province” has the meaning given to it under “Presentation of Information”.

“Ontario Energy Board Act” means the Ontario Energy Board Act, 1998, SO 1998, c 15, Schedule B.

“Orillia Power” means Orillia Power Distribution Corporation.

“PCBs” means polychlorinated biphenyls.

“PDI” means Peterborough Distribution Inc.

“Price Cap IR” has the meaning given to it under “Business of Hydro One – Distribution Business Segment – Regulation – Distribution Rates”.

“Province” has the meaning given to it under “Presentation of Information”.

“PWU” has the meaning given to it under “Business of Hydro One – Employees”.

“Quarterly Floating Rate Period” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“rate base” has the meaning given to it under “Presentation of Information”.

“rate-regulated” has the meaning given to it under “Rate-Regulated Utilities – Rate Applications in Ontario – Framework”.

“Reliability Standards” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Reliability Standards and Regulations for Transmission”.

“Reserve” means a “reserve” as that term is defined in the Indian Act, RSC 1985, c I-5.

“Retraction Date” has the meaning given to it under “Description of Capital Structure – Class B

Preference Shares”.

“Retraction Demand” has the meaning given to it under “Description of Capital Structure – Class B Preference Shares”.

“return on equity” has the meaning given to it under “Presentation of Information”.

“revenue cap escalator factor” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – HOSSM”.

“Revenue Cap Index” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Transmission Rate Setting”.

“Roadmap” means Energy Transition Roadmap.

“ROE” has the meaning given to it under “Rate-Regulated Utilities – Rate Applications in Ontario – Framework”.

“RPP” has the meaning given to it under “The Electricity Industry in Ontario – Ontario 2017 Long-Term

Energy Plan – 2020 Ontario Budget”.

“RPPAG” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Regional Planning”.

“RRF” means the performance-based model set out in the OEB’s Renewed Regulatory Framework for Electricity Distributors.

“S&P” has the meaning given to it under “Credit Ratings”.

“Society” has the meaning given to it under “Business of Hydro One – Employees”.

“trust assets” has the meaning given to it under “Interest of Management and Others in Material Transactions – Relationships with the Province and Other Parties – Transfer Orders”.

“Trust Indenture” has the meaning given to it under “Material Contracts”.

“TS” means transmission station.

“TWh” means terawatt-hours.

“U.S.” means the United States of America.

“U.S. GAAP” means United States Generally Accepted Accounting Principles.

“uniform transmission rates” has the meaning given to it under “Business of Hydro One – Transmission Business Segment – Regulation – Transmission Rate Setting”.

PRESENTATION OF INFORMATION

Unless otherwise specified, all information in this annual information form is presented as at December 31, 2022.

Capitalized terms used in this annual information form are defined under “Glossary”. Words importing the singular number include the plural, and vice versa, and words importing any gender include all genders. The Annual MD&A and the audited consolidated financial statements of Hydro One Inc. as at and for the years ended December 31, 2022 and 2021 are specifically incorporated by reference into and form an integral part of this annual information form. Copies of these documents have been filed with the Canadian securities regulatory authorities and are available on SEDAR under Hydro One Inc.’s profile at www.sedar.com.

Unless otherwise noted or the context otherwise requires, references to “Hydro One” or the “Company” refer to Hydro One Inc. and its subsidiaries taken together as a whole. References to “Hydro One Limited” refer only to Hydro One Limited and references to “Hydro One Inc.” refer only to Hydro One Inc.

In addition, “Province” refers to the Province of Ontario as a provincial government entity, and “Ontario” or the “province” in lower case type refers to the Province of Ontario as a geographical area. References to “management” in this annual information form mean the persons who are identified as executive officers of Hydro One Inc. and its subsidiaries, as applicable, in this annual information form. Any statements made by or on behalf of management are made in such persons’ respective capacities as executive officers of Hydro One Inc. and its subsidiaries, as applicable, and not in their personal capacities. See “Directors and Officers” for more information.

This annual information form refers to certain terms commonly used in the electricity industry, such as “rate-regulated”, “rate base” and “return on equity”. Rate base is an amount that a utility is required to calculate for regulatory purposes, and refers to the net book value of the utility’s assets for regulatory purposes plus an allowance for working capital. Return on equity is a percentage that is set or approved by a utility’s regulator and represents the rate of return that a regulator allows the utility to earn on the equity component of the utility’s rate base. See also “Rate-Regulated Utilities”.

In this annual information form, all dollar amounts are expressed in Canadian dollars unless otherwise indicated. Hydro One Limited and Hydro One Inc. prepare and present their financial statements in accordance with U.S. GAAP.

FORWARD-LOOKING INFORMATION

Certain information in this annual information form contains “forward-looking information” within the meaning of applicable Canadian securities laws. Forward-looking information in this annual information form is based on current expectations, estimates, forecasts and projections about Hydro One’s business and the industry, and the regulatory and economic environments, in which Hydro One operates and includes beliefs of and assumptions made by management. Such statements include, but are not limited to, statements related to: the Company’s transmission and distribution rate applications, and resulting decisions, rates and impacts; expected impacts and timing of changes to the electricity industry; the potential impact of COVID-19, including its variants, on the Company’s business and operations; the Company’s maturing debt; expectations regarding the Company’s financing activities; credit ratings; ongoing and planned projects and/or initiatives; expected future capital investments and expenditures, the nature and timing of these investments and expenditures, including the Company’s plans for sustaining and development capital expenditures for its distribution and transmission systems; expectations regarding allowed return on equity; expectations regarding the ability of the Company to recover expenditures in future rates; expectations relating to the recoverability of incremental costs and lost revenues from ratepayers in connection with the COVID-19 pandemic; expectations regarding the ability to negotiate collective agreements consistent with rate orders; expectations related to work force demographics; expectations regarding taxes; expectations regarding load growth; the regional planning process; expectations related to Hydro One’s CDM requirements and targets; new legislation and regulatory initiatives relating to the electricity industry and the expected impacts of such; expectations regarding the Company’s DMS; the Company’s customer focus and related initiatives; statements related to the Company’s relationships with Indigenous communities; statements related to environmental matters, and the Company’s expected future environmental and remediation expenditures; statements related to the Company’s commitment to releasing an annual sustainability report and to increase the transparency of ESG disclosures; statements relating to the Company’s plans to issue sustainable financing instruments, such as sustainable and green bonds, and to allocate the net proceeds to investments in eligible green and social project categories; statements relating to the Company’s intention to provide annual updates regarding the use of net proceeds of any green and/or sustainable financing; expectations related to the effect of interest rates; the Company’s reputation; cyber and data security; Hydro One Limited’s relationship with the Province; acquisitions and consolidation opportunities and other strategic initiatives; expectations regarding the Governance Agreement and other agreements with the Province; the status of litigation; expectations regarding the manner in which Hydro One will operate and the Company’s strategy; potential conflicts of interest; and legal proceedings in which Hydro One is currently involved.

Words such as “aim”, “could”, “would”, “expect”, “anticipate”, “intend”, “attempt”, “may”, “plan”, “will”, “believe”, “seek”, “estimate”, “goal”, “target”, and variations of such words and similar expressions are intended to identify such forward-looking information. These statements are not guarantees of future performance and involve assumptions and risks and uncertainties that are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed, implied or forecasted in such forward-looking information. Hydro One does not intend, and it disclaims any obligation to update any forward-looking information, except as required by law.

The forward-looking information in this annual information form is based on a variety of factors and

assumptions including, but not limited to: the scope of the COVID-19 pandemic and duration thereof as well as the effect and severity of corporate and other mitigation measures on the Company’s operations, supply chain or employees; no unforeseen changes in the legislative and operating framework for Ontario’s electricity market; favourable decisions from the OEB and other regulatory bodies concerning outstanding and future rate and other applications; no unexpected delays in obtaining required regulatory approvals; no unforeseen changes in rate orders or rate setting methodologies for Hydro One’s distribution and transmission businesses; no unfavourable changes in environmental regulation; continued use of U.S. GAAP; a stable regulatory environment; no significant changes to the Company’s current credit ratings; no unforeseen impacts of new accounting pronouncements; no changes to expectations regarding electricity consumption; no unforeseen changes to economic and market conditions; recoverability of costs and expenses related to the COVID-19 pandemic; completion of operating and capital projects that have been deferred; and no significant event occurring outside the ordinary course of business. These assumptions are based on information currently available to Hydro One, including information obtained from third-party sources. Actual results may differ materially from those predicted by such forward-looking information. While Hydro One does not know what impact any of these differences may have, Hydro One’s business, results of operations, financial condition and credit stability may be materially adversely affected if any such differences occur. Factors that could cause actual results or outcomes to differ materially from the results expressed or implied by forward-looking information include, among other things:

•regulatory risks and risks relating to Hydro One’s revenues, including risks relating to actual performance against forecasts, competition with other transmitters and other applications to the OEB, the rate-setting models for transmission and distribution, the recoverability of capital expenditures, obtaining rate orders or recoverability of total compensation costs;

•risks associated with the Province’s share ownership of Hydro One Limited and other relationships with the Province, including potential conflicts of interest that may arise between Hydro One, the Province and related parties, risks associated with the Province’s exercise of further legislative and regulatory powers, risks relating to the ability of the Company to attract and retain qualified executive talent or the risk of a credit rating downgrade for the Company and its impact on the Company’s funding and liquidity;

•risks relating to the location of the Company’s assets on Reserve lands, that the company’s operations and activities may give rise to the Crown’s duty to consult and potentially accommodate Indigenous communities, and the risk that Hydro One may incur significant costs associated with transferring assets located on Reserves;

•the risk that the Company may be unable to comply with regulatory and legislative requirements or that the Company may incur additional costs for compliance that are not recoverable through rates;

•the risk of exposure of the Company’s facilities to the effects of severe weather conditions, natural disasters, man-made events or other unexpected occurrences for which the Company is uninsured or for which the Company could be subject to claims for

damage;

•the risk of non-compliance with environmental regulations and inability to recover environmental expenditures in rate applications and the risk that assumptions that form the basis of the Company’s recorded environmental liabilities and related regulatory assets may change;

•risks associated with information system security and maintaining complex information technology and operational technology system infrastructure, including system failures or risks of cyber-attacks or unauthorized access to corporate information technology and operational technology systems;

•the risk that the Company may not be able to execute plans for capital projects necessary to maintain the performance of the Company’s assets or to carry out projects in a timely manner or the risk of increased competition for the development of large transmission projects or legislative changes affecting the selection of transmitters;

•risks relating to an outbreak of infectious disease, including the COVID-19 pandemic (including a significant expansion in length or severity of the COVID-19 pandemic, including the spread of its variants, restricting or prohibiting the Company’s operations or significantly impacting the Company’s supply chain or workforce; severity of mitigation measures relating to the COVID-19 pandemic and delays in completion of and increases in costs of operating and capital projects; and the regulatory and accounting treatment of incremental costs and lost revenues of the Company related to the COVID-19 pandemic);

•the risk of labour disputes and inability to negotiate or renew appropriate collective agreements on acceptable terms consistent with the Company’s rate decisions;

•risks related to the Company’s work force demographic and its potential inability to attract and retain qualified personnel;

•the risk that the Company is not able to arrange sufficient cost-effective financing to repay maturing debt and to fund capital expenditures or the risk of a downgrade in the Company’s credit ratings;

•risks associated with fluctuations in interest rates and failure to manage exposure to credit and financial instrument risk;

•risks associated with economic uncertainty and financial market volatility;

•risks associated with asset condition, capital projects and innovation, including public opposition to or delays or denials of the requisite approvals and accommodations for the Company’s planned projects;

•the risk of failure to mitigate significant health and safety risks;

•the risk of not being able to recover the Company’s pension expenditures in future rates and uncertainty regarding the future regulatory treatment of pension, other post-employment benefits and post-retirement benefits costs;

•the impact of the ownership by the Province of lands underlying the Company’s transmission system;

•the risk associated with legal proceedings that could be costly, time-consuming or divert the attention of management and key personnel from the Company’s business operations;

•the impact if the Company does not have valid occupational rights on third-party owned or controlled lands and the risks associated with occupational rights of the Company that may be subject to expiry;

•risks relating to adverse reputational events or political actions;

•the potential that Hydro One may incur significant expenses to replace functions currently outsourced if agreements are terminated or expire before a new service provider is selected;

•risks relating to acquisitions, including the failure to realize the anticipated benefits of such transactions at all, or within the time periods anticipated, and unexpected costs incurred in relation thereto;

•the inability to continue to prepare financial statements using U.S. GAAP; and

•the risk related to the impact of any new accounting pronouncements.

Hydro One cautions the reader that the above list of factors is not exhaustive. Some of these and other factors are discussed in more detail under the heading “Risk Management and Risk Factors” in the Annual MD&A. You should review such section in detail, including the matters referenced therein.

In addition, Hydro One cautions the reader that information provided in this annual information form regarding Hydro One’s outlook on certain matters, including potential future expenditures, is provided in order to give context to the nature of some of Hydro One’s future plans and may not be appropriate for other purposes.

ELECTRICITY INDUSTRY OVERVIEW

General Overview

The electricity industry is made up of businesses that generate, transmit, distribute and sell electricity. While traditionally a mature and stable industry, the electricity industry is facing rapid and dramatic technological change and increasing innovation. Hydro One’s business is focused on the transmission and distribution of electricity.

•Transmission refers to the delivery of electricity over high voltage lines, typically over long distances, from generating stations to local areas and large industrial customers.

•Distribution refers to the delivery of electricity over low voltage lines to end users such as homes, businesses and institutions.

Overview of an Electricity System

The basic configuration of a typical electricity system, showing electricity generation, transmission and distribution, is illustrated in the following diagram:

Note:

The above image shows a typical electricity system with transmission-connected generation.

Transmission and distribution networks are sometimes referred to as the “electricity grid” or simply “the grid”.

THE ELECTRICITY INDUSTRY IN ONTARIO

Regulation of Transmission and Distribution

General

The Electricity Act and the Ontario Energy Board Act establish the general legislative framework for Ontario’s electricity market. The activities of transmitters and distributors in Ontario are overseen by three main regulatory authorities: (i) the OEB, (ii) the IESO, and (iii) the Canadian Energy Regulator. The Minister of Energy is responsible for developing long-term energy plans and has the power to issue directives to the IESO and the OEB regarding implementation of such plans.

Ontario Energy Board

The OEB is an independent regulatory agency. The Ontario Energy Board Act provides the OEB with the authority to regulate Ontario’s electricity market, including the activities of transmitters and distributors.

The OEB has the following legislated objectives in relation to the electricity industry:

•to inform consumers and protect their interests with respect to prices and the adequacy, reliability and quality of electricity service,

•to promote economic efficiency and cost effectiveness in the generation, transmission, distribution, sale and demand management of electricity and to facilitate the maintenance of a financially viable electricity industry,

•to promote electricity conservation and demand management in a manner consistent with the policies of the Province, including having regard to the consumer’s economic circumstances, and

•to facilitate innovation in the electricity sector.

The OEB is responsible for, among other things, approving transmission and distribution rates in Ontario. It also approves the construction, expansion, or reinforcement of transmission lines greater than two kilometres in length, as well as mergers, acquisitions, amalgamations and divestitures involving distributors, transmitters and other entities which it licenses. The activities of transmitters and distributors are subject to the conditions of their licences and a number of industry codes issued by the OEB. These codes and other requirements prescribe minimum standards of conduct and service for licensed participants in the electricity market.

In December 2017, the OEB posted its Strategic Blueprint: Keeping Pace with the Evolving Energy Sector, setting out the OEB’s commitment to modernize its approach to regulation over the next five years and established the Advisory Committee on Innovation (“ACI”). The ACI was tasked with identifying steps to develop a modern regulatory framework in response to technological changes occurring in the energy sector. In 2019, in response to recommendations made by the ACI, the OEB initiated two consultation processes, Utility Remuneration and Responding to Distributed Energy

Resources (“DERs”). In March 2021, the OEB issued a letter which renamed and consolidated these two consultations into a single consultation named Framework for Energy Innovation: Distributed Resources and Utility Incentives (“FEI”). The FEI consultation focused on: (i) investigating and supporting utilities’ use of DERs they do not own as alternatives to traditional wires solutions to meet distribution needs; and (ii) ensuring that utilities’ planning is appropriately informed by DER penetration and forecasts. In January 2023, the OEB released its Framework for Energy Innovation: Setting a Path Forward for DER Integration report. This report is the culmination of the FEI consultation and sets out the OEB’s policies and next steps with respect to the integration of DERs into distribution system planning and operations, as well as the use of DERs by electricity distributors as non-wires alternatives. The OEB has indicated it is developing an Energy Transition Roadmap (the “Energy Transition Roadmap”) that will provide a schedule of initiatives the OEB is taking or plans to undertake with respect to the energy transition. This Roadmap is intended to provide clarity on the OEB’s priorities, support the coordination of interrelated initiatives within the OEB and across the sector and support effective stakeholder engagement.

In October 2022, the Minister of Energy issued a Letter of Direction to the OEB, which included the Minister of Energy’s priorities and expectations for the OEB’s upcoming three-year business planning period. One of the priorities identified was support for the Electrification and Energy Transition Panel. See “The Electricity Industry in Ontario – Issues Affecting the Electricity Industry Generally – Ontario 2017 Long-Term Energy Plan” for more information.

IESO

The IESO delivers key services across the electricity sector, including managing the power system in real time, planning for Ontario’s future energy needs, enabling conservation and designing a more efficient electricity marketplace to support sector evolution. Transmitters and other wholesale market participants must comply with the Market Rules issued by the IESO. The Market Rules require transmitters to comply with mandatory North American reliability standards for transmission issued by the NERC and the NPCC. The IESO enforces these reliability standards and coordinates with system operators and reliability agencies in other jurisdictions to ensure energy adequacy and security across the interconnected bulk electricity system in North America.

In December 2022, the IESO released its Pathways to Decarbonization report in response to the Minister of Energy’s request to evaluate a moratorium on new natural gas generation in Ontario, and to develop an achievable pathway to decarbonization in the electricity system.

Canadian Energy Regulator

In August 2019, the Canadian Energy Regulator Act came into force, replacing the National Energy Board Act. As a result of the new statute, the National Energy Board became the Canadian Energy Regulator. Any decision or order made by the National Energy Board is considered to have been made under the Canadian Energy Regulator Act and may be enforced as such.

The Canadian Energy Regulator has jurisdiction over the construction and operation of international power lines, as well as interprovincial lines that are designated as being under federal jurisdiction (of which there are currently none). As Hydro One owns and operates 11 active international power lines

connecting Ontario’s transmission system with transmission systems in Michigan, Minnesota and New York, Hydro One holds several certificates and permits with the Canadian Energy Regulator.

Transmission

Transmission companies own and operate transmission systems that deliver electricity over high voltage lines. Hydro One’s transmission system accounts for approximately 92% of Ontario’s electricity transmission capacity based on the revenues approved by the OEB. The Company’s transmission system is interconnected to systems in Manitoba, Michigan, Minnesota, New York and Quebec and is part of the North American electricity grid’s Eastern Interconnection. The Eastern Interconnection is a contiguous electricity transmission system that extends from Manitoba to Florida and from east of the Rocky Mountains to the North American east coast. Being part of the Eastern Interconnection provides benefits to Ontario, such as greater security and stability for Ontario’s transmission system, emergency support when there are generation constraints or shortages in Ontario, and the ability to exchange electricity with other jurisdictions.

Distribution

Distributors own and operate distribution systems that deliver electricity over power lines at voltages of 50 kV or less to end users. A local distribution company is responsible for distributing electricity to customers in its OEB-licensed service territory, and in some cases to other distributors. A service territory may cover large portions or all of a particular municipality, or an otherwise defined geographic area. Distribution customers include homes, commercial and industrial businesses and institutions such as governments, schools and hospitals.

In Ontario, as per the OEB’s 2021 Yearbook of Electricity Distributors, as at December 31, 2021, 56 local distribution companies provided electricity to over five million customers. The distribution industry in Ontario is fragmented, with the 10 largest local distribution companies accounting for approximately 80% of the province’s customers.

Hydro One owns the largest local distribution business in Ontario, which serves approximately 1.5 million predominantly rural customers, or approximately 28% of the total number of customers in Ontario.

Issues Affecting the Electricity Industry Generally

Tax Incentives

Tax incentives were included in the 2015 Ontario budget to promote consolidation in the electricity distribution sector. The 2015 Ontario budget announced a reduction in the tax rate for transfers of electricity assets from 33% to 22% and to nil for distributors with fewer than 30,000 customers. In addition, the budget introduced a capital gains exemption where capital gains arise as a result of exiting the payments in lieu of corporate taxes regime. These incentives are in place until December 31, 2024.

Ontario 2017 Long-Term Energy Plan

In October 2017, the Province released its 2017 Long-Term Energy Plan (the “2017 Long-Term Energy Plan”), which set out a number of initiatives for Ontario’s energy system, including: ensuring affordable and accessible energy, ensuring a flexible energy system, innovating to meet the future, improving value and performance for consumers, strengthening its commitment to energy conservation and efficiency, responding to the challenge of climate change, supporting First Nation and Métis capacity and leadership, and supporting regional solutions and infrastructure. The IESO and the OEB developed implementation plans in support of the objectives of the 2017 Long-Term Energy Plan, and each implementation plan was approved by the Minister of Energy in February 2018. The Province is currently consulting industry and stakeholders on a long-term system-planning process to replace the 2017 Long-Term Energy Plan.

In 2022, the Province established the Electrification and Energy Transition Panel (the “Electrification and Energy Transition Panel”). This panel is responsible for advising the Province on the highest value short, medium, and long-term opportunities for the energy sector to help Ontario’s economy prepare for electrification and the energy transition. The Electrification and Energy Transition Panel is also expected to identify opportunities to strengthen Ontario’s long-term energy planning process by better coordinating the fuels and the electricity sector.

2020 Ontario Budget

In November 2020, the Province released its 2020 Ontario Budget: Ontario’s Action Plan: Protect, Support, Recover (the “2020 Ontario Budget”), which included a rate mitigation plan to help certain business and industrial customers. As of January 1, 2021, a portion of non-hydro renewable energy contracts (including wind, solar, bioenergy) is funded by the Province and not ratepayers. According to the 2020 Ontario Budget, this represented an approximately 25% reduction of the current cost of the “Global Adjustment” in Ontario at the time the budget was released. The Global Adjustment is the difference between the guaranteed price and the money the generators earn in the wholesale marketplace. This reduction in the Global Adjustment did not benefit regulated price plan (“RPP”) customers (households, farms, small businesses), who instead continue to be protected by means of the Ontario Electricity Rebate program.

OEB Actions on Electricity Pricing

Since March 2020, the Province has taken a number of actions related to the pricing of electricity to support RPP customers in dealing with the impacts of the COVID-19 pandemic. These government mandated actions include providing different fixed electricity prices for various periods of time. All of these COVID-19 related pricing changes mandated by the Province have been implemented by the OEB and details are available on the OEB’s website. The information contained on the OEB’s website is not incorporated by reference into this annual information form.

In response to direction provided by the Province, in September 2020 the OEB announced that, as of October 13, 2020, all utilities were required to give RPP customers the choice to opt out of time-of-use pricing and to elect instead to be charged on the basis of tiered (or fixed) electricity pricing.

On December 15, 2020, the OEB reset the RPP prices effective January 1, 2021, to reflect a decrease in the RPP supply cost as a result of the reduction in the Global Adjustment as set out in the 2020 Ontario Budget. These RPP prices came into effect at the conclusion of the electricity price changes established to assist customers in dealing with the impacts of the COVID-19 pandemic. In April 2021, the OEB reset the RPP prices effective May 1, 2021 for households and small businesses. In October 2021, the OEB announced that as of November 1, 2021, the electricity prices would not change under the RPP. In January 2022, the OEB temporarily changed the RPP prices for the period from January 18, 2022 to February 7, 2022, fixing the price for this period to the off-peak rate in order to provide temporary electricity rate relief as directed by the Province. In October 2022, the OEB reset the RPP prices effective November 1, 2022 for households and small businesses. Going forward, it is anticipated that the OEB will periodically review the RPP prices and will reset them if required, in accordance with the OEB’s usual practice.

In October 2022, the Province established regulatory requirements, which will require the OEB to direct electricity distributors to implement a new voluntary ultra-low overnight price plan for RPP customers. This requirement would introduce a third pricing option for RPP customers in addition to the currently available time-of-use and tiered pricing plans. RPP costs remain a flow-through cost for utilities. The ultra-low overnight price plan would support electrification and decarbonization by incentivizing customers to shift electricity loads to overnight periods when demand is lower and more electricity from non-emitting sources is available. Utilities are required to implement the new ultra-low overnight rate no later than November 1, 2023. OEB consultations to implement this price plan are ongoing.

Building Broadband Faster Act, 2021

In March 2021, the Province introduced Bill 257, Supporting Broadband and Infrastructure Expansion Act, 2021, to create a new act entitled the Building Broadband Faster Act, 2021 that is aimed at supporting the timely deployment of broadband infrastructure within unserved and underserved rural Ontario communities. Bill 257 received Royal Assent on April 12, 2021. Bill 257 amended the Ontario Energy Board Act to provide the Province with regulation-making authority regarding the development of, access to, or use of electricity infrastructure for non-electricity purposes. The Building Broadband Faster Act Guideline and three regulations informing the legislative changes were published in 2021. In March 2022, the Province introduced Bill 93, Getting Ontario Connected Act, 2022. Bill 93 received Royal Assent on April 14, 2022. Bill 93 amended the Building Broadband Faster Act to ensure that organizations that own underground utility infrastructure near a designated high-speed internet project provide timely access to their infrastructure data, which would allow internet service providers to quickly start work on laying down underground high-speed internet infrastructure. The regulation regarding electricity infrastructure and designated broadband projects under the Ontario Energy Board Act came into force in April 2022. This regulation substantially adopted Hydro One’s proposed approach to allocation of the costs of broadband-related work on utility assets. It also directed the OEB to establish a deferral account for rate-regulated distributors to record incremental costs associated with carrying out activities pertaining to designated broadband projects, which the OEB completed in July 2022. The Company continues to be engaged with the Province and the OEB on implementing an appropriate regulatory framework to support the published Building Broadband Faster Act Guideline and regulations, including arrangements to sustain the Company’s revenues and recovery of reasonable associated costs. In September 2022, the Company launched its choice-based operating model to provide internet service

providers with choices on how to access the Company’s infrastructure in order to effectively execute designated broadband projects.

Legislative Provisions Specific to Hydro One

In addition to legislation in Ontario that impacts all transmitters and distributors, there is legislation that is specific to Hydro One. Specifically, the Electricity Act requires Hydro One’s head office and principal grid control centre to be maintained in Ontario, restricts the disposition of substantially all of its OEB-regulated transmission or distribution business, prohibits any change to its jurisdiction of incorporation and requires the Company to have an ombudsman.

Ombudsman

The Electricity Act requires the Company to have an ombudsman to act as a liaison with customers and to establish procedures for the ombudsman to inquire into and report to the board of directors of Hydro One Limited on matters raised with the ombudsman by or on behalf of customers. See “Business of Hydro One – Ombudsman” for more information.

Hydro One Accountability Act

In August 2018, the Province passed the Hydro One Accountability Act, requiring the board of directors of Hydro One Limited to establish a new compensation framework for the board, CEO and certain other executives, as defined in the legislation, in consultation with the Province and the other five largest shareholders of Hydro One Limited. Pursuant to the Hydro One Accountability Act, in February 2019, the Province issued a directive to Hydro One Limited which set out certain compensation-related requirements for the CEO, other executives and the board of directors of Hydro One Limited that Hydro One Limited was required to follow when developing its board and executive compensation framework, and in March 2019, the Province approved a new compensation framework submitted by Hydro One Limited in compliance with the directive. The Hydro One Accountability Act also requires Hydro One Limited to annually provide public disclosure concerning compensation paid to certain executives. The Ontario Energy Board Act was also amended to preclude the OEB from approving or fixing rates for Hydro One Limited or any of its subsidiaries that include any amount in respect of compensation paid to the CEO and certain other executives.

As of January 1, 2023, the provisions of the Hydro One Accountability Act requiring a compensation framework and the related directive are no longer in effect.

Additional information regarding the Company’s compensation arrangements is found in the Statement of Executive Compensation for Hydro One Inc.

Elimination of Certain Legislation With Respect to Hydro One

In 2015 and 2016, Hydro One ceased to be subject to a number of Ontario statutes that apply to entities owned by the Province. Hydro One Limited is similarly not subject to those statutes. Notwithstanding the elimination of certain legislation with respect to Hydro One, the Company is required under the Financial

Administration Act and the Auditor General Act to provide financial information to the Province for the Province’s public reporting purposes.

Cybersecurity

The Company is exposed to potential risks related to cyberattacks, supply chain compromises and unauthorized access to our systems. As the Company continues to make investments in and rely on additional, more complex and interconnected digital technology to enable efficient operations, the likelihood of a cyber-breach impacting our business increases. In addition, the critical nature of our business further increases the likelihood of a sophisticated cyber attacker taking advantage of our people, processes and technology. The Company takes a risk-aligned approach to cyber related investments to reduce the likelihood of an impactful cyber related breach. Despite having strong security measures in place, a breach could occur. A breach has the ability to corrupt our information technology systems, compromise our sensitive information, effect the integrity of our financial controls, disrupt operations or have impacts to the safety of our work environment. The Company manages these risks by establishing a common set of cybersecurity standards, periodic security testing, program maturity objectives, security partnerships and a unified security strategy built on a set of cybersecurity standards driven by the OEB. This Ontario specific set of standards is in alignment with the National Institute of Standards and Technology’s Cyber Security Framework. In addition to provincial regulatory requirements of the OEB, critical systems that support the North American Bulk Electric System are regulated by the North American Electric Reliability Critical Infrastructure Protection Standards. These two foundational frameworks establish strong security measures across all aspects of our operations.

RECENT DEVELOPMENTS AT HYDRO ONE

Sustainable Financing Framework

In January 2023, Hydro One Limited announced the publication of a Sustainable Financing Framework (as updated on January 23, 2023, the “Framework”), a first for a utility in Canada. The Framework allows Hydro One Limited and its subsidiaries (including Hydro One Inc.) to issue sustainable financing instruments, such as sustainable and green bonds, and allocate the net proceeds to investments in eligible green and social project categories. The project categories include: clean energy, energy efficiency, clean transportation, biodiversity conservation, climate change adaptation, socio-economic advancement of Indigenous peoples and access to essential services (such as the electrical grid and enablement of high-speed broadband internet). Under the Framework, Hydro One Limited will provide annual updates regarding the use of net proceeds of any green and/or sustainable financing, until the net proceeds of any such financing are fully allocated to eligible projects. The Framework has been reviewed by Sustainalytics, a global leader in providing ESG research and analysis. Sustainalytics issued a second party opinion confirming that the Framework aligns with the International Capital Markets Association (ICMA) Sustainability Bond Guidelines 2021, Green and Social Bond Principles 2021 and the Loan Syndications and Trading Association (LSTA) Green and Social Loan Principles 2021.

On January 27, 2023, Hydro One Inc. issued $300 million aggregate principal amount of Series 53 Notes due 2029, $450 million aggregate principal amount of Series 54 Notes due 2033, and $300 million aggregate principal amount of Series 55 Notes due 2053 pursuant to the 2022 MTN Shelf Prospectus. The

offering constituted Hydro One Inc.’s first sustainable bond offering pursuant to the Framework. Hydro One Inc. intends to allocate an amount equal to the proceeds from the sale of the Series 53 Notes, Series 54 Notes, and Series 55 Notes to finance and/or refinance, in whole or in part, new and/or existing eligible projects pursuant to the Framework.

Directors and Executive Officers

Effective February 1, 2023, William Sheffield stepped down as Interim President and Chief Executive Officer. Mr. Sheffield continues as a director of Hydro One Limited and Hydro One Inc.

Effective February 1, 2023, David Lebeter was appointed as President and Chief Executive Officer of Hydro One Limited and Hydro One Inc. and a director of Hydro One Limited and Hydro One Inc.

RATE-REGULATED UTILITIES

Rate Applications in Ontario

Framework

The term “rate-regulated” is used to refer to an electricity business whose rates for transmission, distribution and other services are subject to approval by a regulator. The rate base of a rate-regulated utility means the net book value of the regulated assets of the utility, plus an allowance for working capital. The OEB is the regulator that approves electricity transmission and distribution rates in Ontario. Transmission and distribution rates have historically been determined using either a cost-of-service model or a performance-based model, which typically includes a cost-of-service base year. These models are reviewed and modified by the OEB from time to time.

In a cost-of-service model, a utility charges rates for its services that allow it to recover the costs of providing its services and earn an allowed return on equity. A utility’s return on equity, or “ROE”, is the rate of return that a regulator allows the utility to earn on the equity portion of the utility’s rate base. The utility’s costs of providing its services must be prudently incurred. Cost savings are typically passed on to customers in the form of lower rates reflected in future rate decisions.

Cost of Service ($)

Return on Equity ($)

Revenue Requirement ($)

In a performance-based model, a utility also charges rates for its services that allow it to recover the costs of providing its services and earn an allowed return on equity. However, rates are adjusted formulaically in years subsequent to the initial rebasing of costs. The formulaic adjustments in a performance-based model consider inflation and expectations regarding productivity. They assume that the utility becomes increasingly efficient over time. If a utility achieves cost savings in excess of those established by the regulator, the utility may retain some or all of the benefits of those cost savings, which may permit the utility to earn more than its allowed return on equity. In Ontario, transmission and distribution rates, including those of Hydro One, are now generally determined using a performance-based model.

CORPORATE STRUCTURE

Incorporation and Office

Hydro One Inc. was incorporated as Ontario Hydro Services Company Inc. by articles of incorporation dated December 1, 1998, under the OBCA. On May 1, 2000, it changed its name to Hydro One Inc. Its registered office and head office is located at 483 Bay Street, 8th Floor, South Tower, Toronto, Ontario M5G 2P5. Hydro One Inc. is a wholly-owned subsidiary of Hydro One Limited.

On August 31, 2015, the articles of Hydro One Inc. were amended to provide for certain share ownership restrictions required under amendments to the Electricity Act that came into force that day. On October 30, 2015, the articles of Hydro One Inc. were amended to remove restrictions on the Company’s ability to issue additional shares in its subsidiaries without the prior approval of the Minister of Energy, Science and Technology (predecessor to the Minister of Energy).

On October 31, 2015, the Province revoked all existing unanimous shareholder agreements, shareholder resolutions and shareholder declarations that restricted the powers of the directors to manage or supervise the business and affairs of Hydro One Inc.

Thereafter, on October 31, 2015, Hydro One Inc. repurchased for cancellation all of the outstanding Series A preferred shares in its capital and all of the remaining issued and outstanding shares of Hydro One Inc. were subsequently acquired by Hydro One Limited from the Province in exchange for the issuance to the Province of common shares and Series 1 preferred shares of Hydro One Limited.

On November 2, 2015, the articles of Hydro One Inc. were amended to remove the share ownership restrictions, revise the authorized capital of Hydro One Inc. to be an unlimited number of common shares and an unlimited number of Class A Preference Shares and to modernize the transfer restrictions on its securities.

On November 16, 2017, the articles of Hydro One Inc. were amended to revise the authorized capital of Hydro One Inc. to be an unlimited number of common shares, an unlimited number of Class A Preference Shares and an unlimited number of Class B Preference Shares.

Corporate Structure and Subsidiaries

The following is a simplified chart showing the organizational structure of Hydro One and the name and jurisdiction of incorporation of certain of its subsidiaries. This chart does not include all legal entities within Hydro One’s organizational structure. Hydro One Inc. owns, directly or indirectly, 100% of the voting securities of all of the subsidiaries listed below.

Notes:

(1)As of December 31, 2022, the Province directly owned approximately 47.2% of Hydro One Limited’s outstanding common shares.

Certain of Hydro One’s subsidiaries are described below:

•Hydro One Networks – the principal operating subsidiary that carries on Hydro One’s rate-regulated transmission and distribution businesses.

•Hydro One Remote Communities – generates and supplies electricity to remote communities in northern Ontario.

GENERAL DEVELOPMENT OF THE BUSINESS

Chronological Development of the Business

Background

In August 2015, Hydro One Limited was incorporated by the Province as its sole shareholder. In 2015, prior to the closing of the initial public offering of Hydro One Limited, all of the issued and outstanding common shares of Hydro One Inc. were acquired by Hydro One Limited.

COVID-19 Pandemic and Related Developments

In 2020, the World Health Organization declared COVID-19 a global pandemic. Since the start of the pandemic, the Company has continued to operate in-line with evolving safety procedures and practices. The Company continues to monitor and adhere to guidance provided by the Province and public health experts in an effort to ensure employee, customer and public safety.

As an essential service, Hydro One’s teams have continued to ensure the delivery of reliable power since the start of the pandemic. The Company continues to take actions to protect its employees against the spread of COVID-19 in the workplace. There has been no significant impact to the Company’s services or work programs. Nevertheless, Hydro One has proactively prepared contingency plans in the event of significant labour reductions in any of its lines of business. Strategies implemented would depend on the severity and duration of a reduction in employees.

Global staffing shortages caused by the pandemic have led to supply chain issues in many industries. Hydro One has not been immune to the growing global supply chain disruptions and pricing pressures that are being experienced across the utility industry. However, it has managed these disruptions by shifting projects and taking proactive measures to ensure it has the materials and equipment necessary to complete its capital work program. As a result, there has not been a material impact to the overall work program.

While Hydro One continues to take the necessary steps to mitigate the impact of COVID-19 on the Company’s operations, the development of new variants and constantly changing public health restrictions make it very difficult to determine or estimate the future impacts of COVID-19 on Hydro One’s operations. Potential impacts will be largely dependent on the duration of the pandemic, the attributes of the variants, and the severity of the measures that may be implemented to combat them.

Hydro One will continue to actively monitor the impacts of the COVID-19 pandemic, including guidance provided by the Province and public health experts, and may take further actions that it determines to be in the best interest of its operations, employees, customers, partners and stakeholders, or as required by federal or provincial authorities.

In addition to the above, the following key events occurred from 2020 to 2022 in respect of Hydro One.

2020

Directors and Executive Officers

Effective January 1, 2020, Susan Wolburgh Jenah was appointed as a director of Hydro One Limited and Hydro One Inc.

Effective January 2, 2020, David Lebeter was appointed Chief Operating Officer of Hydro One Networks.

Effective July 23, 2020, Stacey Mowbray was appointed as a director of Hydro One Limited and Hydro One Inc.

Effective September 28, 2020, Megan Telford was appointed Chief Human Resources Officer of Hydro One Networks.

Acquisition of Orillia Power

In August 2016, Hydro One Inc. reached an agreement to acquire Orillia Power, an electricity distribution

company located in Simcoe County, Ontario, from the Corporation of the City of Orillia, subject to the satisfaction of customary closing conditions as well as approval by the OEB. In April 2020, the OEB issued its decision approving Hydro One Inc.’s acquisition of Orillia Power from the City of Orillia. In September 2020, Hydro One Inc. completed the acquisition for a purchase price of approximately $28 million inclusive of closing adjustments. See “General Development of the Business – Chronological Development of the Business – 2021 – Integration of Orillia Power” for more information.

Acquisition of the Business and Distribution Assets of Peterborough Distribution Inc.

In July 2018, Hydro One Inc. reached an agreement to acquire the business and distribution assets of PDI,

an electricity distribution company located in the County of Peterborough, from the Corporation of the City of Peterborough, subject to the satisfaction of customary closing conditions as well as approval by the OEB. In April 2020, the OEB issued its decision approving Hydro One Inc.’s acquisition of the business and distribution assets of PDI from the City of Peterborough. In August 2020, Hydro One Inc. completed the acquisition for a purchase price of approximately $104 million, including the assumption of agreed upon liabilities and final closing adjustments. See “General Development of the Business – Chronological Development of the Business – 2021 – Integration of the Business and Distribution Assets of Peterborough Distribution Inc.” for more information.

2021

Integration of Orillia Power

In June 2021, Hydro One completed the integration of Orillia Power, which was acquired in September 2020. See “General Development of the Business – Chronological Development of the Business – 2020 – Acquisition of Orillia Power” for more information.

Integration of the Business and Distribution Assets of Peterborough Distribution Inc.

In June 2021, Hydro One completed the integration of the business and distribution assets of Peterborough Distribution, including the integration of employees, customer and billing information, business processes and operations. The business and distribution assets of PDI were acquired in August 2020. See “General Development of the Business – Chronological Development of the Business – 2020 – Acquisition of the Business and Distribution Assets of Peterborough Distribution Inc.” for more information.

Acronym Solutions Inc.

In October 2021, Hydro One Telecom was renamed as Acronym Solutions Inc.

2022

Sustainability-Linked Loan Amendments to Hydro One Credit Facilities

In January 2022, Hydro One Limited and Hydro One Inc. successfully amended their syndicated credit facilities to incorporate ESG targets. The facilities now include a pricing adjustment which can increase or decrease Hydro One’s cost of funding based on its performance on certain sustainability performance measures, which are related to Hydro One’s sustainability goals.

Directors and Executive Officers

Effective June 8, 2022, Jessica McDonald resigned as a director of Hydro One Limited and Hydro One Inc. Effective June 8, 2022, Mark Podlasly was elected as a director of Hydro One Limited and Hydro One Inc.

Effective June 21, 2022, Mark Poweska resigned as President and Chief Executive Officer and a director of Hydro One Limited and Hydro One Inc.

Effective June 21, 2022, William Sheffield was appointed as Interim President and Chief Executive Officer of Hydro One Limited and Hydro One Inc.

Effective September 16, 2022, Jason Fitzsimmons resigned as Chief Corporate Affairs and Customer Care Officer of Hydro One Networks.

2022 MTN Shelf Prospectus and Related Offerings

On June 3, 2022, Hydro One Inc. filed a short form base shelf prospectus in each of the provinces of Canada qualifying for issuance of up to $4 billion of medium term notes of Hydro One Inc. from time to time during the 25-month period ending July 6, 2024 (the “2022 MTN Shelf Prospectus”). The 2022 MTN Shelf Prospectus replaced the short form base shelf prospectus of Hydro One Inc. that expired on May 14, 2022. To date, Hydro One Inc. has issued the following medium term notes pursuant to the 2022 MTN Shelf Prospectus on the dates indicated:


MTN Series	Aggregate Principal Amount	Issuance Date

Series 52 Notes due 2028	$750 million	October 27, 2022
Series 53 Notes due 2029	$300 million	January 27, 2023
Series 54 Notes due 2033	$450 million	January 27, 2023
Series 55 Notes due 2053	$300 million	January 27, 2023

Equity Partnership Model with First Nation Communities

In September 2022, Hydro One announced its new equity partnership model pursuant to which it will offer First Nations a 50% equity stake in all new, future large-scale capital transmission line projects with a value exceeding $100 million.

General Development of the Business

In addition to the chronological development of the business, the following general developments in the business have occurred and continue to be relevant.

Customer Focus

Hydro One’s continued focus on customer service remains a critical aspect of its success as a company. Greater corporate accountability for performance outcomes, and company-wide improvements in productivity and efficiency, align with customers’ expectations of how Hydro One should operate. Hydro One intends to continue to offer affordable and reliable electricity, advocate for its customers and empower them to make informed decisions about their energy usage and respond to emerging customer needs.

Customer Service

Hydro One is committed to delivering value to its customers by understanding customers’ current and future needs and expectations so that the Company can continuously improve its service. This includes specific, measurable commitments that encompass all areas of service. In 2022, residential and small business customer satisfaction scores saw a slight decrease from 2021 from 89% to 87%, transmission customer satisfaction also decreased slightly from 2021 from 92% to 88%, and commercial and industrial satisfaction decreased from 2021 from 80% to 74%.

Hydro One is on a multi-year journey to transform the customer experience by continuing to invest in technology such as interaction analytics, home energy insights, and automated performance scorecards for contact service representatives.

As part of the Company’s continued commitment to customers, Hydro One again extended a number of the customer relief measures implemented at the onset of the COVID-19 pandemic. See “General Development of the Business – Chronological Development of the Business – COVID-19 Pandemic and Related Developments”.

Review of Operations

Hydro One is committed to providing value to its customers and shareholders by identifying and acting on opportunities to become the safest and most efficient utility. Hydro One has been focused on the identification of opportunities for improved corporate performance and the development of strategies to drive safer, more efficient and cost-effective operations. Hydro One conducts regular reviews of key corporate activities and programs, covering areas such as construction services and project management practices, asset deployment and controls, asset planning, information technology and cybersecurity, vegetation management practices, fleet services and utilization, supply chain management and business continuity planning. The Company has and continues to observe and implement operational and cost improvements across work planning and execution.

Strategy

In November 2019, Hydro One released its updated corporate strategy which reaffirms the Company’s commitment to Ontario and the provision of safe, reliable and affordable electricity. The strategy focuses on five key aspirational priorities:

•Plan, Design And Build A Grid For The Future

We will plan, design and build a reliable grid taking into account changing technologies to prevent future outages. There will be increased focus on grid resilience in order to restore power after events. Climate change and sustainability factors will be taken into consideration in our planning processes to increase resilience and lower our environmental footprint. We will incorporate distributed energy resources to enable customer choice while delivering exceptional value to customers through best-in-class asset management practices.

•Be The Safest And Most Efficient Utility

We will transform and improve our safety culture through robust safety analytics as well as grass-roots engagement with our employees. Field operations will be more empowered to drive efficiency, productivity and reliability and provided with efficient corporate support. There will be a focus on efficient capital delivery to support an ongoing growing work program.

•Be A Trusted Partner

We will make concerted efforts to build and grow relationships with Indigenous peoples, government and industry partners. We will proactively address community concerns and establish

strong partnerships with our customers through local investment and economic development for the benefit of Ontarians.

•Advocate For Our Customers And Help Them Make Informed Decisions

We will make it easier to do business with Hydro One by strengthening the customer experience through innovative customer-centric practices. We will help our customers make informed decisions with deeper insights and leverage our position as energy experts. We will expand access to energy offerings to become the provider of choice to our customers.

•Innovate And Grow The Business

We will continue to invest responsibly in our core transmission and distribution business. In addition, we will pursue incremental regulated and unregulated business opportunities through innovation and our focused presence in Ontario.

Sustainability Report

In August 2022, Hydro One Limited published its 2021 Sustainability Report, highlighting its progress in 2021 and its plans for future years. The 2021 Sustainability Report provides an account of the Company’s ESG performance. The Sustainability Report provides stakeholders, partners, customers, and communities with a better understanding of how Hydro One manages the opportunities and challenges associated with our business. Hydro One is committed to releasing an annual sustainability report and to continuously increasing the transparency of ESG disclosures. The Company’s annual sustainability reporting is aligned with the Sustainability Accounting Standards Board and the Global Reporting Initiative Standards, and prepared broadly following the recommendations of the Task Force on Climate-related Financial Disclosures. The 2021 Sustainability Report is also aligned with the United Nations Sustainable Development Goals.

BUSINESS OF HYDRO ONE

Segments

Hydro One is Ontario’s largest electricity transmission and distribution utility with approximately $31 billion in assets and 2022 revenues of approximately $7.7 billion. Hydro One owns and operates substantially all of Ontario’s electricity transmission network and is the largest electricity distributor in Ontario by number of customers. Hydro One delivers electricity safely and reliably to approximately 1.5 million customers across the province of Ontario, and to large industrial customers and municipal utilities. Through its subsidiaries, Hydro One Inc. owns and operates approximately 30,000 circuit kilometres of high-voltage transmission lines and approximately 125,000 circuit kilometres of primary low-voltage distribution lines.

Hydro One has three segments: (i) transmission business; (ii) distribution business; and (iii) other. Each of the three segments is described below.

Hydro One’s transmission and distribution businesses are both operated primarily by Hydro One Networks. This allows both businesses to utilize common operating platforms, technology, work

processes, equipment and field staff and thereby take advantage of operating efficiencies and synergies. For regulatory purposes, Hydro One Networks has historically filed separate rate applications with the OEB for each of its licensed transmission and distribution businesses. In 2021, a single application was filed for the Hydro One Networks transmission and distribution businesses for the period 2023 to 2027, which was approved by the OEB in November 2022. See “Transmission Business Segment – Regulation – Transmission Rate Setting” for more information.

Transmission Business Segment

Overview

Hydro One’s transmission business consists of owning, operating and maintaining Hydro One’s transmission system, which accounts for approximately 92% of Ontario’s transmission capacity based on revenue approved by the OEB. All of the Company’s transmission business is carried out through its wholly-owned subsidiaries, Hydro One Networks and HOSSM (formerly Great Lakes Power), as well as through the Company’s approximately 66% interest in B2M Limited Partnership and approximately 55% interest in NRLP. Hydro One’s transmission business represented approximately 60% of its total assets as at December 31, 2022, and accounted for approximately 52% of its total revenues, net of purchased power1 in 2022 and approximately 27% of its total revenues in 2022, and approximately 51% of its total revenues, net of purchased power in 2021 and approximately 25% of its total revenues in 2021.

The Company’s transmission business is a rate-regulated business that earns revenues mainly from transmission rates that are subject to approval by the OEB. Transmission rates are generally determined using a performance-based model, which typically includes a cost-of-service base year. Transmission rates are administered and collected by the IESO and are remitted by the IESO to Hydro One on a monthly basis, which means that Hydro One’s transmission business has no direct exposure to end-customer counterparty risk.

Transmission rates are based on monthly peak electricity demand across Ontario’s transmission network. This gives rise to seasonal variations in Hydro One’s transmission revenues, which are generally higher in the summer and winter due to increased demand, and lower during other periods of reduced demand. Hydro One’s transmission revenues also include revenues associated with exporting energy to markets outside of Ontario. Ancillary revenue includes revenues from providing maintenance services to generators and from third-party land use.

Business

The Company’s transmission system serves substantially all of Ontario and transported approximately 138 TWh of energy throughout the province in 2022. Hydro One’s transmission customers consist of 35 local distribution companies (including Hydro One’s own distribution business) and 85 large industrial

1 Revenues, net of purchased power is a non-GAAP financial measure. Non-GAAP financial measures do not have a standardized meaning under U.S. GAAP, which is used to prepare the Company’s financial statements, and accordingly, these measures may not be comparable to similar measures used by other companies. Additional disclosure for this non-GAAP financial measure is incorporated by reference herein and can be found in the section titled “Non-GAAP Measures” of the Annual MD&A available on SEDAR under Hydro One Inc.’s profile at www.sedar.com.

customers connected directly to the transmission network, including automotive, manufacturing, chemical and natural resources businesses. Electricity delivered over the Company’s transmission network is supplied by 135 generators in Ontario and electricity imported into the province through interties. Interties are transmission interconnections between neighbouring electric systems that allow power to be imported and exported.

The high voltage power lines in Hydro One’s transmission network are categorized as either lines which form part of the “bulk electricity system” or “area supply lines”. Power lines which form part of the bulk electricity system typically connect major generation facilities with transmission stations and often cover long distances, while area supply lines serve a local region. Ontario’s transmission system is connected to the transmission systems of Manitoba, Michigan, Minnesota, New York and Quebec through the use of interties, allowing for the import and export of electricity to and from Ontario.

Hydro One’s transmission assets were approximately $19 billion as at December 31, 2022 and include transmission stations, transmission lines, a control centre and telecommunications facilities. Hydro One has approximately 309 in-service transmission stations and approximately 30,000 circuit kilometres of high voltage lines whose major components include cables, conductors and wood or steel support structures. All of these lines are overhead power lines except for approximately 270 circuit kilometres of underground cables located in primarily urban areas.

Hydro One’s transmission network is managed from a central location. This centre monitors and controls the Company’s entire transmission network and has the capability to remotely monitor and operate transmission equipment, respond to alarms and contingencies and restore and reroute interrupted power. There is also a backup facility which would be staffed in the event of an evacuation of the centre. In 2022, Hydro One’s new primary control centre became fully operational.

Hydro One uses telecommunications systems for the protection and operation of its transmission and distribution networks. These systems are subject to very stringent reliability and security requirements, which help the Company meet its reliability obligations and facilitate the restoration of power following service interruptions.

B2M Limited Partnership is Hydro One’s partnership with the Saugeen Ojibway Nation with respect to the Bruce-to-Milton transmission line. B2M Limited Partnership owns the transmission line assets relating to two circuits between Bruce TS and Milton Switching Station. Hydro One Networks owns the stations where the lines terminate. Hydro One maintains and operates the Bruce-to-Milton line and has an approximately 66% economic interest in the partnership.

NRLP is Hydro One’s partnership with Six Nations of the Grand River Development Corporation and, through a trust, the Mississaugas of the Credit First Nation. NRLP owns the Niagara Line. Hydro One maintains and operates the Niagara Line, and has an approximately 55% interest in the partnership. See “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – Niagara Reinforcement Limited Partnership” for more information.

In 2018, Hydro One completed the operational integration of HOSSM (formerly Great Lakes Power), which was acquired in October 2016.

Regulation

Transmission Rate Setting

The OEB provides two revenue plan options for transmission rates in Ontario: the Custom Incentive Rate Setting Plan (the “Custom IR Method”) and the Incentive-Based Revenue Index Rate Setting Plan (the “Revenue Cap Index”).

Under the Revenue Cap Index, the first year’s revenue requirement reflects the transmitter’s cost of service; and annually thereafter, this amount is subject to a formulaic increase reflecting inflation, partially offset by a productivity factor. The revenue requirement in these subsequent years is set on the assumption that the transmitter will achieve efficiency or productivity improvements to offset the productivity factor imposed by the regulator. Under the Custom IR Method, a similar methodology to the Revenue Cap Index may be used; however, applications are multi-year and are designed to reflect a transmitter-specific revenue trend for the application term. For example, a transmitter may request incremental capital funding beyond amounts established in the base year revenue requirement.

The OEB sets transmission rates based on a two-step process. First, all transmitters apply to the OEB for approval of their revenue requirements. Second, the OEB aggregates the total revenue requirements of all transmitters in Ontario and applies a formula to arrive at a single set of rates that are charged to ratepayers for the three types of transmission services applicable in Ontario, namely: network services, line connection services and transformation connection services. The three separate rates charged for these services are the same for all transmitters and are referred to as “uniform transmission rates”. Uniform transmission rates for all transmitters are set by the OEB on an annual basis, using the revenue requirements set out in the most recent rate decision issued for each transmitter.

The filing requirements for transmitters mandate the integration of core RRF (defined below under “Business of Hydro One – Distribution Business Segment – Regulation – Distribution Rates”) concepts into revenue requirement applications. Transmitters applying for revenue requirements under the Custom IR Method or Revenue Cap Index must include: (i) evidence of the continuous improvement and efficiency gains anticipated to be achieved over the rate term; (ii) a mechanism to protect ratepayers in the event of earnings significantly in excess of the regulatory net income supported by the return on equity established in the approved revenue requirement; and (iii) proposed performance metrics applicable to their individual circumstances. A key component of rate-setting under the RRF is benchmarking evidence to support cost forecasts and system planning proposals.

Recent Transmission Rate Applications

Hydro One Networks, B2M Limited Partnership, HOSSM and NRLP file separate applications to the OEB for the approval of their transmission revenue requirement for transmission services.

Hydro One Networks

In September 2017, the OEB issued its decision on Hydro One Networks’ application for Hydro One

Networks’ 2017-2018 transmission revenue requirement. In the decision, the OEB concluded that the net deferred tax asset resulting from the transition from the payments in lieu of tax regime under the Electricity Act to the federal and provincial tax regimes in connection with Hydro One Limited’s 2015 initial public offering should not accrue entirely to Hydro One Limited’s shareholders, but rather a portion should be shared with Hydro One Networks’ ratepayers. The OEB proposed a basis for sharing a portion of the tax savings resulting from the deferred tax asset with Hydro One Networks’ ratepayers by reducing the amount of taxes approved for recovery in Hydro One Networks’ 2017-2018 transmission revenue requirement. In November 2017, the OEB issued a decision and order that established the portion of the tax savings that should be shared with Hydro One Networks’ ratepayers.

In October 2017, Hydro One Networks filed with the OEB a motion to review and vary the OEB’s decision, and filed an appeal with the Ontario Divisional Court. The motion, among other things, sought allocation to Hydro One Limited’s shareholders of the full amount of the future tax savings arising from the deferred tax asset. In both the motion and the appeal, Hydro One Networks’ position was that the OEB made errors of fact and law in its determination of the allocation of the tax savings between Hydro One Limited’s shareholders and Hydro One Networks’ ratepayers. An OEB hearing of the merits of the motion was held in February 2018. In August 2018, the OEB granted the motion and returned the portion of the decision relating to the deferred tax asset to an OEB panel for reconsideration. In March 2019, the OEB upheld its original decision on the allocation of the deferred tax asset between Hydro One Limited’s shareholders and Hydro One Networks’ ratepayers. As a result, the Company recorded impairment charges relating to Hydro One Networks’ distribution and transmission deferred income tax regulatory asset.

In April 2019, Hydro One Networks filed an appeal with the Ontario Divisional Court with respect to the OEB’s deferred tax asset decision. The appeal was heard in November 2019, and in July 2020, the Ontario Divisional Court rendered its decision. The Ontario Divisional Court set aside the OEB decision, holding that the OEB decision was incorrect in law because the OEB had failed to apply the correct legal test. The Ontario Divisional Court held that the deferred tax asset should be allocated to shareholders in its entirety. However, the Ontario Divisional Court concluded that it did not have jurisdiction to substitute its own decision for that of the OEB and, with clear directions as to what the OEB’s decision must be, ordered that the matter be returned to the OEB. The OEB did not appeal the Ontario Divisional Court’s decision. As a result, the Company has recorded a reversal of the previously recognized impairment charge of Hydro One Networks’ distribution and transmission deferred income tax regulatory asset.

In September 2020, the Ontario Divisional Court issued its final order with respect to its decision. In October 2020, the OEB issued a procedural order to implement the direction of the Ontario Divisional Court and required Hydro One to submit its proposal for the recovery of the deferred tax asset amounts allocated to Hydro One Networks’ ratepayers for the 2017 to 2022 period.

In April 2021, the OEB issued its decision on the implementation of the recovery of the deferred tax asset amounts allocated to Hydro One Networks’ ratepayers for the 2017 to 2022 period. The OEB approved recovery of the deferred tax asset amounts that had been allocated to Hydro One Networks’ ratepayers and included in customer rates for the 2017 to 2021 period plus carrying charges over a two-year recovery period commencing on July 1, 2021. In addition, Hydro One Networks was required to adjust its transmission revenue requirement and its base distribution rates beginning January 1, 2022 to eliminate

any further tax savings flowing to its customers.

In March 2019, Hydro One Networks filed a three-year custom incentive rate application with the OEB for its 2020-2022 transmission revenue requirements. The application requested the OEB’s approval of revenue requirements of $1,623 million for 2020. In June 2019, Hydro One Networks filed updates to the application reflecting recent financial results and other adjustments.

In April 2020, the OEB issued its decision on Hydro One Networks’ 2020-2022 transmission rate application. In July 2020, the OEB issued its final rate order for the 2020-2022 transmission rates approving a revenue requirement of $1,630 million, $1,701 million and $1,772 million for 2020, 2021 and 2022, respectively.

In July 2020, the OEB issued its decision for the uniform transmission rates. The 2020 uniform transmission rates that were put in place on an interim basis on January 1, 2020 continued for the remainder of 2020 in light of the COVID-19 pandemic.

In December 2020, the OEB issued its decision and order setting the final 2021 uniform transmission rates effective January 1, 2021, which included the approval of a two-year disposition period for Hydro One Networks’ 2020 forgone revenue including interest, beginning on January 1, 2021.

In March 2018, the OEB requested that Hydro One Networks file a single application for distribution and transmission revenue requirements for the period from 2023 to 2027. In August 2021, Hydro One Networks filed a custom joint rate application for 2023-2027 (the “JRAP”) which included a proposed investment plan supporting the transmission and distribution revenue requirements. The JRAP requested the OEB’s approval of transmission revenue requirements of $1,823 million for 2023, $1,938 million for 2024, $2,028 million for 2025, $2,140 million for 2026 and $2,219 million for 2027.

In March 2022, Hydro One Networks filed updated evidence as part of the JRAP reflecting the impacts of updated inflation assumptions on the proposed investment plan as well as updated load forecasts. In October 2022, Hydro One Networks filed a settlement proposal with the OEB, which was further updated in November 2022 to reflect, among other things, the OEB’s cost of capital parameters and inflation factor for 2023. In November 2022, the OEB approved the settlement in whole and issued its final rate order for the 2023-2027 transmission rates approving a revenue requirement of $1,952 million, $2,073 million, $2,168 million, $2,277 million, and $2,362 million for 2023, 2024, 2025, 2026, and 2027, respectively. Notwithstanding that the parties to settlement agreed to reduce Hydro One Networks’ proposed capital and operating expenditures, the approved revenue requirement exceeds Hydro One Networks’ proposed revenue requirement due to increases to the OEB’s cost of capital parameters and inflation factor for 2023. See also “Business of Hydro One – Distribution Business Segment – Regulation – Recent Distribution Rate Applications – Hydro One Networks”.

B2M Limited Partnership

In July 2019, B2M Limited Partnership filed a transmission rate application for 2020-2024, seeking a base revenue requirement of $36 million for 2020 (subsequently updated to $33 million for lower ROE and interest rates), and a 1.4% revenue cap escalator index for 2021 to 2024. On December 9, 2019, B2M

Limited Partnership reached a settlement on all issues with OEB staff and intervenors on the five-year revenue cap rate application for 2020-2024 to be effective January 1, 2020. The settlement accepts all of B2M Limited Partnership’s cost submissions but includes additional reliability reporting and a capital adjustment (reduction) factor of 0.6% to account for the decreasing rate base value. In January 2020, the OEB approved the settlement agreement, including a 2020 base revenue requirement of $33 million, and a revenue cap escalator index for 2021 to 2024. In December 2021, the OEB approved a rate increase of 1.9% effective January 1, 2022. In November 2022, the OEB approved a rate increase of 3.2% effective January 1, 2023.

HOSSM

HOSSM is under a ten-year deferred rebasing period for years 2017-2026, following receipt of approval by the OEB of Hydro One’s acquisition of HOSSM in October 2016. In July 2018, HOSSM filed a 2019 application to allow for inflationary increase (“revenue cap escalator factor”) to its previously approved revenue requirement. The revenue cap escalator factor is designed to add inflationary increases to the revenue requirement on an annual basis. In June 2019, the OEB approved the revenue cap escalator index at 1.1% (net), which was applied to HOSSM’s base revenue requirement for 2019, effective February 1, 2019, and also approved the 2019-2026 revenue cap framework. In December 2019, the OEB issued a decision on HOSSM’s request for transmission revenue requirement for 2020. The OEB approved the revenue cap adjustment requesting an increase to the 2020 revenue requirement of 1.5% (inflation factor of 1.8% less stretch factor of 0.3%). In December 2021, the OEB approved a rate increase of 2.2% effective January 1, 2022. In November 2022, the OEB approved a rate increase of 3.5% effective January 1, 2023.

Niagara Reinforcement Limited Partnership

In 2018, the NRLP was formed for the purpose of owning a new 230 kV transmission line in the Niagara region (the “Niagara Line”) to enable generators in the Niagara area to connect to load centres of the Greater Toronto and Hamilton areas.

In October 2019, NRLP filed its revenue cap incentive rate application for 2020-2024. In December 2019, the OEB approved NRLP’s proposed 2020 revenue requirement of $9 million on an interim basis effective January 1, 2020. In February 2020, NRLP reached a settlement on all issues, accepting the 2020 base costs and the 2019 incurred costs as presented. The settlement included a 50% reduction to the inflation component and a 0.6% capital adjustment factor to account for a decreasing rate base value. In April 2020, the OEB approved the settlement agreement. In December 2021, the OEB approved a rate increase of 0.65% effective January 1, 2022. In November 2022, the OEB approved a rate increase of 1.3% effective January 1, 2023.

Reliability Standards and Regulations for Transmission

The Company’s transmission business is required to comply with various mandatory regulations for transmission reliability, including mandatory standards, directories, market rules, and the Transmission System Code (collectively, the “Reliability Standards”) established by NERC, NPCC, the OEB and the IESO, which are international, regional and Ontario reliability regulatory authorities, respectively,

involved in regulating, promoting and otherwise improving the reliability of transmission networks in North America. Hydro One’s compliance with these Reliability Standards is enforced by the OEB, IESO and the Canadian Energy Regulator.

In addition to the currently enforced Reliability Standards, NERC, NPCC, the OEB and IESO continue to develop and issue new and revised Reliability Standards and other regulations, including Critical Infrastructure Protection Standards and Cybersecurity Regulations with which Hydro One and other utilities, owners and operators of the bulk electricity system in North America must comply. Hydro One expects to continue to perform work, and to incur associated costs, in order to achieve, sustain and demonstrate compliance with all of these Reliability Standards. Hydro One anticipates that these costs will be recovered in rates. See the Annual MD&A under the subheadings “Risk Management and Risk Factors – Risks Relating to Hydro One’s Business – Compliance with Laws and Regulations”, “Risk Management and Risk Factors – Risks Relating to Hydro One’s Business – Risk Associated with Information Technology (IT), Operational Technology (OT) Infrastructure and Data Security” and “Risk Management and Risk Factors – Risks Relating to Hydro One’s Business – Risks Relating to Asset Condition, Capital Projects and Innovation” for more information.

Regional Planning

The OEB oversees regional planning processes to ensure that transmission and distribution investments are coordinated at a regional level. One of the OEB objectives for regional planning is to review and/or rely on the recommendations within the regional planning reports to support rate applications submitted by transmitters and distributors and “leave to construct” applications submitted by transmitters. In Ontario, the first and last phases (Needs Assessment and Regional Infrastructural Plan) of the regional planning process are led by the transmitter responsible for a particular geographic region. Hydro One also coordinates with the IESO on its Integrated Regional Resource Planning, which is another phase of the regional planning process. For this purpose, the province is divided into 21 regions. As the largest transmitter in Ontario, Hydro One plays a key role in the regional planning process and is responsible for leading the regional planning process in 20 of the 21 designated regions.

In conducting regional planning, Hydro One works closely with the IESO and all distributors in the region through study teams to jointly identify needs and develop transmission and distribution investment options.

In December 2020, the OEB announced that it was initiating a consultation to undertake a review of the regional planning process that applies to Ontario’s electricity sector, to improve the efficiency and effectiveness of the current regional planning process. As a result, the OEB re-established its Regional Planning Process Advisory Group (“RPPAG”), comprised of a number of interested stakeholders, including Hydro One, to assist in its review. In December 2021, the RPPAG provided its report to the OEB with recommendations intended to improve the regional planning process in Ontario. In April 2022, the OEB issued a letter endorsing the recommendations and provided an implementation plan. The RPPAG has made several changes to the regional planning process, some of which have been implemented and others of which are expected to be formally implemented in early 2023.

Capital Expenditures

The Company anticipates that it will spend in the range of approximately $1,446 million to $1,565 million per year, over the next five years, on capital expenditures relating to its transmission business. The Company’s capital expenditure plans are included in Hydro One’s applications to the OEB for transmission and distribution rates and are subject to approval by the OEB. See the Annual MD&A under the subheadings “Capital Investments – Future Capital Investments” and “Capital Investments – Major Transmission Capital Investment Projects” for more information on future capital expenditures.

The Company incurs both sustaining capital expenditures and development capital expenditures. Sustaining capital expenditures are those investments required to replace or refurbish our assets and facilities to ensure that the transmission system continues to function as originally designed. Hydro One’s plans to maintain, refurbish or replace existing assets are based upon risk assessments, asset condition assessments and end-of-service life criteria specific to each type of asset. Priorities are assigned to each type of investment based upon the extent of the risks that it mitigates.

Investments to sustain Hydro One’s transmission assets are critical to maintain the safety, reliability and integrity of its existing transmission network. Hydro One’s sustainment capital plan is designed to maintain Hydro One’s transmission reliability performance, as determined by measures such as the average frequency and duration (in minutes) of unplanned interruptions per delivery point. The Company expects that significant investments will be required to sustain its existing infrastructure over the long term.

The Company’s development capital expenditure plan is designed to address Ontario’s expected change in the generation profile, accommodate load growth in areas throughout Ontario and support the economic growth in Ontario including industrial and agricultural growth and connection of the remote communities in the northern part of the province. Development capital expenditures include those investments required to develop and build new large-scale projects such as new transmission lines and stations as well as smaller projects such as transmission line or station reinforcements, extensions or additions to connect generation or serve load.

The Company engages with various stakeholders, including its customers and the IESO, as it develops its capital plans. It also engages affected communities and parties who may be impacted by individual projects. The Company also consults with Indigenous communities whose rights may be affected by its projects.

Competitive Conditions

Within our principal market of Ontario, the Company operates and maintains substantially all of the transmission system. Competition for transmission services in Ontario is currently limited. The adoption by the OEB of uniform transmission rates that apply to all transmitters also reduces the financial incentive for customers to seek alternative transmission providers, since each transmitter in Ontario charges the same uniform rate for transmission services. Hydro One competes with other transmitters for the opportunity to build new large-scale transmission facilities in Ontario. The competitive process was amended in 2016 by the proclamation of the Energy Statute Law Amendment Act to allow for the

selection of a transmitter outside the existing competitive process. The 2017 Long-Term Energy Plan directed the IESO to develop a transmission procurement process that is clear, cost-effective, efficient and able to respond to changing policy, market and system needs. In October 2020, the IESO, Infrastructure Ontario and the Canada Infrastructure Bank issued a written market sounding to obtain views and insights of various parties regarding potential IESO-led competitive transmission procurement transaction structures, including the role of government, project development activities, allocation of risks and potential financing arrangements. In early 2021, the IESO initiated an engagement to formalize the bulk system planning process. The IESO has noted that the output of the process will inform competitive mechanisms to meet Ontario’s resource adequacy needs. The IESO has not provided any further direction.

Hydro One does not compete with other transmitters with respect to investments which are made to sustain or develop its existing transmission infrastructure.

Distribution Business Segment

Overview

Hydro One’s distribution business consists of owning, operating and maintaining Hydro One’s distribution system, which Hydro One Inc. owns primarily through its wholly-owned subsidiary, Hydro One Networks, the largest local distribution company in Ontario. The Company’s distribution system is also the largest in Ontario. The Company’s distribution business is a rate-regulated business that earns revenues mainly by charging distribution rates that are subject to approval by the OEB. Hydro One’s distribution business also includes the business of its wholly-owned subsidiary, Hydro One Remote Communities, which supplies electricity to customers in remote communities in northern Ontario. The Company’s distribution rates are generally determined using a performance-based model, except for the distribution rates of Hydro One Remote Communities, which are set on a cost-recovery basis and do not include a return on equity.

Hydro One’s distribution business represented approximately 38% of its total assets as at December 31, 2022, and accounted for approximately 48% of its total revenues in 2022, net of purchased power,2 and approximately 73% of its total revenues in 2022 and approximately 49% of its total revenues in 2021, net of purchased power and approximately 75% of its total revenues in 2021. Distribution revenues include distribution rates approved by the OEB and amounts to reimburse Hydro One for the cost of purchasing electricity delivered to its distribution customers. Distribution revenues also include minor ancillary service revenues, such as fees related to the joint use of the Company’s distribution poles by participants in the telecommunications and cable television industries, as well as miscellaneous charges such as charges for late payments.

As at December 31, 2022, Hydro One’s distribution assets were approximately $12 billion.

Business

Hydro One delivers electricity through its distribution network to approximately 1.5 million residential and business customers, most of whom are located in rural areas, as well as 44 local distribution

2 Revenues, net of purchased power is a non-GAAP financial measure.

companies (including Hydro One’s own distribution business).

Hydro One’s distribution system includes approximately 125,000 circuit kilometres of primary low-voltage distribution lines and approximately 1,000 distribution and regulating stations. Other distribution assets include poles, transformers, service centres and equipment.

Hydro One’s distribution system services a predominantly rural territory. As a result of the lower population density in the Company’s service territory, the Company’s costs to provide distribution services may be higher than those of distributors who service urban areas. Furthermore, unlike the distribution systems found in urban areas, most of Hydro One’s distribution system was not designed with redundancy, to be interconnected in loops with other distribution lines, with the result that interruptions experienced at any point along a distribution line in Hydro One’s network can cause all customers downstream of the interruption point to lose power. Accordingly, the reliability of Hydro One’s distribution system is lower than that of local distribution companies which service urban territories that typically have redundancy built into their systems.

The Company engages in vegetation management activities to maintain the reliability of Hydro One’s distribution system on a preventive basis and to protect public health and safety. This consists of the trimming or removal of trees to lower the risk of contact with distribution lines, thereby reducing the risk of power outages, and preventing potential injury to the public or employees. The Company’s monitoring systems assist with determining areas of priority and with system restoration. The Company relies on its local line crews for these restoration activities.

Hydro One’s distribution business is involved in the connection of new sources of electricity generation, including renewable energy. Hydro One invests in upgrades and modifications to its distribution system to accommodate these new sources of generation and ensure the continued reliability of its distribution network. As at December 31, 2022, there were approximately 18,000 small, mid-size and large embedded generators connected to Hydro One’s distribution network, including approximately 16,500 generators with capacities of up to 10 kW. As at December 31, 2022, Hydro One also had approximately 137 generators pending connection.

Hydro One has played a significant role in the installation of smart meters and the migration of distribution customers to time-of-use pricing in Ontario. Smart meters are regarded as an integral means of promoting a culture of conservation and allow customers to change their electricity consumption patterns and reduce their costs. Hydro One has completed all material activities associated with the implementation of smart meters and has transitioned the vast majority of its customers to Time-of-Use pricing. As part of the JRAP, in November 2022, the OEB approved in whole Hydro One Networks’ proposed capital program to modernize the entire smart metering infrastructure as system and assets reach their end of service over the next several years. The new systems will further enable customer interaction and grid operation capabilities. See “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications” and “Business of Hydro One – Distribution Business Segment – Regulation – Recent Distribution Rate Applications – Hydro One Networks” for more information on Hydro One Networks’ application.

Regulation

Distribution Rates

Distribution rates in Ontario are determined using a performance-based model set out in the OEB’s Renewed Regulatory Framework for Electricity Distributors: A Performance-Based Approach, which is sometimes referred to as the “RRF”. Under the RRF, distributors in Ontario may choose one of three rate-setting methods, depending on their capital requirements: 4th Generation Incentive Rate-Setting (now known as “Price Cap IR”), Custom IR Method, or Annual Incentive Rate-Setting Index.

The RRF contemplates that under the Price Cap IR method, a distributor will apply for the approval of its revenue requirement for an initial base year, reflecting the distributor’s cost of service. The revenue requirement for subsequent years is determined based on a formula that accounts for inflation and certain productivity factors set by the regulator. The revenue requirement in these subsequent years is set on the assumption that the distributor will achieve efficiency or productivity improvements to offset the productivity factor imposed by the regulator.

Under the Custom IR Method, a similar methodology to the Price Cap IR may be used; however, applications are multi-year and are designed to reflect a distributor-specific revenue trend for the application term. For example, a distributor may request incremental capital funding beyond amounts established in the base year revenue requirement.

The scope of applications under the Annual Incentive Rate-Setting Index option is limited to formulaic adjustments to prior year OEB-approved rates. The adjustment provides an increase based on inflation, partially offset by a productivity factor. Distributors under this plan do not have access to mechanisms for additional capital funding beyond the formulaic adjustment.

The RRF allows the distributor to retain all or a portion of the cost savings achieved in excess of the estimate established by the regulator during the period covered by the rate decision, subject to any sharing mechanisms that may be required by the OEB, as indicated in the decision of each rate application. This approach allows the distributor an ability to earn more than its allowed return on equity. The RRF also requires distributors to demonstrate certain performance outcomes, namely: customer focus, operational effectiveness, public policy responsiveness and financial performance. The OEB has stated that customer-focused outcomes and continuous performance improvements by distributors are central to the RRF framework objectives and are considered as part of a distributor rate application.

Performance measures are an important part of the RRF, and the OEB has established a standard performance scorecard for all distributors, which is reported annually. Distributors may also propose additional performance measures for approval by the OEB. Distributors are required to report to the OEB on their performance against the performance measures approved.

The OEB’s review process of the anticipated cost of service for providing distribution services under the RRF follows a process similar to that of a transmission rate application. Once the revenue requirement for distribution services is determined, it is allocated across the distributor’s customer rate classes using a methodology approved by the OEB resulting in the setting of individual rates for distribution services

based on each customer rate class. Distribution rates in Ontario are not the same for all distributors and reflect the particular circumstances of each distributor, including its own costs of providing electricity service to its own particular customers. The OEB policy, A New Distribution Rate Design for Residential Electricity Customers, changes the current distribution rate design for residential customers (a combination of a fixed monthly rate and a variable charge) to a fixed monthly charge only. In December 2015, the OEB increased the transition period for certain customer classes of Hydro One Networks to mitigate bill impacts. Implementation will be completed by 2024 for the majority of Hydro One Networks’ residential customers, depending on rate class. Changes to rate design will not impact the total revenue to be collected from these customer classes.

Recent Distribution Rate Applications

The Company’s distribution rates, other than the distribution rates of Hydro One Remote Communities, are determined by using a performance-based model.

Hydro One Networks

In March 2017, Hydro One Networks filed a custom application with the OEB for its 2018-2022 distribution rates. The application reflects the level of capital investments required to minimize degradation in overall system asset condition, to meet regulatory requirements, and to maintain current reliability levels. In accordance with the OEB decision rendered in March 2019, Hydro One Networks filed its draft rate order reflecting updated revenue requirements of $1,459 million for 2018, $1,498 million for 2019, $1,532 million for 2020, $1,578 million for 2021, and $1,624 million for 2022. In June 2019, the OEB approved the rate order confirming these updated revenue requirements which include impacts of both the 2018-2022 distribution rate decision and the OEB’s deferred tax asset decision.

In March 2018, the OEB issued a letter stating that the OEB expected Hydro One Networks to file a joint distribution-transmission rate application for the period from 2023 to 2027. In August 2021, Hydro One Networks filed a custom joint rate application for 2023-2027 (the “JRAP”) which included a proposed investment plan supporting the transmission and distribution revenue requirements. The JRAP requested the OEB’s approval of distribution revenue requirements of $1,632 million for 2023, $1,711 million for 2024, $1,785 million for 2025, $1,881 million for 2026 and $1,965 million for 2027. In March 2022, Hydro One Networks filed updated evidence reflecting the impacts of updated inflation assumptions on the proposed investment plan as well as updated load forecasts. In October 2022, Hydro One Networks filed a settlement proposal with the OEB, which was further updated in November 2022 to reflect, among other things, the OEB’s cost of capital parameters and inflation factor for 2023. In November 2022, the OEB approved the settlement in whole and issued its final rate order for the 2023-2027 distribution rates approving a revenue requirement of $1,727 million, $1,813 million, $1,886 million, $1,985 million, and $2,071 million for 2023, 2024, 2025, 2026, and 2027, respectively. Notwithstanding that the parties to settlement agreed to reduce Hydro One Networks’ proposed capital and operating expenditures, the approved revenue requirement exceeds Hydro One Networks’ proposed revenue requirement due to increases to the OEB’s cost of capital parameters and inflation factor for 2023. See “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – Hydro One Networks” for more information.

Hydro One Remote Communities

In November 2021, Hydro One Remote Communities filed an application with the OEB seeking approval for a 2.2% increase to 2021 base rates, effective May 1, 2022. The application was subsequently updated to request a 3.3% increase to 2021 base rates to reflect the OEB’s annually updated inflation parameters for electricity distributors for 2022. In March 2022, the OEB approved the application for rates and other charges which became effective on May 1, 2022. In August 2022, Hydro One Remote Communities filed its Cost of Service rate application for 2023-2027, which includes a proposed 3.72% overall rate increase, recovery of variance accounts and additional increases to the Rural and Remote Rate Protection program. A decision is anticipated in early 2023.

Hydro One Remote Communities’ business is exempt from a number of sections of the Electricity Act which relate to the competitive market. For example, Hydro One Remote Communities continues to apply bundled rates to customers in remote communities. Hydro One Remote Communities’ business is operated on a break-even basis, without a return on equity included in rates. As a result, any net income or loss in the year related to the regulated operations of Hydro One Remote Communities is recorded in a regulatory variance account for disposition in future rate applications.

Conservation and Demand Management

In March 2019, the Province directed the IESO to cancel the 2015-2020 Conservation First Framework and assume accountability for centralized delivery of conservation programs under an interim framework. Under the IESO’s previous 2015-2020 Conservation First Framework, distributors in Ontario were responsible for developing and delivering CDM plans approved and funded by the IESO and reporting on their progress towards achieving projected energy savings targets.

The interim framework was in effect from April 1, 2019 to December 31, 2020 and offered energy-efficiency incentives and rebates to electricity customers. This was further extended to December 31, 2021 and again to August 31, 2022 by directives from the Minister of Energy in relation to the impacts of COVID-19. Under the interim framework, distributors, including Hydro One, were allowed to offer local programs that do not overlap with the IESO’s program offerings. Hydro One continues to deliver CDM programs to those customers for whom CDM project applications were approved.

In September 2020, the Minister of Energy issued a directive to the IESO establishing a $692 million CDM framework for the 2021-2024 period, effective January 1, 2021. The CDM framework focuses on cost-effectively meeting the needs of Ontario’s electricity system, regional and/or local electricity systems, including provincial peak demand reductions, which will be reassessed after the first two years. All programs are centrally delivered by IESO and address system needs identified in bulk, regional or distributor planning processes. Under the current framework, local distribution company participation will occur through the IESO’s competitive process. Hydro One is participating as an evaluator in the local initiatives program in two regions.

Capital Expenditures

Hydro One’s asset sustainment activities are based on an assessment of asset condition. Distribution asset

renewals are undertaken when assessments indicate there is a high risk of failure and where further maintenance activities are not appropriate. The Company expects capital expenditures for its distribution business in the near term to focus on new load connections, storm damage, wood pole replacement, and system capability reinforcement. In addition, the Company expects to continue to construct new distribution lines and stations in response to system growth forecasts, continued suburban community development, high load relief requirements and requirements to connect new sources of generation. The Company expects that it will spend in the range of approximately $924 million to $1,043 million per year over the next five years on capital expenditures relating to its distribution business.

Hydro One is continuing to modernize its distribution system through the deployment of smart devices (including remotely controllable switches and breakers as well as faulted circuit indicators) as power system assets are renewed. Hydro One has implemented a Distribution Management System (“DMS”) at its Ontario Grid Control Centre. The DMS has enabled Hydro One to monitor and control distribution components, perform real-time analysis and determine, with greater precision, the location of equipment failures. Additional functionality is planned to allow field staff to view system conditions remotely in real-time. Smart metering data will also be used to deliver operational and asset management benefits such as better notification of outages and their scope, asset loading information and other data. See the Annual MD&A under the subheading “Capital Investments – Future Capital Investments” for more information on future capital expenditures.

Competitive Conditions

Hydro One’s distribution service area is described in its distribution licence issued by the OEB. Only one distributor is permitted to provide distribution services in a service territory, and distributors have exclusive rights to provide service to new customers located within their service territory. As a result, there is very little direct competition for distribution services in Ontario, except near the borders of adjoining service territories, where a distributor may apply to the OEB to claim the right to serve new customers or new loads not currently connected to its distribution grid.

Ontario remains an active environment for local distribution company consolidation, resulting in competition for acquisition or merger opportunities. Potential acquirers may include strategic and financial buyers, in addition to other local distribution companies. Hydro One believes that it is well-positioned to continue to pursue consolidation opportunities within Ontario that are beneficial to all stakeholders. Consolidation continues within Ontario.

Other Segment

Hydro One’s other segment consists of certain corporate activities, including a deferred tax asset and is not rate-regulated. The deferred tax asset arose from the revaluation of the tax bases of Hydro One’s assets to fair market value when the Company transitioned from the provincial payments in lieu of tax regime to the federal tax regime at the time of the Company’s initial public offering in 2015. See “Business of Hydro One – Transmission Business Segment – Regulation – Recent Transmission Rate Applications – Hydro One Networks” for information on the deferred tax asset. Prior to November 6, 2015, Hydro One’s other segment principally consisted of its telecommunications business, run through Hydro One Telecom (now Acronym Solutions Inc.). Acronym Solutions Inc. is an indirect wholly-owned

subsidiary of Hydro One Limited.

The other segment represented approximately 2% of Hydro One’s total assets as at December 31, 2022, and accounted for approximately 0% of its total revenues, net of purchased power,3 in 2022 and 2021 and approximately 0% of its total revenues in 2022 and 2021.

Indigenous Communities

Hydro One believes that building and maintaining respectful, positive and mutually beneficial relationships with Indigenous communities across the province is important to achieving the Company’s corporate objectives. Hydro One has established an Indigenous Relations Policy, demonstrating the Company’s desire to work proactively to build relationships with Indigenous communities based on understanding, respect and mutual trust. Hydro One is committed to working with Indigenous communities in a spirit of cooperation, partnership and shared responsibility. Hydro One’s equity partnerships with the Saugeen Ojibway Nation in respect of the Bruce-to-Milton transmission line and with the Six Nations of the Grand River Development Corporation and the Mississaugas of the Credit First Nation in respect of the Niagara Line demonstrate the Company’s commitment to these principles. In keeping with the Company’s Indigenous Relations Policy, Hydro One’s Indigenous Relations team provides guidance and advice to support the Company in developing and advancing positive relationships. Hydro One also has several programs related to Indigenous communities and their citizens. These include educational and training opportunities which provide opportunities for work terms, Indigenous procurement partnership agreements along with community investments, customer support and outreach. Together, Hydro One Networks and Hydro One Remote Communities serve approximately 100 First Nation communities.

Hydro One supports Indigenous Procurement and has committed to reaching a target of 5% of total sourceable spend with Indigenous businesses by 2026.

The Company’s Indigenous Peoples, Safety & Operations Committee of the Board is responsible for assisting the Board in discharging the Board’s oversight of responsibilities relating to effective occupational health and safety and environmental policies and practices at Hydro One, and its relationship with Indigenous communities.

Outsourced Services

Hydro One has outsourced certain non-core functions, including facilities management services with respect to its stations and other facilities, and certain back-office services such as information technology, payroll, and finance and accounting services. The Company’s back-office services were provided by a third-party service provider under an agreement that expired on December 31, 2021 for finance and accounting services, and the finance and accounting services were insourced back to Hydro One in 2022.

3 Revenues, net of purchased power is a non-GAAP financial measure.

For payroll, an extension of services under an agreement with a third-party provider was negotiated to continue until December 31, 2023, at which time payroll services will be insourced back to Hydro One. The Company’s information technology services are provided by a third-party service provider under an agreement that expires on February 29, 2024, with an option to extend for two additional one-year terms, each at the Company’s discretion. The Company’s facilities management services are provided by a third-party service provider under an agreement that expires on December 31, 2024, with an option for the Company to renew the agreement for an additional term of three years, at the Company’s discretion.

Employees

As at December 31, 2022, Hydro One had approximately 6,400 regular and 1,100 non-regular employees province-wide comprised of a mix of skilled trades, engineering, professional, managerial and executive personnel. The average number of Hydro One employees in 2022 was approximately 9,200, consisting of approximately 6,400 regular employees and approximately 2,800 non-regular employees. Hydro One’s regular employees are supplemented primarily by accessing a large external labour force available through arrangements with the Company’s trade unions for contingent workers, sometimes referred to as “hiring halls”, and also by access to contract personnel. The hiring halls offer Hydro One the ability to access highly trained and appropriately skilled workers on a project-by-project basis. This arrangement provides the Company with more flexibility to address seasonal needs and unanticipated changes to its budgeted work programs. The Company also offers apprenticeship and technical training programs to ensure that future staffing needs will continue to be met.

In February 2021, Hydro One finalized agreements with the Power Workers’ Union (the “PWU”), the Society of United Professionals (the “Society”), Inergi LP, and Capgemini Canada Inc. to transfer approximately 234 represented Inergi LP employees to Hydro One by January 1, 2022.

The collective agreement between Hydro One Inc. and the Society expired on March 31, 2021. On June 25, 2021, Hydro One Inc. and the Society reached a tentative agreement, and the agreement was ratified on July 30, 2021 and will expire on March 31, 2023. Collective bargaining to renew this agreement is currently underway.

The collective agreement between Hydro One Inc. and the PWU (for the main agreement, covering classifications excluding Customer Service Operations (“CSO”)) expires on March 31, 2023. Collective bargaining to renew this agreement is currently underway. The collective agreement between Hydro One Inc. and the PWU covering CSO expired on September 30, 2022. Collective bargaining to renew this agreement commenced on August 29, 2022 and is ongoing.

The construction building trade unions have collective agreements with the Electrical Power Systems Construction Association (the “EPSCA”). EPSCA is an employers’ association of which Hydro One is a member. The EPSCA construction collective agreements, which bind Hydro One, were renewed for a five-year period, covering May 1, 2020 to April 30, 2025. The Canadian Union of Skilled Workers (the “CUSW”) is an electrical construction union that represents Hydro One’s direct hire construction electrician and linespersons. The Hydro One Inc. and CUSW collective agreement expired on April 30, 2022. On April 29, 2022, Hydro One Inc. reached an agreement with CUSW covering the period from May 1, 2022 to April 30, 2026. See the Annual MD&A under the headings “Hydro One Work Force” and

“Collective Agreements” for more information on employees.

Health, Safety and Environmental Management

Hydro One has an integrated Health, Safety and Environment Management System that includes key elements for the successful minimization of risk and continued performance improvements. Health, safety and environmental hazards and risks are identified and assessed, and controls are implemented to mitigate significant risks. The Company has policies in place regarding Health and Safety, Environment, Workplace Violence and Harassment and Public Safety.

Hydro One Networks is a designated “Sustainable Electricity Company” by the Canadian Electricity Association. This designation demonstrates Hydro One’s commitment to responsible environmental, social and economic practices, and to the principles of sustainable development.

Given the nature of the work undertaken by Hydro One employees, health and safety remain one of the Company’s top priorities. Safety is one of Hydro One’s core values. The Company has developed and is continuing to deliver its safety improvement plan consisting of programs and initiatives for incident prevention and to minimize the risk of injury to its employees and the public associated with its facilities and operations.

In 2019, Hydro One’s recordable injury rate reached less than 1 per 200,000 hours worked, a level which has since been maintained year over year. While the Company will continue to monitor and focus on its recordable injury rate, its primary focus is on the elimination of all life altering serious injuries and fatalities as our key Health & Safety performance measure. The Company is also raising the profile of our near miss incident reporting to ensure that the Company learns from and addresses the procedures, training and policies that lead to a safer workplace. All measures are monitored by management and by the Indigenous Peoples, Safety & Operations Committee, a committee of the Board. Management compensation has been tied, in part, to meaningfully improving annual health and safety performance targets. In the event of a fatality and subject to a system investigation, this component of management compensation would not be paid. A program allowing for an effective early and safe return to work has allowed the Company to ensure that, when injuries occur, employees recover and return to the workplace as soon as possible.

Hydro One continues with its “Journey to Zero” safety initiative that began in 2009. This initiative compares Hydro One to other companies to identify performance gaps. Safety perception assessments are completed regularly. The most recent assessment identified opportunities for improvement and, along with other inputs, the Company expects to use this information to develop activities that will make a significant difference to safety in the workplace.

Environmental Regulation

Hydro One is subject to extensive federal, provincial and municipal regulation relating to the protection of the environment that governs, among other things, environmental assessments, discharges to water, air and land, and the generation, storage, transportation, disposal and release of various hazardous substances. Estimated environmental liabilities are reviewed annually or more frequently if significant

changes in regulation or other relevant factors occur. Estimated changes are accounted for prospectively.

Permits and Approvals

The Company is required to obtain and maintain specified permits and approvals from federal, provincial and municipal authorities relating to the design, construction and operation of new and upgraded transmission and distribution facilities. Examples include environmental assessment approvals, permits for facilities to be located in parks or other regulated areas, water crossing permits, and approvals to discharge to air and water. Some projects may require environmental approvals from the federal government. Interconnections with neighbouring utilities in other provinces and states also require federal approval and will be subject to federal regulatory review. Hydro One makes every effort during consultation to ensure that Indigenous communities are engaged and that their issues and concerns are reflected in the Company’s environmental assessment process and planning.

In general, larger projects are subject to a comprehensive environmental assessment process, pursuant to the Environmental Assessment Act. The majority of approvals fall under a class environmental assessment process which provides for more streamlined approvals. The scope, timing and cost of environmental assessments are dependent on the scale and type of project, the location (urban versus rural), the environmental sensitivity of affected lands and the significance of potential environmental effects.

Regulation of Releases

Federal, provincial and municipal environmental legislation regulates the release of specific substances into the environment through the prohibition of discharges that will or may have an adverse effect on the environment, which can include liquids, gasses and noise. Releases occur in the course of the Company’s normal operations. Accordingly, Hydro One has spill, leak prevention and leak mitigation programs involving the testing, replacement, repair and installation of containment systems including re-gasketting of transformers and sulphur-hexafluoride-filled equipment. In addition, the Company has an emergency response capability which the Company believes is sufficient to minimize the environmental impact of spills and to comply with its legal obligations.

Hazardous Substances

Hydro One manages a number of hazardous substances, such as PCBs, herbicides, and wood preservatives. In addition, some facilities have substances present which are designated for special treatment under occupational health and safety legislation, such as asbestos, lead and mercury. The Company has environmental management programs in place to deal with PCBs, herbicides, asbestos, and other hazardous substances.

Land Assessment and Remediation

Hydro One has a proactive land assessment and remediation program in place to identify and, where necessary, remediate historical contamination that has resulted from past operational practices and uses of certain long-lasting chemicals at the Company’s facilities. These programs involve the systematic

identification of contamination at or from these facilities and, where necessary, the development of remediation plans for the Company’s properties and affected adjacent private properties. As at December 31, 2022, future expenditures related to Hydro One’s land assessment and remediation program were estimated at approximately $44 million. These expenditures are expected to be spent over the period ending 2049. Additional acquisitions could add to land assessment and remediation expenditures. The expenditures on this program for 2022 were approximately $6 million. These costs are expected to be recovered in the Company’s transmission and distribution rates and amounts payable to the Company pursuant to the Rural or Remote Electricity Rate Protection Program.

Insurance

Hydro One maintains insurance coverage, including liability, all risk property, boiler and machinery and directors’ and officers’ insurance. The Company also maintains other insurance coverage that is required by law, covering risks such as automobile liability, pesticide liability and aircraft liability. The Company does not have insurance for damage to its transmission and distribution wires, poles or towers located outside transmission and distribution stations, including damage caused by severe weather, other natural disasters or catastrophic events or for environmental remediation costs. The OEB has generally permitted the recovery of costs associated with extreme weather events.

Ombudsman

The Electricity Act requires that the Company have an ombudsman to act as a liaison with customers and to establish procedures for the ombudsman to inquire into and report to the Board on matters raised with the ombudsman by or on behalf of customers. These procedures are set out in a written mandate and terms of reference.

The role of the ombudsman is to facilitate resolution of complaints by customers of the Company that remain unresolved after having been processed through the Company’s complaints handling process. The ombudsman is an impartial and independent investigator, who makes recommendations to facilitate the resolution of both individual and systemic issues with a view to achieving a resolution that is fair to both the customer and the Company. The main purposes of the ombudsman are to address procedural and substantive unfairness, handle unresolved complaints, conduct systemic reviews that will lead to improvements in programs and systems, support the Company in holding its employees accountable for carrying out the Company’s directives and their responsibilities, and support the Board in its mandate to govern in a just, fair, and equitable manner. The ombudsman is mandated to work with the OEB to maintain integrated procedures for liaising with the Company and inquiring into matters raised by customers with the ombudsman. The ombudsman is an office of last resort within the Company.

RISK FACTORS

A discussion of Hydro One Inc.’s risk factors can be found under the heading “Risk Management and Risk Factors” in the Annual MD&A.

DIVIDENDS

Dividends on Hydro One Inc.’s common shares are declared at the discretion of the Board and are recommended by management based on Hydro One Inc.’s results of operations, maintenance of the deemed regulatory capital structure, financial condition, cash requirements and other relevant factors, such as industry practice and shareholder expectations.

In 2022, Hydro One Inc. paid no dividends on its Class A Preference Shares or Class B Preference Shares and paid $653 million of dividends on its common shares.

In 2021, Hydro One Inc. paid no dividends on its Class A Preference Shares or Class B Preference Shares and paid $620 million of dividends on its common shares.

In 2020, Hydro One Inc. paid no dividends on its Class A Preference Shares or Class B Preference Shares and $1 million of dividends on its common shares.

DESCRIPTION OF CAPITAL STRUCTURE

General Description of Capital Structure

The following description may not be complete and is subject to, and qualified in its entirety by reference to, the terms and provisions of Hydro One Inc.’s articles, as they may be amended from time to time.

Hydro One Inc.’s authorized share capital consists of an unlimited number of common shares, an unlimited number of Class A Preference Shares and an unlimited number of Class B Preference Shares. As at December 31, 2022, there were 142,239 common shares, no Class A Preference Shares, and no Class B Preference Shares issued and outstanding.

All of the outstanding common shares of Hydro One Inc. (all of Hydro One Inc.’s voting securities) are owned by Hydro One Limited.

Common Shares

Holders of common shares are entitled to receive notice of and to attend all meetings of shareholders and to vote thereat, except meetings at which only the holders of a specified class of shares are entitled to vote separately as a class or series. On each occasion when holders of common shares are entitled to vote, holders of common shares are entitled to one vote per share at all such meetings of shareholders. Subject to the rights, privileges, restrictions and conditions attaching to any other class of shares of Hydro One Inc., including the Class A Preference Shares and the Class B Preference Shares, holders of the common shares are entitled to receive dividends if, as, and when declared by the Board. Holders of common shares are also entitled to receive the remaining property of Hydro One Inc. upon its liquidation, dissolution or winding-up.

Class A Preference Shares

Hydro One Inc. may from time to time issue Class A Preference Shares. Subject to the rights, privileges, restrictions and conditions attaching to the Class B Preference Shares, the holders of the Class A Preference Shares shall be entitled to receive, as and when declared by the Board, non-cumulative preferential dividends at a rate per share per annum to be determined by the Board.

Subject to the OBCA, holders of Class A Preference Shares are not entitled to receive notice of, or to attend or to vote at, any meeting of the shareholders of Hydro One Inc. The Class A Preference Shares rank junior to the Class B Preference Shares, but are entitled to a preference over the common shares and any other shares ranking junior to the Class A Preference Shares with respect to payment of dividends and the distribution of assets and return of capital in the event of the liquidation, dissolution or winding up of Hydro One Inc.

Subject to the OBCA, Hydro One Inc., at its option, is entitled to redeem at any time or times all or any part of the Class A Preference Shares with or without the consent of such holder by giving notice in writing, (unless such notice is waived by the holder) specifying the number of shares to be redeemed, the redemption price and the date on which Hydro One Inc. wishes to redeem such Class A Preference Shares (the “Class A Redemption Date”). The Class A Redemption Date shall be 30 day(s) after the date on which the notice is given by the Company or such other date as Hydro One Inc. and such holder may agree. From and after the Class A Redemption Date, subject to certain conditions, such Class A Preference Shares shall cease to be entitled to dividends and the holder thereof shall not be entitled to exercise any of the rights of holders of Class A Preference Shares in respect thereof.

Class B Preference Shares

Hydro One Inc. may from time to time issue Class B Preference Shares. The holders of the Class B Preference Shares shall be entitled to receive, as and when declared by the Board, cumulative preferential cash dividends payable quarterly on the 20th day of the months of February, May, August and November in each year commencing February 20, 2018 (each a “Class B Dividend Payment Date”) at the Floating Quarterly Dividend Rate as calculated from time to time as set out in the Company’s articles.

For purposes of the forgoing:

•“Floating Quarterly Dividend Rate” means, for any Quarterly Floating Rate Period, the rate (expressed as a percentage rate rounded down to the nearest one hundred-thousandth of one percent (with 0.000005% being rounded up)) equal to the sum of the CDOR Rate on the applicable Floating Rate Calculation Date plus 0.25%.

•“CDOR Rate” means, for any Quarterly Floating Rate Period, the average rate for Canadian dollar bankers’ acceptances with a term of three months which appears on the Bloomberg Screen CDOR Page as of 10:00 a.m. (Toronto time) on the applicable Floating Rate Calculation Date, provided that if the CDOR Rate does not appear on the Bloomberg Screen CDOR Page as contemplated on a Floating Rate Calculation Date, then the CDOR Rate applicable for the applicable Quarterly Floating Rate Period shall be calculated by Hydro One Inc. as the average of

the rates applicable to Canadian dollar bankers’ acceptances with a term of three months quoted by four chartered banks listed on Schedule I of the Bank Act (Canada) (the “Approved Banks”) at 10:00 a.m. (Toronto time) on the applicable Floating Rate Calculation Date, provided that if fewer that four of the Approved Banks quote the aforementioned rate on the applicable Floating Rate Calculation Date and at the time described above, then the CDOR Rate for the applicable Quarterly Floating Rate Period shall be the average of the rates of the Approved Banks so quoting on the applicable Floating Rate Calculation Date or the rate so quoted by a single Approved Bank if only one such Approved Bank quotes the aforementioned rate on the applicable Floating Rate Calculation Date.

•“Quarterly Floating Rate Period” means the period commencing on each Floating Rate Calculation Date (November 20, 2017 and each Class B Dividend Payment Date thereafter) to, but excluding, the next Floating Rate Calculation Date. Accordingly, on each Class B Dividend Payment Date, the dividend payable on the Class B Preference Shares, if declared, will be in the amount per Class B Preference Share determined by multiplying: (i) the product obtained by multiplying the amount paid up thereon in respect of each Class B Preference Share by the Floating Quarterly Dividend Rate applicable to the Quarterly Floating Rate Period immediately preceding such Class B Dividend Payment Date; by (ii) a fraction, the numerator of which is the actual number of days elapsed in such Quarterly Floating Rate Period and the denominator of which is 365 or 366, depending upon the actual number of days in the applicable year. Dividends on the Class B Preference Shares shall be in priority to any dividends declared on the Class A Preference Shares, the common shares or any other shares of the Company ranking junior to the Class B Preference Shares.

Subject to the OBCA, holders of Class B Preference Shares are not entitled to receive notice of, or to attend or to vote at, any meeting of the shareholders of Hydro One Inc. The Class B Preference Shares are entitled to a preference over the Class A Preference Shares, the common shares and any other shares ranking junior to the Class B Preference Shares with respect to payment of dividends and the distribution of assets and return of capital in the event of the liquidation, dissolution or winding up of Hydro One Inc.

Subject to the OBCA, Hydro One Inc., at its option, is entitled to redeem at any time or times all or any part of the Class B Preference Shares with or without the consent of such holder by giving notice in writing, unless such notice is waived by the holder, specifying the number of shares to be redeemed, the redemption price and the date on which Hydro One Inc. wishes to redeem such Class B Preference Shares (the “Class B Redemption Date”). The Class B Redemption Date shall be 30 days after the date on which the notice is given by the Company or such other date as Hydro One Inc. and such holder may agree. From and after the Class B Redemption Date, subject to certain conditions, such Class B Preference Shares shall cease to be entitled to dividends and the holder thereof shall not be entitled to exercise any of the rights of holders of Class B Preference Shares in respect thereof.

Subject to the OBCA, a holder of any Class B Preference Shares is entitled to require Hydro One Inc. to redeem at any time or times any Class B Preference Shares registered in the name of such holder by tendering to the Company at its registered office a share certificate representing the Class B Preference Shares which the holder desires to have the Company redeem together with a request in writing (the “Retraction Demand”), unless such request is waived by the Company, specifying the number of shares to

be redeemed and the business day (the “Retraction Date”) on which the holder wishes to have the Company redeem such Class B Preference Shares. The Retraction Date shall be the date that is one business day after the date on which the Retraction Demand is tendered to the Company or such other date as the holder and Hydro One Inc. may agree. From and after the Retraction Date, subject to certain conditions, such Class B Preference Shares shall cease to be entitled to dividends and the holder thereof shall not be entitled to exercise any of the rights of holders of Class B Preference Shares in respect thereof.

Except with the consent in writing of the holders of all the Class B Preference Shares outstanding, no dividends shall at any time be declared and paid, or declared and set aside for payment, and no other distributions shall at any time be made on or in respect of the Class A Preference Shares, the common shares, or any other shares of the Company ranking junior to the Class B Preference Shares, if the payment or setting aside for payment of such dividend or the making of such distribution would impair the ability of Hydro One Inc. to redeem any Class B Preference Shares on the Class B Redemption Date or the Retraction Date.

CREDIT RATINGS

As of December 31, 2022, Hydro One Inc.’s long-term and short-term debt ratings were as follows:


Rating Agency	Short-term Debt Rating	Long-term Debt Rating
DBRS Limited (“DBRS”)	R-1 (low)	A (high)
Moody’s Investors Service (“Moody’s”)	Prime-2	A3
S&P Global Ratings (“S&P”)	A-1 (low)	A-

Credit ratings are intended to provide investors with an independent measure of the credit quality of an issue of securities and are indicators of the likelihood of payment and of the capacity and willingness of a company to meet its financial commitment on an obligation in accordance with the terms of the obligation.

The rating agencies rate long-term debt instruments by rating categories ranging from a high of AAA to a low of D (C in the case of Moody’s). Long-term debt instruments which are rated in the A category by S&P are in the third highest category and mean the obligor’s capacity to meet its financial commitments and obligations is strong but is considered somewhat more susceptible to the adverse effects of changes in circumstances and adverse economic conditions than obligations in higher rated categories. S&P may modify the ratings from AA to CCC using a plus (+) or minus (-) sign to show relative standing within the major rating categories. The addition of a rating outlook such as “stable”, “positive”, “negative” or “developing” assesses the potential direction of a long-term credit rating over the intermediate term (typically six months to two years). An outlook is not necessarily a precursor of a ratings change. Long-term debt instruments which are rated in the A category by DBRS are in the third highest category and are considered to be of a good credit quality, with substantial capacity for the payment of financial obligations. Entities in the A category may be vulnerable to future events, but qualifying negative factors are considered manageable. The “high” or “low” modifier indicates relative standing within this rating category by DBRS. The assignment of a “positive”, “stable” or “negative” trend provides guidance in

respect of DBRS’ opinion regarding the trend for the rating. The rating trend indicates the direction in which DBRS considers the rating may move if present circumstances continue, or in certain cases, unless challenges are addressed by the issuer. Long-term debt instruments which are rated in the A category by Moody’s are in the third highest category and are considered upper-medium-grade and are subject to low credit risk. Moody’s applies numerical modifiers 1, 2 and 3 to each generic rating classification from Aa through Caa. The modifier 1 indicates a ranking in the higher end of that generic rating category and a modifier 3 indicates a ranking in the lower end of that generic rating category. The addition of a rating outlook such as “stable”, “positive”, “negative” or “developing” indicates Moody’s opinion regarding the likely rating direction over the medium term.

DBRS’ short-term debt rating is based on its commercial paper and short-term debt rating scale that ranges from R-1 (high) to D. Commercial paper and short-term debt which are rated in the R-1 (low) category by DBRS are in the third highest category and are considered by DBRS to be of good credit quality. The capacity of the issuer for the payment of short-term financial obligations as they fall due is substantial. The overall strength of the obligation is not as favorable as higher rating categories and may be vulnerable to future events, but qualifying negative factors are considered manageable. S&P’s Canada national scale commercial paper ratings range from A-1 (high) to D. A short-term obligation rated A-1 (low) by S&P are in the third highest of eight available ratings categories and mean that such obligations are slightly more susceptible to the adverse effects of changes in circumstances and economic conditions than obligations in higher rating categories. However, the obligor’s capacity to meet its financial commitments on the obligation is satisfactory. Moody’s short-term debt rating is employed on a scale ranging that ranges from P-1 to NP. Short-term debt instruments which are rated in the P-2 category by Moody’s are in the second highest category. The issuer is considered to have a strong ability to repay short-term debt obligations.

The ratings mentioned above are not a recommendation to purchase, sell or hold Hydro One Inc.’s debt securities and do not comment as to market price or suitability for a particular investor. There can be no assurance that the ratings will remain in effect for any given period of time or that the ratings will not be revised or withdrawn entirely by any or all of S&P, DBRS and Moody’s at any time in the future if, in their judgment, circumstances so warrant.

Hydro One Inc. has made, and anticipates making, payments to each of S&P, DBRS and Moody’s pursuant to the ratings agency services agreements entered into with such credit rating organizations. In addition, as debt securities are issued, Hydro One Inc. expects to make payments to such credit rating organizations pursuant to the ratings agency services agreements entered into with such credit rating organizations for the ratings they assign to such debt securities.

Various ratings organizations review the Company’s debt ratings from time to time. These ratings organizations may take various actions, positive or negative. The Company cannot predict what actions rating agencies may take in the future. The failure to maintain the Company’s current credit ratings could adversely affect the Company’s financial condition and results of operations, and a downgrade in the Company’s credit ratings could restrict the Company’s ability to access debt capital markets and increase the Company’s cost of debt.

MARKET FOR SECURITIES

Hydro One Inc.’s Debentures (7.35%) due 2030, Series 2 Notes (6.93%) due 2032, Series 4 Notes (6.35%) due 2034, Series 5 Notes (6.59%) due 2043, Series 9 Notes (5.36%) due 2036, Series 11 Notes (5.00%) due 2046, Series 12 Notes (4.89%) due 2037, Series 17 Notes (6.03%) due 2039, Series 18 Notes (5.49%) due 2040, Series 23 Notes (4.39%) due 2041, Series 24 Notes (4.00%) due 2051, Series 26 Notes (3.79%) due 2062, Series 29 Notes (4.59%) due 2043, Series 30 Notes (4.29%) due 2064, Series 32 Notes (4.17%) due 2044, Series 35 Notes (2.77%) due 2026, Series 36 Notes (3.91%) due 2046, Series 38 Notes (3.72%) due 2047, Series 40 Notes (2.97%) due 2025, Series 41 Notes (3.63%) due 2049, Series 42 Notes (2.54%) due 2024, Series 43 Notes (3.02%) due 2029, Series 44 Notes (3.64%) due 2050, Series 45 Notes (1.76%) due 2025, Series 46 Notes (2.16%) due 2030, Series 47 Notes (2.71%) due 2050, Series 49 Notes (1.69%) due 2031, Series 50 Notes (2.23%) due 2031, Series 51 Notes (3.10%) due 2051, Series 52 Notes (4.91%) due 2028, Series 53 Notes (3.93%) due 2029, Series 54 Notes (4.16%) due 2033, and Series 55 Notes (4.46%) due 2053 are currently outstanding and, except for the Series 29 Notes, are not listed on any exchange or similar market for securities. Hydro One Inc.’s Series 29 Notes are listed for trading on the NYSE.

Prior Sales

In 2022, Hydro One Inc. issued the following tranches of medium term notes:


Note	Issue Date	Principal Amount (million)($)	Sale Price ($) / $100 principal amount	Gross Proceeds ($)
Series 52 Notes (4.91%) due 2028	October 27, 2022	750	99.998	749,985,000
Series 53 Notes (3.93%) due 2029	January 27, 2023	300	99.986	299,958,000
Series 54 Notes (4.16%) due 2033	January 27, 2023	450	99.984	449,928,000
Series 55 Notes (4.46%) due 2053	January 27, 2023	300	99.984	299,952,000

Trading Price and Volume

Hydro One Inc.’s Series 29 Notes (4.59%) due 2043 are listed on the NYSE under the symbol “HYDO43”. During the period from their date of issuance to December 31, 2022, there have been no reported trades of the Series 29 Notes on the NYSE.

DIRECTORS AND OFFICERS

Directors and Executive Officers

The following table sets forth information regarding the directors and executive officers as of December 31, 2022. Each of the directors was first appointed effective August 14, 2018, unless otherwise noted. Each director is elected annually to serve until the earlier of his or her resignation or until his or her

successor is elected or appointed.

Name, Province or State and Country of Residence

Age

Position/Title

Independent Board Member

Principal Occupation

Committees

William Sheffield (1)

Ontario, Canada

Interim President and CEO and Director

Interim President and CEO

Chris Lopez

Alberta, Canada

CFO

Paul Harricks

Ontario, Canada

Chief Legal Officer

Megan Telford

Ontario, Canada

Chief Human Resources Officer

David Lebeter(2)

Ontario, Canada

Chief Operating Officer

Timothy Hodgson

Ontario, Canada

Director and Chair of the Board

Yes

Director

Cherie Brant

Ontario, Canada

Director

Yes

Partner, Borden Ladner Gervais LLP

Governance & Regulatory Committee, Indigenous Peoples, Safety & Operations Committee

Blair Cowper-Smith(3)

Ontario, Canada

Director

Yes

Director

Audit Committee; Human Resources Committee

David Hay

New Brunswick, Canada

Director

Yes

Managing Director, Delgatie Incorporated

Governance & Regulatory Committee; Indigenous Peoples, Safety & Operations Committee (Chair)

Stacey Mowbray(4)

Ontario, Canada

Director

Yes

Director

Audit Committee (Chair); Indigenous Peoples, Safety & Operations Committee

Mark Podlasly(6)

British Columbia, Canada

Director

Yes

Director

Audit Committee; Human Resources Committee

Russel Robertson(3)

Ontario, Canada

Director

Yes

Director

Audit Committee; Human Resources Committee

Melissa Sonberg
Québec, Canada

Director

Yes

Adjunct Professor, McGill University

Audit Committee; Human Resources Committee (Chair)

Susan Wolburgh Jenah(3) (5)

Ontario, Canada

Director

Yes

Director

Governance & Regulatory Committee (Chair); Indigenous Peoples, Safety & Operations Committee

Notes:

(1)Mr. Sheffield was appointed as Interim President and CEO of Hydro One Limited and Hydro One Inc. as of June 21, 2022. Mr. Sheffield resigned as Interim President and CEO of Hydro One Limited and Hydro One Inc. effective February 1, 2023. In his role as a director, Mr. Sheffield became a member of the Governance & Regulatory Committee, and Indigenous Peoples, Safety & Operations Committee effective February 1, 2023.Mr. Sheffield will not be standing for re-election.

(2)Mr. Lebeter was appointed as President and CEO and a director of Hydro One Limited and Hydro One Inc. effective February 1, 2023.

(3)These directors have been designated as the Province’s nominees to the board of directors of Hydro One Limited and Hydro One Inc. for the purpose of the Governance Agreement.

(4)Ms. Mowbray was appointed on July 23, 2020.

(5)Ms. Wolburgh Jenah was appointed on January 1, 2020.

(6)Mr. Podlasly was elected on June 8, 2022.

Effective February 1, 2023, William Sheffield stepped down as Interim President and Chief Executive Officer. Mr. Sheffield continues as a director of Hydro One Limited and Hydro One Inc.

Effective February 1, 2023, David Lebeter was appointed as President and Chief Executive Officer of Hydro One Limited and Hydro One Inc. and a director of Hydro One Limited and Hydro One Inc.

The following includes a brief profile of each of the executive officers and directors of Hydro One Inc., which includes a description of their present occupation and their principal occupations for the past five years:

David Lebeter – President and Chief Executive Officer, Chief Operating Officer

David Lebeter is the President and CEO of Hydro One Limited and Hydro One Inc., a position he assumed after being appointed effective February 1, 2023. Mr. Lebeter is also the Chief Operating Officer (COO) of Hydro One Networks, a role he assumed in January 2020. In his role as COO, Mr. Lebeter is responsible for transmission and distribution, including construction, maintenance, vegetation management as well as system operations, asset planning and engineering.

Mr. Lebeter is a highly regarded leader with over 40 years’ experience in the utility and forestry sectors and a reputation for driving improved safety, employee engagement, productivity, customer centricity and successfully delivering capital investments. Under Mr. Lebeter’s leadership, the company has improved safety, productivity, reliability and customer experience.

Before joining Hydro One, he held progressively senior positions in operations and safety at BC Hydro from 2005 to 2019, including leadership roles in generation, transmission, distribution and safety. During his tenure, he was responsible for improving safety, reliability, employee engagement and customer service, lowering costs and building trust with union leaders and Indigenous communities.

Mr. Lebeter spent 23 years in the forest industry prior to joining the utility sector, working in leadership positions responsible for operations.

He has previously served as an Executive Board Member for Smart Grid Northwest, as an Operations Board Member for Western Energy Institute, and as the Chairman of the Distribution Council with the Canadian Electricity Association.

Mr. Lebeter holds a Bachelor’s degree in Forestry from the University of British Columbia, and is a registered professional forester. In addition, Mr. Lebeter holds an Executive Master of Business Administration from Simon Fraser University. He holds his ICD.D from the Institute of Corporate Directors.

Chris Lopez – Chief Financial Officer

Chris Lopez is the Chief Financial Officer (CFO) of Hydro One Limited and Hydro One Inc., a position he assumed after being appointed as Acting CFO in late 2018. Mr. Lopez joined Hydro One in 2016 as the Senior Vice President of Finance and has more than 23 years of progressive experience in the utilities

industry in Canada, the United States and Australia.

As CFO, Mr. Lopez is responsible for the corporate finance function, including treasury and tax, as well as internal audit, investor relations, risk, pensions and shared services, including supply chain, strategy and growth, including Acronym Solutions Inc., and mergers and acquisitions.

Prior to joining the organization, Mr. Lopez was the Vice President, Corporate Planning and Mergers & Acquisitions at TransAlta Corporation from 2011 to 2015, and the Director of Operations Finance at TransAlta from 2007 to 2011 in Alberta, Canada. He also held senior financial roles for TransAlta in his native Australia, from 1999 to 2007. At the start of his career, he worked as a financial accountant with Rio Tinto in Australia.

Mr. Lopez holds a Bachelor of Business degree from Edith Cowan University in Australia, and a Chartered Accountant designation. He received a graduate diploma in corporate governance and directorships from the Australian Institute of Company Directors in 2007 and holds his GAICD.

Paul Harricks – Chief Legal Officer

Paul Harricks is the Executive Vice-President and Chief Legal Officer of Hydro One Limited and Hydro One Inc., leading all aspects of the organization’s regulatory, legal, compliance, corporate governance and business ethics activities. Prior to joining Hydro One in September 2019, Mr. Harricks practiced law for about 40 years, working extensively in the energy and infrastructure industries and serving as a partner and leader of the Energy Sector Industry Group of Gowling WLG Canada LLP, a major Canadian law firm.

A seasoned and trusted legal and strategic advisor, Mr. Harricks has delivered effective results in the fields of electricity distribution, transmission and generation and has led a range of public and private mergers and acquisitions.

Mr. Harricks is a past Director of the Association of Power Producers of Ontario and is a current member and past Chair of the Energy & Climate Committee of the Toronto Region Board of Trade. He has been an active member of the International Bar Association. He is also a Director and Audit Committee and Compensation Committee member of Pioneering Technology Corp.

He holds a Bachelor’s Degree from the University of Toronto and an LLB from Osgoode Hall Law School.

Megan Telford – Chief Human Resources Officer

Megan Telford is the Chief Human Resources Officer at Hydro One Networks Inc., a role she assumed in September 2020. Ms. Telford is responsible for all areas of human resources across Hydro One, including labour relations, talent management, total rewards and change and culture. In August 2022, Ms. Telford assumed responsibility for the Health, Safety and Environment teams. In September 2022, Ms. Telford also assumed interim responsibility for the Corporate Affairs and Customer Care teams.

Ms. Telford is an experienced leader with deep expertise in law and human resources. Before joining

Hydro One, Ms. Telford held the position of Head of Human Resources at Toronto Dominion (TD) Insurance from 2019 to 2020, and also held a number of increasingly senior roles across the TD Bank in both legal and human resources since 2007. Prior to TD, Ms. Telford practised labour and employment law at a national law firm and worked at the Permanent Court of Arbitration in The Hague.

Ms. Telford holds an Honours Bachelor of Arts degree in Industrial Relations from McMaster University, a Master of Industrial Relations and Juris Doctor from Queen’s University and she was a law clerk for Justices Stone and Strayer at the Federal Court of Appeal.

Timothy E. Hodgson – Board Chair

Timothy Hodgson is a corporate director. He currently serves as Chair of Hydro One and Chair of the New Self-Regulatory Organization of Canada for investment products. Mr. Hodgson also serves on the boards of Dialogue Health Technologies, the Property and Casualty Insurance Compensation Corporation and the Ontario Teachers’ Pension Plan. Mr. Hodgson was formerly Managing Partner of Alignvest Management Corporation from 2012 until his retirement in August 2019. He was Special Advisor to Mr. Mark Carney, the then Governor of the Bank of Canada from 2010 to 2012. From 1990 to 2010, Mr. Hodgson held various positions in New York, London, Silicon Valley, and Toronto with Goldman Sachs and served as Chief Executive Officer of Goldman Sachs Canada from 2005 to 2010.

His prior directorships include PSP Investments, Sagicor Financial Corporation, Sagicor Group Jamaica, MEG Energy, Alignvest Acquisition Corporation, Alignvest Acquisition II Corporation, The Global Risk Institute, KGS-Alpha Capital Markets, Next Canada, the Ivey School of Business, and Bridgepoint Health.

Mr. Hodgson holds a Masters of Business Administration from The Ivey School of Business at Western University and a Bachelor of Commerce from the University of Manitoba. He is a Fellow of the Institute of Chartered Professional Accountants (FCPA) and holds his ICD.D.

Cherie L. Brant – Member of Governance & Regulatory Committee, Member of Indigenous Peoples, Safety & Operations Committee

Cherie Brant is a partner and national leader for the Indigenous law group at Borden Ladner Gervais LLP. Ms. Brant has a commercial practice across a wide variety of sectors, including energy and transmission, land development and financing on First Nations lands and economic development. She also provides strategic policy and governance counsel to Indigenous groups. Prior to joining Borden Ladner Gervais LLP, Ms. Brant was a partner at another major Canadian law firm, where she had been practicing since 2013.

Ms. Brant is both Mohawk and Ojibway from the Mohawks of the Bay of Quinte and Wiikwemkoong Unceded Indian Territory. She serves on the boards of Toronto-Dominion Bank, Canadian Council for Aboriginal Business and Canadian Club of Toronto. Her previous directorships include Women’s College Hospital, Trillium Gift of Life and the Anishnawbe Health Foundation.

Ms. Brant holds a Bachelor of Environmental Studies, Urban and Regional Planning Program from the

University of Waterloo and a Juris Doctor from the University of Toronto. She is a member of the Ontario Bar Association and the Law Society of Ontario.

In 2017, Ms. Brant received the Lexpert Zenith Award, a national award recognizing women’s contributions in the law and in 2012, she was named one of Lexpert’s “Rising Stars: Leading Lawyers Under 40”.

Blair Cowper-Smith – Member of Audit Committee, Member of Human Resources Committee

Blair Cowper-Smith is the principal of Canadian advisory firm Erin Park Business Solutions. Previously, Mr. Cowper-Smith was Corporate Affairs Officer of Ontario Municipal Employees Retirement System (OMERS) where he also served as a member of the Senior Executive Team from 2008 to 2017 where his responsibilities included regulatory affairs, law and governance. Prior to joining OMERS, he was a Senior Partner at McCarthy Tetrault LLP, where his practice focused on mergers and acquisitions, infrastructure, governance and private equity.

Mr. Cowper-Smith’s current board appointments include Porter Airlines, the Financial Services Regulatory Authority of Ontario, Face the Future Foundation and Advisory Board Chair of Timbercreek Capital. Prior board appointments include 407 ETR, Golf Town and the Global Strategic Investment Alliance. He has served on the Public Policy Committee of the Canadian Coalition for Good Governance and on the Securities Advisory Committee of the Ontario Securities Commission. Mr. Cowper-Smith regularly delivers lectures on governance at the Directors College at McMaster University.

Mr. Cowper Smith holds a Bachelor of Laws (LLB) and Master of Laws (LLM) from Osgoode Hall Law School at York University and holds his ICD.D.

David Hay – Chair of Indigenous Peoples, Safety & Operations Committee, Member of Governance & Regulatory Committee

David Hay is the Managing Director of Delgatie Incorporated, a strategic advisory firm. He is the former Vice-Chair and Managing Director of CIBC World Markets Inc., a role he held until 2015. From 2004 until 2010, he was President and Chief Executive Officer of New Brunswick Power Corporation. Prior to that Mr. Hay held senior investment banking roles as Senior Vice-President and Director responsible for mergers and acquisitions with Merrill Lynch Canada and Managing Director of European mergers and acquisitions with Merrill Lynch International based in London, England. Mr. Hay spent the early part of his career as a practicing lawyer at Osler, Hoskin & Harcourt LLP and taught at both the University of Toronto and University of New Brunswick. Mr. Hay was a Law Clerk to the Chief Justice of the High Court of the Supreme Court of Ontario from 1981 until 1982.

Mr. Hay also sits on the boards of EPCOR Utilities Inc. He is a member of the Expert Panel on Churchill Falls 2041 and the Council of Clean and Reliable Energy. Prior directorships include Toronto Hydro-Electric System Limited, where he was Vice Chair, and Associated Electric & Gas Insurance Services Limited (AEGIS). Mr. Hay also chaired both the Beaverbrook Art Gallery and SHAD Canada.

Mr. Hay holds a Bachelor of Laws from Osgoode Hall Law School, York University and a Bachelor of

Arts from the University of Toronto (Victoria College). He is an Executive Fellow of the Ivey Energy and Policy Institute and holds his ICD.D.

Stacey Mowbray – Chair of Audit Committee, Member of Indigenous Peoples, Safety & Operations Committee

Stacey Mowbray is a corporate director. Ms. Mowbray served as President of North America at WW International (formerly Weight Watchers) and as President of WW Canada, from 2014 to 2019. Prior to that, Ms. Mowbray served as President and Chief Executive Officer at The Second Cup Ltd. Ms. Mowbray has extensive marketing and brand experience from years of leading those functions at high profile brands such as Molson Coors Brewing Company, Cara Operations and Pepsi Cola.

Currently, Ms. Mowbray serves on the board of Currency Exchange International/Exchange Bank of Canada, Sleep Country Canada Holdings Inc., Bonne O Holdings Company and dentalcorp Holdings Ltd. Prior directorships have included Trillium Health Partners, Second Cup Coffee, Liquor Control Board of Ontario, Niagara Ventures Corporation and Coffee Association of Canada as Chair.

Ms. Mowbray has received numerous recognitions including Diversity Champion, Inaugural CEO in Residence for Wilfrid Laurier, Top 100 Women’s Executive Network, Top 20 Women’s Post and Schulich School of Business Outstanding Progress and Achievement Award. Ms. Mowbray holds a Master of Business Administration in Finance and Marketing from Schulich School of Business - York University, as well as a Bachelor of Business Administration from Wilfrid Laurier University. Ms. Mowbray holds her ICD.D.

Mark Podlasly – Member of Audit Committee, Member of Human Resources Committee

Mark Podlasly is the Chief Sustainability Officer at the First Nations Major Projects Coalition where he leads policy development at a First Nations collective seeking ownership in major projects such as pipelines, mines, and electric infrastructure, as well as improvements in project environmental practices. He has held this role since 2016.

Mr. Podlasly is a member of the Indigenous Advisory Council at CN Rail and a member of the External Expert Panel of the Manitoba Government (Crown Services) where he provides advice regarding the response to the Economic Review of Bipole III and Keeyask power generation and transmission projects. Mr. Podlasly is the chair of the First Nations Limited Partnership (Gas Pipeline), Trustee of the Nlaka’pamux Nation Legacy Trust, and a member of the Climate Strategy Advisory Board at the Institute of Corporate Directors.

Mr. Podlasly has been an Adjunct Professor at the University of British Columbia Sauder School of Business since 2021. Mr. Podlasly holds a Master in Public Administration degree from Harvard University as well as a Bachelor of Arts, Business Administration from Trinity Western University.

Russel C. Robertson – Member of Audit Committee, Member of Human Resources Committee

Russel Robertson served as Executive Vice-President and Head, Anti-Money Laundering, at BMO

Financial Group from 2014 to 2016. Prior to this Mr. Robertson served as Executive Vice-President, Business Integration from 2011 to 2014, where he oversaw the integration of Harris Bank and Marshall & Ilsley Bank to form BMO Harris Bank and as Chief Financial Officer, BMO Financial Group from 2008 to 2011. Before joining BMO, he spent over 35 years as a Chartered Professional Accountant holding various senior positions, including the positions of Vice-Chair, Deloitte & Touche LLP (Canada) and Canadian Managing Partner, Arthur Andersen LLP (Canada).

Mr. Robertson sits on the board of Bausch Health Companies Inc. and Bausch & Lomb Corporation and he chairs the audit committee of Bausch Health Companies Inc. Previous directorships include Virtus Investment Partners Inc. and Turquoise Hill Resources Ltd.

Mr. Robertson holds a Bachelor of Arts (Honours) in Business Administration from the Ivey School of Business at the Western University. He is a Chartered Professional Accountant (FCPA, FCA), a Fellow of the Institute of Chartered Accountants (Ontario) and holds his ICD.

William H. Sheffield – Member of Governance & Regulatory Committee, Member of Indigenous Peoples, Safety & Operations Committee

William Sheffield is the former CEO of Sappi Fine Papers, headquartered in the U.K. and South Africa. He began his career in the steel industry with Stelco Inc., headquartered in Ontario. Mr. Sheffield also held senior roles in the forest products industry with Abitibi-Price Inc. and Abitibi-Consolidated Inc. where he led the forestry, mill and hydro-electric operations with the Iroquois Falls Division in northern Ontario. Mr. Sheffield held the role of Interim President and CEO of Hydro One Limited and Hydro One Inc. from June 21, 2022 to February 1, 2023.

Mr. Sheffield has been a corporate director since 2004. He currently sits on the board of Atlantic Packaging Products Ltd. and is also completing his last term on the board of Velan Inc. Previous directorships include Ontario Power Generation, Canada Post Corporation, Houston Wire & Cable Company, Pan Asia Paper, Corby Distilleries, Royal Group Technologies, 4iiii Innovations Inc., Family Enterprise Canada, and SHAD. In addition to his engagements on the boards of public companies and Crown corporations, Mr. Sheffield has had experience with family enterprise advisory boards such as Burnbrae Farms, Longview Aviation Capital Corp. and Epicure.

Mr. Sheffield holds a Bachelor of Science (Chemistry) from Carleton University, an MBA from McMaster University and holds his ICD.D. In 2015, he was awarded a Fellowship from the National Association of Corporate Directors in the U.S. He also completed the Family Enterprise Advisors Program (FEA) at the University of British Columbia.

Melissa Sonberg – Chair of Human Resources Committee, Member of Audit Committee

Melissa Sonberg is Professor of Practice at McGill University’s Desautels Faculty of Management, where she has been on the faculty since 2014. She spent the early part of her career in the healthcare industry before joining Air Canada, where she held leadership positions in a range of customer facing, operational and corporate functions. Ms. Sonberg was part of the founding executive team of Aeroplan, which became part of AIMIA Inc. Ms. Sonberg held positions of Senior Vice President, Human Resources &

Corporate Affairs and Senior Vice President, Global Brands, Communications and External Affairs at AIMIA from 2001 to 2013.

Ms. Sonberg sits on the boards of Exchange Income Corporation, Athennian, and the Montreal Children’s Hospital Foundation. Previous directorships include Via Rail Canada, MD Financial Holdings, Inc., Rideau, Inc., Group Touchette, Women in Capital Markets and the McGill University Health Centre.

Ms. Sonberg holds a Bachelor of Science (Psychology) from McGill University, a Masters of Health Administration from the University of Ottawa and holds her ICD.D. She is a Certified Human Resource Executive (CHRE).

Susan Wolburgh Jenah – Chair of Governance & Regulatory Committee, Member of Indigenous Peoples, Safety & Operations Committee

Susan Wolburgh Jenah is a corporate director and has over 30 years’ experience as a senior regulator, executive and lawyer. Throughout her career, she has served on numerous corporate, Crown corporation and not-for-profit boards and expert advisory committees.

Ms. Wolburgh Jenah currently holds board positions at Laurentian Bank of Canada, Aecon Group Inc. and is Vice-Chair of Humber River Hospital. She is a member of the Independent Review Committee of Vanguard Investments Canada. Recent prior directorships include serving as a Public Governor of the U.S. Financial Industry Regulatory Authority, as Chair of the NEO Exchange, and as a director of Aequitas Innovations, The Global Risk Institute, and the Investment Industry Regulatory Organization of Canada (IIROC).

Ms. Wolburgh Jenah was the founding President and CEO of IIROC and held numerous executive roles at the Ontario Securities Commission, including Vice-Chair, Acting Chair, General Counsel and Head of International Affairs.

Ms. Wolburgh Jenah holds a Bachelor of Arts from the University of Toronto and a Juris Doctor from Osgoode Hall Law School. She is also a member of the C.D. Howe National Advisory Council and served as Mentor to the Catalyst Women on Board Program. She is a prior Fellow and Adjunct Professor at Osgoode Hall Law School and recipient of the Osgoode Hall Gold Key for Achievement in 2011. Ms. Wolburgh Jenah holds her ICD.D.

Information Regarding Certain Directors and Executive Officers

As at December 31, 2022, none of the directors or executive officers of Hydro One Inc. beneficially owned, controlled or directed, directly or indirectly, any common shares of Hydro One Inc.

Corporate Cease Trade Orders and Bankruptcies

Except as described below:

•none of the directors or executive officers of Hydro One Inc. nor any shareholder holding shares

sufficient to materially affect control of Hydro One Inc. is, or within the last 10 years has served as, a director or executive officer of any company that, during such service or within a year after the end of such service, became bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency or was subject to or instituted any proceedings, arrangement or compromise with creditors or had a receiver, receiver manager or trustee appointed to hold its assets;

•none of the directors or executive officers of Hydro One Inc. is, or within the last 10 years has served as, a director, CEO or CFO of any company that, during such service or as a result of an event that occurred during such service, was subject to an order (including a cease trade order, or similar order or an order that denied access to any exemption under securities legislation), for a period of more than 30 consecutive days; or

•none of the directors or executive officers of Hydro One Inc. nor any shareholder holding shares sufficient to materially affect control of Hydro One Inc., within the last 10 years has become bankrupt, made a proposal under any legislation relating to bankruptcy or insolvency, or become subject to or instituted any proceedings, arrangement or compromise with creditors, or had a receiver, receiver manager or trustee appointed to hold the assets of the director, executive officer or shareholder.

Blair Cowper-Smith served as a director of Golfsmith International Holdings GP Inc. and Golf Town Canada Inc. (“Golf Town”) from 2016 to 2018. On September 14, 2016, Golf Town filed for and was granted Court bankruptcy protection under the CCAA. Golf Town emerged from Court protection after being sold to Fairfax Financial Holdings Limited and CI Investments Inc. in October 2016.

Penalties or Sanctions

None of the directors or executive officers of Hydro One Inc., nor any shareholder holding shares sufficient to materially affect control of Hydro One Inc., has been subject to any penalties or sanctions imposed by a court relating to securities legislation or by a securities regulatory authority or has entered into a settlement agreement with a securities regulatory authority or been subject to any other penalties or sanctions imposed by a court or regulatory body that would likely be considered important to a reasonable investor making an investment decision.

Conflicts of Interest

To the best of the Company’s knowledge, there are no existing material potential conflicts of interest among the Company and the directors or executive officers of the Company as a result of their outside business interests as at the date of this annual information form. Certain of the directors and executive officers serve as directors and executive officers of other public companies. Accordingly, conflicts of interest may arise which could influence these persons in evaluating possible acquisitions or in generally acting on behalf of the Company. Where conflicts arise, they are managed through a variety of measures, including declaration of the conflict, recusal from meetings and/or portions of meetings, and the creation of separate board materials for the affected directors.

Indebtedness of Directors and Executive Officers

No director, executive officer, employee, former director, former executive officer or former employee or associate of any director or executive officer of Hydro One Inc. or any of its subsidiaries had any outstanding indebtedness to Hydro One Inc. or any of its subsidiaries except routine indebtedness or had any indebtedness that was the subject of a guarantee, support agreement, letter of credit or other similar arrangement or understanding provided by Hydro One Inc. or any of its subsidiaries.

CORPORATE GOVERNANCE

Hydro One and the Board recognize the importance of corporate governance to the effective long-term management of the Company. Independence, integrity and accountability are the foundation of the Company’s approach to corporate governance.

Hydro One Inc.’s corporate governance practices are influenced by, and to the extent applicable, largely mimic the corporate governance practices of Hydro One Limited. Hydro One Inc.’s corporate governance practices are also influenced by the obligations of Hydro One Limited under the Governance Agreement.

The Governance Agreement requires the Board to be constituted to have the same members as the board of directors of Hydro One Limited unless the board of directors of Hydro One Limited determines otherwise. The Governance Agreement also requires, among other things, that Hydro One Limited cause its subsidiaries, including Hydro One Inc., to manage and operate their business and affairs on a basis that permits Hydro One Limited to maintain, and act in accordance with corporate governance policies, procedures and practices that are consistent with the best practices of leading Canadian publicly listed companies, having regard to Hydro One Limited’s ownership structure and the Governance Agreement.

For further details on Hydro One Limited’s corporate governance practices, including information about its various board committees, please refer to the management information circular of Hydro One Limited for its upcoming annual meeting which, once filed, can be found under Hydro One Limited’s profile on SEDAR at www.sedar.com.

INTEREST OF MANAGEMENT AND OTHERS IN MATERIAL TRANSACTIONS

Other than as noted below and elsewhere in this annual information form, there are no material interests, direct or indirect, of any director or executive officer of the Company, any shareholder that beneficially owns, or controls or directs (directly or indirectly), more than 10% of any class or series of Hydro One Inc.’s outstanding voting securities, or any associate or affiliate of any of the foregoing persons, in any transaction within the three most recently completed financial years or during the current financial year, up to the date of this annual information form, that has materially affected or is reasonably expected to materially affect the Company.

Relationships with the Province and Other Parties

Overview

The Province is Hydro One Limited’s principal shareholder, and Hydro One Limited directly or indirectly owns all of the issued and outstanding shares of Hydro One Inc. The OEB is the principal regulator of Ontario’s electricity industry. The Province appoints the board members of the OEB and fills any vacancies on the OEB. The OEB is obligated to implement approved directives of the Province concerning general policy and objectives to be pursued by the OEB and other directives aimed at addressing existing or potential abuses of market power by industry participants. The IESO, among other matters, directs the operation of the Ontario power system by balancing supply and demand of electricity and directing electricity flow and assumed the responsibility for forecasting supply and demand of electricity over the medium and long term to meet the needs of the province. The board of directors of the IESO, other than its CEO, is appointed by the Province in accordance with the regulations in effect from time to time under the Electricity Act.

In connection with the initial public offering of Hydro One Limited, Hydro One Limited entered into the Governance Agreement with the Province, which, among other things, addressed the Province’s role in the governance of Hydro One Limited. The Governance Agreement requires the Board to be constituted to have the same members as the board of directors of Hydro One Limited unless the board of directors of Hydro One Limited determines otherwise. The Governance Agreement also requires, among other things, that Hydro One Limited cause its subsidiaries, including Hydro One Inc., to manage and operate their business and affairs on a basis that permits Hydro One Limited to maintain, and act in accordance with corporate governance policies, procedures and practices that are consistent with the best practices of leading Canadian publicly listed companies, having regard to Hydro One Limited’s ownership structure and the Governance Agreement. For a complete description of the Governance Agreement, and the other details of the relationship between Hydro One Limited and the Province, please refer to Hydro One Limited’s annual information form dated February 14, 2023 which is available under Hydro One Limited’s profile on SEDAR at www.sedar.com.

A copy of the Governance Agreement can also be found under Hydro One Limited’s profile on SEDAR at www.sedar.com. Also see the Annual MD&A under the heading “Related Party Transactions”.

Letter Agreement

In July 2018, Hydro One Limited, on behalf of itself and Hydro One Inc., announced that it had entered into the Letter Agreement for the purpose of the orderly replacement of the board of directors of Hydro One Limited and Hydro One Inc. and the retirement of the then CEO effective July 11, 2018.

For a description of the Letter Agreement, and the other details of the relationship between Hydro One Limited and the Province, please refer to Hydro One Limited’s annual information form dated February 14, 2023 which is available under Hydro One Limited’s profile on SEDAR at www.sedar.com.

A copy of the Letter Agreement can also be found under Hydro One Limited’s profile on SEDAR at www.sedar.com.

Transfer Orders

The transfer orders pursuant to which Hydro One Inc. acquired Ontario Hydro’s electricity transmission, distribution and energy services businesses as of April 1, 1999, did not transfer certain assets, rights, liabilities or obligations where the transfer would constitute a breach of the terms of any such asset, right, liability or obligation or a breach of any law or order (the “trust assets”). The transfer orders did not transfer title to assets located on Reserves, which assets are held by OEFC. See the Annual MD&A under the subheading “Risk Management and Risk Factors – Risks Relating to Hydro One’s Business – Risk from Transfer of Assets Located on Reserves” for more information.

Until it has obtained all consents necessary to complete the transfer of title to these assets to Hydro One, Hydro One is obligated under the transfer orders to manage both the trust assets and the assets otherwise retained by OEFC that relate to Hydro One’s businesses. Hydro One has entered into an agreement with OEFC under which it is obligated, in managing these assets, to take instructions from OEFC if Hydro One’s actions could have a material adverse effect on OEFC. OEFC has retained the right to take control of and manage the assets, although it must notify and consult with Hydro One before doing so and must exercise its powers relating to the assets in a manner that will facilitate the operation of Hydro One’s businesses. The consent of OEFC is also required prior to any disposition of these assets.

The Province also transferred officers, employees, assets, liabilities, rights and obligations of Ontario Hydro in a similar manner to its other successor transferees. These transfer orders include a dispute resolution mechanism to resolve any disagreement among the various transferees with respect to the transfer of specific assets, liabilities, rights or obligations.

The transfer orders do not contain any representations or warranties from the Province or OEFC with respect to the transferred officers, employees, assets, liabilities, rights and obligations. Furthermore, under the Electricity Act, OEFC was released from liability in respect of all assets and liabilities transferred by the transfer orders, except for liability under Hydro One’s indemnity from OEFC. The parties, with the consent of the Minister of Finance, agreed to terminate such indemnity effective October 31, 2015. By the terms of the transfer orders, each transferee indemnifies OEFC with respect to any assets and liabilities related to that transferee’s business not effectively transferred, and is obligated to take all reasonable measures to complete the transfers where the transfers were not effective.

Hydro One has indemnified OEFC in respect of the damages, losses, obligations, liabilities, claims, encumbrances, penalties, interest, taxes, deficiencies, costs and expenses arising from matters relating to the Company’s business and any failure by Hydro One to comply with its obligations to OEFC under agreements dated as of April 1, 1999. These obligations include obligations to employ the employees transferred to Hydro One under the transfer orders, make and remit employee source deductions (including tax withholding amounts, and employer contributions), manage the real and personal properties which OEFC continues to hold in trust or otherwise and take any necessary action to transfer all of these properties to the Company, to pay realty taxes and other costs, provide access to books and records and to assume other responsibilities in respect of the assets held by OEFC in trust for the Company.

MATERIAL CONTRACTS

The following are the only material contracts that Hydro One Inc. has entered into since January 1, 2002 that remain in effect, other than those contracts entered into by Hydro One Inc. in the ordinary course of business:

(a)

(i)a third supplemental trust indenture dated as of January 31, 2003 relating to the issuance of Series 4 Notes in the aggregate principal amount of $1,000,000,000, of which $200,000,000 was drawn down on January 31, 2003, $120,000,000 was drawn down on June 25, 2004 and $65,000,000 was drawn down on August 24, 2004, pursuant to the Trust Indenture dated as of June 4, 2001 between Hydro One Inc. and Computershare Trust Company of Canada (the “Trust Indenture”);

(ii)a fourth supplemental trust indenture dated as of April 22, 2003 relating to the issuance of Series 5 Notes in the aggregate principal amount of $1,000,000,000, of which $250,000,000 was drawn down on April 22, 2003 and $65,000,000 was drawn down on August 20, 2004, pursuant to the Trust Indenture;

(iii)an eighth supplemental indenture dated as of May 19, 2005 relating to the issuance of Series 9 Notes in the aggregate principal amount of $1,000,000,000, of which $350,000,000 was drawn down on May 19, 2005 and $250,000,000 was drawn down on April 24, 2006, pursuant to the Trust Indenture;

(iv)a tenth supplemental trust indenture dated as of October 19, 2006 relating to the issuance of Series 11 Notes in the aggregate principal amount of $1,000,000,000, of which $75,000,000 was drawn down on October 19, 2006, and $250,000,000 was drawn down on September 13, 2010, pursuant to the Trust Indenture;

(v)an eleventh supplemental trust indenture dated as of March 13, 2007 relating to the issuance of Series 12 Notes in the aggregate principal amount of $1,000,000,000, of which $400,000,000 was drawn on March 13, 2007, pursuant to the Trust Indenture;

(vi)a sixteenth supplemental trust indenture dated as of March 3, 2009 relating to the issuance of Series 17 Notes in the aggregate principal amount of $1,000,000,000, of which $300,000,000 was drawn down on March 3, 2009, pursuant to the Trust Indenture;

(vii)a seventeenth supplemental trust indenture dated as of July 16, 2009 relating to the issuance of Series 18 Notes in the aggregate principal amount of $1,000,000,000, of which $300,000,000 was drawn down on July 16, 2009 and $200,000,000 was drawn on March 15, 2010, pursuant to the Trust Indenture;

(viii)a twenty-second supplemental trust indenture dated as of July 29, 2011 amending the definition of “Canadian GAAP” in the Trust Indenture;

(ix)a twenty-third supplemental trust indenture dated as of September 26, 2011 relating to the issuance of Series 23 Notes in the aggregate principal amount of $1,000,000,000, of which $300,000,000 was drawn down on September 26, 2011, pursuant to the Trust Indenture;

(x)a twenty-fourth supplemental trust indenture dated as of December 22, 2011 relating to the issuance of Series 24 Notes in the aggregate principal amount of $1,000,000,000, of which $100,000,000 was drawn down on December 22, 2011, and $125,000,000 was drawn down on May 22, 2012, pursuant to the Trust Indenture;

(xi)a twenty-sixth supplemental trust indenture dated as of July 31, 2012 relating to the issuance of Series 26 Notes in the aggregate principal amount of $1,000,000,000, of which $75,000,000 was drawn down on July 31, 2012, and $235,000,000 was drawn down on August 16, 2012, pursuant to the Trust Indenture;

(xii)a twenty-ninth supplemental trust indenture dated as of October 9, 2013 relating to the issuance of Series 29 Notes in the aggregate principal amount of $1,000,000,000, of which $435,000,000 was drawn down on October 9, 2013, pursuant to the Trust Indenture;

(xiii)a thirtieth supplemental trust indenture dated as of January 29, 2014 relating to the issuance of Series 30 Notes in the aggregate principal amount of $1,000,000,000, of which $50,000,000 was drawn down on January 29, 2014, pursuant to the Trust Indenture;

(xiv)a thirty-second supplemental trust indenture dated as of June 6, 2014 relating to the issuance of Series 32 Notes in the aggregate principal amount of $1,000,000,000 of which $350,000,000 was drawn down on June 6, 2014, pursuant to the Trust Indenture;

(xv)a thirty-fifth supplemental trust indenture dated as of February 24, 2016 relating to the issuance of Series 35 Notes in the aggregate principal amount of $1,000,000,000 of which $500,000,000 was drawn down on February 24, 2016, pursuant to the Trust Indenture;

(xvi)a thirty-sixth supplemental trust indenture dated as of February 24, 2016 relating to the issuance of Series 36 Notes in the aggregate principal amount of $1,000,000,000 of which $350,000,000 was drawn down on February 24, 2016, pursuant to the Trust Indenture;

(xvii)a thirty-eighth supplemental trust indenture dated as of November 18, 2016 relating to the issuance of Series 38 Notes in the aggregate principal amount of $1,000,000,000 of which $450,000,000 was drawn down on November 18, 2016, pursuant to the Trust Indenture;

(xviii)a fortieth supplemental trust indenture dated as of June 26, 2018 relating to the issuance of Series 40 Notes in the aggregate principal amount of $1,000,000,000 of which $350,000,000 was drawn down on June 26, 2018, pursuant to the Trust Indenture;

(xix)a forty-first supplemental trust indenture dated as of June 26, 2018 relating to the issuance of Series 41 Notes in the aggregate principal amount of $1,000,000,000 of which $750,000,000 was drawn down on June 26, 2018, pursuant to the Trust Indenture;

(xx)a forty-second supplemental trust indenture dated as of April 5, 2019 relating to

the issuance of Series 42 Notes in the aggregate principal amount of $1,000,000,000 of which $700,000,000 was drawn down on April 5, 2019, pursuant to the Trust Indenture;

(xxi)a forty-third supplemental trust indenture dated as of April 5, 2019 relating to the issuance of Series 43 Notes in the aggregate principal amount of $1,000,000,000 of which $550,000,000 was drawn down on April 5, 2019, pursuant to the Trust Indenture;

(xxii)a forty-fourth supplemental trust indenture dated as of April 5, 2019 relating to the issuance of Series 44 Notes in the aggregate principal amount of $1,000,000,000 of which $250,000,000 was drawn down on April 5, 2019, pursuant to the Trust Indenture;

(xxiii)a forty-fifth supplemental trust indenture dated as of February 28, 2020 relating to the issuance of Series 45 Notes in the aggregate principal amount of $1,000,000,000 of which $400,000,000 was drawn down on February 28, 2020, pursuant to the Trust Indenture;

(xxiv)a forty-sixth supplemental trust indenture dated as of February 28, 2020 relating to the issuance of Series 46 Notes in the aggregate principal amount of $1,000,000,000 of which $400,000,000 was drawn down on February 28, 2020, pursuant to the Trust Indenture;

(xxv)a forty-seventh supplemental trust indenture dated as of February 28, 2020 relating to the issuance of Series 47 Notes in the aggregate principal amount of $1,000,000,000 of which $300,000,000 was drawn down on February 28, 2020 and $200,000,000 was drawn on October 9, 2020, in each case pursuant to the Trust Indenture;

(xxvi)a forty-ninth supplemental trust indenture dated as of October 9, 2020 relating to the issuance of Series 49 Notes in the aggregate principal amount of $1,000,000,000 of which $400,000,000 was drawn down on October 9, 2020, pursuant to the Trust Indenture;

(xxvii)a fiftieth supplemental trust indenture dated as of September 17, 2021 relating to the issuance of Series 50 Notes in the aggregate principal amount of $1,000,000,000 of which $450,000,000 was drawn down on September 17, 2021, pursuant to the Trust Indenture;

(xxviii)a fifty-first supplemental trust indenture dated as of September 17, 2021 relating to the issuance of Series 51 Notes in the aggregate principal amount of $1,000,000,000 of which $450,000,000 was drawn down on September 17, 2021, pursuant to the Trust Indenture;

(xxix)a fifty-second supplemental trust indenture dated as of October 27, 2022 relating to the issuance of Series 52 Notes in the aggregate principal amount of $1,000,000,000 of which $750,000,000 was drawn down on October 27, 2022, pursuant to the Trust Indenture;

(xxx)a fifty-third supplemental trust indenture dated as of January 27, 2023 relating to the issuance of Series 53 Notes in the aggregate principal amount of $1,000,000,000 of which $300,000,000 was drawn down on January 27, 2023,

pursuant to the Trust Indenture;

(xxxi)a fifty-fourth supplemental trust indenture dated as of January 27, 2023 relating to the issuance of Series 54 Notes in the aggregate principal amount of $1,000,000,000 of which $450,000,000 was drawn down on January 27, 2023, pursuant to the Trust Indenture; and

(xxxii)a fifty-fifth supplemental trust indenture dated as of January 27, 2023 relating to the issuance of Series 55 Notes in the aggregate principal amount of $1,000,000,000 of which $300,000,000 was drawn down on January 27, 2023, pursuant to the Trust Indenture.

Each of these supplemental trust indentures supplement the terms of the Trust Indenture, which contains customary covenants and representations by Hydro One Inc. for the public issuance of debt securities in the Canadian market.

(b) a dealer agreement (the “Dealer Agreement”) dated June 3, 2022 between Hydro One Inc. and BMO Nesbitt Burns Inc., Casgrain & Company Limited, CIBC World Markets Inc., Desjardins Securities Inc., Laurentian Bank Securities Inc., National Bank Financial Inc., RBC Dominion Securities Inc., Scotia Capital Inc. and TD Securities Inc. (collectively, the “Dealers”), relating to the public offering of unsecured medium term notes of Hydro One Inc. in a maximum aggregate principal amount of up to $4,000,000,000. The Dealer Agreement provides for the appointment of the Dealers as non-exclusive agents of Hydro One Inc. to solicit, from time to time, offers to purchase its medium term notes in Canada, the United States and, in certain circumstances, other jurisdictions.

Copies of the foregoing material agreements have been filed with the Canadian securities regulatory authorities and are available on SEDAR at www.sedar.com.

LEGAL PROCEEDINGS AND REGULATORY ACTIONS

The Company is from time to time involved in legal proceedings of a nature considered normal to its business. Except as disclosed below, Hydro One believes that none of the litigation in which it is currently involved, or has been involved since the beginning of the most recently completed financial year, individually or in the aggregate, is material to its consolidated financial condition or results of operations. The Company is not subject to any material regulatory actions.

In connection with the reorganization of Ontario Hydro, Hydro One Inc. and certain of its subsidiaries succeeded Ontario Hydro as party to various pending legal proceedings relating to the businesses, assets, real estate and employees transferred to them. Hydro One Inc. and certain of its subsidiaries also assumed responsibility for future claims relating to the businesses, assets, real estate and employees acquired by them respectively and arising out of events occurring prior to, as well as after, April 1, 1999. In addition to claims assumed by the Company, it is, from time to time, named as a defendant in legal actions arising in the normal course of business. There are currently no actions that are outstanding which are expected to have a material adverse effect on the Company.

See the Annual MD&A under the heading “Risk Management and Risk Factors – Risks Relating to Hydro One’s Business – Litigation Risks” for more information.

INTEREST OF EXPERTS

KPMG LLP, Chartered Professional Accountants, located at 333 Bay Street, Suite 4600, Bay Adelaide Centre, Toronto, Ontario M5H 2S5, is the auditor of Hydro One Inc. and has audited the consolidated financial statements of Hydro One Inc. as at and for the years ended December 31, 2022 and 2021. KPMG LLP has confirmed that it is independent of Hydro One Inc. within the meaning of the relevant rules and related interpretations prescribed by the relevant professional bodies in Canada and any applicable legislation or regulation, and also that they are independent accountants with respect to Hydro One Inc. under all relevant U.S. professional and regulatory standards.

TRUSTEE AND REGISTRAR

The trustee and registrar for Hydro One Inc.’s debt securities is Computershare Trust Company of Canada, located in Toronto, Ontario. The U.S. trustee and registrar for certain of Hydro One Inc.’s debt securities is Computershare Trust Company, N.A., located in New York, New York.

ADDITIONAL INFORMATION

Additional information relating to Hydro One Inc. may be found on SEDAR at www.sedar.com.

Additional financial information is provided in the Annual MD&A and in the consolidated financial statements and notes thereto of Hydro One Inc. for 2022.

STATEMENT OF EXECUTIVE COMPENSATION

In March 2019, Hydro One Inc. was granted exemptive relief (the “Executive Compensation Exemptive Relief”) by securities regulatory authorities in each of the provinces of Canada, exempting Hydro One Inc. from the requirement to provide executive compensation disclosure required by securities laws in its annual information form, for so long as: (i) Hydro One Inc. files such executive compensation disclosure as a stand-alone document with the securities regulatory authorities in each of the provinces of Canada no later than 140 days after its most recently completed financial year and (ii) Hydro One Inc. includes in its annual information form in respect of a financial year a notice that its executive compensation disclosure in respect of that financial year, when filed, is deemed to be incorporated by reference in its annual information form.

In accordance with the Executive Compensation Exemptive Relief, the Statement of Executive Compensation for Hydro One Inc. in respect of 2022, when filed with the securities regulatory authorities in each of the provinces of Canada, will be deemed to be incorporated by reference into and form an integral part of this annual information form. The Statement of Executive Compensation for Hydro One Inc. in respect of 2022, when filed, will be available under Hydro One Inc.’s profile on SEDAR at www.sedar.com.

HYDRO ONE INC.

MANAGEMENT’S REPORT

The Consolidated Financial Statements, Management’s Discussion and Analysis (MD&A) and related financial information have been prepared by the management of Hydro One Inc. (Hydro One or the Company). Management is responsible for the integrity, consistency and reliability of all such information presented. The Consolidated Financial Statements for the year ended December 31, 2022 and accompanying notes thereto (together, the Consolidated Financial Statements) have been prepared in accordance with United States Generally Accepted Accounting Principles and applicable securities legislation. The MD&A has been prepared in accordance with National Instrument 51-102.

The preparation of the Consolidated Financial Statements and information in the MD&A involves the use of estimates and assumptions based on management’s judgment, particularly when transactions affecting the current accounting period cannot be finalized with certainty until future periods. Estimates and assumptions are based on historical experience, current conditions and various other assumptions believed to be reasonable in the circumstances, with critical analysis of the significant accounting policies followed by the Company as described in Note 2 to the Consolidated Financial Statements. The preparation of the Consolidated Financial Statements and the MD&A includes information regarding the estimated impact of future events and transactions. The MD&A also includes information regarding sources of liquidity and capital resources, operating trends, risks and uncertainties. Actual results in the future may differ materially from the present assessment of this information because future events and circumstances may not occur as expected.

Management is responsible for establishing and maintaining adequate disclosure controls and procedures and internal control over financial reporting as described in the annual MD&A. Management evaluated the effectiveness of the design and operation of disclosure controls and procedures, and internal control over financial reporting based on the framework and criteria established in the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management concluded that the Company’s internal control over financial reporting was effective at a reasonable level of assurance as at December 31, 2022. As required, the results of that evaluation were reported to the Audit Committee of the Hydro One Board of Directors and the external auditors.

The Consolidated Financial Statements have been audited by KPMG LLP, independent external auditors appointed by the shareholders of the Company. The external auditors’ responsibility is to express their opinion on whether the Consolidated Financial Statements are fairly presented in all material respects in conformity with United States Generally Accepted Accounting Principles. The Report of Independent Registered Public Accounting Firm outlines the scope of their examination and their opinion.

The Hydro One Board of Directors, through its Audit Committee, is responsible for ensuring that management fulfills its responsibilities for financial reporting and internal control over financial reporting and disclosure. The Audit Committee of Hydro One met periodically with management, the internal auditors and the external auditors to satisfy itself that each group had properly discharged its respective responsibility with respect to the Consolidated Financial Statements before recommending approval by the Board of Directors. The external auditors had direct and full access to the Audit Committee, with and without the presence of management, to discuss their audit findings.

On behalf of Hydro One’s management:



David Lebeter						Christopher Lopez
President and Chief Executive Officer						Chief Financial Officer


			1

HYDRO ONE INC.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the Shareholder and Board of Directors of Hydro One Inc.

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Hydro One Inc. (the Company) as of December 31, 2022 and 2021, the related consolidated statements of operations and comprehensive income, changes in equity, and cash flows for each of the years in the two-year period ended December 31, 2022, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and the results of its operations and its cash flows for each of the years in the two-year period ended December 31, 2022, in conformity with U.S. generally accepted accounting principles.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audits, we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion.

Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of a critical audit matter does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

Evaluation of regulatory assets and liabilities and the impact of rate regulation on the consolidated financial statements

As discussed in Note 2 to the consolidated financial statements, the Company accounts for its regulated operations in accordance with Financial Accounting Standards Board Accounting Standard Codification Topic 980, Regulated Operations (ASC 980). Under ASC 980, the actions of the Company’s regulator may result in the recognition of revenue and costs in time periods that are different than non-rate-regulated enterprises. When this occurs, the Company records incurred and allowed costs that it has assessed are probable of recovery in future electricity rates as regulatory assets or property, plant and equipment. Obligations imposed or probable to be imposed by the regulator to refund previously collected revenue or expenditure of revenue collected from customers on future costs are recorded as regulatory liabilities. As disclosed in Note 12 to the consolidated financial statements, as of December 31, 2022, the Company’s regulatory assets were $3,153 million and regulatory liabilities were $1,262 million.

We identified the evaluation of regulatory assets and liabilities and the impact of rate regulation as a critical audit matter. Accounting for regulated operations under ASC 980 affects multiple financial statement accounts and disclosures in the Company’s consolidated financial statements. Assessing the accounting for regulated operations requires industry knowledge and significant auditor judgment due to interpretations of regulatory decisions and judgments involved in evaluating the Company’s assessment of the probability associated with recovery of regulatory assets and property, plant and equipment, and imposition of regulatory liabilities.

The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s regulatory accounting process. This included controls over the evaluation of the probability of (1) the recovery in future rates of costs deferred as regulatory assets, and (2) a refund of previously collected revenue or expenditure of revenue collected from customers on future costs that should be reported as regulatory liabilities, and controls over the monitoring and evaluation of regulatory developments that may affect the probability of recovering costs in future rates or imposing of regulatory liabilities. We evaluated the Company’s assessment of the probability of


			2

HYDRO ONE INC.

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

recovery of the carrying amount of regulatory assets and property, plant and equipment and the imposition of regulatory liabilities, through consideration of selected on-going regulatory proceedings and decisions. For a selection of regulatory proceedings and decisions, we read the Company’s assessment and interpretations. For a selection of regulatory assets and liabilities, we recalculated the amounts recorded based on methodologies approved by the regulator and agreed the data used in the calculations to the Company’s underlying books and records. We compared the amounts calculated by the Company to the amounts recorded in the consolidated financial statements.

Chartered Professional Accountants, Licensed Public Accountants

We have served as the Company’s auditor since 2008.

Toronto, Canada

February 13, 2023


			3

HYDRO ONE INC.

CONSOLIDATED STATEMENTS OF OPERATIONS AND COMPREHENSIVE INCOME

For the years ended December 31, 2022 and 2021



Year ended December 31 (millions of Canadian dollars, except per share amounts)	2022	2021
Revenues
Distribution (includes $288 related party revenues; 2021 - $286) (Note 28)	5,660	5,359
Transmission (includes $2,066 related party revenues; 2021 - $1,835) (Note 28)	2,080	1,826
	7,740	7,185

Costs
Purchased power (includes $2,396 related party costs; 2021 - $2,252) (Note 28)	3,724	3,579
Operation, maintenance and administration (Note 28)	1,226	1,081
Depreciation, amortization and asset removal costs (Note 4)	957	913
	5,907	5,573

Income before financing charges and income tax expense	1,833	1,612
Financing charges (Note 5)	478	453

Income before income tax expense	1,355	1,159
Income tax expense (Note 6)	290	179
Net income	1,065	980

Other comprehensive income (Note 7)	19	16
Comprehensive income	1,084	996

Net income attributable to:
Noncontrolling interest (Note 27)	8	8

Common shareholder	1,057	972
	1,065	980

Comprehensive income attributable to:
Noncontrolling interest (Note 27)	8	8

Common shareholder	1,076	988
	1,084	996

Earnings per common share (Note 25)
Basic	$7,431	$6,834
Diluted	$7,431	$6,834

See accompanying notes to Consolidated Financial Statements.


			4

HYDRO ONE INC.

CONSOLIDATED BALANCE SHEETS

At December 31, 2022 and 2021


As at December 31 (millions of Canadian dollars)	2022	2021
Assets
Current assets:
Cash and cash equivalents	458	499
Accounts receivable (Note 8)	765	697
Due from related parties (Note 28)	453	399
Other current assets (Note 9)	276	301
	1,952	1,896

Property, plant and equipment (Note 10)	24,970	23,748
Other long-term assets:
Regulatory assets (Note 12)	2,964	3,561
Deferred income tax assets (Note 6)	4	10
Intangible assets (Note 11)	605	567
Goodwill	373	373
Other assets (Note 13)	422	66
	4,368	4,577
Total assets	31,290	30,221

Liabilities
Current liabilities:

Short-term notes payable (Notes 16, 18)	1,374	1,045
Long-term debt payable within one year (Notes 16, 17, 18)	733	603
Accounts payable and other current liabilities (Note 14)	1,250	1,042
Due to related parties (Note 28)	251	255
	3,608	2,945

Long-term liabilities:
Long-term debt (Notes 16, 17)	12,606	12,593
Regulatory liabilities (Note 12)	1,123	362
Deferred income tax liabilities (Note 6)	713	367
Other long-term liabilities (Note 15)	1,558	2,694
	16,000	16,016
Total liabilities	19,608	18,961

Contingencies and Commitments (Notes 30, 31)
Subsequent Events (Note 33)

Noncontrolling interest subject to redemption (Note 27)	20	20

Equity
Common shares (Note 23)	2,957	2,957
Retained earnings	8,634	8,229
Accumulated other comprehensive income (loss)	5	(14)
Hydro One shareholder’s equity	11,596	11,172

Noncontrolling interest (Note 27)	66	68
Total equity	11,662	11,240
	31,290	30,221

See accompanying notes to Consolidated Financial Statements.

On behalf of the Board of Directors:



Timothy Hodgson						Stacey Mowbray
Chair						Chair, Audit Committee


			5

HYDRO ONE INC.

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

For the years ended December 31, 2022 and 2021


Year ended December 31, 2022 (millions of Canadian dollars)	Common Shares	Retained Earnings	Accumulated Other Comprehensive Income	Hydro One Shareholder’s Equity	Non- controlling Interest (Note 27)	Total Equity
January 1, 2022	2,957	8,229	(14)	11,172	68	11,240
Net income	—	1,057	—	1,057	6	1,063
Other comprehensive income (Note 7)	—	—	19	19	—	19
Distributions to noncontrolling interest (Note 27)	—	—	—	—	(8)	(8)
Dividends on common shares (Note 24)	—	(652)	—	(652)	—	(652)
December 31, 2022	2,957	8,634	5	11,596	66	11,662


Year ended December 31, 2021 (millions of Canadian dollars)	Common Shares	Retained Earnings	Accumulated Other Comprehensive Loss	Hydro One Shareholder’s Equity	Non- controlling Interest (Note 27)	Total Equity
January 1, 2021	2,957	7,877	(30)	10,804	72	10,876
Net income	—	972	—	972	6	978
Other comprehensive income (Note 7)	—	—	16	16	—	16
Distributions to noncontrolling interest (Note 27)	—	—	—	—	(10)	(10)

Dividends on common shares (Note 24)	—	(620)	—	(620)	—	(620)

December 31, 2021	2,957	8,229	(14)	11,172	68	11,240

See accompanying notes to Consolidated Financial Statements.


			6

HYDRO ONE INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

For the years ended December 31, 2022 and 2021


Year ended December 31 (millions of Canadian dollars)	2022	2021
Operating activities
Net income	1,065	980
Environmental expenditures	(33)	(30)
Adjustments for:
Depreciation and amortization (Note 4)	822	806
Regulatory assets and liabilities	44	70
Deferred income tax expense	261	155
Other	32	58
Changes in non-cash balances related to operations (Note 29)	(6)	69
Net cash from operating activities	2,185	2,108

Financing activities
Long-term debt issued	750	900
Long-term debt repaid	(603)	(804)
Short-term notes issued	6,335	4,150
Short-term notes repaid	(6,000)	(3,905)


Dividends paid (Note 24)	(652)	(620)
Distributions paid to noncontrolling interest	(10)	(8)

Costs to obtain financing	(10)	(7)
Net cash used in financing activities	(190)	(294)

Investing activities
Capital expenditures (Note 29)
Property, plant and equipment	(1,942)	(1,908)
Intangible assets	(120)	(142)
Capital contributions received (Note 29)	12	14

Other	14	9
Net cash used in investing activities	(2,036)	(2,027)

Net change in cash and cash equivalents	(41)	(213)
Cash and cash equivalents, beginning of year	499	712
Cash and cash equivalents, end of year	458	499

See accompanying notes to Consolidated Financial Statements.


			7

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

1. DESCRIPTION OF THE BUSINESS

Hydro One Inc. (Hydro One or the Company) was incorporated on December 1, 1998, under the Business Corporations Act (Ontario) and is wholly-owned by Hydro One Limited. The principal businesses of Hydro One are the transmission and distribution of electricity to customers within Ontario.

Rate Setting

The Company's transmission business consists of the transmission system operated by its subsidiaries, which include Hydro One Networks Inc. (Hydro One Networks) and Hydro One Sault Ste. Marie LP (HOSSM), as well as an approximately 66% interest in B2M Limited Partnership (B2M LP), and an approximately 55% interest in Niagara Reinforcement Limited Partnership (NRLP).

Hydro One’s distribution business consists of the distribution systems operated by its subsidiaries, Hydro One Networks, and Hydro One Remote Communities Inc. (Hydro One Remotes).

Transmission

On March 7, 2019, the Ontario Energy Board (OEB) issued its reconsideration decision (DTA Decision) with respect to Hydro One's rate-setting treatment of the benefits of the deferred tax asset (DTA) resulting from the transition from the payments in lieu of tax regime to tax payments under the federal and provincial tax regimes. On July 16, 2020, the Ontario Divisional Court rendered its decision (ODC Decision) on the Company's appeal of the OEB's DTA Decision. On April 8, 2021, the OEB rendered its decision and order (DTA Implementation Decision) regarding the recovery of the DTA amounts allocated to ratepayers for the 2017 to 2022 period. See Note 12 - Regulatory Assets and Liabilities for additional details.

On April 23, 2020, the OEB rendered its decision on Hydro One Networks' 2020-2022 transmission rate application (2020-2022 Transmission Decision). On July 16, 2020, the OEB issued its final rate order for the 2020-2022 transmission rates approving a revenue requirement of $1,630 million, $1,701 million and $1,772 million for 2020, 2021 and 2022, respectively. On July 30, 2020, the OEB issued its decision for Uniform Transmission Rates (UTRs). The 2020 UTRs that were put in place on an interim basis on January 1, 2020 continued for the remainder of 2020 in light of the COVID-19 pandemic. On December 17, 2020, the OEB issued its decision and order setting the final 2021 UTRs effective January 1, 2021, which included the approval of a two-year disposition period for Hydro One Network's 2020 foregone revenue including interest, beginning on January 1, 2021.

On July 31, 2019, B2M LP filed a transmission rate application for 2020-2024. On January 16, 2020, the OEB approved the 2020 base revenue requirement of $33 million, and a revenue cap escalator index for 2021 to 2024.

On October 25, 2019, NRLP filed its revenue cap incentive rate application for 2020-2024. On December 19, 2019, the OEB approved NRLP’s proposed 2020 revenue requirement of $9 million on an interim basis effective January 1, 2020. On April 9, 2020, final OEB approval was received.

HOSSM is under a 10-year deferred rebasing period for years 2017-2026, as approved in the OEB Mergers Acquisitions Amalgamations and Divestitures (MAAD) decision dated October 13, 2016.

On August 5, 2021 Hydro One Networks filed a custom joint rate application (JRAP) for 2023-2027 transmission and distribution rates. On November 29, 2022 the OEB approved the application and issued its rate order for 2023-2027 transmission rates approving revenue requirement for Hydro One Networks' Transmission Business of $1,952 million for 2023, $2,073 million for 2024, $2,168 million for 2025, $2,277 million for 2026 and $2,362 million for 2027.

Distribution

In March 2017, Hydro One Networks filed an application with the OEB for 2018-2022 distribution rates. On March 7, 2019, the OEB rendered its decision on the distribution rates application. In accordance with the OEB decision, the Company filed its draft rate order reflecting updated revenue requirements of $1,459 million for 2018, $1,498 million for 2019, $1,532 million for 2020, $1,578 million for 2021, and $1,624 million for 2022. On June 11, 2019, the OEB approved the rate order confirming these updated revenue requirements.

On August 28, 2017, Hydro One Remotes filed a distribution rate application for 2018-2022. On April 12, 2018 the OEB approved Hydro One Remotes' 2018 revenue requirement of $54 million effective May 1, 2018, with a price cap escalator index for 2019-2022.

On November 3, 2020, Hydro One Remote Communities filed an application with the OEB seeking approval for a 2% increase to 2020 base rates, effective May 1, 2021, which was subsequently updated to 2.2% in accordance with the OEB’s 2021 inflation parameters for electricity distributors issued on November 9, 2020. On March 25, 2021, the OEB approved Hydro One Remote Communities’ application for rates and other charges to be effective May 1, 2021.


			8

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

the OEB’s annually updated inflation parameters for electricity distributors for 2022. On March 24, 2022, the OEB approved the application for rates and other charges which became effective on May 1, 2022.

On August 5, 2021 Hydro One Networks filed a JRAP for 2023-2027 transmission and distribution rates. On November 29, 2022, as part of the approval of the JRAP application, the OEB issued its rate order for 2023-2027 distribution rates approving revenue requirement for Hydro One Networks' Distribution Business of $1,727 million for 2023, $1,813 million for 2024, $1,886 million for 2025, $1,985 million for 2026 and $2,071 million for 2027.

2. SIGNIFICANT ACCOUNTING POLICIES

Basis of Consolidation and Presentation

These consolidated financial statements (Consolidated Financial Statements) include the accounts of the Company and its subsidiaries. Inter-company transactions and balances have been eliminated.

Basis of Accounting

These Consolidated Financial Statements are prepared and presented in accordance with United States (US) Generally Accepted Accounting Principles (GAAP) and in Canadian dollars.

Use of Management Estimates

The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenues, expenses, gains and losses during the reporting periods. Management evaluates these estimates on an ongoing basis based upon historical experience, current conditions, and assumptions believed to be reasonable at the time the assumptions are made, with any adjustments being recognized in results of operations in the period they arise. Significant estimates relate to unbilled revenues, regulatory assets and regulatory liabilities, environmental liabilities, pension benefits, and post-retirement and post-employment benefits. Actual results may differ significantly from these estimates.

Regulatory Accounting

The OEB has the general power to include or exclude revenues, costs, gains or losses in the rates of a specific period, resulting in a change in the timing of accounting recognition from that which would have been applied in an unregulated company. Such change in timing involves the application of rate-regulated accounting in accordance with Financial Accounting Standards Board Accounting Standard Codification Topic 980, Regulated Operations. within the Company's regulated business, giving rise to the recognition of regulatory assets and liabilities. The Company’s regulatory assets represent certain amounts receivable from future electricity customers and costs that have been deferred for accounting purposes because it is probable that they will be recovered in future rates. In addition, the Company has recorded regulatory liabilities that generally represent amounts that are refundable to electricity customers in future rates. The Company continually assesses the likelihood of recovery of each of its regulatory assets and continues to believe that it is probable that the OEB will include its regulatory assets and liabilities in setting future rates. If, at some future date, the Company judges that it is no longer probable that the OEB will include a regulatory asset or liability in setting future rates, the appropriate carrying amount would be reflected in results of operations prospectively from the date the Company’s assessment is made, unless the change meets the requirements for a subsequent event adjustment.

Cash and Cash Equivalents

Cash and cash equivalents include cash and short-term investments with an original maturity of three months or less.

Revenue Recognition

Transmission revenues predominantly consist of transmission tariffs, which are collected through OEB-approved UTRs which are applied against the monthly peak demand for electricity across Hydro One's high-voltage network. OEB-approved UTRs are based on an approved revenue requirement that includes a rate of return. The transmission tariffs are designed to recover revenues necessary to support the Company's transmission system with sufficient capacity to accommodate the maximum expected demand which is influenced by weather and economic conditions. Transmission revenues are recognized as electricity is transmitted and delivered to customers.

Distribution revenues attributable to the delivery of electricity are based on OEB-approved distribution rates and are recognized on an accrual basis and include billed and unbilled revenues. Billed revenues are based on electricity delivered as measured from customer meters. At the end of each month, electricity delivered to customers since the date of the last billed meter reading is estimated, and the corresponding unbilled revenue is recorded. The unbilled revenue estimate is affected by energy consumption, weather, and changes in the composition of customer classes.

Revenues also include amounts related to sales of other services and equipment. Such revenue is recognized as services are rendered or as equipment is delivered. Revenues are recorded net of indirect taxes.


			9

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Accounts Receivable and Allowance for Doubtful Accounts

Billed accounts receivable are recorded at the invoiced amount, net of allowance for doubtful accounts. Unbilled accounts receivable are recorded at their estimated value, net of allowance for doubtful accounts. Overdue amounts related to regulated billings bear interest at OEB-approved rates. The allowance for doubtful accounts reflects the Company’s current lifetime expected credit losses (CECL) for all accounts receivable balances. The Company estimates the CECL by applying internally developed loss rates to all outstanding receivable balances by aging category on an undiscounted basis. Loss rates applied to the accounts receivable balances are based on historical overdue balances, customer payments and write-offs, which may be further supplemented from time to time to reflect management's best estimate of the loss. Accounts receivable are written-off against the allowance when they are deemed uncollectible. The allowance for doubtful accounts is affected by changes in volume, prices and economic conditions.

Noncontrolling interest

Noncontrolling interest represents the portion of equity ownership in subsidiaries that is not attributable to shareholders of Hydro One. Noncontrolling interest is initially recorded at fair value and subsequently the amount is adjusted for the proportionate share of net income and other comprehensive income (OCI) or other comprehensive loss (OCL) attributable to the noncontrolling interest and any dividends or distributions paid to the noncontrolling interest.

If a transaction results in the acquisition of all, or part, of a noncontrolling interest in a subsidiary, the acquisition of the noncontrolling interest is accounted for as an equity transaction. No gain or loss is recognized in consolidated net income or comprehensive income as a result of changes in the noncontrolling interest, unless a change results in the loss of control by the Company.

Income Taxes

Income taxes are accounted for using the asset and liability method. Current tax assets and liabilities are recognized based on the taxes payable or refundable on the current and prior year’s taxable income. Current and deferred income taxes are computed based on the tax rates and tax laws enacted as at the balance sheet date. Tax benefits associated with income tax positions are recorded only when the more-likely-than-not recognition threshold is satisfied and are measured at the largest amount of benefit that has a greater than 50% likelihood of being realized upon settlement. Management evaluates each position based solely on the technical merits and facts and circumstances of the position, assuming the position will be examined by a taxing authority having full knowledge of all relevant information. Significant management judgment is required to determine recognition thresholds and the related amount of tax benefits to be recognized in the Consolidated Financial Statements. Management re-evaluates tax positions each period using new information about recognition or measurement as it becomes available.

Deferred Income Taxes

Deferred income tax assets and liabilities are recognized on all temporary differences between the tax bases and carrying amounts of assets and liabilities, including the carry forward unused tax credits and tax losses to the extent that it is more-likely-than-not that these deductions, credits, and losses can be utilized. Deferred income tax assets and liabilities are measured at the tax rates that are expected to apply in the period when the liability is settled or the asset is realized, based on the tax rates and tax laws that have been enacted as at the balance sheet date.

Deferred income taxes associated with its regulated operations which are considered to be more-likely-than-not to be recoverable or refunded in the future regulated rates charged to customers are recognized as deferred income tax regulatory assets and liabilities with an offset to deferred income tax expense.

Investment tax credits are recorded as a reduction of the related expenses or income tax expense in the current or future period to the extent it is more likely than not that the credits can be utilized.

Management reassesses the deferred income tax assets at each balance sheet date and reduces the amount to the extent that it is more likely than not that the deferred income tax asset will not be realized. Previously unrecognized deferred income tax assets are reassessed at each balance sheet date and are recognized to the extent that it has become more likely than not that the tax benefit will be realized.

Materials and Supplies

Materials and supplies represent consumables, small spare parts and construction materials held for internal construction and maintenance of property, plant and equipment. These assets are carried at average cost less any impairments recorded.

Property, Plant and Equipment

Property, plant and equipment is recorded at original cost, net of customer contributions, and any accumulated impairment losses. The cost of additions, including betterments and replacement asset components, is included on the consolidated balance sheets as property, plant and equipment.

The original cost of property, plant and equipment includes direct materials, direct labour (including employee benefits), contracted services, attributable capitalized financing costs, asset retirement costs, and direct and indirect overheads that are


			10

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

related to the capital project or program. Indirect overheads include a portion of corporate costs such as finance, treasury, human resources, and information technology. Overhead costs, including corporate functions and field services costs, are capitalized on a fully allocated basis, consistent with an OEB-approved methodology.

Property, plant and equipment in service consists of transmission, distribution, communication, administration and service assets and land easements. Property, plant and equipment also includes future use assets, such as land, major components and spare parts, and capitalized project development costs associated with deferred capital projects.

Transmission

Transmission assets include assets used for the transmission of high-voltage electricity, such as transmission lines, support structures, foundations, insulators, connecting hardware and grounding systems, and assets used to step up the voltage of electricity from generating stations for transmission and to step down voltages for distribution, including transformers, circuit breakers and switches.

Distribution

Distribution assets include assets related to the distribution of low-voltage electricity, including lines, poles, switches, transformers, protective devices and metering systems.

Communication

Communication assets include fibre optic and microwave radio systems, optical ground wire, towers, telephone equipment and associated buildings.

Administration and Service

Administration and service assets include administrative buildings, personal computers, transport and work equipment, tools and other minor assets.

Easements

Easements include a statutory easement for the use of transmission corridor and related abutting lands pursuant to Part IX.1 of the Electricity Act, 1998 (Ontario) (Electricity Act), as well as other land rights for occupation.

Intangible Assets

Intangible assets separately acquired or internally developed are measured on initial recognition at cost, which comprises purchased software, direct labour (including employee benefits), consulting, engineering, overheads and attributable capitalized financing charges. Following initial recognition, intangible assets are carried at cost, net of any accumulated amortization and accumulated impairment losses. The Company’s intangible assets primarily represent major computer applications.

Capitalized Financing Costs

Capitalized financing costs represent interest costs attributable to the construction of property, plant and equipment or development of intangible assets. The financing cost of attributable borrowed funds is capitalized as part of the acquisition cost of such assets. The capitalized financing costs are a reduction of financing charges recognized in the consolidated statements of operations and comprehensive income. Capitalized financing costs are calculated using the Company’s weighted average effective cost of debt.

Construction and Development in Progress

Construction and development in progress consists of the capitalized cost of constructed assets that are not yet complete and which have not yet been placed in service.

Depreciation and Amortization

The cost of property, plant and equipment and intangible assets is depreciated or amortized on a straight-line basis based on the estimated remaining service life of each asset category, except for transport and work equipment, which is depreciated on a declining balance basis.

The Company periodically initiates an external independent review of its property, plant and equipment and intangible asset depreciation and amortization rates, as required by the OEB. Any changes arising from OEB approval of such a review are implemented on a remaining service life basis, consistent with their inclusion in electricity rates. The most recent reviews resulted in changes to rates effective January 1, 2015 and January 1, 2020 for Hydro One Networks’ distribution and transmission


			11

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

businesses, respectively. A summary of average service lives and depreciation and amortization rates for the various classes of assets is included below:


	Average	Rate
	Service Life	Range	Average
Property, plant and equipment:
Transmission	55 years	1% - 3%	2	%
Distribution	46 years	1% - 7%	2	%
Communication	16 years	1% - 15%	5	%
Administration and service	25 years	1% - 20%	3	%
Intangible assets	10 years	10%	7	%

In accordance with group depreciation practices, the original cost of property, plant and equipment, or major components thereof, and intangible assets that are normally retired, is charged to accumulated depreciation, with no gain or loss being reflected in results of operations. Where a disposition of property, plant and equipment occurs through sale, a gain or loss is calculated based on proceeds and such gain or loss is included in depreciation expense.

Acquisitions and Goodwill

The Company accounts for business acquisitions using the acquisition method of accounting and, accordingly, the assets and liabilities of the acquired entities are primarily measured at their estimated fair value at the date of acquisition. Costs associated with pending acquisitions are expensed as incurred. Goodwill represents the cost of acquired companies that is in excess of the fair value of the net identifiable assets acquired at the acquisition date. Goodwill is not included in rate base.

Goodwill is evaluated for impairment on an annual basis, or more frequently if circumstances require. The Company performs a qualitative assessment to determine whether it is more likely than not that the fair value of the applicable reporting unit is less than its carrying amount. If the Company determines, as a result of its qualitative assessment, that it is not more likely than not that the fair value of the applicable reporting unit is less than its carrying value, no further testing is required. If the Company determines, as a result of its qualitative assessment, that it is more likely than not that the fair value of the applicable reporting unit is less than its carrying amount, a quantitative goodwill impairment assessment is performed. The quantitative assessment compares the fair value of the applicable reporting unit to its carrying amount, including goodwill. If the fair value of goodwill is less than the carrying amount, an impairment loss is recorded as a reduction to goodwill and as a charge to results of operations.

Based on the assessment performed as at September 30, 2022 and with no significant events since, the Company has concluded that goodwill was not impaired at December 31, 2022.

Long-Lived Asset Impairment

When circumstances indicate the carrying value of long-lived assets may not be recoverable, the Company evaluates whether the carrying value of such assets, excluding goodwill, has been impaired. For such long-lived assets, the Company evaluates whether impairment may exist by estimating future estimated undiscounted cash flows expected to result from the use and eventual disposition of the asset. When alternative courses of action to recover the carrying amount of a long-lived asset are under consideration, a probability-weighted approach is used to develop estimates of future undiscounted cash flows. If the carrying value of the long-lived asset is not recoverable based on the estimated future undiscounted cash flows, an impairment loss is recorded, measured as the excess of the carrying value of the asset over its fair value. As a result, the asset’s carrying value is adjusted to its estimated fair value.

Within its regulated business, the carrying costs of most of Hydro One’s long-lived assets are included in rate base where they earn an OEB-approved rate of return. Asset carrying values and the related return are recovered through approved rates. As a result, such assets are only tested for impairment in the event that the OEB disallows recovery, in whole or in part, or if such a disallowance is judged to be probable.

Management assesses the fair value of such long-lived assets using commonly accepted techniques. Techniques used to determine fair value include, but are not limited to, the use of recent third-party comparable sales for reference and internally developed discounted cash flow analysis. Significant changes in market conditions, changes to the condition of an asset, or a change in management’s intent to utilize the asset are generally viewed by management as triggering events to reassess the cash flows related to these long-lived assets. As at December 31, 2022 and 2021, no asset impairment had been recorded.

Costs of Arranging Debt Financing

For financial liabilities classified as other than held-for-trading, the Company defers the external transaction costs related to obtaining financing and presents such amounts net of related debt on the consolidated balance sheets. Deferred issuance costs are amortized over the contractual life of the related debt on an effective-interest basis and the amortization is included within financing charges in the consolidated statements of operations and comprehensive income. Transaction costs for items classified as held-for-trading are expensed immediately.


			12

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Comprehensive Income

Comprehensive income is comprised of net income and OCI. Hydro One presents net income and OCI in a single continuous consolidated statement of operations and comprehensive income.

Financial Assets and Liabilities

All financial assets and liabilities are classified into one of the following five categories: held-to-maturity; loans and receivables; held-for-trading; other liabilities; or available-for-sale. Financial assets and liabilities classified as held-for-trading are measured at fair value. All other financial assets and liabilities are measured at amortized cost. Accounts receivable and amounts due from related parties are classified as loans and receivables. The Company considers the carrying amounts of accounts receivable and amounts due from related parties to be reasonable estimates of fair value because of the short time to maturity of these instruments. The Company estimates the CECL for all accounts receivable balances, which are recognized as adjustments to the allowance for doubtful accounts. Accounts receivable are written-off against the allowance when they are deemed uncollectible. All financial instrument transactions are recorded at trade date.

The Company determines the classification of its financial assets and liabilities at the date of initial recognition. The Company designates certain of its financial assets and liabilities to be held at fair value, when it is consistent with the Company’s risk management policy disclosed in Note 17 - Fair Value of Financial Instruments and Risk Management.

Derivative Instruments and Hedge Accounting

The Company closely monitors the risks associated with changes in interest rates on its operations and, where appropriate, uses various instruments to hedge these risks. Certain of these derivative instruments qualify for hedge accounting and are designated as accounting hedges, while others either do not qualify as hedges or have not been designated as hedges (hereinafter referred to as undesignated contracts) as they are part of economic hedging relationships.

The accounting guidance for derivative instruments requires the recognition of all derivative instruments not identified as meeting the normal purchase and sale exemption as either assets or liabilities recorded at fair value on the consolidated balance sheets. For derivative instruments that qualify for hedge accounting, the Company may elect to designate such derivative instruments as either cash flow hedges or fair value hedges. The Company offsets fair value amounts recognized on its consolidated balance sheets related to derivative instruments executed with the same counterparty under the same master netting agreement.

For derivative instruments that qualify for hedge accounting and which are designated as cash flow hedges, any unrealized gain or loss, net of tax, is recorded as a component of accumulated OCI (AOCI). Amounts in AOCI are reclassified to results of operations in the same period or periods during which the hedged transaction affects results of operations and presented in the same line item as the earnings effect of the hedged item. Any gains or losses on the derivative instrument that represent hedge components excluded from the assessment of effectiveness are recognized in the same line item of the consolidated statements of operations as the hedged item. For fair value hedges, changes in fair value of both the derivative instrument and the underlying hedged exposure are recognized in the consolidated statements of operations and comprehensive income in the current period. The gain or loss on the derivative instrument is included in the same line item as the offsetting gain or loss on the hedged item in the consolidated statements of operations and comprehensive income. The changes in fair value of the undesignated derivative instruments are reflected in results of operations.

Embedded derivative instruments are separated from their host contracts and are carried at fair value on the consolidated balance sheets when: (a) the economic characteristics and risks of the embedded derivative are not clearly and closely related to the economic characteristics and risks of the host contract; (b) the hybrid instrument is not measured at fair value, with changes in fair value recognized in results of operations each period; and (c) the embedded derivative itself meets the definition of a derivative. The Company does not engage in derivative trading or speculative activities and had no embedded derivatives that required bifurcation at December 31, 2022 or 2021.

Hydro One periodically develops hedging strategies taking into account risk management objectives. At the inception of a hedging relationship where the Company has elected to apply hedge accounting, Hydro One formally documents the relationship between the hedged item and the hedging instrument, the related risk management objective, the nature of the specific risk exposure being hedged, and the method for assessing the effectiveness of the hedging relationship. The Company also assesses, both at the inception of the hedge and on a quarterly basis, whether the hedging instruments are effective in offsetting changes in fair values or cash flows of the hedged items.

Employee Future Benefits

Employee future benefits provided by Hydro One include pension, post-retirement and post-employment benefits. The costs of the Company’s pension, post-retirement and post-employment benefit plans are recorded over the periods during which employees render service.

The Company recognizes the funded status of its defined benefit pension plan (Pension Plan) and its post-retirement and post-employment plans on its consolidated balance sheets and subsequently recognizes the changes in funded status at the end of each reporting year. Defined benefit pension, post-retirement and post-employment plans are considered to be underfunded when the projected benefit obligation (PBO) exceeds the fair value of the plan assets. Liabilities are recognized on the


			13

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

consolidated balance sheets for any net underfunded PBO. The net underfunded PBO may be disclosed as a current liability, long-term liability, or both. The current portion is the amount by which the actuarial present value of benefits included in the benefit obligation payable in the next 12 months exceeds the fair value of plan assets. If the fair value of plan assets exceeds the PBO of the plan, an asset is recognized equal to the net overfunded PBO. The post-retirement and post-employment benefit plans are unfunded because there are no related plan assets.

Hydro One recognizes its contributions to the defined contribution pension plan (DC Plan) as pension expense, with a portion being capitalized as part of labour costs included in capital expenditures. The expensed amount is included in operation, maintenance and administration (OM&A) costs in the consolidated statements of operations and comprehensive income.

Defined Benefit Pension

Defined benefit pension costs are recorded on an accrual basis for financial reporting purposes. Pension costs are actuarially determined using the projected benefit method prorated on service and are based on assumptions that reflect management’s best estimate of the effect of future events, including future compensation increases. Past service costs from plan amendments and all actuarial gains and losses are amortized on a straight-line basis over the expected average remaining service period of active employees in the plan, or over the estimated remaining life expectancy of inactive employees in the plan. Pension plan assets, consisting primarily of listed and unlisted equity securities, marketable and private debt, corporate and government debt securities as well as unlisted real estate and unlisted infrastructure investments, are recorded at fair value at the end of each year. Hydro One records a regulatory asset or liability equal to the net underfunded or overfunded PBO for its pension plan. Defined benefit pension costs are attributed to labour costs on a cash basis and a portion directly related to acquisition and development of capital assets is capitalized as part of the cost of property, plant and equipment and intangible assets. The remaining defined benefit pension costs are charged to results of operations (OM&A costs).

Post-retirement and Post-employment Benefits

Post-retirement and post-employment benefits are recorded and included in rates on an accrual basis. Costs are determined by independent actuaries using the projected benefit method prorated on service and based on assumptions that reflect management’s best estimates. For post-retirement benefits, past service costs from plan amendments are amortized to results of operations based on the expected average remaining service period.

For post-retirement benefits, all actuarial gains or losses are deferred using the “corridor” approach. The amount calculated above the “corridor” is amortized to results of operations on a straight-line basis over the expected average remaining service life of active employees in the plan or over the remaining life expectancy of inactive employees in the plan. The post-retirement benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory account, to the extent of the remeasurement adjustment.

The actuarial gains and losses on post-employment obligations that are incurred during the year are recognized immediately to results of operations. The post-employment benefit obligation is remeasured to its fair value at each year end based on an annual actuarial report, with an offset to the associated regulatory account, to the extent of the remeasurement adjustment.

All post-retirement and post-employment benefit costs are attributed to labour costs and are either charged to results of operations (OM&A costs) or capitalized as part of the cost of property, plant and equipment and intangible assets (applies to the service cost component of benefit cost) and to regulatory assets for all other components of the benefit cost, consistent with their inclusion in OEB-approved rates.

Stock-Based Compensation

Share Grant Plans

Hydro One measures share grant plans based on fair value of share grants as estimated based on Hydro One Limited's grant date common share price. The costs are recognized in the financial statements using the graded-vesting attribution method for share grant plans that have both a performance condition and a service condition. The Company records a regulatory asset equal to the accrued costs of share grant plans recognized in each period. Costs are transferred from the regulatory asset to labour costs at the time the share grants vest and are issued, and are recovered in rates. Forfeitures are recognized as they occur.

Deferred Share Unit (DSU) Plans

The Company records the liabilities associated with its Directors’ and Management DSU Plans at fair value at each reporting date until settlement, recognizing compensation expense over the vesting period on a straight-line basis. The fair value of the DSU liability is based on Hydro One Limited's common share closing price at the end of each reporting period.

Society Restricted Share Unit (RSU) Plan

The Company measures its Society RSU plan based on fair value of share grants as estimated based on Hydro One Limited's grant date common share price. The costs are recognized over the vesting period using the straight-line attribution method. The Company records a regulatory asset equal to the accrued costs of the Society RSU plan recognized in each period. Costs are


			14

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

transferred from the regulatory asset to labour costs at the time the share grants vest and are issued, and are recovered in rates. Forfeitures are recognized as they occur.

Long-term Incentive Plan (LTIP)

The Company measures the awards issued under Hydro One Limited's LTIP, at fair value based on Hydro One Limited grant date common share price. The related compensation expense is recognized over the vesting period on a straight-line basis. Forfeitures are recognized as they occur.

Loss Contingencies

Hydro One is involved in certain legal and environmental matters that arise in the normal course of business. In the preparation of its Consolidated Financial Statements, management makes judgments regarding the future outcome of contingent events and records a loss for a contingency based on its best estimate when it is determined that such loss is probable and the amount of the loss can be reasonably estimated. Where the loss amount is recoverable in future rates, a regulatory asset is also recorded. When a range estimate for the probable loss exists and no amount within the range is a better estimate than any other amount, the Company records a loss at the minimum amount within the range.

Management regularly reviews current information available to determine whether recorded provisions should be adjusted and whether new provisions are required. Estimating probable losses may require analysis of multiple forecasts and scenarios that often depend on judgments about potential actions by third parties, such as federal, provincial and local courts or regulators. Contingent liabilities are often resolved over long periods of time. Amounts recorded in the Consolidated Financial Statements may differ from the actual outcome once the contingency is resolved. Such differences could have a material impact on future results of operations, financial position and cash flows of the Company.

Provisions are based upon current estimates and are subject to greater uncertainty where the projection period is lengthy. A significant upward or downward trend in the number of claims filed, the nature of the alleged injuries, and the average cost of resolving each claim could change the estimated provision, as could any substantial adverse or favourable verdict at trial. A federal or provincial legislative outcome or structured settlement could also change the estimated liability. Legal fees are expensed as incurred.

Environmental Liabilities

Environmental liabilities are recorded in respect of past contamination when it is determined that future environmental remediation expenditures are probable under existing statute or regulation and the amount of the future expenditures can be reasonably estimated. Hydro One records a liability for the estimated future expenditures associated with contaminated land assessment and remediation (LAR) and for the phase-out and destruction of polychlorinated biphenyl (PCB)-contaminated mineral oil removed from electrical equipment, based on the present value of these estimated future expenditures. The Company determines the present value with a discount rate that produces an amount at which the environmental liabilities could be settled in an arm’s length transaction with a third party. As the Company anticipates that the future expenditures will continue to be recoverable in future rates, an offsetting regulatory asset has been recorded to reflect the future recovery of these environmental expenditures from customers. Hydro One reviews its estimates of future environmental expenditures annually, or more frequently if there are indications that circumstances have changed. Estimate changes are accounted for prospectively.

Asset Retirement Obligations

Asset retirement obligations are recorded for legal obligations associated with the future removal and disposal of long-lived assets. Such obligations may result from the acquisition, construction, development and/or normal use of the asset. Conditional asset retirement obligations are recorded when there is a legal obligation to perform a future asset retirement activity but where the timing and/or method of settlement are conditional on a future event that may or may not be within the control of the Company. In such a case, the obligation to perform the asset retirement activity is unconditional even though uncertainty exists about the timing and/or method of settlement. This uncertainty is incorporated in the fair value measurement of the obligation.

When recording an asset retirement obligation, the present value of the estimated future expenditures required to complete the asset retirement activity is recorded in the period in which the obligation is incurred, if a reasonable estimate can be made. In general, the present value of the estimated future expenditures is added to the carrying amount of the associated asset and the resulting asset retirement cost is depreciated over the estimated useful life of the asset. The present value is determined with a discount rate that equates to the Company’s credit-adjusted risk-free rate. Where an asset is no longer in service when an asset retirement obligation is recorded, the asset retirement cost is recorded in results of operations.

Leases

At the commencement date of a lease, the minimum lease payments are discounted and recognized as a lease obligation. Discount rates used correspond to the Company's incremental borrowing rates. Renewal options are assessed for their likelihood of being exercised and are included in the measurement of the lease obligation when it is reasonably certain they will be exercised. The Company does not recognize leases with a term of less than 12 months. A corresponding Right-of-Use (ROU) asset is recognized at the commencement date of a lease. The ROU asset is measured as the lease obligation adjusted for any lease payments made and/or any lease incentives and initial direct costs incurred. ROU assets are included in other long-term


			15

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

assets, and corresponding lease obligations are included in other current liabilities and other long-term liabilities on the consolidated balance sheets.

Subsequent to the commencement date, the lease expense recognized at each reporting period is the total remaining lease payments over the remaining lease term. Lease obligations are measured as the present value of the remaining unpaid lease payments using the discount rate established at commencement date. The amortization of the ROU assets is calculated as the difference between the lease expense and the accretion of interest, which is calculated using the effective interest method. Lease modifications and impairments are assessed at each reporting period to assess the need for a remeasurement of the lease obligations or ROU assets.

3. NEW ACCOUNTING PRONOUNCEMENTS

The following tables present Accounting Standard Updates (ASUs) issued by the Financial Accounting Standards Board that are applicable to Hydro One:

Recently Adopted Accounting Guidance

Guidance

Date issued

Description

Effective date

Impact on Hydro One

ASU 2020-06

August 2020

The update addresses the complexity associated with applying US GAAP for certain financial instruments with characteristics of liabilities and equity. The amendments reduce the number of accounting models for convertible debt instruments and convertible preferred stock.

January 1, 2022

No impact upon adoption

ASU
2021-05

July 2021

The amendments are intended to align lease classification requirements for lessors under Topic 842 with Topic 840's practice.

January 1, 2022

No impact upon adoption

ASU 2021-10

November 2021

The update addresses diversity on the recognition, measurement, presentation and disclosure of government assistance received by business entities.

January 1, 2022

No impact upon adoption

Recently Issued Accounting Guidance Not Yet Adopted

Guidance

Date issued

Description

Effective date

Anticipated Impact on Hydro One

ASU
2021-08

October 2021

The amendments address how to determine whether a contractual obligation represents a liability to be recognized by the acquirer in a business combination.

January 1, 2023

No expected impact upon adoption

ASU 2022-02

March 2022

The amendments eliminate the troubled debt restructuring (TDR) accounting model for entities that have adopted Topic 326 Financial Instrument – Credit Losses and modifies the guidance on vintage disclosure requirements to require disclosure of current-period gross write-offs by year of origination.

January 1, 2023

Upon adoption, the Company will disclose the current period gross write-offs by year of origination relating to its accounts receivable

4. DEPRECIATION, AMORTIZATION AND ASSET REMOVAL COSTS



Year ended December 31 (millions of dollars)	2022	2021
Depreciation of property, plant and equipment1	708	700
Amortization of intangible assets	81	76
Amortization of regulatory assets	33	30

Depreciation and amortization	822	806
Asset removal costs	135	107
	957	913

1 Includes gain on sale of assets of $39 million (2021 - $8 million).


			16

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

5. FINANCING CHARGES



Year ended December 31 (millions of dollars)	2022	2021
Interest on long-term debt	499	499
Interest on short-term notes	27	1
Interest on regulatory accounts	8	5
Realized (gain) loss on cash flow hedges (interest-rate swap agreements) (Notes 7, 17)	(3)	12
Other	14	11
Less: Interest capitalized on construction and development in progress	(63)	(60)
DTA carrying charges	2	(12)
Interest earned on cash and cash equivalents	(6)	(3)
	478	453

6. INCOME TAXES

As a rate regulated utility company, the Company recovers income taxes from its ratepayers based on estimated current income tax expense in respect of its regulated business. The amounts of deferred income taxes related to regulated operations which are considered to be more likely-than-not to be recoverable from, or refundable to, ratepayers in future periods are recognized as deferred income tax regulatory assets or liabilities, with an offset to deferred income tax recovery or expense, respectively. The Company’s consolidated tax expense or recovery for the period includes all current and deferred income tax expenses for the period net of the regulated accounting offset to deferred income tax expense arising from temporary differences to be recovered from, or refunded to, customers in future rates. Thus, the Company’s income tax expense or recovery differs from the amount that would have been recorded using the combined Canadian federal and Ontario statutory income tax rate.

The reconciliation between the statutory and the effective tax rates is provided as follows:


Year ended December 31 (millions of dollars)	2022	2021
Income before income tax expense	1,355	1,159
Income tax expense at statutory rate of 26.5% (2021 - 26.5%)	359	307

Increase (decrease) resulting from:
Net temporary differences recoverable in future rates charged to customers:
Impact of DTA Implementation Decision1	96	9
Capital cost allowance in excess of depreciation and amortization	(90)	(81)

Overheads capitalized for accounting but deducted for tax purposes	(35)	(22)
Interest capitalized for accounting but deducted for tax purposes	(17)	(16)
Pension and post-retirement benefit contributions in excess of pension expense	(11)	(9)
Environmental expenditures	(9)	(8)
Other	—	(1)
Net temporary differences attributable to regulated business	(66)	(128)
Net permanent differences	(3)	—
Total income tax expense	290	179


Effective income tax rate									21.4		%	15.4		%

1 Pursuant to the DTA Implementation Decision, the impact represents the amounts recovered from ratepayers in respect of tax deductions previously shared with the ratepayers. See Note 12 - Regulatory Assets and Liabilities.

The major components of income tax expense are as follows:


Year ended December 31 (millions of dollars)	2022	2021
Current income tax expense	36	30
Deferred income tax expense	254	149
Total income tax expense	290	179

Deferred Income Tax Assets and Liabilities

Deferred income tax assets and liabilities reflect the future tax consequences attributable to temporary differences between the tax bases and the financial statement carrying amounts of the assets and liabilities including the carry forward amounts of tax losses and tax credits. Deferred income tax assets and liabilities attributable to the Company’s regulated business are recognized with a corresponding offset in deferred income tax regulatory assets and liabilities to reflect the anticipated recovery


			17

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

or repayment of these balances in the future electricity rates. At December 31, 2022 and 2021, deferred income tax assets and liabilities consisted of the following:


As at December 31 (millions of dollars)	2022	2021
Deferred income tax assets
Post-retirement and post-employment benefits expense in excess of cash payments	503	655
Pension obligations	—	257
Regulatory assets and liabilities	301	—
Non-capital losses	188	213
Non-depreciable capital property	273	273
Tax credit carryforwards	181	147
Investment in subsidiaries	102	99
Environmental expenditures	34	44
	1,582	1,688
Less: valuation allowance	(381)	(378)
Total deferred income tax assets	1,201	1,310

Deferred income tax liabilities
Capital cost allowance in excess of depreciation and amortization	1,776	1,354
Pension assets	129
Regulatory assets and liabilities	—	308
Other	5	5
Total deferred income tax liabilities	1,910	1,667

Net deferred income tax liabilities	(709)	(357)

The net deferred income tax liabilities are presented on the consolidated balance sheets as follows:


As at December 31 (millions of dollars)	2022	2021
Long-term:
Deferred income tax assets	4	10
Deferred income tax liabilities	(713)	(367)
Net deferred income tax liabilities	(709)	(357)

The valuation allowance for deferred tax assets as at December 31, 2022 was $381 million (2021 - $378 million). The valuation allowance primarily relates to temporary differences for non-depreciable assets and investments in subsidiaries. As of December 31, 2022 and 2021, the Company had non-capital losses carried forward available to reduce future years’ taxable income, which expire as follows:


Year of expiry (millions of dollars)	2022	2021
2035	—	—
2036	136	481
2037	175	121
2038	140	5
2039	213	183
2040	3	2
2041	5	8
2042	17	—
Total losses	689	800

7. OTHER COMPREHENSIVE INCOME



Year ended December 31 (millions of dollars)	2022	2021
Gain on cash flow hedges (interest-rate swap agreements) (Notes 5, 17)1	10	12
Gain on transfer of other post-employment benefits (OPEB) (Note 19)	2	—
Other	7	4
	19	16

1 Includes $2 million after-tax realized gain (2021 - $8 million loss) and $3 million before-tax (2021 - $12 million loss) on cash flow hedges reclassified to financing charges.


			18

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

8. ACCOUNTS RECEIVABLE


As at December 31 (millions of dollars)	2022	2021
Accounts receivable - billed	356	344
Accounts receivable - unbilled	472	409
Accounts receivable, gross	828	753
Allowance for doubtful accounts	(63)	(56)
Accounts receivable, net	765	697

The following table shows the movements in the allowance for doubtful accounts for the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)	2022	2021
Allowance for doubtful accounts – beginning	(56)	(46)
Write-offs	25	15
Additions to allowance for doubtful accounts	(32)	(25)
Allowance for doubtful accounts – ending	(63)	(56)

9. OTHER CURRENT ASSETS


As at December 31 (millions of dollars)	2022	2021
Regulatory assets (Note 12)	189	226
Prepaid expenses and other assets	58	53
Materials and supplies	24	22
Derivative assets (Note 17)	5	—
	276	301

10. PROPERTY, PLANT AND EQUIPMENT


As at December 31, 2022 (millions of dollars)	Property, Plant and Equipment	Accumulated Depreciation	Construction in Progress	Total
Transmission	20,162	6,641	938	14,459
Distribution	12,707	4,380	107	8,434
Communication	1,299	1,046	71	324
Administration and service	2,120	1,065	85	1,140
Easements	701	88		613
	36,989	13,220	1,201	24,970

As at December 31, 2021 (millions of dollars)	Property, Plant and Equipment	Accumulated Depreciation	Construction in Progress	Total
Transmission	18,970	6,307	1,183	13,846
Distribution	12,045	4,163	95	7,977
Communication	1,246	981	46	311
Administration and service	1,963	1,022	78	1,019
Easements	679	84	—	595
	34,903	12,557	1,402	23,748

Financing charges capitalized on property, plant and equipment under construction were $57 million in 2022 (2021 - $57 million).


			19

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

11. INTANGIBLE ASSETS


As at December 31, 2022 (millions of dollars)	Intangible Assets	Accumulated Amortization	Development in Progress	Total
Computer applications software	1,175	737	167	605
Other	5	5	—	—
	1,180	742	167	605

As at December 31, 2021 (millions of dollars)	Intangible Assets	Accumulated Amortization	Development in Progress	Total
Computer applications software	1,094	657	130	567
Other	5	5	—	—
	1,099	662	130	567

Financing charges capitalized to intangible assets under development were $6 million in 2022 (2021 - $3 million). The estimated annual amortization expense for intangible assets is as follows: 2023 - $74 million; 2024 - $63 million; 2025 - $62 million; 2026 - $59 million; and 2027 - $52 million.

12. REGULATORY ASSETS AND LIABILITIES

Regulatory assets and liabilities arise as a result of the rate-setting process. Hydro One has recorded the following regulatory assets and liabilities:


As at December 31 (millions of dollars)	2022	2021
Regulatory assets:
Deferred income tax regulatory asset	2,724	2,509
Post-retirement and post-employment benefits - non-service cost	141	125
Environmental	93	122
Deferred tax asset sharing	73	204
Stock-based compensation	34	38
Conservation and Demand Management (CDM) variance	25	8
Rural and Remote Rate Protection (RRRP) variance	25	10
Pension benefit regulatory asset	—	713
Foregone revenue deferral	—	25
Other	38	33
Total regulatory assets	3,153	3,787
Less: current portion	(189)	(226)
	2,964	3,561

Regulatory liabilities:
Post-retirement and post-employment benefits	506	33
Pension benefit regulatory liability	358	—
Tax rule changes variance	100	86
Earnings sharing mechanism deferral	75	42
Retail settlement variance account (RSVA)	53	58
External revenue variance	50	52
Asset removal costs cumulative variance	41	36
Pension cost differential	26	30
Capitalized overhead tax variance	16	—
Green energy expenditure variance	5	13
Deferred income tax regulatory liability	4	4
Other	28	18
Total regulatory liabilities	1,262	372
Less: current portion	(139)	(10)
	1,123	362


			20

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Deferred Income Tax Regulatory Asset and Liability

Deferred income taxes are recognized on temporary differences between the carrying amount of assets and liabilities in the financial statements and the corresponding tax bases used in the computation of taxable income. The Company has recognized regulatory assets and liabilities that correspond to deferred income taxes that flow through the rate-setting process. In the absence of rate-regulated accounting, the Company’s income tax expense would have been recognized using the liability method and there would be no regulatory accounts established for taxes to be recovered through future rates. As a result, the 2022 income tax expense would have been higher by approximately $66 million (2021 - $127 million). The $66 million (2021 - $127 million) impact is offset against deferred income tax regulatory asset and liability, deferred tax asset sharing, and post-retirement and post-employment benefits - non-service cost.

Post-Retirement and Post-Employment Benefits - Non-Service Cost

Hydro One has recorded a regulatory asset relating to the future recovery of its post-retirement and post-employment benefits other than service costs. The regulatory asset includes the applicable tax impact to reflect taxes payable. Prior to adoption of ASU 2017-07 in 2018, these amounts were capitalized to property, plant and equipment and intangible assets. As part of Hydro One Networks' 2020-2022 Transmission Decision, the OEB concluded that the non-service cost component of Hydro One's OPEB costs shall be recognized as OM&A for both its transmission and distribution businesses. Furthermore, Hydro One Networks distribution continued to record the non-service cost component of OPEBs in this account until the end of 2022. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One Networks' transmission and distribution account balances as at December 31, 2020, including accrued interest, which will be recovered from ratepayers over a one-year period ending December 31, 2023 and a three-year period ending December 31, 2025, respectively.

Environmental

Hydro One records a liability for the estimated future expenditures required to remediate environmental contamination. A regulatory asset is recognized because management considers it to be probable environmental expenditures will be recovered in the future through the rate-setting process. The Company has recorded an equivalent amount as a regulatory asset. In 2022, the revaluation adjustment increased the environmental regulatory asset by $3 million (2021 - $18 million) to reflect changes in the recoverable portion of the Company’s PCB and LAR environmental liabilities. The environmental regulatory asset is amortized to results of operations based on the pattern of actual expenditures incurred and charged to environmental liabilities. The OEB has the discretion to examine and assess the prudence and the timing of recovery of all of Hydro One’s actual environmental expenditures. In the absence of rate-regulated accounting, with respect to the revaluation adjustment, 2022 OM&A expenses would have been higher by $3 million (2021 - higher by $18 million). In addition, 2022 amortization expense would have been lower by $33 million (2021 - lower by $30 million), and 2022 financing charges would have been higher by $1 million (2021 - higher by $1 million).

Deferred Tax Asset Sharing

On October 2, 2020, the OEB issued a procedural order to implement the direction of the Ontario Divisional Court which required Hydro One to submit its proposal for the recovery of the DTA amounts allocated to ratepayers for the 2017 to 2022 period. On April 8, 2021, the OEB rendered the DTA Implementation Decision, in which the OEB approved recovery of the DTA amounts allocated to ratepayers for the 2017 to 2021 period, plus carrying charges over a two-year period, commencing on July 1, 2021. In addition, Hydro One was approved to adjust the transmission revenue requirement and the base distribution rates beginning January 1, 2022 to eliminate any further amounts of future tax savings flowing to customers. As at December 31, 2022, Hydro One has a regulatory asset of $73 million for the cumulative DTA amounts shared with ratepayers since 2017 to date, net of the amount recovered from ratepayers pursuant to the DTA Implementation Decision. The regulatory asset of $73 million (2021 - $204 million) consists of $24 million (2021 - $72 million) and $49 million (2021 - $132 million) for Hydro One Networks’ distribution and transmission segments, respectively. As a result of the OEB’s procedural order, the $73 million regulatory asset relating to the cumulative DTA amounts allocated to ratepayers since 2017 has been separately presented from the deferred income tax regulatory asset. The balance of this regulatory account will continue to decrease as amounts are recovered over the next 6 months.

Stock-based Compensation

The Company recognizes costs associated with share grant plans and Society RSUs in a regulatory asset as management considers it probable that share grant plans' and Society RSU costs will be recovered in the future through the rate-setting process. In the absence of rate-regulated accounting, OM&A expenses would be lower by $2 million (2021 - $1 million). Share grant and Society RSU costs are transferred to labour costs at the time they vest and are issued, and are recovered in rates in accordance with recovery of these labour costs.

CDM Variance

The CDM variance account tracks the impact of actual CDM and demand response programs on the actual load forecast compared to the estimated load forecast included in revenue requirement. As per the OEB's decision on Hydro One Networks' transmission rates for 2017 to 2019, this account was maintained to record any variances for 2017, 2018, and 2019. In April 2020, the 2017 balance, plus accrued interest through December 31, 2018 was approved for disposition over a three-year period


			21

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

that ended on December 31, 2022. CDM variance amounts for 2018 and 2019 were calculated and proposed for disposition in the Hydro One Networks JRAP application. In November 2022, the amount as at December 31, 2020, including accrued interest, was approved for disposition by the OEB. The amount was approved to be recovered from ratepayers over a one-year period ending December 31, 2023. Since CDM revenues qualify as a Type A program under the Alternative Revenue Program, $23 million was recognized in transmission revenues.

RRRP Variance

Hydro One Remotes receives RRRP amounts from the Independent Electricity System Operator (IESO). At December 31, 2022, the Company recognized a regulatory asset representing the amounts required to achieve breakeven net income, as regulated under the cost recovery model, in excess of cumulative RRRP amounts received. In 2022, RRRP amounts received were lower (2021 - lower) than amounts required to achieve breakeven net income, and as such, the regulatory asset was increased by $15 million (2021 - $4 million). In the absence of rate-regulated accounting, 2022 revenue would have been lower by $15 million (2021 - lower by $4 million).

Foregone Revenue Deferral

As at December 31, 2021, the foregone revenue deferral account was made up of the remaining balance reflecting Hydro One Networks transmission business' foregone revenue, based on the difference between approved 2020 UTRs and interim 2020 UTRs, which was approved by the OEB to be collected from ratepayers over a two-year period that ended on December 31, 2022.

Post-Retirement and Post-Employment Benefits

In accordance with OEB rate orders, post-retirement and post-employment benefits costs are recovered on an accrual basis. The Company recognizes the net unfunded or overfunded status of post-retirement and post-employment obligations on the consolidated balance sheets with an incremental offset to the associated regulatory asset or regulatory liability, as the case may be. A regulatory asset or liability is recognized because management considers it to be probable that post-retirement and post-employment benefit costs will be recovered or returned in the future through the rate-setting process. The post-retirement and post-employment benefit obligation is remeasured to the present value of the actuarially determined benefit obligation at each year end based on an annual actuarial report, with an offset to the associated regulatory asset or liability as the case may be, to the extent of the remeasurement adjustment. In the absence of rate-regulated accounting, 2022 OCI would have been higher by $473 million (2021 - OCI higher by $94 million).

Pension Benefit Regulatory Asset / Liability

In accordance with OEB rate orders, pension costs recovered on a cash basis as employer contributions are paid to the pension fund in accordance with the Pension Benefits Act (Ontario). The Company recognizes the net unfunded or overfunded status of pension obligations on the consolidated balance sheets with an offset to the associated regulatory asset or liability. The pension benefit obligation is remeasured to the present value of the actuarially determined benefit obligation at each year end based on an annual actuarial report, with an offset to the associated regulatory asset or liability, to the extent of the remeasurement adjustment. In the absence of rate-regulated accounting, OCI would have been higher by $1,035 million (2021 - OCI higher by $1,017 million) and OM&A expenses would have been lower by $36 million (2021 - higher by $132 million).

Tax Rule Changes Variance

The 2019 federal and Ontario budgets (Budgets) provided certain time-limited investment incentives permitting Hydro One to deduct accelerated capital cost allowance of up to three times the first-year rate for capital investments acquired after November 20, 2018 and placed in-service before January 1, 2028 (Accelerated Depreciation). Following the enactment of the Budget measures in the second quarter of 2019, the OEB directed all Ontario regulated utilities including Hydro One to track the full revenue impact of the tax benefits related to the Accelerated Depreciation rules to ratepayers. The tax benefit to be returned to ratepayers in the future gave rise to a regulatory liability and resulted in a decrease in revenues as current rates do not include the benefit of the Accelerated Depreciation; therefore, the revenue subject to refund cannot be recognized. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One Networks' transmission and distribution account balances as at December 31, 2020, including accrued interest, which will be returned to ratepayers over a one-year period ending December 31, 2023 and a three-year period ending December 31, 2025, respectively.

Earnings Sharing Mechanism Deferral

In March 2019, the OEB approved the establishment of an earnings sharing mechanism deferral account for Hydro One Networks' distribution segment to record over-earnings including tax impacts, if any, realized for any year from 2018 to 2022. Under this mechanism, Hydro One shares 50% of regulated earnings that exceed the OEB-approved regulatory return-on-equity by more than 100 basis points with distribution ratepayers. A similar account was also approved for B2M LP in January 2020, and Hydro One Networks transmission and NRLP in April 2020. HOSSM's account was approved as part of the acquisition decision in October 2016 and became effective in 2022. The balance in the account as at December 31, 2022 mostly relates to Hydro One Networks distribution and transmission. As part of the JRAP Decision received in November 2022, the OEB approved


			22

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

the disposition of Hydro One networks' distribution business' balance as at December 31, 2020, including accrued interest, over a three-year period ending December 31, 2025.

RSVA

Hydro One has deferred certain retail settlement variance amounts under the provisions of Article 490 of the OEB’s Accounting Procedures Handbook. The RSVA account tracks the difference between the cost of power purchased from the IESO and the cost of power recovered from ratepayers. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One networks' distribution business' balance as at December 31, 2020, including accrued interest, over a three-year period ending December 31, 2025.

External Revenue Variance

The external revenue variance account balance reflects the difference between Hydro One Networks' transmission business' actual export service revenue and external revenues from secondary land use, and the OEB-approved amounts. The account also records the difference between actual net external station maintenance, engineering and construction services revenue, and other external revenue, and the OEB-approved amounts. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One networks' transmission business' balance as at December 31, 2020, including accrued interest, over a one-year period ending December 31, 2023.

Asset Removal Costs Cumulative Variance

In April 2020, the OEB approved the establishment of an asset removal costs cumulative variance account for Hydro One Networks' transmission business to record the difference between the revenue requirement associated with forecast asset removal costs included in depreciation expense and actual asset removal costs incurred from 2020 to 2022. This account is asymmetrical to the benefit of ratepayers on a cumulative basis over the 2020-2022 rate period. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One networks' transmission business' balance as at December 31, 2020, including accrued interest, over a one-year period ending December 31, 2023.

Pension Cost Differential

Variances between the pension cost recognized and the cost embedded in rates as part of the rate-setting process for Hydro One Networks' transmission and distribution businesses are recognized as a regulatory asset or regulatory liability, as the case may be. As part of the JRAP Decision received in November 2022, the OEB approved the disposition of Hydro One Networks' transmission and distribution account balances as at December 31, 2020, including accrued interest, which will be returned to ratepayers over a one-year period ending December 31, 2023 and a three-year period ending December 31, 2025, respectively. In the absence of rate-regulated accounting, 2022 revenue would have been lower by $4 million (2021 - higher by $1 million).

Capitalized Overhead Tax Variance

In November 2022, the OEB approved the establishment of a capitalized overhead tax variance account to capture the difference between the capitalized overheads deducted in calculating the regulatory tax expense included in rates and the actual capitalized overhead costs deducted in Hydro One's tax returns for Hydro One Networks' transmission and distribution businesses for the 2016 to 2027 period. Variance amounts are recognized at the earlier of (i) when the tax year has been audited by the Canada Revenue Agency or (ii) when the taxation year is statute barred.

Green Energy Expenditure Variance

In April 2010, the OEB requested the establishment of deferral accounts which capture the difference between the revenue recorded on the basis of Green Energy Plan expenditures incurred and the actual recoveries received.

13. OTHER LONG-TERM ASSETS


As at December 31 (millions of dollars)	2022	2021
Deferred pension assets (Note 19)	358	—
Right-of-Use assets (Note 22)	53	53
Other long-term assets	11	13
	422	66


			23

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

14. ACCOUNTS PAYABLE AND OTHER CURRENT LIABILITIES


As at December 31 (millions of dollars)	2022	2021
Accrued liabilities	673	606
Accounts payable	284	249
Regulatory liabilities (Note 12)	139	10
Accrued interest	118	123
Environmental liabilities (Note 20)	25	34
Lease obligations (Note 22)	11	12
Derivative liabilities (Note 17)	—	8
	1,250	1,042

15. OTHER LONG-TERM LIABILITIES


As at December 31 (millions of dollars)	2022	2021
Post-retirement and post-employment benefit liability (Note 19)	1,364	1,784
Environmental liabilities (Note 20)	68	88
Lease obligations (Note 22)	42	44
Asset retirement obligations (Note 21)	28	14
Due to related parties (Note 28)	26	29

Long-term accounts payable	1	3
Pension benefit liability (Note 19)	—	713
Other long-term liabilities	29	19
	1,558	2,694

16. DEBT AND CREDIT AGREEMENTS

Short-Term Notes and Credit Facilities

Hydro One meets its short-term liquidity requirements in part through the issuance of commercial paper under its Commercial Paper Program which has a maximum authorized amount of $2,300 million. These short-term notes are denominated in Canadian dollars with varying maturities up to 365 days. The Commercial Paper Program is supported by the Company’s committed and unsecured revolving standby credit facilities totaling $2,300 million (Operating Credit Facilities).

At December 31, 2022, Hydro One’s Operating Credit Facilities consisted of the following:


(millions of dollars)	Maturity	Total Amount	Amount Drawn
Revolving standby credit facilities	June 20271	2,300	—

1 On June 1, 2022, the maturity dates for the Operating Credit Facilities were extended from June 2026 to June 2027.

The Company may use the Operating Credit Facilities for working capital and general corporate purposes. If used, interest on the Operating Credit Facilities would apply based on Canadian benchmark rates. The obligation of each lender to make any credit extension under its credit facility is subject to various conditions including that no event of default has occurred or would result from such credit extension.


			24

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Long-Term Debt

The following table presents long-term debt outstanding at December 31, 2022 and 2021:


As at December 31 (millions of dollars)	2022	2021
3.20% Series 25 notes due 2022	—	600
0.71% Series 48 notes due 2023	600	600
2.54% Series 42 notes due 2024	700	700
1.76% Series 45 notes due 2025	400	400
2.97% Series 40 notes due 2025	350	350
2.77% Series 35 notes due 2026	500	500
4.91% Series 52 notes due 2028	750	—
3.02% Series 43 notes due 2029	550	550
2.16% Series 46 notes due 2030	400	400
7.35% Debentures due 2030	400	400
1.69% Series 49 notes due 2031	400	400
2.23% Series 50 notes due 2031	450	450
6.93% Series 2 notes due 2032	500	500
6.35% Series 4 notes due 2034	385	385
5.36% Series 9 notes due 2036	600	600
4.89% Series 12 notes due 2037	400	400
6.03% Series 17 notes due 2039	300	300
5.49% Series 18 notes due 2040	500	500
4.39% Series 23 notes due 2041	300	300
6.59% Series 5 notes due 2043	315	315
4.59% Series 29 notes due 2043	435	435
4.17% Series 32 notes due 2044	350	350
5.00% Series 11 notes due 2046	325	325
3.91% Series 36 notes due 2046	350	350
3.72% Series 38 notes due 2047	450	450
3.63% Series 41 notes due 2049	750	750
2.71% Series 47 notes due 2050	500	500
3.64% Series 44 notes due 2050	250	250
3.10% Series 51 notes due 2051	450	450
4.00% Series 24 notes due 2051	225	225
3.79% Series 26 notes due 2062	310	310
4.29% Series 30 notes due 2064	50	50
Hydro One long-term debt (a)	13,245	13,095

6.6% Senior Secured Bonds due 2023 (Principal amount - $95 million)	97	105
4.6% Note Payable due 2023 (Principal amount - $36 million)	36	37
HOSSM long-term debt (b)	133	142

	13,378	13,237

Add: Net unamortized debt premiums	8	9

Less: Unamortized deferred debt issuance costs	(47)	(50)
Total long-term debt	13,339	13,196

(a) Hydro One long-term debt

At December 31, 2022, long-term debt of $13,245 million (2021 - $13,095 million) was outstanding, the majority of which was issued under Hydro One’s Medium Term Note (MTN) Program. In June 2022, Hydro One filed a short form base shelf prospectus in connection with its MTN Program, which has a maximum authorized principal amount of notes issuable of $4,000 million, expiring in July 2024. At December 31, 2022, $3,250 million remained available for issuance under the MTN Program prospectus.

In 2022, Hydro One issued long-term debt totaling $750 million (2021 - $900 million) and repaid long-term debt of $600 million (2021 - $800 million) under the MTN Program.


			25

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

(b) HOSSM long-term debt

At December 31, 2022, HOSSM long-term debt of $133 million (2021 - $142 million), with a principal amount of $131 million (2021 - $134 million) was outstanding. In 2022, no long-term debt was issued (2021 - $nil), and $3 million (2021 - $4 million) of long-term debt was repaid.

The total long-term debt is presented on the consolidated balance sheets as follows:


As at December 31 (millions of dollars)	2022	2021
Current liabilities:
Long-term debt payable within one year	733	603
Long-term liabilities:
Long-term debt	12,606	12,593
Total long-term debt	13,339	13,196

Principal and Interest Payments

At December 31, 2022, future principal repayments, interest payments, and related weighted-average interest rates were as follows:


	Long-Term Debt Principal Repayments	Interest Payments	Weighted-Average Interest Rate
	(millions of dollars)	(millions of dollars)	(%)
Year 1	731	512	1.7
Year 2	700	507	2.5
Year 3	750	489	2.3
Year 4	500	473	2.8
Year 5	—	467	—
	2,681	2,448	2.3
Years 6-10	3,450	1,976	4.1
Thereafter	7,245	3,663	4.5
	13,376	8,087	3.9

17. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

Fair value is considered to be the exchange price in an orderly transaction between market participants to sell an asset or transfer a liability at the measurement date. The fair value definition focuses on an exit price, which is the price that would be received in the sale of an asset or the amount that would be paid to transfer a liability.

Hydro One classifies its fair value measurements based on the following hierarchy, as prescribed by the accounting guidance for fair value, which prioritizes the inputs to valuation techniques used to measure fair value into three levels:

Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that Hydro One has the ability to access. An active market for the asset or liability is one in which transactions for the asset or liability occur with sufficient frequency and volume to provide ongoing pricing information.

Level 2 inputs are those other than quoted market prices that are observable, either directly or indirectly, for an asset or liability. Level 2 inputs include, but are not limited to, quoted prices for similar assets or liabilities in an active market, quoted prices for identical or similar assets or liabilities in markets that are not active and inputs other than quoted market prices that are observable for the asset or liability, such as interest-rate curves and yield curves observable at commonly quoted intervals, volatilities, credit risk and default rates. A Level 2 measurement cannot have more than an insignificant portion of the valuation based on unobservable inputs.

Level 3 inputs are any fair value measurements that include unobservable inputs for the asset or liability for more than an insignificant portion of the valuation. A Level 3 measurement may be based primarily on Level 2 inputs.

Non-Derivative Financial Assets and Liabilities

At December 31, 2022 and 2021, the Company’s carrying amounts of cash and cash equivalents, accounts receivable, due from related parties, short-term notes payable, accounts payable, and due to related parties are representative of fair value due to the short-term nature of these instruments.


			26

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Fair Value Measurements of Long-Term Debt

The fair values and carrying values of the Company’s long-term debt at December 31, 2022 and 2021 are as follows:


	2022	2022	2021	2021
As at December 31 (millions of dollars)	Carrying Value	Fair Value	Carrying Value	Fair Value

Long-term debt, including current portion	13,339	12,655	13,196	15,162

Fair Value Measurements of Derivative Instruments

Fair Value Hedges

At December 31, 2022 and 2021, Hydro One had no fair value hedges.

Cash Flow Hedges

At December 31, 2022 and 2021, Hydro One had a total of $800 million in pay-fixed, receive-floating interest-rate swap agreements designated as cash flow hedges. These cash flow hedges are intended to offset the variability of interest rates on the issuances of short-term commercial paper between January 9, 2020 and March 9, 2023.

At December 31, 2022 and 2021, the Company had no derivative instruments classified as undesignated contracts.

Fair Value Hierarchy

The fair value hierarchy of financial assets and liabilities at December 31, 2022 and 2021 is as follows:


As at December 31, 2022 (millions of dollars)	Carrying Value	Fair Value	Level 1	Level 2	Level 3
Assets:
Derivative instruments (Note 9)
Cash flow hedges, including current portion	5	5	—	5	—

Liabilities:
Long-term debt, including current portion	13,339	12,655	—	12,655	—


As at December 31, 2021 (millions of dollars)	Carrying Value	Fair Value	Level 1	Level 2	Level 3





Liabilities:
Long-term debt, including current portion	13,196	15,162	—	15,162	—
Derivative instruments (Note 14)
Cash flow hedges, including current portion	8	8	—	8	—
	13,204	15,170	—	15,170	—

The fair value of the interest rate swaps designated as cash flow hedges is determined using a discounted cash flow method based on period-end swap yield curves.

The fair value of the long-term debt is based on unadjusted period-end market prices for the same or similar debt of the same remaining maturities.

There were no transfers between any of the fair value levels during the years ended December 31, 2022 or 2021.

Risk Management

Exposure to market risk, credit risk and liquidity risk arises in the normal course of the Company’s business.

Market Risk

Market risk refers primarily to the risk of loss which results from changes in values, foreign exchange rates and interest rates. The Company is exposed to fluctuations in interest rates, as its regulated return on equity is derived using a formulaic approach that takes anticipated interest rates into account. The Company is not currently exposed to material commodity price risk or material foreign exchange risk.

The Company uses a combination of fixed and variable-rate debt to manage the mix of its debt portfolio. The Company also uses derivative financial instruments to manage interest-rate risk. The Company may utilize interest-rate swaps designated as fair value hedges as a means to manage its interest rate exposure to achieve a lower cost of debt. The Company may also utilize interest-rate derivative instruments, such as cash flow hedges, to manage its exposure to short-term interest rates or to lock in interest-rate levels on forecasted financing.


			27

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

A hypothetical 100 basis point increase in interest rates associated with variable-rate debt would not have resulted in a significant decrease to Hydro One’s net income for the years ended December 31, 2022 and 2021, respectively.

For derivative instruments that are designated and qualify as cash flow hedges, the unrealized gain or loss, after tax, on the derivative instrument is recorded as OCI or OCL and is reclassified to results of operations in the same period during which the hedged transaction affects results of operations. During the year ended December 31, 2022, a $12 million after-tax unrealized gain (2021 - $4 million loss), $17 million before-tax (2021 - $5 million loss), was recorded in OCI, and a $2 million after-tax realized gain (2021 - $8 million loss), $3 million before-tax (2021 - $12 million loss), was reclassified to financing charges. This resulted in an accumulated other comprehensive income (AOCI) of $4 million related to cash flow hedges at December 31, 2022 (2021 - accumulated other comprehensive loss (AOCL) - $6 million). The Company estimates that the amount of AOCI, after tax, related to cash flow hedges to be reclassified to results of operations in the next 12 months is $4 million. Actual amounts reclassified to results of operations depend on the interest rate risk in effect until the derivative contracts mature. For all forecasted transactions, at December 31, 2022, the maximum term over which the Company is hedging exposures to the variability of cash flows is less than three months.

The Pension Plan manages market risk by diversifying investments in accordance with the Pension Plan’s Statement of Investment Policies and Procedures. Interest rate risk arises from the possibility that changes in interest rates will affect the fair value of the Pension Plan’s financial instruments. In addition, changes in interest rates can also impact discount rates which impact the valuation of the pension and post-retirement and post-employment liabilities. Currency risk is the risk that the value of the Pension Plan’s financial instruments will fluctuate due to changes in foreign currencies relative to the Canadian dollar. Other price risk is the risk that the value of the Pension Plan’s investments in equity securities will fluctuate as a result of changes in market prices, other than those arising from interest rate risk or currency risk. All three factors may contribute to changes in values of the Pension Plan investments. See Note 19 - Pension and Post-Retirement and Post-Employment Benefits for further details.

Credit Risk

Financial assets create a risk that a counterparty will fail to discharge an obligation, causing a financial loss. At December 31, 2022 and 2021, there were no significant concentrations of credit risk with respect to any class of financial assets. The Company’s revenue is earned from a broad base of customers. As a result, Hydro One did not earn a material amount of revenue from any single customer. At December 31, 2022 and 2021, there was no material accounts receivable balance due from any single customer.

At December 31, 2022, the Company’s allowance for doubtful accounts was $63 million (2021 - $56 million). The allowance for doubtful accounts reflects the Company's CECL for all accounts receivable balances, which are based on historical overdue balances, customer payments and write-offs. At December 31, 2022, approximately 4% (2021 - 5%) of the Company’s net accounts receivable were outstanding for more than 60 days.

Hydro One manages its counterparty credit risk through various techniques including (i) entering into transactions with highly rated counterparties, (ii) limiting total exposure levels with individual counterparties, (iii) entering into master agreements which enable net settlement and the contractual right of offset, and (iv) monitoring the financial condition of counterparties. The Company monitors current credit exposure to counterparties on both an individual and an aggregate basis. The Company’s credit risk for accounts receivable is limited to the carrying amounts on the consolidated balance sheets.

Derivative financial instruments result in exposure to credit risk since there is a risk of counterparty default. The maximum credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts in an asset position at the reporting date. At December 31, 2022 and 2021, the counterparty credit risk exposure on the fair value of these interest-rate swap contracts was not material. At December 31, 2022, Hydro One’s credit exposure for all derivative instruments, and applicable payables and receivables, was with two financial institutions with investment grade credit ratings as counterparties.

The Pension Plan manages its counterparty credit risk with respect to bonds by investing in investment-grade corporate and government bonds and with respect to derivative instruments by transacting only with highly rated financial institutions and by ensuring that exposure is diversified across counterparties.

Liquidity Risk

Liquidity risk refers to the Company’s ability to meet its financial obligations as they come due. Hydro One meets its short-term operating liquidity requirements using cash and cash equivalents on hand, funds from operations, the issuance of commercial paper, and the Operating Credit Facilities. The short-term liquidity under the commercial paper program, the Operating Credit Facilities, and anticipated levels of funds from operations are expected to be sufficient to fund the Company’s operating requirements. The Company's currently available liquidity is also expected to be sufficient to address any reasonably foreseeable impacts that the COVID-19 pandemic may have on the Company’s cash requirements.


			28

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

The Pension Plan’s short-term liquidity is provided through cash and cash equivalents, contributions, investment income and proceeds from investment transactions. In the event that investments must be sold quickly to meet current obligations, the majority of the Pension Plan’s assets are invested in securities that are traded in an active market and can be readily disposed of as liquidity needs arise.

18. CAPITAL MANAGEMENT

The Company’s objectives with respect to its capital structure are to maintain effective access to capital on a long-term basis at reasonable rates, and to deliver appropriate financial returns. In order to ensure ongoing access to capital, the Company targets to maintain strong credit quality. At December 31, 2022 and 2021, the Company’s capital structure was as follows:


As at December 31 (millions of dollars)	2022	2021
Short-term notes payable	1,374	1,045
Long-term debt payable within one year	733	603
Less: cash and cash equivalents	(458)	(499)
	1,649	1,149

Long-term debt	12,606	12,593
Common shares	2,957	2,957
Retained earnings	8,634	8,229
Total capital	25,846	24,928

Hydro One and HOSSM have customary covenants typically associated with long-term debt. Long-term debt and credit facility covenants limit permissible debt to 75% of its total capitalization, limit the ability to sell assets and impose a negative pledge provision, subject to customary exceptions. At December 31, 2022, the Company was in compliance with all financial covenants and limitations associated with the outstanding borrowings and credit facilities.

19. PENSION AND POST-RETIREMENT AND POST-EMPLOYMENT BENEFITS

Hydro One has a Pension Plan, a DC Plan, a supplementary pension plan (Supplementary Plan), and post-retirement and post-employment benefit plans.

DC Plan

Hydro One established a DC Plan effective January 1, 2016. The DC Plan covers eligible management employees hired on or after January 1, 2016, as well as management employees hired before January 1, 2016 who were not eligible to join the Pension Plan as of September 30, 2015. Members of the DC Plan have an option to contribute 4%, 5% or 6% of their pensionable earnings, with matching contributions by Hydro One up to an annual contribution limit. There is also a Supplementary DC Plan that provides members of the DC Plan with employer contributions beyond the limitations imposed by the Income Tax Act (Canada) in the form of credits to a notional account. Hydro One contributions to the DC Plan for the year ended December 31, 2022 were $3 million (2021 - $2 million).

Pension Plan, Supplementary Plan, and Post-Retirement and Post-Employment Plans

The Pension Plan is a defined benefit contributory plan which covers eligible regular employees of Hydro One and its subsidiaries. The Pension Plan provides benefits based on highest three-year average pensionable earnings. For management employees who commenced employment on or after January 1, 2004, and for the Society of United Professionals (Society)-represented staff hired after November 17, 2005, benefits are based on highest five-year average pensionable earnings. After retirement, pensions are indexed to inflation. Membership in the Pension Plan was closed to management employees who were not eligible to join the Pension Plan as of September 30, 2015. These employees are eligible to join the DC Plan.

Company and employee contributions to the Pension Plan are based on actuarial reports, including valuations performed at least every three years, and actual or projected levels of pensionable earnings, as applicable. The most recent actuarial valuation was performed effective December 31, 2021 and filed on September 26, 2022. Total annual cash Pension Plan employer contributions for 2022 were $89 million (2021 - $62 million). Estimated annual Pension Plan employer contributions for the years 2023, 2024, 2025, 2026 and 2027 are approximately $91 million, $101 million, $103 million, $106 million, and $109 million, respectively.

The Supplementary Plan provides members of the Pension Plan with benefits that would have been earned and payable under the Pension Plan beyond the limitations imposed by the Income Tax Act (Canada). The Supplementary Plan obligation is included with other post-retirement and post-employment benefit obligations on the consolidated balance sheets.

Hydro One recognizes the overfunded or underfunded status of the Pension Plan, and post-retirement and post-employment benefit plans (Plans) as an asset or liability on its consolidated balance sheets, with offsetting regulatory assets and liabilities as appropriate. The overfunded benefit asset and underfunded benefit obligations for the Plans, in the absence of regulatory


			29

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

accounting, would be recognized in AOCI. The impact of changes in assumptions used to measure pension and post-retirement benefit obligations is generally recognized over the expected average remaining service period of the employees and using the corridor approach for the post-retirement benefit plan. For post-employment benefit plan, the impact of changes in assumptions are recognized immediately in the net periodic benefit cost. The measurement date for the Plans is December 31.

The following tables provide the components of the unfunded status of the Company's Plans at December 31, 2022 and 2021:


	Pension Benefits		Post-Retirement and Post-Employment Benefits
Year ended December 31 (millions of dollars)	2022	2021	2022	2021
Change in projected benefit obligation
Projected benefit obligation, beginning of year	9,358	9,763	1,846	1,841
Current service cost	214	240	63	65
Employee contributions	63	61	—	—
Interest cost	283	257	57	51
Benefits paid	(402)	(392)	(51)	(47)
Net actuarial loss	(1,970)	(571)	(493)	(98)
Transfers from other plans1	—	—	8	34
Projected benefit obligation, end of year	7,546	9,358	1,430	1,846

Change in plan assets
Fair value of plan assets, beginning of year	8,645	8,103	—	—
Actual return on plan assets	(470)	834	—	—
Benefits paid	(402)	(392)	(51)	(47)
Employer contributions	89	62	51	47
Employee contributions	63	61	—	—
Administrative expenses	(21)	(23)	—	—

Fair value of plan assets, end of year	7,904	8,645	—	—

Unfunded (funded) status	(358)	713	1,430	1,846

1 See below for information related to the transfer from other plans in 2021 as well as future transfers from other plans for employees transferred in 2021 and 2022.

Future Transfers from Other Plans

Hydro One and Inergi LP agreed to transfer the employment of certain Inergi LP employees (Transferred Employees) to Hydro One Networks. Employees related to the Information Technology Operations, Finance and Accounting, Payroll, Source to Pay, Settlements and certain Shared Services functions were transferred over a period ending January 1, 2022. The Transferred Employees who were participants in the Inergi LP Pension Plan (Inergi Plan) became participants in the Hydro One Pension Plan upon transfer to Hydro One Networks. In December 2022, approval was granted by the Financial Services Regulatory Authority of Ontario to transfer the assets and liabilities of the Inergi Plan, however, the assets and liabilities have not yet been transferred to the Hydro One Pension Plan. The values of assets and liabilities of the Inergi Plan to be transferred to the Plan will be determined at the date of transfer, which is expected to occur in Q1 or Q2 2023. Inergi and Hydro One Networks also agreed to transfer OPEB liabilities related to the Transferred Employees to Hydro One’s post-retirement and post-employment benefit plans.

On March 1, 2021, Transferred Employees associated with information technology operations (ITO Employees) transferred to Hydro One Networks, and the transfer of the OPEB liability of $28 million related to the ITO Employees was completed. The liability was recorded as a post-retirement and post-employment benefit liability with an offset to OCL, and cash totaling $27 million was transferred to Hydro One and recorded as an asset with an offset to OCI. Both, the OCI resulting from the transfer of the cash asset and the OCL resulting from the transfer of the other post-retirement benefit liability are being recognized in net income over the expected average remaining service lifetime (EARSL) of the ITO Employees.

On November 1, 2021, Transferred Employees associated with source to pay operations (S2P Employees) transferred to Hydro One Networks, and the transfer of the OPEB liability of $6 million related to the S2P Employees was completed. The liability was recorded as a post-retirement and post-employment benefit liability with an offset to OCL, and cash totaling $6 million was transferred to Hydro One and recorded as an asset with an offset to OCI. Both, the OCI resulting from the transfer of the cash asset and the OCL resulting from the transfer of the other post-retirement benefit liability are being recognized in net income over the EARSL of the S2P Employees.

The transfer of Finance and Accounting, Payroll and certain Shared Services functions occurred on January 1, 2022 and the transfer of the OPEB liability of $9 million related to these Employees was completed in the first quarter. The liability was recorded as a post-retirement and post-employment benefit liability with an offset to OCL, and cash totaling $10 million was transferred to Hydro One and recorded as an asset with an offset to OCI. Both the OCI resulting from the transfer of the cash asset and the OCL resulting from the transfer of the other post-retirement benefit liability are being recognized in net income over the EARSL of the Finance and Accounting, Payroll and certain Shared Services employees.


			30

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Hydro One presents its benefit obligations and plan assets net on its consolidated balance sheets as follows:


	Pension Benefits		Post-Retirement and Post-Employment Benefits
As at December 31 (millions of dollars)	2022	2021	2022	2021
Other assets1	9	10	—	—
Deferred pension assets	358	—	—	—
Accrued liabilities	—	—	66	62
Pension benefit liability	—	713	—	—
Post-retirement and post-employment benefit liability	—	—	1,364	1,784
Net unfunded (funded) status	(367)	703	1,430	1,846

1 Represents the funded status of HOSSM defined benefit pension plan.

The funded or unfunded status of the Plans refers to the difference between the fair value of plan assets and the PBO for the Plans. The funded/unfunded status changes over time due to several factors, including contribution levels, assumed discount rates and actual returns on plan assets.

The following table provides the PBO, accumulated benefit obligation (ABO) and fair value of plan assets for the Pension Plan:


As at December 31 (millions of dollars)	2022	2021
PBO	7,546	9,358
ABO	7,002	8,451
Fair value of plan assets	7,904	8,645

On an ABO basis, the Pension Plan was funded at 113% as at December 31, 2022 (2021 - 102%). On a PBO basis, the Pension Plan was funded at 105% at December 31, 2022 (2021 - 92%). The ABO differs from the PBO in that the ABO includes no assumption about future compensation levels.

Components of Net Periodic Benefit Costs

The following table provides the components of the net periodic benefit costs for the years ended December 31, 2022 and 2021 for the Pension Plan:



Year ended December 31 (millions of dollars)	2022	2021
Current service cost	214	240
Interest cost	283	257
Expected return on plan assets, net of expenses	(507)	(430)
Prior service cost amortization	2	2
Amortization of actuarial losses	61	125
Net periodic benefit costs	53	194

Charged to results of operations1	34	26

1 The Company accounts for pension costs consistent with their inclusion in OEB-approved rates. During the year ended December 31, 2022, pension costs of $87 million (2021 - $73 million) were attributed to labour, of which $34 million (2021 - $26 million) was charged to operations, and $53 million (2021 - $47 million) was capitalized as part of the cost of property, plant and equipment and intangible assets.

The following table provides the components of the net periodic benefit costs for the years ended December 31, 2022 and 2021 for the post-retirement and post-employment benefit plans:


Year ended December 31 (millions of dollars)	2022	2021
Current service cost	63	65
Interest cost	57	51

Prior service cost amortization	11	7
Amortization of actuarial losses	(8)	(2)
Net periodic benefit costs	123	121

Charged to results of operations1,2	70	63

1 The Company accounts for post-retirement and post-employment costs consistent with their inclusion in OEB-approved rates. During the year ended December 31, 2022, post-retirement and post-employment costs of $123 million (2021 - $121 million) were attributed to labour, of which $70 million (2021 - $63 million) was charged to operations, $15 million (2021 - $14 million) was recorded in the Hydro One Networks distribution post-retirement and post-employment benefits non-service cost regulatory asset, and $38 million (2021 - $44 million) was capitalized as part of the cost of property, plant and equipment and intangible assets.

2 In the 2020-2022 Transmission Decision, the OEB approved the recovery of the non-service cost component of post-retirement and post-employment benefits as part of operation, maintenance and administration costs for the Company's transmission business. These costs were previously capitalized and recovered through rate base. As a result, during the year ended December 31, 2022, additional other post-retirement and post-employment costs of $14 million (2021 - $14 million) attributed to labour were charged to operations.


			31

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Assumptions

The measurement of the obligations of the Plans and the costs of providing benefits under the Plans involves various factors, including the development of valuation assumptions and accounting policy elections. When developing the required assumptions, the Company considers historical information as well as future expectations. The measurement of benefit obligations and costs is impacted by several assumptions including the discount rate applied to benefit obligations, the long-term expected rate of return on plan assets, Hydro One’s expected level of contributions to the Plans, the incidence of mortality, the expected remaining service period of plan participants, the level of compensation and rate of compensation increases, employee age, length of service, and the anticipated rate of increase of health care costs, among other factors. The impact of changes in assumptions used to measure the obligations of the Plans is generally recognized over the expected average remaining service period of the plan participants. In selecting the expected rate of return on plan assets, Hydro One considers historical economic indicators that impact asset returns, as well as expectations regarding future long-term capital market performance, weighted by target asset class allocations. In general, equity securities, real estate and private equity investments are forecasted to have higher returns than fixed-income securities.

The following weighted average assumptions were used to determine the benefit obligations at December 31, 2022 and 2021:


	Pension Benefits				Post-Retirement and Post-Employment Benefits
Year ended December 31	2022		2021		2022		2021
Significant assumptions:
Weighted average discount rate	5.06	%	3.00	%	5.07	%	3.04	%
Rate of compensation scale escalation (long-term)	2.50	%	2.25	%	2.50	%	2.25	%
Rate of cost of living increase	2.00	%	1.75	%	2.00	%	1.75	%
Rate of increase in health care cost trends1	—		—		4.19	%	3.97	%

1 5.02% per annum in 2023, grading down to 4.19% per annum in and after 2031 (2021 - 4.88% per annum in 2022, grading down to 3.97% per annum in and after 2031)

The following weighted average assumptions were used to determine the net periodic benefit costs for the years ended December 31, 2022 and 2021. Assumptions used to determine current year-end benefit obligations are the assumptions used to estimate the subsequent year’s net periodic benefit costs.


Year ended December 31	2022		2021
Pension Benefits:
Weighted average expected rate of return on plan assets	6.00	%	5.40	%
Weighted average discount rate	3.00	%	2.60	%
Rate of compensation scale escalation (long-term)	2.25	%	2.25	%
Rate of cost of living increase	1.75	%	1.75	%
Average remaining service life of employees (years)	14		14

Post-Retirement and Post-Employment Benefits:
Weighted average discount rate	3.04	%	2.60	%
Rate of compensation scale escalation (long-term)	2.25	%	2.25	%
Rate of cost of living increase	1.75	%	1.75	%
Average remaining service life of employees (years)	14.9		15.3
Rate of increase in health care cost trends1	3.97	%	3.70	%

1 4.88% per annum in 2022, grading down to 3.97% per annum in and after 2031 (2021 - 4.74% per annum in 2021, grading down to 3.70% per annum in and after 2031)

The discount rate used to determine the current year pension obligation and the subsequent year’s net periodic benefit costs is based on a yield curve approach. Under the yield curve approach, expected future benefit payments for each plan are discounted by a rate on a third-party bond yield curve corresponding to each duration. The yield curve is based on “AA” long-term corporate bonds. A single discount rate is calculated that would yield the same present value as the sum of the discounted cash flows.

The following approximate life expectancies were used in the mortality assumptions to determine the PBO for the pension and post-retirement and post-employment plans at December 31, 2022 and 2021:


As at December 31	2022	2021
Life expectancy at age 65 for a member currently at:	(years)	(years)
Age 65 - male	23	23
Age 65 - female	25	25
Age 45 - male	24	24
Age 45 - female	26	26


			32

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Estimated Future Benefit Payments

At December 31, 2022, estimated future benefit payments to the participants of the Plans were:


(millions of dollars)	Pension Benefits	Post-Retirement and Post-Employment Benefits
2023	395	67
2024	405	68
2025	414	70
2026	420	71
2027	424	71
2028 through to 2032	2,187	368
Total estimated future benefit payments through to 2032	4,245	715

Components of Regulatory Accounts

A portion of actuarial gains and losses and prior service costs is recorded within regulatory accounts on Hydro One’s consolidated balance sheets to reflect the expected regulatory inclusion of these amounts in future rates, which would otherwise be recorded in OCI. These amounts are reflected in the following table:


Year ended December 31 (millions of dollars)	2022	2021
Pension Benefits:
Net actuarial gain for the year	(972)	(891)
Amortization of actuarial losses	(61)	(124)
Amortization of prior service cost	(2)	(2)
	(1,035)	(1,017)

Post-Retirement and Post-Employment Benefits:
Actuarial gain for the year	(471)	(91)
Amortization of actuarial losses	(2)	(3)

	(473)	(94)

The following table provides the components of regulatory accounts that have not been recognized as components of net periodic benefit costs for the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)	2022	2021
Pension Benefits:
Actuarial loss (gain)	(358)	713

Post-Retirement and Post-Employment Benefits:
Actuarial gain	(506)	(33)

Pension Plan Assets

Investment Strategy

On a regular basis, Hydro One evaluates its investment strategy to ensure that Pension Plan assets will be sufficient to pay Pension Plan benefits when it comes due. As part of this ongoing evaluation, Hydro One may make changes to its targeted asset allocation and investment strategy. The Pension Plan is managed at a net asset level. The main objective of the Pension Plan is to sustain a certain level of net assets in order to meet the pension obligations of the Company. The Pension Plan fulfils its primary objective by adhering to specific investment policies outlined in its Statement of Investment Policies and Procedures (SIPP), which is reviewed and approved annually by the Human Resource Committee of Hydro One’s Board of Directors. The Company manages net assets by engaging external investment managers who are charged with the fiduciary responsibility of investing existing funds and new funds (current year’s employee and employer contributions) in accordance with the approved SIPP. The performance of the underlying investment managers is monitored through a governance structure. Increases in net assets are a direct result of investment income generated by investments held by the Pension Plan and contributions to the Pension Plan by eligible employees and by the Company. The main use of net assets is for benefit payments to eligible Pension Plan members.


			33

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Pension Plan Asset Mix

At December 31, 2022, the Pension Plan actual weighted average, target, and range asset allocations were as follows:


	Actual (%)	Target Allocation (%)	Range Allocation (%)
Equity securities	48	40	25 - 55
Debt securities	33	35	30 - 40
Real Estate and Infrastructure	19	25	0 - 35
	100	100

At December 31, 2022, the Pension Plan held $21 million (2021 - $22 million) Hydro One corporate bonds and $425 million (2021 - $603 million) of debt securities of the Province.

Concentrations of Credit Risk

Hydro One evaluated its Pension Plan’s asset portfolio for the existence of significant concentrations of credit risk as at December 31, 2022 and 2021. Concentrations that were evaluated include, but are not limited to, investment concentrations in a single entity, concentrations in a type of industry, and concentrations in individual funds. At December 31, 2022 and 2021, there were no significant concentrations (defined as greater than 10% of plan assets) of risk in the Pension Plan’s assets.

The Pension Plan's Statement of Investment Beliefs and Guidelines provides guidelines and restrictions for eligible investments taking into account credit ratings, maximum investment exposure and other controls in order to limit the impact of this risk. The Pension Plan manages its counterparty credit risk with respect to bonds by investing in investment-grade and government bonds and with respect to derivative instruments by transacting only with highly rated financial institutions, and also by ensuring that exposure is diversified across counterparties. The risk of default on transactions in listed securities is considered minimal, as the trade will fail if either party to the transaction does not meet its obligation.

Fair Value Measurements

The following tables present the Pension Plan assets and liabilities measured and recorded at fair value on a recurring basis and their level within the fair value hierarchy at December 31, 2022 and 2021:


As at December 31, 2022 (millions of dollars)	Level 1	Level 2	Level 3	Total
Pooled funds	—	26	2,315	2,341
Cash and cash equivalents	233	—	—	233
Short-term securities	—	116	—	116
Derivative instruments	—	—	—	—
Corporate shares - Canadian	139	—	—	139
Corporate shares - Foreign	2,702	204	—	2,906
Bonds and debentures - Canadian	—	2,044	—	2,044
Bonds and debentures - Foreign	—	84	—	84
Total fair value of plan assets1	3,074	2,474	2,315	7,863


Derivative instruments	—	1	—	1
Total fair value of plan liabilities1	—	1	—	1

1 At December 31, 2022, the total fair value of Pension Plan assets and liabilities excludes $44 million of interest and dividends receivable, $5 million of pension administration expenses payable, $2 million of taxes payable, $3 million receivable from participants, $4 million of sold investments receivable, and $2 million of purchased investments payable.


As at December 31, 2021 (millions of dollars)	Level 1	Level 2	Level 3	Total
Pooled funds	—	21	1,937	1,958
Cash and cash equivalents	144	—	—	144
Short-term securities	—	86	—	86
Derivative instruments	—	2	—	2
Corporate shares - Canadian	167	—	—	167
Corporate shares - Foreign	3,412	258	—	3,670
Bonds and debentures - Canadian	—	2,491	—	2,491
Bonds and debentures - Foreign	—	97	—	97
Total fair value of plan assets1	3,723	2,955	1,937	8,615


Derivative instruments	—	1	—	1
Total fair value of plan liabilities1	—	1	—	1

1 At December 31, 2021, the total fair value of Pension Plan assets and liabilities excludes $39 million of interest and dividends receivable, $5 million of pension administration expenses payable, $2 million of taxes payable, $4 million payable to participants, $6 million of sold investments receivable, and $3 million of purchased investments payable.


			34

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

See Note 17 - Fair Value of Financial Instruments and Risk Management for a description of levels within the fair value hierarchy.

Changes in the Fair Value of Financial Instruments Classified in Level 3

The following table summarizes the changes in fair value of financial instruments classified in Level 3 for the years ended December 31, 2022 and 2021. The Pension Plan classifies financial instruments as Level 3 when the fair value is measured based on at least one significant input that is not observable in the markets or due to lack of liquidity in certain markets. The gains and losses presented in the table below could, therefore, include changes in fair value based on both observable and unobservable inputs. The Level 3 financial instruments are comprised of pooled funds whose valuations are provided by the investment managers. Sensitivity analysis is not provided as the underlying assumptions used by the investment managers are not available.


Year ended December 31 (millions of dollars)	2022	2021
Fair value, beginning of year	1,937	1,429
Realized and unrealized gains	128	307
Purchases	336	308
Sales and disbursements	(86)	(107)
Fair value, end of year	2,315	1,937

There were no significant transfers between any of the fair value levels during the years ended December 31, 2022 and 2021.

Valuation Techniques Used to Determine Fair Value

Pooled funds mainly consist of private equity, real estate infrastructure and private debt investments. Private equity investments represent private equity funds that invest in operating companies that are not publicly traded on a stock exchange. Investment strategies in private equity include limited partnerships in businesses that are characterized by high internal growth and operational efficiencies, venture capital, leveraged buyouts and special situations such as distressed investments. Real estate and infrastructure investments represent funds that invest in real assets which are not publicly traded on a stock exchange. Investment strategies in real estate include limited partnerships that seek to generate a total return through income and capital growth by investing primarily in global and Canadian limited partnerships. Investment strategies in infrastructure include limited partnerships in core infrastructure assets focusing on assets that are expected to generate stable, long-term cash flows and deliver incremental returns relative to conventional fixed-income investments. Private equity, real estate and infrastructure valuations are reported by the fund manager and are based on the valuation of the underlying investments which includes inputs such as cost, operating results, discounted future cash flows and market-based comparable data. Private debt valuations are reported by the fund manager. Private debt is credit that is extended to companies on a bilaterally negotiated basis. It is not readily marketable and takes a wide range of forms, such as senior secured and unsecured loans, infrastructure project financing, investments secured by real estate assets, and securitized lease/loan obligations supported by a pool of assets. Since these valuation inputs are not highly observable, private equity, real estate infrastructure and private debt investments have been categorized as Level 3 within pooled funds.

Cash equivalents consist of demand cash deposits held with banks and cash held by the investment managers. Cash equivalents are categorized as Level 1.

Short-term securities are valued at cost plus accrued interest, which approximates fair value due to their short-term nature. Short-term securities are categorized as Level 2.

Derivative instruments are used to hedge the Pension Plan’s foreign currency exposure back to Canadian dollars. The notional principal amount of contracts outstanding as at December 31, 2022 was $355 million (2021 - $414 million), the most significant currencies being hedged against the Canadian dollar are the United States dollar, euro, British pound sterling, Swedish krona and Japanese yen. The net realized loss on contracts for the year ended December 31, 2022 was $4 million (2021 - $2 million net realized gain). The terms to maturity of the forward exchange contracts at December 31, 2022 are within three months. The fair value is determined using standard interpolation methodology primarily based on the World Markets exchange rates. Derivative instruments are categorized as Level 2.

Corporate shares are valued based on quoted prices in active markets and are categorized as Level 1. Corporate shares which are valued based on quoted prices in active markets, but held within a pension investment holding company, are categorized as Level 2. Investments denominated in foreign currencies are translated into Canadian currency at year-end rates of exchange.

Bonds and debentures are presented at published closing trade quotations, and are categorized as Level 2.


			35

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

20. ENVIRONMENTAL LIABILITIES

The following tables show the movements in environmental liabilities for the years ended December 31, 2022 and 2021:


Year ended December 31, 2022 (millions of dollars)	PCB	LAR	Total
Environmental liabilities - beginning	68	54	122
Interest accretion	1	—	1
Expenditures	(40)	(6)	(46)
Revaluation adjustment	20	(4)	16
Environmental liabilities - ending	49	44	93
Less: current portion	(20)	(5)	(25)
	29	39	68


Year ended December 31, 2021 (millions of dollars)	PCB	LAR	Total
Environmental liabilities - beginning	76	57	133
Interest accretion	1	—	1
Expenditures	(24)	(6)	(30)
Revaluation adjustment	15	3	18
Environmental liabilities - ending	68	54	122
Less: current portion	(27)	(7)	(34)
	41	47	88

The following tables show the reconciliation between the undiscounted basis of the environmental liabilities and the amount recognized on the consolidated balance sheets after factoring in the discount rate:


As at December 31, 2022 (millions of dollars)	PCB	LAR	Total
Undiscounted environmental liabilities	50	44	94
Less: discounting environmental liabilities to present value	(1)	—	(1)
Discounted environmental liabilities	49	44	93


As at December 31, 2021 (millions of dollars)	PCB	LAR	Total
Undiscounted environmental liabilities	70	54	124
Less: discounting environmental liabilities to present value	(2)	—	(2)
Discounted environmental liabilities	68	54	122

At December 31, 2022, the estimated future environmental expenditures were as follows:


(millions of dollars)
2023			25
2024			25
2025			14
2026			2
2027			2
Thereafter			26
			94

Hydro One records a liability for the estimated future expenditures for LAR and for the phase-out and destruction of PCB-contaminated mineral oil removed from electrical equipment when it is determined that future environmental remediation expenditures are probable under existing statute or regulation and the amount of the future expenditures can be reasonably estimated.

There are uncertainties in estimating future environmental costs due to potential external events such as changes in legislation or regulations, and advances in remediation technologies. In determining the amounts to be recorded as environmental liabilities, the Company estimates the current cost of completing required work and makes assumptions as to when the future expenditures will actually be incurred, in order to generate future cash flow information. A long-term inflation rate assumption of approximately 2% has been used to express these current cost estimates as estimated future expenditures. Future expenditures have been discounted using factors ranging from approximately 2.0% to 6.3% (2021 - 2.0% to 6.3%) depending on the appropriate rate for the period when expenditures are expected to be incurred. All factors used in estimating the Company’s environmental liabilities represent management’s best estimates of the present value of costs required to meet existing legislation or regulations. However, it is reasonably possible that numbers or volumes of contaminated assets, cost estimates to perform work, inflation assumptions and the assumed pattern of annual cash flows may differ significantly from the Company’s current assumptions. In addition, with respect to the PCB environmental liability, the availability of critical resources such as skilled labour and replacement assets and the ability to take maintenance outages in critical facilities may influence the timing of expenditures.


			36

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

PCBs

The Environment Canada regulations, enacted under the Canadian Environmental Protection Act, 1999, govern the management, storage and disposal of PCBs based on certain criteria, including type of equipment, in-use status, and PCB-contamination thresholds. Under current regulations, Hydro One’s PCBs have to be disposed of by the end of 2025, with the exception of specifically exempted equipment. Contaminated equipment will generally be replaced, or will be decontaminated by removing PCB-contaminated insulating oil and retro filling with replacement oil that contains PCBs in concentrations of less than 2 ppm.

At December 31, 2022, the Company’s best estimate of the total estimated future expenditures to comply with current PCB regulations was $50 million (2021 - $70 million). These expenditures are expected to be incurred over the period from 2023 to 2025. As a result of its annual review of environmental liabilities, the Company recorded a revaluation adjustment in 2022 to increase the PCB environmental liability by $20 million (2021 - $15 million).

LAR

At December 31, 2022, the Company’s best estimate of the total estimated future expenditures to complete its LAR program was $44 million (2021 - $54 million). These expenditures are expected to be incurred over the period from 2023 to 2049. As a result of its annual review of environmental liabilities, the Company recorded a revaluation adjustment in 2022 to decrease the LAR environmental liability by $4 million (2021 - increase of $3 million).

21. ASSET RETIREMENT OBLIGATIONS

Hydro One records a liability for the estimated future expenditures for the removal and disposal of asbestos-containing materials installed in some of its facilities, as well as for the estimated expenditure for the future decommissioning and removal of some diesel generating stations and related assets operated by its subsidiary, Hydro One Remotes.

Asset retirement obligations, which represent legal obligations associated with the retirement of certain tangible long-lived assets, are computed as the present value of the projected expenditures for the future retirement of specific assets and are recognized in the period in which the liability is incurred, if a reasonable estimate can be made. If the asset remains in service at the recognition date, the present value of the liability is added to the carrying amount of the associated asset in the period the liability is incurred and this additional carrying amount is depreciated over the remaining life of the asset. If an asset retirement obligation is recorded in respect of an out-of-service asset, the asset retirement cost is charged to results of operations. Subsequent to the initial recognition, the liability is adjusted for any revisions to the estimated future cash flows associated with the asset retirement obligation, which can occur due to a number of factors including, but not limited to, cost escalation, changes in technology applicable to the assets to be retired, changes in legislation or regulations, as well as for accretion of the liability due to the passage of time until the obligation is settled. Depreciation expense is adjusted prospectively for any increases or decreases to the carrying amount of the associated asset.

Some of the Company’s transmission and distribution assets, particularly those located on unowned easements and rights-of-way, may have asset retirement obligations, conditional or otherwise. The majority of the Company’s easements and rights-of-way are either of perpetual duration or are automatically renewed annually. Land rights with finite terms are generally subject to extension or renewal. As the Company expects to use the majority of its facilities in perpetuity, no asset retirement obligations have been recorded for these assets. If, at some future date, a particular facility is shown not to meet the perpetuity assumption, it will be reviewed to determine whether an estimable asset retirement obligation exists. In such a case, an asset retirement obligation would be recorded at that time.

In determining the amounts to be recorded as asset retirement obligations, the Company estimates the current fair value for completing required work and makes assumptions as to when the future expenditures will actually be incurred, in order to generate future cash flow information. A long-term inflation assumption of approximately 2% has been used to express these current cost estimates as estimated future expenditures. Future expenditures have been discounted using factors ranging from approximately 2.0% to 4.0% (2021 - 2.0% to 4.0%) depending on the appropriate rate for the period when expenditures are expected to be incurred. All factors used in estimating the Company’s asset retirement obligations represent management’s best estimates of the cost required to meet existing legislation or regulations. However, it is reasonably possible that numbers or volumes of contaminated assets, cost estimates to perform work, inflation assumptions and the assumed pattern of annual cash flows may differ significantly from the Company’s current assumptions. Asset retirement obligations are reviewed annually or more frequently if significant changes in regulations or other relevant factors occur. Estimate changes are accounted for prospectively. During the year, the Company recorded an asset retirement obligation associated with the decommissioning and removal of diesel generating stations within the Hydro One Remotes operating territory. As a result of its annual review of asset retirement obligations, the Company also recorded a revaluation adjustment in 2022 to increase the asset retirement obligations related to the removal and disposal of asbestos-containing materials installed in some of its facilities by $3 million (2021 - no revaluation adjustment to the asset retirement obligations was recorded).

At December 31, 2022, Hydro One had recorded a total asset retirement obligation of $28 million (2021 - $14 million), primarily consisting of the estimated future expenditures associated with the removal and disposal of asbestos-containing materials


			37

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

installed in some of its facilities of $17 million (2021 - $14 million), and the decommissioning and removal of diesel generating stations of $11 million.

22. LEASES

Hydro One has operating lease contracts for buildings used in administrative and service-related functions and storing telecommunications equipment. These leases have terms between three and eight years with renewal options of additional three- to five-year terms at prevailing market rates at the time of extension. All leases include a clause to enable upward revision of the rental charge on an annual basis or on renewal according to prevailing market conditions or pre-established rents. There are no restrictions placed upon Hydro One by entering into these leases. Renewal options are included in the lease term when their exercise is reasonably certain. Other information related to the Company's operating leases was as follows:


Year ended December 31 (millions of dollars)	2022		2021
Lease expense	10		13
Lease payments made	13		13

As at December 31	2022		2021
Weighted-average remaining lease term1 (years)	5		6
Weighted-average discount rate	2.4	%	2.3	%

1 Includes renewal options that are reasonably certain to be exercised.

At December 31, 2022, future minimum operating lease payments were as follows:


(millions of dollars)
2023												12
2024												11
2025												9
2026												9
2027												8
Thereafter												7
Total undiscounted minimum lease payments												56
Less: discounting minimum lease payments to present value												(4)
Total discounted minimum lease payments												52

At December 31, 2021, future minimum operating lease payments were as follows:


(millions of dollars)
2022												14
2023												10
2024												9
2025												7
2026												7
Thereafter												13
Total undiscounted minimum lease payments												60
Less: discounting minimum lease payments to present value												(4)
Total discounted minimum lease payments												56

Hydro One presents its ROU assets and lease obligations on the consolidated balance sheets as follows:


As at December 31 (millions of dollars)	2022	2021
Other long-term assets (Note 13)	53	53
Accounts payable and other current liabilities (Note 14)	11	12
Other long-term liabilities (Note 15)	42	44


			38

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

23. SHARE CAPITAL

Common Shares

The Company is authorized to issue an unlimited number of common shares. At December 31, 2022 and 2021, the Company had 142,239 common shares issued and outstanding.

Preferred Shares

The Company is authorized to issue an unlimited number of preferred shares, issuable in series. At December 31, 2022 and 2021, the Company had no preferred shares issued and outstanding.

24. DIVIDENDS

In 2022, common share dividends in the amount of $652 million (2021 - $620 million) were declared and paid. See Note 33 - Subsequent Events for dividends declared subsequent to December 31, 2022.

25. EARNINGS PER COMMON SHARE

Basic and diluted earnings per common share is calculated by dividing net income attributable to common shareholder of Hydro One by the weighted-average number of common shares outstanding. The weighted-average number of common shares outstanding at December 31, 2022 and 2021 were 142,239. There were no dilutive securities during 2022 and 2021.

26. STOCK-BASED COMPENSATION

The following compensation plans were established by Hydro One Limited, however they represent components of compensation costs of Hydro One in current and future periods.

Share Grant Plans

Hydro One Limited has two share grant plans (Share Grant Plans), one for the benefit of certain members of the Power Workers’ Union (PWU) (PWU Share Grant Plan) and one for the benefit of certain members of the Society (Society Share Grant Plan). Hydro One and Hydro One Limited entered into an intercompany agreement, such that Hydro One will pay Hydro One Limited for the compensation costs associated with these plans.

The PWU Share Grant Plan provides for the issuance of common shares of Hydro One Limited from treasury to certain eligible members of the PWU annually, commencing on April 1, 2017 and continuing until the earlier of April 1, 2028 or the date an eligible employee no longer meets the eligibility criteria of the PWU Share Grant Plan. To be eligible, an employee must be a member of the Pension Plan on April 1, 2015, be employed on the date annual share issuance occurs and continue to have under 35 years of service. The requisite service period for the PWU Share Grant Plan began on July 3, 2015, which is the date the share grant plan was ratified by the PWU. The number of common shares issued annually to each eligible employee will be equal to 2.7% of such eligible employee’s salary as at April 1, 2015, divided by $20.50, being the price of the common shares of Hydro One Limited in the Initial Public Offering (IPO). The aggregate number of Hydro One Limited common shares issuable under the PWU Share Grant Plan shall not exceed 3,981,763 common shares. In 2015, 3,952,212 Hydro One Limited common shares were granted under the PWU Share Grant Plan relevant to the total share-based compensation recognized by Hydro One.

The Society Share Grant Plan provides for the issuance of common shares of Hydro One Limited from treasury to certain eligible members of the Society annually, commencing on April 1, 2018 and continuing until the earlier of April 1, 2029 or the date an eligible employee no longer meets the eligibility criteria of the Society Share Grant Plan. To be eligible, an employee must be a member of the Pension Plan on September 1, 2015, be employed on the date annual share issuance occurs and continue to have under 35 years of service. Therefore, the requisite service period for the Society Share Grant Plan began on September 1, 2015. The number of common shares issued annually to each eligible employee will be equal to 2.0% of such eligible employee’s salary as at September 1, 2015, divided by $20.50, being the price of the common shares of Hydro One Limited in the IPO. The aggregate number of Hydro One Limited common shares issuable under the Society Share Grant Plan shall not exceed 1,434,686 common shares. In 2015, 1,367,158 Hydro One Limited common shares were granted under the Society Share Grant Plan relevant to the total share-based compensation recognized by Hydro One.

The fair value of the Hydro One Limited 2015 share grants of $111 million was estimated based on the grant date Hydro One Limited share price of $20.50 and is recognized using the graded-vesting attribution method as the share grant plans have both a performance condition and a service condition. In 2022, 382,156 common shares of Hydro One Limited (2021 - 410,575) were issued under the Share Grant Plans to eligible employees of Hydro One. Total share-based compensation recognized during 2022 was $4 million (2021 - $5 million) and was recorded as a regulatory asset.


			39

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

A summary of share grant activity under the Share Grant Plans during the years ended December 31, 2022 and 2021 is presented below:


Year ended December 31, 2022	Share Grants (number of common shares)		Weighted-Average Price
Share grants outstanding - beginning		2,616,351	$20.50
Vested and issued1		(382,156)	—
Forfeited		(82,617)	$20.50
Share grants outstanding - ending		2,151,578	$20.50

1 In 2022, Hydro One Limited issued 382,156 common shares from treasury to eligible Hydro One employees in accordance with provisions of the Share Grant Plans. In accordance with the intercompany agreement between Hydro One and Hydro One Limited, Hydro One made payments to Hydro One Limited for the common shares issued.


Year ended December 31, 2021	Share Grants (number of common shares)		Weighted-Average Price
Share grants outstanding - beginning		3,100,165	$20.50
Vested and issued1		(410,575)	—
Forfeited		(73,239)	$20.50
Share grants outstanding - ending		2,616,351	$20.50

1 In 2021, Hydro One Limited issued 410,575 common shares from treasury to eligible Hydro One employees in accordance with provisions of the Share Grant Plans. In accordance with the intercompany agreement between Hydro One and Hydro One Limited, Hydro One made payments to Hydro One Limited for the common shares issued.

Directors' DSU Plan

Under the Directors’ DSU Plan, directors can elect to receive credit for their annual cash retainer in a notional account of DSUs in lieu of cash. Hydro One Limited’s Board of Directors may also determine from time to time that special circumstances exist that would reasonably justify the grant of DSUs to a director as compensation in addition to any regular retainer or fee to which the director is entitled. Each DSU represents a unit with an underlying value equivalent to the value of one common share of Hydro One Limited and is entitled to accrue Hydro One Limited common share dividend equivalents in the form of additional DSUs at the time dividends are paid, subsequent to declaration by Hydro One Limited’s Board of Directors.

A summary of DSU awards activity under the Directors' DSU Plan during the years ended December 31, 2022 and 2021 is presented below:


Year ended December 31 (number of DSUs)	2022	2021
DSUs outstanding - beginning	80,813	65,240
Granted	19,126	20,888
Settled	—	(5,315)
DSUs outstanding - ending	99,939	80,813

For the year ended December 31, 2022, an expense of less than $1 million (2021 - $1 million) was recognized in earnings with respect to the Directors' DSU Plan. At December 31, 2022, a liability of $4 million (2021 - $3 million) related to Directors' DSUs has been recorded at the closing price of Hydro One Limited common shares of $36.27. This liability is included in other long-term liabilities on the consolidated balance sheets.

Management DSU Plan

Under the Management DSU Plan, eligible executive employees can elect to receive a specified proportion of their annual short-term incentive in a notional account of DSUs in lieu of cash. Each DSU represents a unit with an underlying value equivalent to the value of one common share of the Company and is entitled to accrue common share dividend equivalents in the form of additional DSUs at the time dividends are paid, subsequent to declaration by Hydro One’s Board of Directors.

A summary of DSU awards activity under the Management DSU Plan during the years ended December 31, 2022 and 2021 is presented below:


Year ended December 31 (number of DSUs)	2022	2021
DSUs outstanding - beginning	90,240	61,880
Granted	37,524	28,360
Paid	(9,259)	—
DSUs outstanding - ending	118,505	90,240

For the year ended December 31, 2022, an expense of $1 million (2021 - $1 million) was recognized in earnings with respect to the Management DSU Plan. At December 31, 2022, a liability of $4 million (2021 - $3 million) related to Management DSUs has


			40

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

been recorded at the closing price of Hydro One Limited common shares of $36.27. This liability is included in other long-term liabilities on the consolidated balance sheets.

Employee Share Ownership Plan

In 2015, Hydro One Limited established Employee Share Ownership Plans (ESOP) for certain eligible management and non-represented employees (Management ESOP) and for certain eligible Society-represented staff (Society ESOP). Under the Management ESOP, the eligible management and non-represented employees may contribute between 1% and 6% of their base salary towards purchasing common shares of Hydro One Limited. The Company matches 50% of their contributions, up to a maximum Company contribution of $25,000 per calendar year. Under the Society ESOP, the eligible Society-represented staff may contribute between 1% and 4% of their base salary towards purchasing common shares of Hydro One Limited. The Company matches 25% of their contributions, with no maximum Company contribution per calendar year. In 2022, Company contributions made under the ESOP were $2 million (2021 - $2 million).

LTIP

Effective August 31, 2015, the Board of Directors of Hydro One Limited adopted an LTIP. Under the LTIP, long-term incentives were granted to certain executive and management employees of Hydro One Limited and its subsidiaries, and all equity-based awards would be settled in newly issued shares of Hydro One Limited from treasury, consistent with the provisions of the plan which also permit the participants to surrender a portion of their awards to satisfy related withholding taxes requirements. The aggregate number of shares issuable under the LTIP shall not exceed 11,900,000 shares of Hydro One Limited.

The LTIP provides flexibility to award a range of vehicles, including Performance Share Units (PSUs), RSUs, stock options, share appreciation rights, restricted shares, DSUs, and other share-based awards. The mix of vehicles is intended to vary by role to recognize the level of executive accountability for overall business performance.

PSUs and RSUs

A summary of PSU and RSU awards activity under the LTIP during the years ended December 31, 2022 and 2021 is presented below:


	PSUs		RSUs
Year ended December 31 (number of units)	2022	2021	2022	2021
Units outstanding - beginning	—	106,070	—	133,620
Vested and issued	—	(106,070)	—	(98,860)
Settled	—	—	—	(34,760)
Units outstanding - ending	—	—	—	—

No awards were granted in 2022 or 2021. The compensation expense related to the PSU and RSU awards recognized by the Company during 2022 was $nil (2021 - less than $1 million).

Society RSU Plan

As a result of the renewal of the Company's prior collective agreement with members of the Society, the Company provided equity compensation in the form of RSUs to certain eligible members. The equity compensation provides for the purchase of common shares of Hydro One Limited from the open market, effective March 1, 2021 in one equity grant vesting in equal portions over a two-year period. To be eligible, an employee must be an employee of the Company as of July 30, 2021, the date the plan was ratified by the Society; the grant date. The number of common shares issued to each eligible employee will be equal to 1.0% of such eligible employee’s salary as at April 1, 2021, divided by $30.80, being the price of the common shares of Hydro One Limited at the grant date. Each RSU is entitled to accrue common share dividend equivalents in the form of additional RSUs at the time dividends are paid, subsequent to declaration by Hydro One’s Board of Directors.

A summary of RSU awards activity under the Society RSU Plan during the years ended December 31, 2022 and 2021 is presented below:


Year ended December 31 (number of RSUs)	2022	2021
RSUs outstanding - beginning	68,005	—
Granted	1,638	68,005
Vested and issued	(32,841)	—
Settled	(1,106)	—
Forfeited	(1,077)	—
RSUs outstanding - ending	34,619	68,005


			41

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Stock Options

Hydro One Limited is authorized to grant stock options under its LTIP to certain eligible employees. No stock options were granted in 2022 or 2021.

The fair value-based method is used to measure compensation expense related to stock options and the expense was recognized over the vesting period on a straight-line basis. The fair value of the stock option awards granted was estimated on the date of grant using a Black-Scholes valuation model.

A summary of stock options activity during the years ended December 31, 2022 and 2021 is presented below:


	Number of Stock Options	Weighted-average exercise price
Stock options outstanding - January 1, 2021	108,710	$	20.66
Exercised1	(108,710)	$	20.66
Stock options outstanding - December 31, 2021	—	$	—
Stock options outstanding - December 31, 2022	—	—

1 The stock options exercised in 2021 had an aggregate intrinsic value of $1 million.

No compensation expense related to stock options was recognized by the Company during 2022 or 2021. At December 31, 2022 and 2021, no amounts were payable to Hydro One Limited relating to stock options awards.

27. NONCONTROLLING INTEREST

Total noncontrolling interest consists of noncontrolling interest attributable to B2M LP and NRLP. The following tables show the movements in total noncontrolling interest during the years ended December 31, 2022 and 2021:


Year ended December 31, 2022 (millions of dollars)	Temporary Equity		Equity	Total
Noncontrolling interest - beginning		20	68	88
Distributions to noncontrolling interest		(2)	(8)	(10)
Net income attributable to noncontrolling interest		2	6	8
Noncontrolling interest - ending		20	66	86


Year ended December 31, 2021 (millions of dollars)	Temporary Equity		Equity	Total
Noncontrolling interest - beginning		22	72	94
Distributions to noncontrolling interest		(4)	(10)	(14)
Net income attributable to noncontrolling interest		2	6	8
Noncontrolling interest - ending		20	68	88

B2M LP

On December 16, 2014, transmission assets totaling $526 million were transferred from Hydro One Networks to B2M LP. This was financed by 60% debt ($316 million) and 40% equity ($210 million). On December 17, 2014, the SON acquired a 34.2% equity interest in B2M LP for consideration of $72 million, representing the fair value of the equity interest acquired. The SON’s initial investment in B2M LP consists of $50 million of Class A units and $22 million of Class B units.

The Class B units have a mandatory put option which requires that upon the occurrence of an enforcement event (i.e., an event of default such as a debt default by the SON or insolvency event), Hydro One purchase the Class B units of B2M LP for net book value on the redemption date. The noncontrolling interest relating to the Class B units is classified on the consolidated balance sheet as temporary equity because the redemption feature is outside the control of the Company. The balance of the noncontrolling interest is classified within equity.

The following tables show the movements in B2M LP noncontrolling interest during the years ended December 31, 2022 and 2021:


Year ended December 31, 2022 (millions of dollars)	Temporary Equity		Equity	Total
Noncontrolling interest - beginning		20	46	66
Distributions to noncontrolling interest		(2)	(5)	(7)
Net income attributable to noncontrolling interest		2	4	6
Noncontrolling interest - ending		20	45	65


			42

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021


Year ended December 31, 2021 (millions of dollars)	Temporary Equity		Equity	Total
Noncontrolling interest - beginning		22	49	71
Distributions to noncontrolling interest		(4)	(7)	(11)
Net income attributable to noncontrolling interest		2	4	6
Noncontrolling interest - ending		20	46	66

NRLP

On September 18, 2019, Hydro One Networks sold to the Six Nations of the Grand River Development Corporation and, through a trust, to the Mississaugas of the Credit First Nation a 25.0% and 0.1%, respectively, equity interest in NRLP partnership units for total consideration of $12 million, representing the fair value of the equity interest acquired. On January 31, 2020, the Mississaugas of the Credit First Nation purchased an additional 19.9% equity interest in NRLP partnership units from Hydro One Networks for total cash consideration of $9 million. Following this transaction, Hydro One's interest in the equity portion of NRLP partnership units was reduced to 55%, with the Six Nations of the Grand River Development Corporation and the Mississaugas of the Credit First Nation owning 25% and 20%, respectively, of the equity interest in NRLP partnership units. The First Nations Partners' noncontrolling interest in NRLP is classified within equity.

The following table shows the movements in NRLP noncontrolling interest during the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)	2022	2021
Noncontrolling interest - beginning	22	23

Distributions to noncontrolling interest	(3)	(3)
Net income attributable to noncontrolling interest	2	2
Noncontrolling interest - ending	21	22

28. RELATED PARTY TRANSACTIONS

Hydro One is owned by Hydro One Limited. The Province is a shareholder of Hydro One Limited with approximately 47.2% ownership at December 31, 2022. The IESO, Ontario Power Generation Inc. (OPG), Ontario Electricity Financial Corporation (OEFC), the OEB, Acronym Solutions Inc. (Acronym) and Hydro One Broadband Solutions Inc. (HOBSI) are related parties to Hydro One because they are controlled or significantly influenced by the Ministry of Energy or by Hydro One Limited. The following is a summary of the Company’s related party transactions during the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)
Related Party	Transaction	2022	2021
IESO	Power purchased	2,374	2,238
	Revenues for transmission services	2,062	1,832
	Amounts related to electricity rebates	1,031	1,065
	Distribution revenues related to rural rate protection	247	245
	Distribution revenues related to supply of electricity to remote northern communities	35	35
	Funding received related to CDM programs	3	1
OPG	Power purchased	20	13
	Revenues related to provision of services and supply of electricity	7	7
	Capital contribution received from OPG	5	3
	Costs related to the purchase of services	2	2
OEFC	Power purchased from power contracts administered by the OEFC	2	1
OEB	OEB fees	10	8

Hydro One Limited	Dividends paid	652	620
	Stock-based compensation costs	5	6
	Cost recovery for services provided	7	7
Acronym	Services received – costs expensed	26	24
	Revenues for services provided	2	2
HOBSI	Increase (decrease) in capital contribution from HOBSI	(2)	3
	Revenues for services provided	1	—

Sales to and purchases from related parties are based on the requirements of the OEB’s Affiliate Relationships Code. Outstanding balances at period end from external related parties are interest-free and settled in cash. Invoices are issued monthly, and amounts are due and paid on a monthly basis.


			43

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

29. CONSOLIDATED STATEMENTS OF CASH FLOWS

The changes in non-cash balances related to operations consist of the following:



Year ended December 31 (millions of dollars)	2022	2021
Accounts receivable	(72)	17
Due from related parties	(56)	26
Materials and supplies (Note 9)	(2)	1
Prepaid expenses and other assets (Note 9)	(5)	(3)
Other long-term assets (Note 13)	1	(3)
Accounts payable	22	(3)
Accrued liabilities (Note 14)	67	49
Due to related parties	(3)	(73)
Accrued interest (Note 14)	(5)	7
Long-term accounts payable and other long-term liabilities (Note 15)	8	1
Post-retirement and post-employment benefit liability	39	50
	(6)	69

Capital Expenditures

The following tables reconcile investments in property, plant and equipment and intangible assets and the amounts presented in the consolidated statements of cash flows for the years ended December 31, 2022 and 2021. The reconciling items include net change in accruals and capitalized depreciation.



Year ended December 31, 2022 (millions of dollars)	Property, Plant and Equipment	Intangible Assets	Total
Capital investments	(1,986)	(122)	(2,108)
Reconciling items	44	2	46
Cash outflow for capital expenditures	(1,942)	(120)	(2,062)



Year ended December 31, 2021 (millions of dollars)	Property, Plant and Equipment	Intangible Assets	Total
Capital investments	(1,963)	(141)	(2,104)
Reconciling items	55	(1)	54
Cash outflow for capital expenditures	(1,908)	(142)	(2,050)

Capital Contributions

Hydro One enters into contracts governed by the OEB Transmission System Code when a transmission customer requests a new or upgraded transmission connection. The customer is required to make a capital contribution to Hydro One based on the shortfall between the present value of the costs of the connection facility and the present value of revenues. The present value of revenues is based on an estimate of load forecast for the period of the contract with Hydro One. Once the connection facility is commissioned, in accordance with the OEB Transmission System Code, Hydro One will periodically reassess the estimated load forecast which will lead to a decrease, or an increase in the capital contributions from the customer. The increase or decrease in capital contributions is recorded directly to property, plant and equipment in service. In 2022, there were $12 million capital contributions from these assessments (2021 - $14 million).

Supplementary Information



Year ended December 31 (millions of dollars)	2022	2021
Net interest paid	517	500
Income taxes paid	33	20


			44

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

30. CONTINGENCIES

Legal Proceedings

Hydro One is involved in various lawsuits and claims in the normal course of business. In the opinion of management, the outcome of such matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations or cash flows.

Transfer of Assets

The transfer orders by which the Company acquired certain of Ontario Hydro’s businesses as of April 1, 1999 did not transfer title to some assets located on Reserves (as defined in the Indian Act (Canada)). Currently, the OEFC holds these assets. Under the terms of the transfer orders, the Company is required to manage these assets until it has obtained all consents necessary to complete the transfer of title of these assets to itself. The Company cannot predict the aggregate amount that it may have to pay, either on an annual or one-time basis, to obtain the required consents. In 2022, the Company paid approximately $5 million (2021 - $2 million) in respect of consents obtained. If the Company cannot obtain the required consents, the OEFC will continue to hold these assets for an indefinite period of time. If the Company cannot reach a satisfactory settlement, it may have to relocate these assets to other locations at a cost that could be substantial or, in a limited number of cases, to abandon a line and replace it with diesel-generation facilities. The costs relating to these assets could have a material adverse effect on the Company’s results of operations if the Company is not able to recover them in future rate orders.

31. COMMITMENTS

The following table presents a summary of Hydro One’s commitments under outsourcing and other agreements due in the next five years and thereafter:


As at December 31, 2022 (millions of dollars)	Year 1	Year 2	Year 3	Year 4	Year 5	Thereafter
Outsourcing and other agreements	184	10	—	—	1	13
Long-term software/meter agreement	12	11	4	1	1	3

Outsourcing and Other Agreements

In February 2021, Hydro One entered into a three-year agreement for information technology services with Capgemini Canada Inc., which expires on February 29, 2024, and includes an option to extend for two additional one-year terms at Hydro One’s discretion. This agreement resulted in commitments of $143 million over the initial three-year term of the agreement.

Brookfield Global Integrated Solutions (BGIS) provides services to Hydro One, including facilities management and execution of certain capital projects as deemed required by the Company. The agreement with BGIS for these services expires in December 2024, with an option for the Company to renew the agreement for an additional term of three years.

Anixter Power Solutions Canada Inc. (Wesco) provides services to Hydro One to support its Broadband Development Project. Under the agreement with Wesco, as at December 31, 2022, Hydro One has committed to purchases in the amount of $61 million.

Long-term Software/Meter Agreement

Trilliant Holdings Inc. and Trilliant Networks (Canada) Inc. (collectively Trilliant) provide services to Hydro One for the supply, maintenance and support services for smart meters and related hardware and software, including additional software licences, as well as certain professional services. The agreement with Trilliant for these services expires in December 2030.


			45

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021

Other Commitments

The following table presents a summary of Hydro One’s other commercial commitments by year of expiry in the next five years and thereafter:


As at December 31, 2022 (millions of dollars)	Year 1	Year 2	Year 3	Year 4	Year 5	Thereafter
Operating Credit Facilities1	—	—	—	—	2,300	—
Letters of credit2	186	2	—	—	—	—
Guarantees3	475	—	—	—	—	—

1 On June 1, 2022, the maturity date for the Operating Credit Facilities was extended to 2027.

2 Letters of credit consist of $163 million letters of credit related to retirement compensation arrangements, a $18 million letter of credit provided to the IESO for prudential support, $4 million in letters of credit to satisfy debt service reserve requirements, and $3 million in letters of credit for various operating purposes.

3 Guarantees consist of $475 million prudential support provided to the IESO by Hydro One on behalf of its subsidiaries.

Prudential Support

Purchasers of electricity in Ontario, through the IESO, are required to provide security to mitigate the risk of their default based on their expected activity in the market. The IESO could draw on these guarantees and/or letters of credit if these purchasers fail to make a payment required by a default notice issued by the IESO. The maximum potential payment is the face value of any letters of credit plus the amount of the parental guarantees.

Retirement Compensation Arrangements

Bank letters of credit have been issued to provide security for Hydro One’s liability under the terms of a trust fund established pursuant to the supplementary pension plan for eligible employees of Hydro One. The supplementary pension plan trustee is required to draw upon these letters of credit if Hydro One is in default of its obligations under the terms of this plan. Such obligations include the requirement to provide the trustee with an annual actuarial report as well as letters of credit sufficient to secure Hydro One’s liability under the plan, to pay benefits payable under the plan and to pay the letter of credit fee. The maximum potential payment is the face value of the letters of credit.

32. SEGMENTED REPORTING

Hydro One has three reportable segments:

•The Transmission Segment, which comprises the transmission of high voltage electricity across the province, interconnecting local distribution companies and certain large directly connected industrial customers throughout the Ontario electricity grid;

•The Distribution Segment, which comprises the delivery of electricity to end customers and certain other municipal electricity distributors; and

•Other Segment, which includes certain corporate activities. The Other Segment includes the DTA which arose from the revaluation of the tax bases of Hydro One’s assets to fair market value when the Company transitioned from the provincial payments in lieu of tax regime to the federal tax regime at the time of Hydro One’s initial public offering in 2015. This DTA is not required to be shared with ratepayers, the Company considers it to not be part of the regulated transmission and distribution segment assets, and it is included in the other segment.

The designation of segments has been based on a combination of regulatory status and the nature of the services provided. Operating segments of the Company are determined based on information used by the chief operating decision-maker in deciding how to allocate resources and evaluate the performance of each of the segments. The Company evaluates segment performance based on income before financing charges and income tax expense from continuing operations (excluding certain allocated corporate governance costs).


			46

HYDRO ONE INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (continued)

For the years ended December 31, 2022 and 2021


Year ended December 31, 2022 (millions of dollars)	Transmission	Distribution	Other	Consolidated
Revenues	2,080	5,660	—	7,740
Purchased power	—	3,724	—	3,724
Operation, maintenance and administration	464	744	18	1,226
Depreciation, amortization and asset removal costs	509	448	—	957
Income (loss) before financing charges and income tax expense	1,107	744	(18)	1,833

Capital investments	1,209	899	—	2,108


Year ended December 31, 2021 (millions of dollars)	Transmission	Distribution	Other	Consolidated
Revenues	1,826	5,359	—	7,185
Purchased power	—	3,579	—	3,579
Operation, maintenance and administration	414	664	3	1,081
Depreciation, amortization and asset removal costs	485	428	—	913
Income (loss) before financing charges and income tax expense	927	688	(3)	1,612

Capital investments	1,320	784	—	2,104

Total Assets by Segment:


As at December 31 (millions of dollars)	2022	2021
Transmission	18,747	18,109
Distribution	11,880	11,475
Other	663	637
Total assets	31,290	30,221

Total Goodwill by Segment:


As at December 31 (millions of dollars)	2022	2021
Transmission	157	157
Distribution	216	216
Total goodwill	373	373

All revenues, assets and substantially all costs, as the case may be, are earned, held or incurred in Canada.

33. SUBSEQUENT EVENTS

Sustainable Financing Framework

On January 12, 2023, Hydro One Limited published a Sustainable Financing Framework, which allows Hydro One Limited and its subsidiaries to issue sustainable financing instruments.

Debt Issuance

On January 27, 2023, Hydro One issued sustainable bonds totaling $1,050 million under its MTN Program as follows:

a.$300 million Series 53 notes with a maturity date of November 30, 2029 and a coupon rate of 3.93%; and

b.$450 million Series 54 notes with a maturity date of January 27, 2033 and a coupon rate of 4.16%; and

c.$300 million Series 55 notes with a maturity date of January 27, 2053 and a coupon rate of 4.46%.

Dividends

On February 13, 2023, common share dividends of $165 million were declared.


			47

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS

For the years ended December 31, 2022 and 2021

The following Management’s Discussion and Analysis (MD&A) of the financial condition and results of operations should be read together with the consolidated financial statements and accompanying notes thereto of Hydro One Inc. (Hydro One or the Company) for the year ended December 31, 2022 (together, the Consolidated Financial Statements). The Consolidated Financial Statements have been prepared in accordance with United States (US) Generally Accepted Accounting Principles (GAAP). All financial information in this MD&A is presented in Canadian dollars, unless otherwise indicated.

The Company has prepared this MD&A in accordance with National Instrument 51-102 - Continuous Disclosure Obligations of the Canadian Securities Administrators. Under the US/Canada Multijurisdictional Disclosure System, the Company is permitted to prepare this MD&A in accordance with the disclosure requirements of Canadian securities laws and regulations, which can vary from those of the US. This MD&A provides information as at and for the year ended December 31, 2022, based on information available to management as of February 13, 2023.

CONSOLIDATED FINANCIAL HIGHLIGHTS AND STATISTICS



Year ended December 31 (millions of dollars, except as otherwise noted)	2022	2021	Change
Revenues	7,740	7,185	7.7	%
Purchased power	3,724	3,579	4.1	%
Revenues, net of purchased power1	4,016	3,606	11.4	%
Operation, maintenance and administration (OM&A) costs	1,226	1,081	13.4	%
Depreciation, amortization and asset removal costs	957	913	4.8	%
Financing charges	478	453	5.5	%
Income tax expense	290	179	62.0	%
Net income to common shareholder of Hydro One	1,057	972	8.7	%

Basic earnings per common share (EPS)	$7,431	$6,834	8.7	%
Diluted EPS	$7,431	$6,834	8.7	%

Net cash from operating activities	2,185	2,108	3.7	%
Funds from operations (FFO)1	2,181	2,031	7.4	%

Capital investments	2,108	2,104	0.2	%
Assets placed in-service	2,258	1,746	29.3	%

Transmission: Average monthly Ontario 60-minute peak demand (MW)	20,368	19,915	2.3	%
Distribution: Electricity distributed to Hydro One customers (GWh)	30,803	29,966	2.8	%


As at December 31	2022		2021
Debt to capitalization ratio2	55.1	%	55.2	%

1 The Company prepares and presents its financial statements in accordance with US GAAP. The Company also utilizes non-GAAP financial measures to assess its business and measure overall underlying business performance. Revenues, net of purchased power and FFO are non-GAAP financial measures. Non-GAAP financial measures do not have a standardized meaning under GAAP, which is used to prepare the Company’s Consolidated Financial Statements and might not be comparable to similar financial measures presented by other entities. See section “Non-GAAP Financial Measures” for a discussion of these non-GAAP financial measures and a reconciliation of such measures to the most directly comparable GAAP measure.

2 Debt to capitalization ratio is a non-GAAP ratio. Non-GAAP ratios do not have a standardized meaning under GAAP, which is used to prepare the Company’s Consolidated Financial Statements, and might not be comparable to similar financial measures presented by other entities. See section “Non-GAAP Financial Measures” for a discussion of this non-GAAP ratio and its component elements.


			1

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

OVERVIEW

Hydro One is Ontario’s largest electricity transmission and distribution utility. Hydro One owns and operates substantially all of Ontario’s electricity transmission network and is the largest electricity distributor in Ontario by number of customers. The Company’s regulated transmission and distribution operations are owned by Hydro One. Hydro One delivers electricity safely and reliably to approximately 1.5 million customers across the province of Ontario, and to large industrial customers and municipal utilities. Hydro One Inc. owns and operates approximately 30,000 circuit kilometres of high-voltage transmission lines and approximately 125,000 circuit kilometres of primary low-voltage distribution lines. Hydro One has three segments: (i) transmission; (ii) distribution; and (iii) other.

For the years ended December 31, 2022 and 2021, Hydro One's segments accounted for the Company's total revenues, as follows:


Year ended December 31	2022		2021
Transmission	27	%	25	%
Distribution	73	%	75	%
Other	—	%	—	%

When adjusted for the recovery of purchased power costs, Hydro One’s segments accounted for the Company’s total revenues, net of purchased power,1 for the years ended December 31, 2022 and 2021 as follows:


Year ended December 31	2022		2021
Transmission	52	%	51	%
Distribution	48	%	49	%
Other	—	%	—	%

At December 31, 2022 and 2021, Hydro One’s segments accounted for the Company’s total assets as follows:


As at December 31	2022		2021
Transmission	60	%	60	%
Distribution	38	%	38	%
Other	2	%	2	%

Transmission Segment

Hydro One’s transmission business owns, operates and maintains Hydro One's transmission system, which accounts for approximately 92% (2021 - 98%) of Ontario’s transmission capacity based on revenue approved by the Ontario Energy Board (OEB). As at December 31, 2022, the Company's transmission business consists of the transmission system operated by its subsidiaries, which include Hydro One Networks Inc. (Hydro One Networks) and Hydro One Sault Ste. Marie LP (HOSSM), as well as an approximately 66% interest in B2M Limited Partnership (B2M LP), and an approximately 55% interest in Niagara Reinforcement Limited Partnership (NRLP). The Company’s transmission business is rate-regulated and earns revenues mainly by charging transmission rates that are approved by the OEB.


As at and for the year ended December 31	2022	2021
Electricity transmitted1 (MWh)	137,569,865	133,844,210
Transmission lines spanning the province (circuit-kilometres)	29,910	30,023
Rate base (millions of dollars)	14,450	13,745
Capital investments (millions of dollars)	1,209	1,320
Assets placed in-service (millions of dollars)	1,405	1,008

1 Electricity transmitted represents total electricity transmitted in Ontario by all transmitters.

Distribution Segment

Hydro One’s distribution business is the largest in Ontario and consists of the distribution systems operated by its subsidiaries, Hydro One Networks, and Hydro One Remote Communities Inc. (Hydro One Remotes). The Company’s distribution business is rate-regulated and earns revenues mainly by charging distribution rates that are approved by the OEB, as well as amounts to recover the cost of purchased power.

1 Revenues, net of purchased power, is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.


			2

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021


As at and for the year ended December 31	2022	2021
Electricity distributed to Hydro One customers (GWh)	30,803	29,966
Electricity distributed through Hydro One lines (GWh)1	40,875	40,433
Distribution lines spanning the province (circuit-kilometres)	125,013	124,825
Distribution customers (number of customers)	1,492,404	1,476,491
Rate base (millions of dollars)	9,155	8,854
Capital investments (millions of dollars)	899	784
Assets placed in-service (millions of dollars)	853	738

1 Units distributed through Hydro One lines represent total distribution system requirements and include electricity distributed to consumers who purchased power directly from the Independent Electricity System Operator (IESO).

Other Segment

Hydro One's other segment consists of certain corporate activities, and is not rate-regulated. The other segment also includes the deferred tax asset which arose from the revaluation of the tax bases of Hydro One’s assets to fair market value when the Company transitioned from the provincial payments in lieu of tax regime to the federal tax regime at the time of the initial public offering of Hydro One Limited in 2015.

PRIMARY FACTORS AFFECTING RESULTS OF OPERATIONS

Transmission Revenues

Transmission revenues primarily consist of regulated transmission rates approved by the OEB which are charged based on the monthly peak electricity demand across Hydro One’s high-voltage network. Transmission rates are designed to generate revenues necessary to construct, upgrade, extend and support a transmission system with sufficient capacity to accommodate maximum forecasted demand and a regulated return on the Company’s investment. Peak electricity demand is primarily influenced by weather and economic conditions. Transmission revenues also include export revenues associated with transmitting electricity to markets outside of Ontario as well as ancillary revenues associated with providing maintenance services to power generators and from third-party land use.

Distribution Revenues

Distribution revenues primarily consist of regulated distribution rates approved by the OEB, as well as the recovery of purchased power costs. Distribution rates are designed to generate revenues necessary to construct and support the local distribution system with sufficient capacity to accommodate existing and new customer demand and a regulated return on the Company’s investment. Accordingly, distribution revenues are influenced by distribution rates, the cost of purchased power, and the amount of electricity the Company distributes. Distribution revenues also include ancillary distribution service revenues, such as fees related to the joint use of Hydro One’s distribution poles by the telecommunications and cable television industries, as well as miscellaneous revenues such as charges for late payments.

Purchased Power Costs

Purchased power costs are incurred by the distribution business and represent the cost of the electricity purchased by the Company for delivery to customers within Hydro One’s distribution service territory. These costs are comprised of: (i) the wholesale commodity cost of energy; (ii) the Global Adjustment, which is the difference between the guaranteed price and the money the generators earn in the wholesale marketplace; and (iii) the wholesale market service and transmission charges levied by the IESO. Hydro One passes on the cost of electricity that it delivers to its customers, and is therefore not exposed to wholesale electricity commodity price risk.


			3

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Operation, Maintenance and Administration Costs

OM&A costs are incurred to support the operation and maintenance of the transmission and distribution systems, and include other costs such as property taxes related to transmission and distribution stations and buildings, and the operation of information technology (IT) systems. Transmission OM&A costs are required to sustain the Company’s high-voltage transmission stations, lines, and rights-of-way, and include preventive and corrective maintenance costs related to power equipment, overhead transmission lines, transmission station sites, and forestry control to maintain safe distances between line spans and trees. Distribution OM&A costs are required to maintain the Company’s low-voltage distribution system to provide safe and reliable electricity to the Company's residential, small business, commercial, and industrial customers across the province. These include costs related to distribution line clearing and forestry control to reduce power outages caused by trees, line maintenance and repair, land assessment and remediation, as well as issuing timely and accurate bills and responding to customer inquiries.

Hydro One manages its costs through ongoing efficiency and productivity initiatives, while continuing to complete planned work programs associated with the development and maintenance of its transmission and distribution networks.

Depreciation, Amortization and Asset Removal Costs

Depreciation and amortization costs relate primarily to depreciation of the Company’s property, plant and equipment, and amortization of certain intangible assets and regulatory assets. Asset removal costs consist of costs incurred to remove property, plant and equipment where no asset retirement obligations have been recorded on the balance sheet.

Financing Charges

Financing charges relate to the Company’s financing activities, and include interest expense on the Company’s long-term debt and short-term borrowings, as well as gains and losses on interest rate swap agreements, foreign exchange or other similar contracts, net of interest earned on short-term investments. A portion of financing charges incurred by the Company is capitalized to the cost of property, plant and equipment associated with the periods during which such assets are under construction before being placed in-service.

RESULTS OF OPERATIONS

Net Income

Net income attributable to the common shareholder for the year ended December 31, 2022 of $1,057 million is an increase of $85 million, or 8.7%, from the prior year. Significant influences on the change in net income attributable to common shareholder of Hydro One included:

•higher revenues, net of purchased power,2 resulting from:

•an increase in transmission revenues due to OEB-approved 2022 transmission rates, higher peak demand and the recognition of conservation and demand management (CDM) revenues following receipt of the OEB's Decision and Order approving Hydro One's Joint Rate Application (JRAP) Settlement Proposal in November 2022 (JRAP Decision); and

•an increase in distribution revenues, net of purchased power,2 mainly due to OEB-approved 2022 distribution rates.

•higher OM&A costs primarily resulting from higher work program expenditures including environmental management, stations and lines maintenance, and IT initiatives.

•higher depreciation, amortization and asset removal costs due to growth in capital assets as the Company continues to place new assets in-service, consistent with its ongoing capital investment program, as well as higher asset removal costs primarily resulting from storm restoration efforts, partially offset by a gain realized on the sale of surplus property.

•higher financing charges attributable to the recognition of carrying charges associated with the recovery of deferred tax asset (DTA) amounts previously shared with ratepayers (DTA Recovery Amounts) pursuant to the OEB's decision in April 2021 (DTA Implementation Decision) in the second quarter of 2021, as well as higher weighted-average interest rates on short-term notes.

•higher income tax expense primarily attributable to:

•higher pre-tax earnings adjusted for the impact of the DTA Recovery Amounts pursuant to the DTA Implementation Decision; partially offset by

•higher deductible timing differences compared to the prior year.

Revenue was also positively impacted by the DTA Implementation Decision. In its decision, the OEB approved recovery of DTA amounts allocated to ratepayers and included in customer rates for the 2017 to 2021 period plus carrying charges over a two-year recovery period commencing on July 1, 2021. In addition, the DTA Implementation Decision required that Hydro One adjust the transmission revenue requirement and base distribution rates effective January 1, 2022 to eliminate any further tax savings flowing to customers. These impacts are partially offset by the impact of a regulatory adjustment recognized following receipt of

2 Revenues, net of purchased power, is a non-GAAP financial measure. See section "Non-GAAP Financial Measures".


			4

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

the JRAP decision which resulted from the deduction of capitalized overheads for tax purposes in excess of those deducted for rate making purposes (Capitalized Overhead Tax Variance). Together these items are offset by a net increase in tax expense and are therefore net income neutral in the period. See section "Regulation" for additional details.

Revenues



Year ended December 31 (millions of dollars, except as otherwise noted)	2022	2021	Change
Transmission	2,080	1,826	13.9	%
Distribution	5,660	5,359	5.6	%
Total revenues	7,740	7,185	7.7	%

Transmission	2,080	1,826	13.9	%
Distribution revenues, net of purchased power1	1,936	1,780	8.8	%
Total revenues, net of purchased power1	4,016	3,606	11.4	%

Transmission: Average monthly Ontario 60-minute peak demand (MW)	20,368	19,915	2.3	%
Distribution: Electricity distributed to Hydro One customers (GWh)	30,803	29,966	2.8	%

1 Revenues, net of purchased power, is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.

Transmission Revenues

Transmission revenues increased by 13.9% compared to the year ended December 31, 2021, primarily due to the following:

•higher revenues resulting from OEB-approved 2022 rates;

•higher peak demand; and

•positive regulatory adjustments, including the recognition of CDM revenues following the receipt of the JRAP Decision which was partially offset by a deferred adjustment associated with the OEB-approved Earnings Sharing Mechanism; partially offset by

•net income neutral items, including DTA Recovery Amounts and the adjustment to transmission revenue requirement effective January 1, 2022 to cease sharing of DTA amounts going forward, pursuant to the DTA Implementation Decision which was partially offset by a regulatory adjustment associated with the Capitalized Overhead Tax Variance. The net increase in revenue is offset by a corresponding net increase in tax expense.

Distribution Revenues

Distribution revenues increased by 5.6% compared to the year ended December 31, 2021, primarily due to the following:

•higher purchased power costs, which are fully recovered from ratepayers and are thus net income neutral;

•higher revenues resulting from OEB-approved 2022 rates; and

•a lower deferred regulatory adjustment associated with the Earnings Sharing Mechanism in 2022; partially offset by

•net income neutral items, including DTA Recovery Amounts and the adjustment to base distribution rates effective January 1, 2022 to cease sharing of DTA amounts going forward, pursuant to the DTA Implementation Decision which was partially offset by a regulatory adjustment associated with the Capitalized Overhead Tax Variance. The net increase in revenue is offset by a corresponding net increase in tax expense.

Distribution revenues, net of purchased power,3 increased by 8.8% during the year ended December 31, 2022, primarily due to the reasons noted above, adjusted for the recovery of purchased power costs.

OM&A Costs



Year ended December 31 (millions of dollars)	2022	2021	Change
Transmission	464	414	12.1	%
Distribution	744	664	12.0	%
Other	18	3	500.0	%
	1,226	1,081	13.4	%

Transmission OM&A Costs

Transmission OM&A costs were 12.1% higher than the year ended December 31, 2021, primarily due to:

•higher work program expenditures including those related to a higher volume of maintenance work on stations, lines and facilities;

3 Revenues, net of purchased power, is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.


			5

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

•higher property taxes; and

•higher corporate support costs; partially offset by

•lower project write-offs.

Distribution OM&A Costs

Distribution OM&A costs were 12.0% higher than the year ended December 31, 2021, primarily due to:

•higher work program expenditures related to emergency restoration, environmental management, IT initiatives and customer programs as well as increased spend on technical studies;

•costs related to storm restoration efforts that have been recovered from third parties and are offset in revenue, therefore net income neutral;

•higher project write-offs; and

•higher allowance for doubtful accounts; partially offset by

•costs associated with the integration of the Peterborough Distribution and Orillia Power operations in the prior year.

Depreciation, Amortization and Asset Removal Costs

Depreciation, amortization and asset removal costs increased by $44 million, or 4.8%, for the year ended December 31, 2022, primarily due to growth in capital assets as the Company continues to place new assets in-service, consistent with its ongoing capital investment program, and higher asset removal costs primarily resulting from storm-related asset replacements. These increases were partially offset by a gain realized on the sale of surplus property in the fourth quarter of 2022.

Financing Charges

Financing charges increased by $25 million, or 5.5%, for the year ended December 31, 2022, primarily due to higher weighted-average interest rates on short-term notes and the recognition of carrying charges associated with the DTA Recovery Amounts pursuant to the DTA Implementation Decision in the prior year, which were partially offset by the change in gains and losses on interest-rate swap agreements year over year.

Income Tax Expense

Income taxes are accounted for using the asset and liability method. Current taxes are recorded based on the taxes expected to be paid in respect of the current and prior years’ taxable income. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts and the respective tax basis of assets and liabilities including carryforward unused tax losses and credits.

As prescribed by the regulators, the Company recovers income taxes in revenues from ratepayers based on estimate of current tax expense in respect of regulated operations. The amounts of deferred income taxes related to regulated operations, which are considered to be more likely-than-not of recovery from, or refund to, ratepayers in future periods are recognized as deferred income tax regulatory assets or liabilities, with an offset to deferred tax expense. Therefore the consolidated tax expense or recovery for the current period is based on the total current and deferred tax expense or recovery, net of the regulatory accounting offset to deferred tax expense arising from temporary differences recoverable from or refundable to customers in the future.

Income tax expense was $290 million for the year ended December 31, 2022, compared to $179 million in 2021. The $111 million increase in income tax expense for the year ended December 31, 2022 was primarily attributable to:

•net income neutral items, including incremental tax expense relating to the DTA Implementation Decision which was partially offset by the tax recovery relating to Capitalized Overhead Tax Variance. The net tax expense is offset by a corresponding net increase in revenue; and

•higher pre-tax earnings adjusted for the DTA Implementation Decision and Capitalized Overhead Tax Variance; partially offset by

•higher deductible timing differences compared to the prior year.

The Company realized an effective tax rate (ETR) of approximately 21.4% for the year ended December 31, 2022 compared to approximately 15.4% realized in 2021. The increase of 6.0% was primarily attributable to the factors noted above.


			6

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

SELECTED ANNUAL FINANCIAL STATISTICS


Year ended December 31 (millions of dollars, except per share amounts)	2022	2021	2020
Revenues	7,740	7,185	7,250
Net income to common shareholder of Hydro One	1,057	972	1,792

Basic EPS	$7,431	$6,834	$12,599
Diluted EPS	$7,431	$6,834	$12,599

Dividends per common share declared	$4,584	$4,359	$7


As at December 31 (millions of dollars)	2022	2021	2020
Total assets	31,290	30,221	30,133
Total non-current financial liabilities1	12,649	12,640	12,387

1 Total non-current financial liabilities include long-term debt, long-term lease obligations, derivative liabilities, and long-term accounts payable.

Net Income - 2021 compared to 2020

Net income attributable to the common shareholder for the year ended December 31, 2021 of $972 million is a decrease of $820 million, or 45.8%, from the prior year. Significant influences on net income attributable to the common shareholder of Hydro One included:

•higher revenues, net of purchased power4, primarily resulting from:

•an increase in distribution revenues, net of purchased power4, primarily due to OEB-approved distribution rates, DTA Recovery Amounts pursuant to the DTA Implementation Decision, and the temporary suspension of late payment charges in the prior year, which were accompanied by the Company's efforts to help customers access relief programs, including flexible payment options; and

•an increase in transmission revenues mainly due to OEB-approved 2021 transmission rates and DTA Recovery Amounts pursuant to the DTA Implementation Decision, partially offset by the recognition of CDM revenues in the prior year following receipt of the 2020 OEB's Decision on transmission rates as well as higher regulatory adjustments.

•higher OM&A costs primarily resulting from:

•higher work program expenditures including IT initiatives, emergency restoration efforts, and vegetation management;

•higher project write-offs in 2021; and

•lower insurance proceeds received in 2021; partially offset by

•lower costs related to COVID-19.

•higher income tax expense primarily attributable to:

•income tax recovery recorded in the prior year following the July 2020 decision of the Ontario Divisional Court (ODC Decision) (see section "Regulation - Deferred Tax Asset");

•income tax expense relating to the DTA Recovery Amounts pursuant to the DTA Implementation Decision; and

•higher pre-tax earnings and lower net deductible timing differences.

Further contributing to the year-over-year impact on net income attributable to the common shareholder was the redemption of the Series 1 Preferred Shares announced in the third quarter of 2020.

4 Revenues, net of purchased power, is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.


			7

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

QUARTERLY RESULTS OF OPERATIONS


Quarter ended (millions of dollars, except EPS and ratio)	Dec 31, 2022			Sep 30, 2022		Jun 30, 2022		Mar 31, 2022		Dec 31, 2021		Sep 30, 2021		Jun 30, 2021	Mar 31, 2021
Revenues		1,851		2,022		1,830		2,037		1,768		1,903		1,712	1,802
Purchased power		895		963		852		1,014		914		933		838	894
Revenues, net of purchased power1		956		1,059		978		1,023		854		970		874	908
Net income to common shareholder		181		308		256		312		159		302		240	271

Basic and diluted EPS		$	1,273	$	2,165	$	1,800	$	2,193	$	1,118	$	2,123	$1,687	$1,905

Earnings coverage ratio2		3.4		3.4		3.3		3.3		3.1		3.1		3.0	3.0

1 Revenues, net of purchased power is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.

2 Earnings coverage ratio is a non-GAAP ratio. Non-GAAP ratios do not have a standardized meaning under GAAP, which is used to prepare the Company’s Consolidated Financial Statements and might not be comparable to similar financial measures presented by other entities. See section “Non-GAAP Financial Measures” for a discussion of this non-GAAP ratio and its component elements.

Variations in revenues and net income over the quarters are primarily due to the impact of seasonal weather conditions on customer demand and market pricing, as well as timing of regulatory decisions.

CAPITAL INVESTMENTS

The Company makes capital investments to maintain the safety, reliability and integrity of its transmission and distribution system assets and to provide for the ongoing growth and modernization required to meet the expanding and evolving needs of its customers and the electricity market. This is achieved through a combination of sustaining capital investments, which are required to support the continued operation of Hydro One’s existing assets, and development capital investments, which involve additions to both existing assets and large-scale projects such as new transmission lines and transmission stations.

Assets Placed In-Service

The following table presents Hydro One’s assets placed in-service during the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)	2022	2021	Change
Transmission	1,405	1,008	39.4	%
Distribution	853	738	15.6	%
Total assets placed in-service	2,258	1,746	29.3	%

Transmission Assets Placed In-Service

Transmission assets placed in-service increased by $397 million, or 39.4%, during the year ended December 31, 2022, compared to the year ended December 31, 2021, primarily due to the following:

•substantial completion of the end-of-life air blast circuit breakers replacement at Bruce B Switching Station;

•timing of assets placed in-service for major development projects including the new Lakeshore Transmission Station (TS) and the Wataynikaneyap Line to Pickle Lake Connection, partially offset by the East-West Tie Connection;

•higher investments associated with customer connections placed in-service; and

•higher volume of transmission line refurbishments and replacements; partially offset by

•substantial completion of the new Ontario grid control centre in the City of Orillia in 2021.

Distribution Assets Placed In-Service

Distribution assets placed in-service increased by $115 million, or 15.6%, during the year ended December 31, 2022 compared to the year ended December 31, 2021, primarily due to the following:

•higher volume of storm-related asset replacements following storms in May and December 2022;

•partial in-service of the South Middle Road feeder development project;

•higher volume of assets placed in-service associated with customer connections; and

•investment placed in-service for the Dunnville Operation Centre; partially offset by

•substantial completion of the new Ontario grid control centre in the City of Orillia in 2021; and .

•lower volume of work on line refurbishments and wood pole replacements.


			8

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Capital Investments

The following table presents Hydro One’s capital investments during the years ended December 31, 2022 and 2021:



Year ended December 31 (millions of dollars)	2022	2021	Change
Transmission
Sustaining	897	906	(1.0	%)
Development	214	296	(27.7	%)
Other	98	118	(16.9	%)
	1,209	1,320	(8.4	%)
Distribution
Sustaining	433	332	30.4	%
Development	383	332	15.4	%
Other	83	120	(30.8	%)
	899	784	14.7	%
Total capital investments	2,108	2,104	0.2	%

Total 2022 capital investments of $2,108 million were largely in-line with the previously disclosed expected amount of $2,021 million.

Transmission Capital Investments

Transmission capital investments decreased by $111 million, or 8.4%, in the year ended December 31, 2022 compared to the year ended December 31, 2021, primarily due to the following:

•timing of work on major development projects;

•lower volume of station refurbishments and replacements;

•investment in the new Ontario grid control centre in the City of Orillia in 2021; and

•lower volume of work on customer connections; partially offset by

•higher volume of transmission line refurbishments and replacements;

•higher spend on minor fixed asset and spare transformer purchases; and

•higher spend on demand capital investment.

Distribution Capital Investments

Distribution capital investments increased by $115 million, or 14.7%, in the year ended December 31, 2022 compared to the year ended December 31, 2021, primarily due to the following:

•higher spend on storm-related asset replacements following the storms in May and December 2022;

•higher volume of work on customer connections; and

•higher spend on system capability reinforcement projects; partially offset by

•lower volume of line refurbishments and wood pole replacements; and

•investment in the new Ontario grid control centre in the City of Orillia in the prior year.


			9

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Major Transmission Capital Investment Projects

The following table summarizes the status of significant transmission projects at December 31, 2022:

Project Name

Location

Type

Anticipated
In-Service Date

Estimated
Cost

Capital Cost
To Date

(year)

(millions of dollars)

Development Projects:

Barrie Area Transmission
Upgrade

Barrie-Innisfil
Southern Ontario

Upgraded transmission line
and stations

2023

125

East-West Tie Station Expansion1

Northern Ontario

New transmission connection
and station expansion

2024

191

182

Waasigan Transmission Line2

Thunder Bay-Atikokan-Dryden
Northwestern Ontario

New transmission line and station expansion

2024

Chatham to Lakeshore
Transmission Line3

Southwestern Ontario

New transmission line and
station expansion

2025

268

St. Clair
Transmission Line4

Southwestern Ontario

New transmission line and
station expansion

2025

Longwood to Lakeshore
Transmission Line5

Southwestern Ontario

New transmission line and
station expansion

TBD

Second Longwood to Lakeshore
Transmission Line5

Southwestern Ontario

New transmission line and
station expansion

TBD

Lakeshore to Windsor

Transmission Line5

Southwestern Ontario

New transmission line and
station expansion

TBD

Sustainment Projects:

Beck #2 Transmission Station
Circuit Breaker Replacement

Niagara area
Southwestern Ontario

Station sustainment

2023

135

113

Cherrywood Transmission Station
Circuit Breaker Replacement

Pickering
Central Ontario

Station sustainment

2023

115

Bruce B Switching Station
Circuit Breaker Replacement

Tiverton
Southwestern Ontario

Station sustainment

2024

185

166

Middleport Transmission Station
Circuit Breaker Replacement

Middleport
Southwestern Ontario

Station sustainment

2025

184

117

Lennox Transmission Station
Circuit Breaker Replacement

Napanee
Southeastern Ontario

Station sustainment

2026

152

116

Esplanade x Terauley
Underground Cable Replacement

Toronto
Southwestern Ontario

Line sustainment

2026

117

1 The East-West Tie Station Expansion project has been placed in-service in phases, with significant portions of the project placed in-service over the 2021-22 period, and final project in-service expected in 2024.

2 The estimated cost of the Waasigan Transmission Line relates to the development phase of the project and the anticipated in-service date reflects the anticipated completion date of the development phase only. On May 4, 2022 and November 18, 2022, Hydro One entered into agreements with First Nations communities that provide them the opportunity to acquire 50% ownership in the project. Completion of the line remains subject to stakeholder consultation and regulatory approvals.

3 The Chatham to Lakeshore Transmission Line project includes the line and associated facilities and is further discussed in the section “Other Developments - Supporting Critical Infrastructure in Southwestern Ontario”.

4 The estimated cost of the St. Clair Transmission Line relates to the development phase of the project and the anticipated in-service date reflects the anticipated completion date of the development phase only. Completion of the line remains subject to stakeholder consultation and regulatory approvals.

5 The scope and timing of these Southwestern Ontario transmission reinforcements are currently under review.


			10

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Future Capital Investments

The Company estimates future capital investments based on management’s expectations of the amount of capital expenditures that will be required to provide transmission and distribution services that are efficient, reliable, and provide value for customers, consistent with the OEB’s Renewed Regulatory Framework.

The 2023 to 2027 capital estimates differ from prior disclosures as the Company has updated its plan for timing and pacing of future capital investments, as well as re-prioritization of work. The overall increase in the transmission business is primarily related to projects outside of the OEB-approved JRAP investment plan.

The following tables summarize Hydro One’s annual projected capital investments for 2023 to 2027 by business segment and by category:


By business segment: (millions of dollars)	2023	2024	2025	2026	2027
Transmission1	1,565	1,547	1,446	1,475	1,539
Distribution	924	1,027	1,043	1,001	989
Total capital investments3	2,489	2,574	2,489	2,476	2,528


By category: (millions of dollars)	2023	2024	2025	2026	2027
Sustainment	1,534	1,658	1,629	1,548	1,480
Development1	691	710	669	730	891
Other2	264	206	191	198	157
Total capital investments3	2,489	2,574	2,489	2,476	2,528

1 Figures include investments in certain development projects of Hydro One Networks not included in the investment plan approved by the OEB in the JRAP decision.

2 "Other" capital expenditures include investments in fleet, real estate, IT, and operations technology and related functions.

3 On March 29, 2021, the IESO requested Hydro One initiate work to develop and construct a new transmission line between Chatham and Lambton (the St Clair Line) to support agricultural growth in Southwestern Ontario. On March 31, 2022, the Minister of Energy directed the OEB to amend Hydro One Networks' transmission licence to require it to develop and seek approvals for this and three other priority transmission lines to meet growing demand in Southwestern Ontario (see section “Other Developments”). The future capital investments presented do not include capital expenditures of the three additional lines, as Hydro One is currently evaluating the scope and timing of this work.

SUMMARY OF SOURCES AND USES OF CASH

Hydro One’s primary sources of cash flows are funds generated from operations, capital market debt issuances and bank credit facilities that are used to satisfy Hydro One’s capital resource requirements, including the Company’s capital expenditures, servicing and repayment of debt, and dividend payments.



Year ended December 31 (millions of dollars)	2022	2021
Net cash from operating activities	2,185	2,108
Net cash used in financing activities	(190)	(294)
Net cash used in investing activities	(2,036)	(2,027)
Decrease in cash and cash equivalents	(41)	(213)

Net cash from operating activities

Cash from operating activities increased by $77 million for the year ended December 31, 2022 compared to the same period of 2021. The increase was impacted by various factors, including the following:

•higher pre-tax earnings; and

•the impacts of the DTA Implementation Decision recognized in the year; partially offset by

•decrease in net working capital deficiency primarily attributable to higher receivables including those from the IESO associated with provincial funding programs, partially offset by a higher cost of power payable to the IESO related to the global adjustment rate; and

•changes to regulatory account balances.

Net cash used in financing activities

Cash used in financing activities decreased by $104 million for the year ended December 31, 2022 compared to the same period of 2021. This was impacted by various factors, including the following:

Uses of cash

•the Company repaid $6,000 million of short-term notes in 2022, compared to $3,905 million repaid in 2021.

•the Company repaid $603 million of long-term debt in 2022, compared to $804 million repaid in 2021.

•common share dividends paid in 2022 were $652 million, compared to dividends of $620 million paid in 2021.


			11

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Sources of cash

•the Company received proceeds of $6,335 million from the issuance of short-term notes in 2022, compared to $4,150 million received in 2021.

•the Company issued $750 million of long-term debt in 2022, compared to $900 million of long-term debt issued in 2021.

Net cash used in investing activities

Cash used in investing activities for the year ended December 31, 2022 was $9 million higher than the same period of 2021 as a result of higher capital investments in the current year. See section "Capital Investments" for comparability of capital investments made by the Company during the year ended December 31, 2022 compared to the prior year.

LIQUIDITY AND FINANCING STRATEGY

Short-term liquidity is provided through FFO,5 Hydro One’s commercial paper program, and the Company’s consolidated bank credit facilities. Under the commercial paper program, Hydro One is authorized to issue up to $2,300 million in short-term notes with a term to maturity of up to 365 days.

At December 31, 2022, Hydro One had $1,374 million in commercial paper borrowings outstanding, compared to $1,045 million outstanding at December 31, 2021. The Company also has revolving bank credit facilities (Operating Credit Facilities) with a total available balance of $2,300 million at December 31, 2022. In January 2022, Hydro One successfully amended its Operating Credit Facilities to incorporate environmental, social and governance (ESG) targets. The facilities now include a pricing adjustment which can increase or decrease Hydro One’s cost of funding based on its performance on certain Sustainability Performance Measures, which are related to Hydro One's sustainability goals. On January 12, 2023, Hydro One published a Sustainable Financing Framework (Framework), which allows the Company and its subsidiaries to issue sustainable financing instruments and allocate the net proceeds to investments in eligible green and social project categories. On June 1, 2022, the maturity date for the Operating Credit Facilities was extended from 2026 to 2027. No amounts were drawn on the Operating Credit Facilities at December 31, 2022 or 2021. The Company may use the Operating Credit Facilities for working capital and general corporate purposes. The short-term liquidity under the commercial paper program, the Operating Credit Facilities, available cash on hand and anticipated levels of FFO5 are expected to be sufficient to fund the Company’s operating requirements.

At December 31, 2022, the Company had long-term debt outstanding in the principal amount of $13,376 million, which included $13,245 million of long-term debt issued by Hydro One and long-term debt in the principal amount of $131 million issued by HOSSM. The majority of long-term debt issued by Hydro One has been issued under its Medium Term Note (MTN) Program, as further described below. The Company's total long-term debt consists of notes and debentures that mature between 2023 and 2064, and at December 31, 2022, had a weighted-average term to maturity of approximately 14.2 years (2021 - 15.1 years) and a weighted-average coupon rate of 3.9% (2021 - 3.9%).

In June 2022, Hydro One filed a short form base shelf prospectus in connection with its MTN Program, which has a maximum authorized principal amount of notes issuable of $4,000 million, and expires in July 2024. At December 31, 2022, $3,250 million remained available for issuance under the MTN Program prospectus. On January 27, 2023, Hydro One issued $1,050 million of long-term debt under its MTN program, consisting of $300 million (Series 53 notes) maturing in 2029 with a coupon rate of 3.93%, $450 million (Series 54 notes) maturing in 2033 with a coupon rate of 4.16% and $300 million (Series 55 notes) maturing in 2053 with a coupon rate of 4.46%. This represents Hydro One's first issuance of medium-term notes pursuant to the Framework.

Compliance

At December 31, 2022, the Company was in compliance with all financial covenants and limitations associated with the outstanding borrowings and credit facilities.

Credit Ratings

5 FFO is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.


			12

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

At December 31, 2022, Hydro One’s long-term and short-term debt ratings were as follows:


Rating Agency	Short-term Debt Rating	Long-term Debt Rating
DBRS	R-1 (low)	A (high)
Moody's	Prime-2	A3
S&P	A-1 (low)	A-

Effect of Interest Rates

The Company is exposed to fluctuations of interest rates as its regulated return on equity (ROE) is derived using a formulaic approach that takes into account changes in benchmark interest rates for Government of Canada debt and the A-rated utility corporate bond yield spread. The Company issues debt from time to time to refinance maturing debt and for general corporate purposes. The Company is therefore exposed to fluctuations in interest rates in relation to such issuances of debt. See section “Risk Management and Risk Factors - Risks Relating to Hydro One’s Business - Market, Financial Instrument and Credit Risk” for more details.

Pension Plan

In 2022, Hydro One made cash contributions of $89 million to its pension plan, compared to cash contributions of $62 million in 2021, and incurred $53 million in net periodic pension benefit costs, compared to $194 million incurred in 2021.

In September 2022, Hydro One filed a triennial actuarial valuation of its pension plan at December 31, 2021. Based on this valuation, Hydro One estimates that total Company pension contributions for 2023, 2024, 2025, 2026 and 2027 are approximately $91 million, $101 million, $103 million, $106 million, and $109 million, respectively. Future minimum contributions beyond 2024 will be updated following the actuarial funding valuation as of December 31, 2024, which is expected to be filed by no later than September 30, 2025. Should Hydro One elect to file a valuation earlier than required, contributions for 2023 and 2024 would also be updated, as applicable.

As a result of the transfer of 234 Inergi LP employees to Hydro One that occurred over a period ending January 1, 2022, the assets and liabilities of the Inergi Pension Plan will be transferred to the Hydro One Pension Plan (the Plan). The value of these assets and liabilities will be included in the Plan as of the date of transfer, which is expected to occur sometime in 2023.

The Company’s pension benefits obligation is impacted by various assumptions and estimates, such as the discount rate, rate of return on plan assets, rate of cost of living increase and mortality assumptions. A full discussion of the significant assumptions and estimates can be found in the section “Critical Accounting Estimates - Employee Future Benefits”.

OTHER OBLIGATIONS

Off-Balance Sheet Arrangements

There are no off-balance sheet arrangements that have, or are reasonably likely to have, a material current or future effect on the Company’s financial condition, changes in financial condition, revenues or expenses, results of operations, liquidity, capital expenditures or capital resources.


			13

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Summary of Contractual Obligations and Other Commercial Commitments

The following table presents a summary of Hydro One’s debt and other major contractual obligations and commercial commitments:


As at December 31, 2022 (millions of dollars)	Total	Less than 1 year	1-3 years	3-5 years	More than 5 years
Contractual obligations (due by year)
Long-term debt - principal repayments	13,376	731	1,450	500	10,695
Long-term debt - interest payments	8,087	512	996	940	5,639
Short-term notes payable	1,374	1,374	—	—	—
Pension contributions1	510	91	204	215	—
Environmental and asset retirement obligations	138	28	40	4	66
Outsourcing and other agreements	208	184	10	1	13
Lease obligations	56	12	20	17	7
Long-term software/meter agreement	32	12	15	2	3
Total contractual obligations	23,781	2,944	2,735	1,679	16,423

Other commercial commitments (by year of expiry)
Operating Credit Facilities2	2,300	—	—	2,300	—
Letters of credit3	188	186	2	—	—
Guarantees4	475	475	—	—	—
Total other commercial commitments	2,963	661	2	2,300	—

1 Contributions to the Hydro one Pension Plan are based on actuarial reports, including valuations performed at least every three years, and actual or projected levels of pensionable earnings, as applicable. The most recent actuarial valuation was performed effective December 31, 2021 and filed on September 26, 2022. See section "Liquidity and Financing Strategy - Pension Plan"

2 On June 1, 2022, the maturity dates for the Operating Credit Facilities were extended from June 2026 to June 2027.

3 Letters of credit consist of $163 million letters of credit related to retirement compensation arrangements, a $18 million letter of credit provided to the IESO for prudential support, $4 million in letters of credit to satisfy debt service reserve requirements, and $3 million in letters of credit for various operating purposes.

4 Guarantees consist of $475 million prudential support provided to the IESO by Hydro One on behalf of its subsidiaries.

SHARE CAPITAL

Hydro One is authorized to issue an unlimited number of common shares. The amount and timing of any dividends payable by Hydro One is at the discretion of the Hydro One Board of Directors (Board) and is established on the basis of Hydro One’s results of operations, maintenance of its deemed regulatory capital structure, financial condition, cash requirements, the satisfaction of solvency tests imposed by corporate laws for the declaration and payment of dividends and other factors that the Board may consider relevant. At February 13, 2023, Hydro One had 142,239 issued and outstanding common shares.

The Company is authorized to issue an unlimited number of preferred shares, issuable in series. At February 13, 2023, the Company had no preferred shares issued and outstanding.


			14

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

REGULATION

Electricity Rates - Joint Rate Application

In March 2018, the OEB issued a letter (OEB Letter) requesting Hydro One Networks file a single application for distribution rates and transmission revenue requirement for the period from 2023 to 2027. The OEB Letter had indicated that Hydro One Remotes should be included in the single application, however, this requirement was later removed by the OEB.

On August 5, 2021, Hydro One Networks filed a custom JRAP for 2023-2027. The JRAP included a proposed investment plan supporting the transmission and distribution revenue requirements. On March 31, 2022, Hydro One Networks filed updated evidence reflecting the impacts of updated inflation assumptions on the proposed investment plan as well as updated load forecasts. On October 24, 2022, Hydro One and the other parties involved in the JRAP proceeding entered into a Settlement Agreement, which was submitted to the OEB for approval. On November 16, 2022, Hydro One updated its revenue requirement to reflect the OEB's cost of capital parameters which were issued October 20, 2022. On November 29, the OEB issued a Decision and Order approving the JRAP Settlement Proposal in full. This marks the end of the JRAP proceeding. The following table lists the rate base and revenue requirements arising from the approved settlement:

Hydro One Networks - Transmission

Hydro One Networks - Distribution

Year

Rate Base

Revenue

Requirement

Rate Base

Revenue

Requirement

2023

$14,534 million

$1,952 million

$9,460 million

$1,727 million

2024

$15,342 million

$2,073 million

$9,979 million

$1,813 million

2025

$16,271 million

$2,168 million

$10,573 million

$1,886 million

2026

$17,148 million

$2,277 million

$11,153 million

$1,985 million

2027

$17,940 million

$2,362 million

$11,656 million

$2,071 million

Following the OEB approval of the JRAP Settlement and the pending completion of the recovery of DTA amounts previously shared with ratepayers in 2023, Hydro One's effective tax rate over the next five years is expected to be between 13% and 16%.

Deferred Tax Asset

On March 7, 2019, the OEB issued its reconsideration decision (DTA Decision) with respect to Hydro One's rate-setting treatment of the benefits of the DTA resulting from the transition from the payments in lieu of tax regime to tax payments under the federal and provincial tax regimes. On April 5, 2019, the Company filed an appeal with the ODC with respect to the DTA Decision.

On July 16, 2020, the ODC rendered its decision in which it agreed with the submissions of Hydro One that the DTA should be allocated to shareholders in its entirety.

On April 8, 2021, the OEB rendered its DTA Implementation Decision regarding the recovery of the DTA amounts allocated to ratepayers for the 2017 to 2022 period. In its DTA Implementation Decision, the OEB approved recovery of the DTA amounts allocated to ratepayers and included in customer rates for the 2017 to 2021 period, plus carrying charges, over a two-year recovery period commencing on July 1, 2021. The recovery of the previously shared DTA amounts plus carrying charges resulted in a $135 million increase in FFO6 for the twelve months ended December 31, 2022 (2021 - $65 million) and is expected to result in FFO6 of approximately $65 million in 2023. In addition, the DTA Implementation Decision required that Hydro One adjust the transmission revenue requirement and the base distribution rates beginning January 1, 2022 to eliminate any further tax savings flowing to customers. This resulted in an incremental $49 million of FFO6 in 2022 and is expected to result in additional FFO6 of approximately $46 million in 2023, but will decline annually thereafter.

Hydro One Remotes

On November 3, 2021, Hydro One Remotes filed an application with the OEB seeking approval for a 2.2% increase to 2021 base rates, effective May 1, 2022. The application was subsequently updated to request a 3.3% increase to 2021 base rates to reflect the OEB’s annually updated inflation parameters for electricity distributors for 2022. On March 24, 2022, the OEB approved the application for rates and other charges which became effective on May 1, 2022.

On August 31, 2022, Hydro One Remotes filed its price cap incentive rate application for 2023-2027 which includes a proposed 3.72% overall rate increase. A decision is anticipated in the first quarter of 2023.

6 FFO is a non-GAAP financial measure. See section “Non-GAAP Financial Measures”.


			15

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

OTHER DEVELOPMENTS

Equity Partnership Model with First Nation Communities

On September 22, 2022, Hydro One announced its new equity partnership model pursuant to which it will offer First Nations a 50 per cent equity stake in all new, future large-scale capital transmission line projects with a value exceeding $100 million.

Building Broadband Faster Act, 2021

In March 2021, the Province introduced Bill 257, Supporting Broadband and Infrastructure Expansion Act, 2021, to create a new act entitled the Building Broadband Faster Act, 2021 that is aimed at supporting the timely deployment of broadband infrastructure within unserved and underserved rural Ontario communities. Bill 257 received Royal Assent on April 12, 2021. Bill 257 amended the Ontario Energy Board Act to provide the Province with regulation-making authority regarding the development of, access to, or use of electricity infrastructure for non-electricity purposes. The Building Broadband Faster Act Guideline and three regulations informing the legislative changes were published in 2021. In March 2022, the Province introduced Bill 93, Getting Ontario Connected Act, 2022. Bill 93 received Royal Assent on April 14, 2022. Bill 93 amended the Building Broadband Faster Act to ensure that organizations that own underground utility infrastructure near a designated high-speed internet project provide timely access to their infrastructure data, which would allow internet service providers to quickly start work on laying down underground high-speed internet infrastructure. The regulation regarding electricity infrastructure and designated broadband projects under the Ontario Energy Board Act came into force in April 2022. This regulation substantially adopted Hydro One's proposed approach to allocation of the costs of broadband-related work on utility assets. It also directed the OEB to establish a deferral account for rate-regulated distributors to record incremental costs associated with carrying out activities pertaining to designated broadband projects, which the OEB completed in July 2022. The Company continues to be engaged with the Province and the OEB on implementing an appropriate regulatory framework to support the published Building Broadband Faster Act Guideline and regulations, including arrangements to sustain the Company’s revenues and recovery of reasonable associated costs. In September 2022, the Company launched its choice-based operating model to provide internet service providers with choices on how to access the Company’s infrastructure in order to effectively execute designated broadband projects.

Supporting Critical Transmission Infrastructure in Southwestern Ontario

On March 31, 2022, the Minister of Energy directed the OEB to amend Hydro One Networks' licence to require it to develop and seek approvals for four priority transmission line projects to meet growing electricity demand in Southwestern Ontario: the St. Clair Line (a 230kV line from Lambton TS to Chatham Switching Station (SS)); two 500 kV lines from Longwood TS to Lakeshore TS; and a 230kV line connecting the Windsor area to the Lakeshore TS.

On May 9, 2022, Hydro One filed a leave-to-construct application seeking OEB approval for the Chatham to Lakeshore Transmission Line project in Southwestern Ontario. In December 2020, the Minister of Energy issued a directive to the OEB to amend Hydro One Networks’ transmission licence to include a requirement that Hydro One proceed to develop and seek all necessary approvals for the project. The cost of this project is estimated at $268 million (see section "Major Transmission Capital Investment Projects"). On November 24, 2022, the OEB issued its Decision and Order granting leave to construct as requested in the application, with standard conditions of approval. On December 28, 2022, the Haudenosaunee Development Institute filed an appeal to the Divisional Court, under s.22 of the Ontario Energy Board Act, 1998, of this decision. The appeal, amongst other items, asked to set aside the OEB's decision granting Hydro One approval to construct the Chatham to Lakeshore Transmission Line project and to deny the application.

Sustainability Report

The Hydro One Limited 2021 Sustainability Report entitled "Energizing life for people & communities" is available on the Company’s website at www.hydroone.com/sustainability.

The 2021 Sustainability Report discloses the Company’s environmental, social and governance performance and provides a better understanding of how Hydro One manages the opportunities and challenges associated with its business. The report also includes disclosure relating to the Company’s current efforts in its priority areas of People, Planet and Community.

HYDRO ONE BOARD OF DIRECTORS AND EXECUTIVE OFFICERS

Board of Directors

On June 8, 2022, Jessica McDonald resigned from the Board of Hydro One. On the same day, Mark Podlasly was elected to the Board of Hydro One.

Executive Officers

On June 21, 2022, Mark Poweska resigned as a director and President and Chief Executive Officer of Hydro One. On the same day, William (Bill) Sheffield was appointed as Interim President and Chief Executive Officer of Hydro One. Upon his resignation,


			16

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Mr. Poweska remained with Hydro One as an advisor until such time as he assumed the role of President of Enmax Corporation in September 2022.

On August 26, 2022, Lyla Garzouzi resigned as Chief Safety Officer of Hydro One.

On September 16, 2022, Jason Fitzsimmons resigned as Chief Corporate Affairs & Customer Care Officer of Hydro One.

On January 10, 2023, the Board of Directors of Hydro One announced the appointment of David Lebeter as President and Chief Executive Officer effective February 1, 2023. On February 1, 2023, Mr. Sheffield stepped down from his role as Interim President and Chief Executive Officer, however continues in his role as a director of Hydro One, but will not stand for re-election at the Company's upcoming Annual General Meeting.

HYDRO ONE WORK FORCE

At December 31, 2022, Hydro One had a skilled and flexible work force of approximately 6,400 (2021 - 6,100) regular employees and 1,100 (2021 - 2,100) non-regular employees province-wide, comprising a mix of skilled trades, engineering, professional, managerial and executive personnel. Hydro One’s regular employees are supplemented primarily by accessing a large external labour force available through arrangements with the Company’s trade unions for contingent workers, sometimes referred to as “hiring halls”, and also by access to contract personnel. The hiring halls offer Hydro One the ability to flexibly use highly trained and appropriately skilled workers on a project-by-project and seasonal basis.

The following table sets out the number of Hydro One employees as at December 31, 2022:


	Regular Employees	Non-Regular Employees	Total
Power Workers' Union (PWU)1	3,801	839	4,640
Society of United Professionals (Society)	1,776	41	1,817
Canadian Union of Skilled Workers (CUSW) and construction building trade unions	—	169	169
Total employees represented by unions	5,577	1,049	6,626
Management and non-represented employees	810	23	833
Total employees2	6,387	1,072	7,459

1 Includes 732 non-regular “hiring hall” employees covered by the PWU agreement.

2 The average number of Hydro One employees in 2022 was approximately 9,200, consisting of approximately 6,400 regular employees and approximately 2,800 non-regular employees.

Collective Agreements

In March 2022, Hydro One and the CUSW commenced collective bargaining with the official exchange of bargaining agendas. The agreement was ratified by the CUSW membership in May. The term of the agreement is for four years, expiring on April 30, 2026.

Hydro One’s collective agreement with the PWU for Customer Service Operations expired on September 30, 2022. Collective bargaining to renew this agreement commenced on August 29, 2022 and is ongoing.

Hydro One’s collective agreements with the PWU and Society will expire on March 31, 2023. Collective bargaining to renew these agreements commenced on January 11, 2023 and January 16, 2023, respectively, and are on-going.

Stock-based Compensation

Hydro One Limited granted Deferred Stock Units (DSUs) to Directors and Management and Restricted Stock Units (RSUs) related to the new collective agreement with the Society (Society RSUs). At December 31, 2022 and 2021, the following Long-Term Incentive Plan and other awards were outstanding:


December 31 (number of units)	2022	2021
Management DSUs	118,505	90,240
Director DSUs	99,939	80,813
Society RSUs	34,619	68,005

NON-GAAP FINANCIAL MEASURES

Hydro One uses a number of financial measures to assess its performance. Adjusted measures, which include Adjusted EPS (basic and diluted) and Adjusted net income (collectively, adjusted measures), remove items from reported results for EPS (basic and diluted) and net income to calculate the adjusted measures. The Company presents FFO or “funds from operations” to reflect a measure of the Company’s cash flow; and revenues, net of purchased power to reflect revenues net of the cost of purchased power. Adjusted EPS (basic and diluted), Adjusted net income, FFO and revenues, net of purchased power are non-GAAP financial measures which do not have a standardized meaning prescribed by GAAP and might not be comparable to


			17

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

similar measures presented by other entities. They should not be considered in isolation nor as a substitute for analysis of the Company’s financial information reported under GAAP.

Hydro One also uses financial ratios that are non-GAAP ratios such as debt to capitalization ratio and earnings coverage ratio. Non-GAAP ratios do not have a standardized meaning prescribed by GAAP and might not be comparable to similar measures presented by other entities. They should not be considered in isolation nor as a substitute for analysis of the Company’s financial information reported under US GAAP.

FFO

FFO is defined as net cash from operating activities, adjusted for (i) changes in non-cash balances related to operations, (ii) dividends paid on preferred shares, and (iii) distributions to noncontrolling interest. Management believes that FFO is helpful as a supplemental measure of the Company’s operating cash flows as it excludes timing-related fluctuations in non-cash operating working capital and cash flows not attributable to common shareholders. As such, management believes that FFO provides a consistent measure of the cash generating performance of the Company’s assets.

The following table provides a reconciliation of GAAP (reported) results to non-GAAP (adjusted) results on a consolidated basis.


Year ended December 31 (millions of dollars)	2022	2021
Net cash from operating activities	2,185	2,108
Changes in non-cash balances related to operations	6	(69)
Distributions to noncontrolling interest	(10)	(8)
FFO	2,181	2,031

Revenues, Net of Purchased Power

Revenues, net of purchased power is defined as revenues less the cost of purchased power; distribution revenues, net of purchased power is defined as distribution revenues less the cost of purchased power. These measures are used internally by management to assess the impacts of revenue on net income and are considered useful because they exclude the cost of power that is fully recovered through revenues and therefore net income neutral.

The following tables provide a reconciliation of GAAP (reported) revenues to non-GAAP (adjusted) revenues, net of purchased power on a consolidated basis.


Year ended December 31 (millions of dollars)	2022	2021
Revenues	7,740	7,185
Less: Purchased power	3,724	3,579
Revenues, net of purchased power	4,016	3,606


Year ended December 31 (millions of dollars)	2022	2021
Distribution revenues	5,660	5,359
Less: Purchased power	3,724	3,579
Distribution revenues, net of purchased power	1,936	1,780


Quarter ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Revenues	1,851	2,022	1,830	2,037	1,768	1,903	1,712	1,802
Less: Purchased power	895	963	852	1,014	914	933	838	894
Revenues, net of purchased power	956	1,059	978	1,023	854	970	874	908


Quarter ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Distribution revenues	1,370	1,459	1,314	1,517	1,347	1,395	1,263	1,354
Less: Purchased power	895	963	852	1,014	914	933	838	894
Distribution revenues, net of purchased power	475	496	462	503	433	462	425	460


			18

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Debt to Capitalization Ratio

The Company believes that the debt to capitalization ratio is an important non-GAAP ratio in the management of its debt levels. This non-GAAP ratio does not have a standardized meaning under US GAAP and may not be comparable to similar measures presented by other entities. Debt to capitalization ratio has been calculated as total debt (including total long-term debt and short-term borrowings, net of cash and cash equivalents) divided by total debt plus total shareholder's equity, but excluding any amounts related to noncontrolling interest. Management believes that the debt to capitalization ratio is helpful as a measure of the proportion of debt in the Company's capital structure.


Year ended December 31 (millions of dollars)	2022	2021

Short-term notes payable	1,374	1,045
Less: cash and cash equivalents	(458)	(499)
Long-term debt (current portion)	733	603
Long-term debt (long-term portion)	12,606	12,593
Total debt (A)	14,255	13,742

Shareholder's equity (excluding noncontrolling interest)	11,596	11,172
Total debt plus shareholder's equity (B)	25,851	24,914


Debt-to-capitalization ratio (A/B)									55.1		%	55.2		%

Earnings Coverage Ratio

Earnings coverage ratio is defined as earnings before income taxes and financing charges attributable to shareholder, divided by the sum of financing charges and capitalized interest, and is calculated on a rolling twelve-month basis. The Company believes that the earnings coverage ratio is an important non-GAAP measure in the management of its liquidity. This non-GAAP ratio does not have a standardized meaning under US GAAP and may not be comparable to similar measures presented by other entities.


Quarter ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Net income to common shareholder	181	308	256	312	159	302	240	271
Income tax expense	41	101	68	80	54	71	27	27
Financing charges	125	121	118	114	122	116	101	114
Earnings before income taxes and financing charges attributable to common shareholder	347	530	442	506	335	489	368	412

Twelve months ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Earnings before income taxes and financing charges attributable to common shareholder (A)	1,825	1,813	1,772	1,698	1,604	1,579	1,516	1,526

Quarter ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Financing charges	125	121	118	114	122	116	101	114
Capitalized interest	16	16	16	15	16	15	16	13
Financing charges and capitalized interest	141	137	134	129	138	131	117	127

Twelve months ended (millions of dollars)	Dec 31, 2022	Sep 30, 2022	Jun 30, 2022	Mar 31, 2022	Dec 31, 2021	Sep 30, 2021	Jun 30, 2021	Mar 31, 2021
Financing charges and capitalized interest (B)	541	538	532	515	513	505	502	516

Earnings coverage ratio = A/B	3.4	3.4	3.3	3.3	3.1	3.1	3.0	3.0


			19

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

RELATED PARTY TRANSACTIONS

Hydro One is owned by Hydro One Limited. The Province is a shareholder of Hydro One Limited with approximately 47.2% ownership at December 31, 2022. The IESO, OPG, Ontario Electricity Financial Corporation (OEFC), the OEB, Acronym Solutions Inc. (Acronym) and Hydro One Broadband Solutions Inc, (HOBSI) are related parties to Hydro One because they are controlled or significantly influenced by the Ministry of Energy or by Hydro One Limited. The following is a summary of the Company’s related party transactions during the years ended December 31, 2022 and 2021:


Year ended December 31 (millions of dollars)

Related Party	Transaction	2022	2021
IESO	Power purchased	2,374	2,238
	Revenues for transmission services	2,062	1,832
	Amounts related to electricity rebates	1,031	1,065
	Distribution revenues related to rural rate protection	247	245
	Distribution revenues related to supply of electricity to remote northern communities	35	35
	Funding received related to CDM programs	3	1
OPG	Power purchased	20	13
	Revenues related to provision of services and supply of electricity	7	7
	Capital contribution received from OPG	5	3
	Costs related to the purchase of services	2	2
OEFC	Power purchased from power contracts administered by the OEFC	2	1
OEB	OEB fees	10	8

Hydro One Limited	Dividends paid	652	620
	Stock-based compensation costs	5	6
	Cost recovery for services provided	7	7
Acronym	Services received – costs expensed	26	24
	Revenues for services provided	2	2
HOBSI	Increase (decrease) in capital contribution from HOBSI	(2)	3
	Revenues for services provided	1	—

RISK MANAGEMENT AND RISK FACTORS

Hydro One is subject to numerous risks and uncertainties. Critical to Hydro One’s success is the identification, management and, to the extent possible, mitigation of these risks. Hydro One’s Enterprise Risk Management (ERM) program assists decision-makers throughout the organization with the management of key business risks, including new and emerging risks and opportunities.

The material risks relating to Hydro One and its business that the Company believes would be the most likely to influence an investor’s decision to purchase Hydro One’s securities are set out in the risk factors below. These risks, if they materialize, could have a materially adverse effect on the Company or its business, financial condition, or results of operations. This list is not a comprehensive list of all the risks to the Company, and the actual effect of any of the risks cited below could be materially different from what is described below. Additionally, other risks may arise or risks currently not considered material may become material in the future.

Risks Relating to Hydro One’s Business

Regulatory Risks and Risks Relating to Hydro One’s Revenues

Risks Relating to Actual Performance Against Forecasts

The Company’s ability to recover the actual costs of providing service and earn the allowed ROE depends on the Company achieving its forecasts established and approved in the rate-setting process. Actual costs could exceed the approved forecasts if, for example, the Company incurs operations, maintenance, administration, capital and financing costs above those included in the Company’s approved revenue requirement. The inability to recover any significant difference between forecast and actual expenses and to obtain associated regulatory approvals to recover the difference could materially adversely affect the Company’s financial condition and results of operations.

Further, the OEB approves the Company’s transmission and distribution rates based on projected electricity load and consumption levels, among other factors. If actual load or consumption materially falls below projected levels, the Company’s revenue, net income and cash flows for either, or both, of these businesses could be materially adversely affected.


			20

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

The Company’s current revenue requirements for its transmission and distribution businesses are based on cost and other assumptions, including inflation, that may not materialize. There is no assurance that the OEB would allow rate increases sufficient to offset unfavourable financial impacts from unanticipated changes in electricity demand or in the Company’s costs.

The Company is subject to risk of revenue loss from other factors, such as economic trends and conditions, changes in service territory, and weather conditions that influence the demand for electricity. The Company’s overall operating results may fluctuate substantially on a seasonal and year-to-year basis based on these trends and weather conditions. For instance, a cooler than normal summer or warmer than normal winter can be expected to reduce demand for electricity below that forecast by the Company, causing a decrease in the Company’s revenues, net income and cash flows as compared to the same period of the previous year.

The Company’s load could also be negatively affected by successful CDM programs whose results exceed forecasted expectations.

Risks Relating to Non-Rate Applications to the OEB

In addition to the matters described in the “Risks Relating to Obtaining Rate Orders” subsection below, the Company is also subject to the risk that it will not obtain, or will not obtain in a timely manner, required regulatory approvals for other matters, such as leave to construct applications, applications for mergers, acquisitions, amalgamations and divestitures, and environmental approvals. Appeals of OEB decisions and/or the need to obtain required occupation rights may result in significant delays, which could also lead to increased costs and project delays.

Decisions to acquire or divest other regulated businesses licensed by the OEB are subject to OEB approval. Accordingly, there is the risk that such matters may not be approved, that the Company may not be selected to build new transmission as part of the competitive process, or that unfavourable conditions will be imposed by the OEB.

Hydro One may face increased competition with other transmitters for opportunities to build new, large-scale transmission facilities in Ontario. The Company is subject to the risk that it will not be selected to build new transmission in Ontario, which could impair growth, disrupt operations and/or development, or have other adverse impacts.

Risks Relating to Rate-Setting Models for Transmission and Distribution

The OEB approves and periodically changes the rate-setting models and methodology for the transmission and distribution businesses. Changes to the application type, filing requirements, rate-setting model or methodology, or revenue requirement determination may have a material negative impact on Hydro One’s revenue and net income. For example, the OEB may in the future decide to reduce the allowed ROE for either of these businesses, modify the formula or methodology it uses to determine the ROE, or reduce the weighting of the equity component of the deemed capital structure. Any such reduction could reduce the net income of the Company. Similarly, the OEB is currently considering other utility remuneration models, and any such change could affect Hydro One’s revenue and net income.

The OEB’s Custom Incentive Rate-setting model requires that the term of a custom rate application be for multi-year periods. There are risks associated with forecasting key inputs such as revenues, operating expenses and capital over such a long period. For instance, if unanticipated capital expenditures arise that were not contemplated in the Company’s most recent rate decision, the Company may be required to incur costs that may not be recoverable until a future period or not recoverable at all in future rates. This could have a material adverse effect on the Company.

When rates are set for a multi-year period, including under a Custom Incentive Rate application, the OEB expects there to be no further rate applications for annual updates within the multi-year period, unless there are exceptional circumstances, with the exception of the clearance of established deferral and variance accounts. For example, the OEB does not expect to address annual rate applications for updates for cost of capital (including ROE), working capital allowance or sales volumes. If there were an increase in interest rates over the period of a rate decision and no corresponding changes were permitted to the Company’s revenue requirement (including cost of capital parameters), then the result could be a decrease in the Company’s financial performance.

To the extent that the OEB approves an in-service variance account for the transmission and/or distribution businesses, and should the Company fail to meet the threshold levels of in-service capital, the OEB may reclaim a corresponding portion of the Company’s revenues.

Risks Relating to Capital Expenditures

In order to be recoverable in rates, capital expenditures require the approval of the OEB. There can be no assurance that all capital expenditures, including any imposed by or resulting from government or regulatory bodies, incurred by Hydro One will be approved by the OEB. For example, capital cost overruns including those due to economic trends and conditions including inflation, unexpected capital expenditures in maintaining or improving the Company’s assets, unexpected costs as a result of proposed legislation, including that relating to the expansion of broadband service in Canada, may not be recoverable in transmission or distribution rates. To the extent possible, Hydro One aims to mitigate this risk by ensuring expenditures are


			21

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

reasonable and prudent, and also by seeking from the regulator clear policy direction on cost responsibility, and by obtaining pre-approval of the need for capital expenditures.

Any regulatory decision by the OEB to disallow or limit the recovery of any capital expenditures would lead to a lower-than-expected approved revenue requirement or rate base, potential asset impairment or charges to the Company’s results of operations, any of which could have a material adverse effect on the Company.

Risks Relating to Obtaining Rate Orders

The Company is subject to the risk that the OEB will not approve the Company’s transmission and distribution revenue requirements requested in outstanding or future applications for rates. Rate applications for revenue requirements are subject to the OEB’s review process, usually involving participation from intervenors and a public hearing process. There can be no assurance that resulting decisions or rate orders issued by the OEB will permit Hydro One to recover all costs actually incurred, including the costs of debt and income taxes, or to earn a particular ROE. A failure to obtain acceptable rate orders, or approvals of appropriate returns on equity and the ability to recover in rates costs actually incurred, may materially adversely affect: Hydro One’s transmission and distribution businesses, the undertaking or timing of capital expenditures, ratings assigned by credit rating agencies, the cost and issuance of long-term debt, and other matters, any of which may in turn have a material adverse effect on the Company. In addition, there is no assurance that the Company will receive regulatory decisions in a timely manner and, therefore, the Company may incur costs before having an approved revenue requirement and cash flows could be impacted. The Company is also subject to the risk that the OEB could change the regulatory treatment of certain costs which may affect the Company’s accounting treatment of and ability to recover such costs.

Risk of Recoverability of Total Compensation Costs

Hydro One manages all of its total compensation costs, including pension and other post-employment and post-retirement benefits (OPEBs), subject to restrictions and requirements imposed by the collective bargaining process and legislative requirements. Any element of total compensation costs which is disallowed in whole or part by the OEB and therefore not recoverable from customers in rates could result in costs which could be material and could decrease net income, which could have a material adverse effect on the Company. The OEB Act prohibits Hydro One from recovering specified executive compensation costs in its rates.

The Company provides OPEBs, including workers' compensation benefits and long-term disability benefits to qualifying employees. Hydro One currently maintains the accrual accounting method with respect to OPEBs. If the OEB directed Hydro One to transition to a different accounting method for OPEBs or otherwise adjusted the basis of recovery for OPEB costs, this could result in income volatility, due to an inability of the Company to book the difference between the accrual and cash as a regulatory asset, and the Company might not be able to recover some costs. A determination that some of the Company’s post-employment and post-retirement benefit costs are not recoverable could have a material adverse effect on the Company.

Risks Relating to Government Action

The Province is, and is likely to remain, the largest shareholder in Hydro One Limited. The Province may be in a position of conflict from time to time as a result of being an investor in Hydro One Limited and also being a government actor setting broad policy objectives in the electricity industry. Government actions may not be in the interests of the Company or investors.

Governments may pass legislation or issue regulations at any time, including legislation or regulation impacting Hydro One, which could have potential material adverse effects on Hydro One and its business. Such government actions may include, but are not limited to, legislation, regulation, directives or shareholder action intended to reduce electricity rates, place constraints on compensation, or affect the governance of Hydro One. Such government actions could adversely affect the Company’s financial condition and results of operations, as well as public opinion and the Company’s reputation. Government action may also hinder Hydro One’s ability to pursue its strategy and/or objectives.

The Province has in the past passed legislation to place limits on executive compensation at Hydro One and there is no guarantee they may not do so in the future. Potential involvement by the Province in the Company’s executive compensation practices may inhibit the Company’s ability to attract and retain qualified executive talent, which may also impact the Company’s performance, strategy and/or objectives. The failure to attract and retain qualified executives could have a material adverse effect on the Company.

Government action may also impact the Company’s credit ratings as the Company’s credit ratings reflect, in part, the rating agencies’ assessment of government involvement in the business of Hydro One. The Company cannot predict what actions rating agencies may take in the future, positive or negative, including in response to government action or inaction relating to or impacting Hydro One. The failure to maintain the Company’s current credit ratings could adversely affect the Company’s financial condition and results of operations, and a downgrade in the Company’s credit ratings could restrict the Company’s ability to access debt capital markets and increase the Company’s cost of debt.

Indigenous Claims Risk

Some of the Company’s current and proposed transmission and distribution assets are or may be located on reserve (as defined in the Indian Act (Canada)) (Reserve) lands, or lands over which Indigenous people have Aboriginal, treaty, or other legal rights


			22

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

or claims. Some Indigenous leaders, communities, and their members have made assertions related to sovereignty and jurisdiction over Reserve lands and traditional territories (land traditionally occupied or used by a First Nation, Métis or Inuit group) and are increasingly willing to assert their claims through the courts, tribunals, or direct action. These claims, and/or the settlement or resolution of these claims could have a material adverse effect on the Company or otherwise materially adversely impact the Company’s operations, including the development of current and future projects.

The Company’s operations and activities may give rise to the Crown having a duty to consult and potentially accommodate Indigenous communities. Procedural aspects of the Crown's duty to consult may be delegated to the Company by the Province or the federal government. A perceived failure by the Crown to sufficiently consult an Indigenous community, including communities with a traditional governance model not recognized under the Indian Act (Canada), or a perceived failure by the Company in relation to delegated consultation obligations, could result in legal challenges against the Crown or the Company, including judicial review or injunction proceedings, or could potentially result in direct action against the Company by a community or its citizens. If this occurs, it could disrupt or delay the Company’s operations and activities, including current and future projects, and have a material adverse effect on the Company.

Risk from Transfer of Assets Located on Reserves

The transfer orders by which the Company acquired certain of Ontario Hydro’s businesses as of April 1, 1999 did not transfer title to assets located on Reserves. The transfer of title to these assets did not occur because authorizations originally granted by the federal government for the construction and operation of these assets on Reserves could not be transferred without required consent. In several cases, the authorizations had either expired or had never been issued.

Currently, OEFC holds legal title to these assets and it is expected that the Company will manage them until it has obtained permits to complete the title transfer. To occupy Reserves, the Company must have valid permits as required by the Indian Act (Canada). For each permit, the Company may need to negotiate (an) agreement(s) with the First Nation, OEFC and any members of the First Nation who have occupancy rights. Any such agreement(s) include provisions whereby the First Nation consents to the issuance of a permit. For transmission assets, the Company must negotiate terms of payment. It is difficult to predict the aggregate amount that the Company may have to pay to obtain the required agreements from First Nations. If the Company cannot reach satisfactory agreements with the relevant First Nation to obtain federal permits, or is unable to obtain the actual federal permits for any other reason, it may have to relocate these assets to other locations and restore the lands at a cost that could be substantial. In a limited number of cases, it may be necessary to abandon a line and replace it with diesel generation facilities. In either case, the costs relating to these assets could have a material adverse effect on the Company if the costs are not recoverable in future rate orders.

Compliance with Laws and Regulations

Hydro One must comply with numerous laws and regulations affecting its business, including requirements relating to transmission and distribution companies, environmental laws, employment laws and health and safety laws. The failure of the Company to comply with these laws could have a material adverse effect on the Company’s business. See also “Environment Risk” and “Health and Safety Risk”.

For example, Hydro One’s licensed transmission and distribution businesses are required to comply with the terms of their licences, with codes and rules issued by the OEB, and with other regulatory requirements. In Ontario, the Market Rules issued by the IESO require the Company to, among other things, comply with applicable reliability standards established by the North American Electric Reliability Corporation (NERC) and Northeast Power Coordinating Council, Inc. (NPCC). The costs associated with compliance with these reliability standards are expected to be recovered through rates, but there can be no assurance that the OEB will approve the recovery of all of such costs. Failure to obtain such approvals could have a material adverse effect on the Company.

There is the risk that new legislation, regulations, requirements or policies will be introduced in the future. These may reduce Hydro One’s revenue, or may require Hydro One to incur additional costs, which may or may not be recovered in future transmission and distribution rates.

Risk of Natural and Other Unexpected Occurrences

The Company’s facilities are exposed to the effects of severe weather conditions, natural disasters, man-made events including, but not limited to, cyber and physical terrorist type attacks, events which originate from third-party connected systems, and any other potentially catastrophic events. The Company’s facilities may not withstand occurrences of these types in all circumstances.

The Company could also be subject to claims for damages from events which may be proximately connected with the Company’s assets (for example, forest fires), claims for damages caused by its failure to transmit or distribute electricity, costs related to ensuring its continued ability to transmit or distribute electricity or costs related to information or cyber security.

The Company does not have insurance for damage to its transmission and distribution wires, poles and towers located outside its transmission and distribution stations resulting from these or other events. Where insurance is available for the Company’s


			23

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

other assets and for damage claims and cyber security claims, such insurance coverage may have deductibles, limits and/or exclusions that may still expose the Company to material losses. Losses from lost revenues and repair costs could be substantial, especially for many of the Company’s facilities that are located in remote areas.

In the event that the Company is unable to recover such costs, this could have a material adverse effect on the Company.

Risk Associated with Information Technology (IT), Operational Technology (OT) Infrastructure, and Data Security

The Company’s ability to operate effectively in the Ontario electricity market is, in part, dependent upon it developing, modernizing, maintaining and managing complex IT and OT systems which are employed to operate and monitor its transmission and distribution facilities, financial and billing systems and other business systems. The Company’s increasing reliance on information systems and expanding data networks, as well as growing volume and complexity of data, increases its vulnerability, and exposure to information security threats. The Company’s transmission business is required to comply with various rules and standards for transmission reliability, including mandatory standards established by the NERC and the NPCC. These include standards relating to cyber-security and OT, which only apply to certain of the Company’s assets (generally being those whose failure could impact the functioning of the bulk electricity system). The Company may maintain different or lower levels of security for its assets that are not subject to these mandatory standards. The Company must also comply with various cyber-security and privacy-related regulatory requirements under the OEB’s Ontario Cyber Security Framework and legislative and licence requirements relating to the collection, use and disclosure of personal information and information regarding consumers, wholesalers, generators and retailers.

Cyber-attacks or unauthorized access to corporate IT and OT systems could result in service disruptions and system failures, which could have a material adverse effect on the Company, including as a result of a failure to provide electricity to customers. Because it operates critical infrastructure, Hydro One may be at greater risk of cyber-attacks from third parties (including state run or controlled parties) that could impair or incapacitate its assets. In addition, in the course of its operations, the Company collects, uses, processes and stores information which could be exposed in the event of a cyber-security incident or other unauthorized access or disclosure, such as information about customers, suppliers, counterparties, employees and other third parties.

Security and system disaster recovery controls are in place; however, there can be no assurance that there will not be system failures or security breaches or that such threats would be detected or mitigated on a timely basis. Upon occurrence and detection, the focus would shift from prevention to isolation, remediation and recovery until the incident has been fully addressed. Any such system failures or security breaches could have a material adverse effect on the Company.

Environment Risk

The Company is subject to extensive Canadian federal, provincial and municipal environmental regulation. Failure to comply could subject the Company to fines or other penalties. In addition, the presence or release of hazardous or other harmful substances could lead to claims by third parties or governmental orders requiring the Company to take specific actions such as investigating, controlling and remediating the effects of these substances. Although Hydro One is not a large emitter of greenhouse gases, the Company monitors its emissions to track and report on all sources, including sulphur hexafluoride or “SF6”. The Company could be subject to costs and other risks related to emissions. Contamination of the Company’s properties could limit its ability to sell or lease these assets in the future.

In addition, actual future environmental expenditures may vary materially from the estimates used in the calculation of the environmental liabilities provided for in the Company’s financial statements. The Company does not have insurance coverage for these environmental expenditures.

There is also risk associated with obtaining governmental approvals, permits, or renewals of existing approvals and permits related to constructing or operating facilities. This may require environmental assessment or result in the imposition of conditions, or both, which could result in delays and cost increases. Failure to obtain necessary approvals or permits could result in an inability to complete projects which may have a material adverse effect on the Company.

The Company’s facilities are exposed to the effects of severe weather conditions and natural disasters. The Company recognizes the risks associated with potential climate change and has developed plans to respond as appropriate. Climate change may have the effect of shifting weather patterns and increasing the severity and frequency of extreme weather events and natural disasters, which could impact Hydro One’s business. The Company’s facilities may not withstand occurrences of these types in all circumstances. Notwithstanding Hydro One’s efforts to adapt and increase grid resilience, the Company’s facilities are exposed to risks which may have an adverse effect on grid resilience. The Company could also be subject to claims for damages from events which may be proximately connected with the Company’s assets (for example, forest fires), claims for damages caused by its failure to transmit or distribute electricity or costs related to ensuring its continued ability to transmit or distribute electricity. The Company does not have insurance for damage to its transmission and distribution wires, poles and towers located outside its transmission and distribution stations resulting from these or other events. Where insurance is available for the Company’s other assets and for damage claims, such insurance coverage may have deductibles, limits and/or exclusions that may still expose the Company to material losses.


			24

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Losses from lost revenues and repair costs could be substantial, especially for many of the Company’s facilities that are located in remote areas.

In the event that the Company is unable to recover such costs, this could have a material adverse effect on the Company.

Labour Relations Risk

A substantial majority of the Company’s employees are unionized and are primarily represented by either the PWU or the Society. Over the past several years, significant effort has been expended to increase Hydro One’s flexibility to conduct operations in a more cost-efficient manner. Although the Company has achieved improved flexibility in its collective agreements, the Company may not be able to achieve further improvements, or at least not without increasing the risk of labour disruption. The Company reached an agreement with the Society for a collective agreement, covering the period from April 1, 2021 to March 31, 2023. Agreements were also reached with the Society and the PWU to facilitate the insourcing of Customer Service Operations (CSO) services effective March 1, 2018, as well as all remaining services provided by Inergi LP (IT, Supply Chain, Finance and Accounting, and Payroll) on various dates between March 1, 2021 and January 1, 2022. The Company also reached a main collective agreement with the PWU, covering the period from April 1, 2020 to March 31, 2023, and a CSO collective agreement with the PWU covering the period from October 1, 2019 to September 30, 2022. The Company also reached a collective agreement with the CUSW, covering the period from May 1, 2022 to April 30, 2026. Additionally, Electrical Power Systems Construction Association (EPSCA) and a number of building trade unions have agreements, to which Hydro One is bound, covering the period from May 1, 2020 to April 30, 2025.

Future negotiations with unions present the risk of a labour disruption or dispute, risk to the Company’s ability to sustain the continued supply of electricity to customers, as well as potential risks to public safety and reputation. The Company also faces financial risks related to its ability to negotiate collective agreements consistent with its rate orders. Any of these could have a material adverse effect on the Company. Negotiations with the PWU for the renewal of the CSO collective agreement that expired on September 30, 2022 remain ongoing. Collective agreements requiring renewal in 2023 include the Society collective agreement and the main PWU collective agreement, both expiring on March 31, 2023. Failure to renew these agreements on terms acceptable to Hydro One could have a material adverse effect on its business and results of operations and expose Hydro One to the risks noted above.

Risks Relating to Asset Condition, Capital Projects and Innovation

The Company continually incurs sustainment and development capital expenditures and monitors the condition of its assets to manage the risk of equipment failures and to determine the need for and timing of major refurbishments and replacements of its transmission and distribution infrastructure.

While traditionally a mature and stable industry, the electricity industry is facing rapid and dramatic technological change and increasing innovation, the consequences of which could have a material adverse effect on the Company, including a reduction in revenue.

Execution of the Company’s capital expenditure programs is partially dependent on external factors, such as OEB approvals; environmental approvals; municipal permits; equipment outage schedules that accommodate the IESO, generators and customers; other interrelated projects being on schedule; supply chain availability and/or cost and schedule variability for equipment suppliers, contracted services, and consulting services; and availability of contractor resources including in relation to workforce and equipment. Many of these external factors are beyond the Company’s control. There may also be a need for, among other things, Environmental Assessment Act (Ontario) approvals, approvals which require public meetings, appropriate engagement with Indigenous communities, OEB approvals of expropriation or early access to property, and other activities. Obtaining approvals and carrying out these processes may also be impacted by opposition to the proposed site of the capital investments. Delays in obtaining required approvals or failure to complete capital projects on a timely basis, or at all, could materially adversely affect transmission reliability or customers’ service quality or increase maintenance costs which could have a material adverse effect on the Company. Failure to receive approvals for projects when spending has already occurred would result in the inability of the Company to recover the investment in the project as well as forfeit the anticipated return on investment. The assets involved may be considered impaired and result in the write off of the value of the asset, negatively impacting net income. If the Company is unable to carry out capital expenditure plans in a timely manner, equipment performance may degrade, which may reduce network capacity, result in customer interruptions, compromise the reliability of the Company’s networks or increase the costs of operating and maintaining these assets. Any of these consequences could have a material adverse effect on the Company.

Increased competition for the development of large transmission projects and legislative changes relating to the selection of transmitters could impact the Company’s ability to expand its existing transmission system, which may have an adverse effect on the Company. To the extent that other parties are selected to construct, own and operate new transmission assets, the Company’s share of Ontario’s transmission network would be reduced. Any delays in these new transmitters’ projects may impact the Company’s own projects that it is undertaking to in-service these new transmission assets.


			25

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Infectious Disease Risk

An outbreak of infectious disease, in the form of an epidemic, a pandemic (such as COVID-19 and the emergence of its variants), or a similar public health threat, could materially adversely impact the Company. The extent of any such adverse impact on the Company is uncertain, and may depend on the length and severity of any such infectious disease outbreak, any resultant government regulations, guidelines and actions, and any related adverse changes in general economic and market conditions. Such circumstances could impact, in particular: the Company’s operations and workforce, including security of supply, both with respect to availability and affordability, which individually or collectively may impact the Company's ability to complete operating and capital work programs as planned, including within scope and budget; certain financial obligations of the Company, including pension contributions and other post-retirement benefits, as a result of changes in prevailing market conditions; the Company’s expected revenues; reductions in overall electricity consumption and load, both short term and long term; overdue accounts and bad debt increases as a result of changes in the ability of the Company’s customers to pay; liquidity and the Company’s ability to raise capital; the timing of increased rates; the Company’s ability to recover incremental costs and lost revenues linked to the outbreak; the Company’s ability to file regulatory filings on a timely basis; timing of regulatory decisions and the impacts those decisions may have on the Company or its ability to implement them; and customer and stakeholder needs and expectations.

The Company also faces risks and costs associated with implementation of business continuity plans and modified work conditions, including the risks and costs associated with maintaining or reducing its workforce, making the required resources available to its workforce to enable essential work, including remotely where possible, and to keep its workforce healthy, as well as risks and costs associated with recovery of normal operations. Furthermore, the Company is dependent on third party providers for certain activities, and relies on a strong international supply chain. Any significant disruption to those providers or the supply chain resulting from an outbreak of infectious disease could materially adversely impact the Company.

Work Force Demographic Risk

By the end of 2022, approximately 10% of the Company’s employees who are members of the Company’s defined benefit and defined contribution pension plans were eligible for retirement, and by the end of 2023, approximately 11% could be eligible. These percentages are not evenly spread across the Company’s work force, but tend to be most significant in the most senior levels of the Company’s staff and among management staff. During 2022, approximately 4% of the Company’s work force (remaining consistent with 2021) elected to retire. Accordingly, the Company’s continued success will be tied to its ability to continue to attract and retain sufficient qualified staff to replace the capability lost through retirements and meet the demands of the Company’s work programs.

In addition, the Company expects the skilled labour market for its industry will remain highly competitive. Many of the Company’s current and potential employees are sought after as they possess skills and experience that are also highly coveted by other organizations inside and outside the electricity sector. The failure to attract, retain and deploy qualified personnel for Hydro One’s business could have a material adverse effect on the Company.

Risk Associated with Arranging Debt Financing

The Company expects to borrow to repay its existing indebtedness and to fund a portion of capital expenditures. Hydro One has substantial debt principal repayments coming due, including $731 million in 2023, $700 million in 2024 and $750 million in 2025. In addition, from time to time, the Company may draw on its syndicated bank lines and/or issue short-term debt under Hydro One Inc.’s $2,300 million commercial paper program which would mature within one year of issuance. The Company also plans to incur continued material capital expenditures for each of 2023 and 2024. Cash generated from operations, after the payment of expected dividends, will not be sufficient to fund the repayment of the Company’s existing indebtedness and capital expenditures. The Company’s ability to arrange sufficient and cost-effective debt financing could be materially adversely affected by numerous factors, including the regulatory environment in Ontario, the Company’s results of operations and financial position, market conditions, the ratings assigned to its debt securities by credit rating agencies, an inability of the Company to comply with its debt covenants, and general economic conditions (such as, among other things, changes in interest rates). A downgrade in the Company’s credit ratings could restrict the Company’s ability to access debt capital markets and increase the Company’s cost of debt. Any failure or inability on the Company’s part to borrow the required amounts of debt on satisfactory terms could impair its ability to repay maturing debt, fund capital expenditures and meet other obligations and requirements and, as a result, could have a material adverse effect on the Company. Increasing investor interest in ESG performance and reporting also has the potential to impact the cost and availability of the Company’s funding, as these factors may be increasingly connected to the quality of the Company’s ESG practices and related reporting, including reports addressing the allocation of funds and impact reporting under Hydro One’s Sustainable Financing Framework.

Market, Financial Instrument and Credit Risk

Market risk refers primarily to the risk of loss that results from changes in costs, foreign exchange rates and interest rates, including potentially negative interest rates. The Company is exposed to fluctuations in interest rates as its regulated ROE is derived using a formulaic approach that takes into account anticipated interest rates. The Company issues debt from time to time to refinance maturing debt and for general corporate purposes. The Company is therefore exposed to fluctuations in interest


			26

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

rates in relation to such issuances of debt. Fluctuations in interest rates may also impact the funded position of Hydro One’s Defined Benefit Pension Plan, and associated pension asset or liability (see also “Pension Plan Risk”). The Company is not currently exposed to material foreign exchange risk.

The OEB-approved adjustment formula for calculating ROE in a deemed regulatory capital structure of 60% debt and 40% equity provides for increases and decreases depending on changes in benchmark interest rates for Government of Canada debt and the A-rated utility corporate bond yield spread. For the transmission and distribution businesses, during the Custom Incentive Rate period from 2023 to 2027, the OEB does not expect to address annual rate applications for updates to allowed ROE, so fluctuations will have no impact to net income. The Company has interest rate exposure in 2023 and beyond associated with the refinancing of maturing short- and long-term debt, as well as with debt issued for general corporate purposes and under the Sustainable Financing Framework which may include debt issued in relation to growth in rate base. The Company periodically uses interest rate swap agreements to mitigate elements of interest rate risk.

Financial assets create a risk that a counterparty will fail to discharge an obligation, causing a financial loss. Derivative financial instruments result in exposure to credit risk, since there is a risk of counterparty default. Hydro One monitors and minimizes credit risk through various techniques, including dealing with highly rated counterparties, limiting total exposure levels with individual counterparties, entering into agreements which enable net settlement, and monitoring the financial condition of counterparties. The Company does not trade in any energy derivatives. The Company is required to procure electricity on behalf of competitive electricity retailers and certain local distribution companies for resale to their customers. The resulting concentrations of credit risk are mitigated through the use of various security arrangements, including letters of credit, which are incorporated into the Company’s service agreements with these retailers in accordance with the OEB’s Retail Settlement Code.

The failure to properly manage these risks could have a material adverse effect on the Company.

Health and Safety Risk

Hydro One’s work environment can be inherently dangerous and there is a risk to health and safety of both the public and our employees, as well as possible resultant operational and/or financial impacts. The Company is subject to federal and provincial legislation and regulations relating to health and safety. Findings of a failure to comply with these requirements could result in penalties and reputational risk, which could negatively impact the Company. Failure to comply could subject the Company to fines or other penalties. Any regulatory decision to disallow or limit the recovery of such costs could have a material adverse effect on the Company.

Pension Plan Risk

Hydro One has the Hydro One Defined Benefit Pension Plan in place for the majority of its employees. Contributions to the pension plan are established by actuarial valuations which are required to be filed with the Financial Services Regulatory Authority of Ontario on a triennial basis. The most recently filed valuation was prepared as at December 31, 2021, and was filed in September 2022, covering a three-year period from 2022 to 2024. The next required valuation will be prepared as at December 31, 2024 and is expected to be filed by no later than September 2025. Hydro One’s contributions to its pension plan satisfy, and are expected to continue to satisfy, minimum funding requirements. Contributions beyond 2023 will depend on the funded position of the plan, which is determined by investment returns, interest rates and changes in benefits and actuarial assumptions at that time. A determination by the OEB that some of the Company’s pension expenditures are not recoverable through rates could have a material adverse effect on the Company, and this risk may be exacerbated if the amount of required pension contributions increases.

Hydro One currently reports and recovers its pension costs on a cash basis, and maintains the accrual method with respect to OPEBs. Transitioning from the cash basis to an accrual method for pension costs may have material negative rate impacts for customers or material negative impacts on the Company should recovery of costs be disallowed by the OEB.

See also “Regulatory Risks and Risks Relating to Hydro One’s Revenues - Risk of Recoverability of Total Compensation Costs” for risks relating to recovery of pension costs.

Risk from Provincial Ownership of Transmission Corridors

The Province owns some of the corridor lands underlying the Company’s transmission system. Although the Company has the statutory right to use these transmission corridors, the Company may be limited in its options to expand or operate its systems. Also, other uses of the transmission corridors by third parties in conjunction with the operation of the Company’s systems, or adjacent land use by third parties, may increase safety or environmental risks, which could have a material adverse effect on the Company.

Litigation Risks

In the normal course of the Company’s operations, it becomes involved in, is named as a party to and is the subject of, various legal proceedings, including regulatory proceedings, tax proceedings and legal actions, relating to actual or alleged violations of law, common law damages claims, personal injuries, property damage, property taxes, land rights, the environment, contract


			27

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

disputes, claims by former employees and claims and proceedings by Indigenous groups. The outcome of outstanding, pending or future proceedings cannot be predicted with certainty and may be determined adversely to the Company, which could have a material adverse effect on the Company. Even if the Company prevails in any such legal proceeding, the proceedings could be costly and time-consuming and would divert the attention of management and key personnel from the Company’s business operations, which could adversely affect the Company.

Transmission Assets on Third-Party Lands Risk

Some of the lands on which the Company’s transmission assets are located are owned by third parties, including the Province and federal Crown, and are or may become subject to land claims by First Nations. The Company requires valid occupation rights to occupy such lands (which may take the form of land use permits, easements or otherwise). If the Company does not have valid occupational rights on third-party owned or controlled lands or has occupancy rights that are subject to expiry, it may incur material costs to obtain or renew such occupancy rights, or if such occupancy rights cannot be renewed or obtained it may incur material costs to remove and relocate its assets and restore the subject land. If the Company does not have valid occupancy rights and must incur costs as a result, this could have a material adverse effect on the Company or otherwise materially adversely impact the Company’s operations.

Reputational, Public Opinion and Political Risk

Reputation risk is the risk of negative publicity or the public’s negative perceptions towards Hydro One that may result in a detrimental impact to Hydro One’s business, operations or financial condition leading to a deterioration of Hydro One’s reputation. Hydro One’s reputation could be negatively impacted by changes in public opinion, attitudes towards the Company’s privatization, failure to deliver on its customer and/or stakeholder promises, failure to comply with mandatory reliability regulations established by the NERC and NPCC, failure to adequately respond to social issues raised by employees, partners and/stakeholders and other external forces. Adverse reputational events or political actions could have a material adverse effect on Hydro One’s business and prospects including, but not limited to, delays or denials of requisite approvals, such as denial of requested rates, and accommodations for Hydro One’s planned projects, escalated costs, legal or regulatory action, and damage to stakeholder and community relationships. Any of these could have a material adverse impact on Hydro One and its business, financial condition and results of operations.

Risk Associated with Outsourcing Arrangements

Hydro One has entered into an outsourcing arrangement with a third party for the provision of certain back office and IT services. If the services are disrupted, it could have a material adverse effect on the Company. Additionally, if the outsourcing arrangement or statements of work thereunder are terminated for any reason or expire before a new supplier is selected and fully transitioned, the Company could be required to transfer to another service provider or insource, which could have a material adverse effect on the Company’s business, operating results, financial condition or prospects.

Risks Associated with Acquisitions

Acquisitions include inherent risks that some or all of the expected benefits may fail to materialize, or may not occur within the time periods anticipated, and Hydro One may incur material unexpected costs or liabilities. Realization of the anticipated benefits would depend, in part, on the Company’s ability to successfully integrate the acquired business, including the requirement to devote management attention and resources to integrating business practices and support functions. The failure to realize the anticipated benefits, the diversion of management’s attention, or any delays or difficulties encountered in connection with the integration could have an adverse effect on the Company’s business, results of operations, financial condition or cash flows.

Risks Relating to the Company’s Relationship with Hydro One Limited and the Province

Indirect Ownership and Continued Influence by the Province and Voting Power

The Province currently owns approximately 47.2% of the outstanding common shares of Hydro One Limited and it is expected to continue to maintain a significant ownership interest in voting securities of Hydro One Limited for an indefinite period.

As a result of its significant ownership of the common shares of Hydro One Limited, the Province has, and is expected indefinitely to have, the ability to determine or significantly influence the outcome of shareholder votes at Hydro One Limited, subject to the restrictions in the Governance Agreement between Hydro One Limited and the Province dated November 5, 2015 (Governance Agreement) (available on SEDAR at www.sedar.com). Despite the terms of the Governance Agreement in which the Province has agreed to engage in the business and affairs of Hydro One Limited as an investor and not as a manager, there is a risk that the Province’s engagement in the business and affairs of Hydro One Limited as an investor will be informed by its policy objectives and may influence the conduct of the business and affairs of Hydro One Limited in ways that may not be aligned with the interests of other investors in Hydro One Limited. Notwithstanding the Governance Agreement, and in light of actions historically taken by the Province, there can be no assurance that the Province will not take other actions in the future that could be detrimental to the interests of investors in Hydro One Limited. This influence may also extend to Hydro One. As a result, the Province may influence the conduct of the business and affairs of Hydro One, and decisions may be made by the


			28

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Province as a shareholder of Hydro One Limited which may not be aligned with the interests of the other security holders of Hydro One. See “Risks Relating to Government Action” above.

Composition of the Board of Directors of Hydro One

Under the Governance Agreement, Hydro One Limited has agreed that the Board of Hydro One and Hydro One Networks will be constituted to have the same members as the Board of Hydro One Limited, unless the Board of Hydro One Limited determines otherwise. The Governance Agreement contains provisions governing the independence of the members of the Board of Hydro One Limited and the ability of the Province to nominate and, in certain circumstances, remove directors, which could indirectly impact the composition of the Board of Hydro One in a manner which may not be aligned with the interests of the other security holders of Hydro One. There is a risk that the Province will nominate or confirm individuals who satisfy the independence requirements but who it considers are disposed to support and advance its policy objectives and give disproportionate weight to the Province’s interests in exercising their business judgment and balancing the interests of the stakeholders of Hydro One Limited. Those same individuals, to the extent they are also on the Board of Hydro One, could similarly give disproportionate weight to the Province’s indirect interest in Hydro One in exercising their business judgment and balancing the interests of the stakeholders of Hydro One.

More Extensive Regulation

Although under the Governance Agreement, the Province has agreed to engage in the business and affairs of Hydro One Limited as an investor and not as a manager and has stated that its intention is to achieve its policy objectives through legislation and regulation as it would with respect to any other utility operating in Ontario, there is a risk that the Province will exercise its legislative and regulatory power to achieve policy objectives in a manner that has a material adverse effect on Hydro One Limited, which in turn could have a material adverse effect on Hydro One. See “Risks Relating to Government Action” above.

Prohibitions on Selling the Company’s Transmission or Distribution Business

The Electricity Act, 1998 (Ontario) prohibits Hydro One Limited from selling all or substantially all of the business, property or assets related to its transmission system or distribution system that is regulated by the OEB. There is a risk that these prohibitions may limit the ability of Hydro One Limited, and in turn, Hydro One, to engage in sale transactions involving a substantial portion of either system, even where such a transaction may otherwise be considered to provide substantial benefits to Hydro One Limited, Hydro One or their security holders.

CRITICAL ACCOUNTING ESTIMATES AND JUDGMENTS

The preparation of Hydro One Consolidated Financial Statements requires the Company to make key estimates and critical judgments that affect the reported amounts of assets, liabilities, revenues and costs, and related disclosures of contingencies. Hydro One bases its estimates and judgments on historical experience, current conditions and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities, as well as identifying and assessing the Company’s accounting treatment with respect to commitments and contingencies. Actual results may differ from these estimates and judgments. Hydro One has identified the following critical accounting estimates and judgements used in the preparation of its Consolidated Financial Statements:

Revenues

Regulatory Assets and Liabilities

Hydro One’s regulatory assets represent certain amounts receivable from future electricity customers and costs that have been deferred for accounting purposes because it is probable that they will be recovered in future rates. The regulatory assets mainly include amounts related to the deferred income taxes, pension benefit liability, post-retirement and post-employment non-service costs, deferred tax asset sharing, environmental liabilities and share-based compensation costs. The Company’s regulatory liabilities represent certain amounts that are refundable to future electricity customers. They pertain primarily to deferral and variance accounts, and includes amounts related to the pension asset in the current year. The regulatory assets and liabilities can be recognized for rate-setting and financial reporting purposes only if the amounts have been approved for inclusion in the electricity rates by the OEB, or if such approval is judged to be probable by management. If, at some future date, management judges that it is no longer probable that the OEB will allow the inclusion of a regulatory asset or liability in future electricity rates, the appropriate carrying amount would be reflected in results of operations prospectively from the date the Company’s assessment is made, unless the change meets the requirements for a subsequent event adjustment.


			29

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Environmental Liabilities

Hydro One records a liability for the estimated future expenditures associated with the removal and destruction of polychlorinated biphenyl (PCB)-contaminated insulating oils and related electrical equipment, and for the assessment and remediation of chemically contaminated lands. There are uncertainties in estimating future environmental costs due to potential external events such as changes in legislation or regulations and advances in remediation technologies. In determining the amounts to be recorded as environmental liabilities, the Company estimates the current cost of completing required work and makes assumptions as to when the future expenditures will actually be incurred, in order to generate future cash flow information. All factors used in estimating the Company’s environmental liabilities represent management’s best estimates of the present value of costs required to meet existing legislation or regulations. However, it is reasonably possible that numbers or volumes of contaminated assets, cost estimates to perform work, inflation assumptions and the assumed pattern of annual cash flows may differ significantly from the Company’s current assumptions. Environmental liabilities are reviewed annually or more frequently if significant changes in regulations or other relevant factors occur. Estimate changes are accounted for prospectively.

Employee Future Benefits

Hydro One’s employee future benefits consist of pension and post-retirement and post-employment plans, and include pension, group life insurance, health care, and long-term disability benefits provided to the Company’s current and retired employees. Employee future benefits costs are included in Hydro One’s labour costs that are either charged to results of operations or capitalized as part of the cost of property, plant and equipment and intangible assets. Changes in assumptions affect the benefit obligation of the employee future benefits and the amounts that will be charged to results of operations or capitalized in future years. The following significant assumptions and estimates are used to determine employee future benefit costs and obligations:

Weighted Average Discount Rate

The weighted average discount rate used to calculate the employee future benefits obligation is determined at each year end by referring to the most recently available market interest rates based on “AA”-rated corporate bond yields reflecting the duration of the applicable employee future benefit plan. The discount rate at December 31, 2022 increased to 5.06% (from 3.00% at December 31, 2021) for pension benefits and increased to 5.07% (from 3.00% at December 31, 2021) for the post-retirement and post-employment plans. The increase in the discount rate has resulted in a corresponding decrease in employee future benefits liabilities for the pension, post-retirement and post-employment plans for accounting purposes. The liabilities are determined by independent actuaries using the projected benefit method prorated on service and based on assumptions that reflect management’s best estimates.

Expected Rate of Return on Plan Assets

The expected rate of return on pension plan assets of 6.00% (2021 - 5.40%) is based on expectations of long-term rates of return at the beginning of the year and reflects the current pension plan asset mix dated November 8, 2022. The expected rate of return for the December 31, 2022 disclosures and the 2023 registered pension plan expense is based on the plan’s ultimate target asset mix.

Rates of return on the respective portfolios are determined with reference to respective published market indices. The expected rate of return on pension plan assets reflects the Company’s long-term expectations. The Company believes that this assumption is reasonable because, with the pension plan’s balanced investment approach, the higher volatility of equity investment returns is intended to be offset by the greater stability of fixed-income and short-term investment returns. The net result, on a long-term basis, is a lower return than might be expected by investing in equities alone. In the short term, the pension plan can experience fluctuations in actual rates of return.

Rate of Cost of Living Increase

The rate of cost of living increase is determined by considering differences between long-term Government of Canada nominal bonds and real return bonds, which increased from 1.80% per annum as at December 31, 2021 to approximately 2.12% per annum as at December 31, 2022. Based on the Bank of Canada’s commitment to keep long-term inflation between 1.00% and 3.00%, in addition to current and anticipated trends, management believes that a long-term assumption of 2.00% per annum is reasonable for employee future benefits liability valuation purposes as at December 31, 2022 (1.75% per annum was used for the purpose of December 31, 2021 disclosures and 2022 benefit cost).

Salary Increase Assumptions

Salary increases should reflect general wage increases plus an allowance for merit and promotional increases for current members of the plan and should be consistent with the assumptions for consumer price inflation and real wage growth in the economy. The merit and promotion scale was developed based on the salary increase assumption review performed in 2017. The review considers actual salary experience from 2002 to 2016 using valuation data for all active members as at December


			30

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

31, 2016, based on age and service and Hydro One’s expectation of future salary increases. Additionally, the salary scale reflects negotiated salary increases over the contract period as well as slightly lower expected increases in the short term.

Mortality Assumptions

The Company’s employee future benefits liability is also impacted by changes in life expectancies used in mortality assumptions. Increases in life expectancies of plan members result in increases in the employee future benefits liability. For the pension and post-retirement plans, the mortality assumption used at December 31, 2022 is 90% of the 2014 Canadian Pensioners Mortality Private Sector table projected generationally using improvement Scale B. The multiplier applied to the assumed mortality table is based on the result of a mortality experience study that was conducted in 2021. For the post-employment plan, the mortality assumption used at December 31, 2022 is the disability mortality table from the 2009-2015 Canadian Institute of Actuaries Group Long Term Disability Termination Study, which is the most recent publicly available table that reflects Canadian experience and is commonly used by Canadian plan sponsors.

Rate of Increase in Health Care Cost Trends

The costs of post-retirement and post-employment benefits are determined at the beginning of the year and are based on assumptions for expected claims experience and future health care cost inflation. For the post-retirement benefit plans, a study of Hydro One’s historical per capita health care cost trend experience was conducted in 2017. The health and dental trends reflect the results of this study as well as macroeconomic inputs such as the expected long-term rates of general inflation and real GDP growth. The current environment of high general inflation in Canada is resulting in short-term upward pressure on the cost of certain medical services covered by Hydro One's post-retirement and post-employment benefit plans. However, these effects are muted somewhat by plan design and government regulation. Based on this, Hydro One has adopted a modest increase of 25 basis points to its health care trend assumptions for the purpose of the December 31, 2022 disclosures. This adjustment aligns with the adjustment to the assumed long-term rate of cost of living increase being adopted at December 31, 2022.

DISCLOSURE CONTROLS AND PROCEDURES AND INTERNAL CONTROL OVER FINANCIAL REPORTING

Disclosure controls and procedures are the processes designed to ensure that information is recorded, processed, summarized and reported on a timely basis to the Company’s management, including its CEO and CFO, as appropriate, to make timely decisions regarding required disclosure in the MD&A and consolidated financial statements. At the direction of the Company’s CEO and CFO, management evaluated disclosure controls and procedures as of the end of the period covered by this report. Based on that evaluation, management concluded that the Company’s disclosure controls and procedures were effective as at December 31, 2022.

Internal control over financial reporting is designed by, or under the direction of the CEO and CFO to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with US GAAP. The Company’s internal control over financial reporting framework includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and disposition of the assets of the Company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of consolidated financial statements in accordance with US GAAP, and that receipts and expenditures of the Company are being made only in accordance with authorization of management and directors of the Company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of the Company’s assets that could have a material effect on the Company’s consolidated financial statements.

The Company’s management, at the direction of the CEO and CFO, evaluated the effectiveness of the design and operation of internal control over financial reporting based on the criteria established in the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). Based on that evaluation, management concluded that the Company’s internal control over financial reporting was effective as at December 31, 2022.

Internal controls, no matter how well designed and operated, can provide only reasonable assurance of achieving the desired control objectives and due to its inherent limitations, may not prevent or detect all misrepresentations. Furthermore, the effectiveness of internal control is affected by change and subject to the risk that internal control effectiveness may change over time.

There were no changes in the design of the Company’s internal control over financial reporting during the three months ended December 31, 2022 that have materially affected, or are reasonably likely to materially affect, the operation of the Company’s internal control over financial reporting.

Management will continue to monitor its systems of internal control over reporting and disclosure and may make modifications from time to time as considered necessary.


			31

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

NEW ACCOUNTING PRONOUNCEMENTS

The following tables present Accounting Standards Updates (ASUs) issued by the Financial Accounting Standards Board (FASB) that are applicable to Hydro One:

Recently Adopted Accounting Guidance

Guidance

Date issued

Description

Effective date

Impact on Hydro One

ASU 2020-06

August 2020

January 1, 2022

No impact upon adoption

ASU
2021-05

July 2021

The amendments are intended to align lease classification requirements for lessors under Topic 842 with Topic 840's practice.

January 1, 2022

No impact upon adoption

ASU 2021-10

November 2021

The update addresses diversity on the recognition, measurement, presentation and disclosure of government assistance received by business entities.

January 1, 2022

No impact upon adoption

Recently Issued Accounting Guidance Not Yet Adopted

Guidance

Date issued

Description

Effective date

Anticipated Impact on Hydro One

ASU
2021-08

October 2021

The amendments address how to determine whether a contractual obligation represents a liability to be recognized by the acquirer in a business combination.

January 1, 2023

No expected impact upon adoption

ASU 2022-02

March 2022

January 1, 2023

Upon adoption, the Company will disclose the current period gross write-offs by year of origination relating to its accounts receivable


			32

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

SUMMARY OF FOURTH QUARTER RESULTS OF OPERATIONS


Three months ended December 31 (millions of dollars, except EPS)	2022	2021	Change
Revenues
Distribution	1,370	1,347	1.7	%
Transmission	481	421	14.3	%
	1,851	1,768	4.7	%

Costs
Purchased power	895	914	(2.1	%)
OM&A
Distribution	223	163	36.8	%
Transmission	148	107	38.3	%
Other	8	3	166.7	%
	379	273	38.8	%

Depreciation, amortization and asset removal costs	229	244	(6.1	%)
	1,503	1,431	5.0	%

Income before financing charges and income tax expense	348	337	3.3	%
Financing charges	125	122	2.5	%

Income before income tax expense	223	215	3.7	%
Income tax expense	41	54	(24.1	%)
Net income	182	161	13.0	%

Net income to common shareholder of Hydro One	181	159	13.8	%

Basic and Diluted EPS	$1,273	$1,118	13.9	%

Assets Placed In-Service
Distribution	326	257	26.8	%
Transmission	761	526	44.7	%
	1,087	783	38.8	%

Capital Investments
Distribution	253	218	16.1	%
Transmission	310	303	2.3	%
	563	521	8.1	%

Net Income

Net income attributable to common shareholder for the quarter ended December 31, 2022 of $181 million is an increase of $22 million, or 13.8%, from the prior year. Significant influences on net income included:

•higher revenues, net of purchased power,7 primarily resulting from:

•an increase in transmission and distribution OEB-approved 2022 rates; and

•positive regulatory adjustments, including the recognition of CDM revenues following the receipt of the JRAP Decision and a lower deferred adjustment as a result of the Earnings Sharing Mechanism in 2022.

•higher OM&A costs primarily resulting from:

•higher work program expenditures including stations and lines maintenance, environmental management, IT initiatives and storm restoration; and

•higher corporate support costs.

•lower depreciation, amortization and asset removal costs primarily resulting from a gain realized on the sale of surplus property, partially offset by higher depreciation resulting from the growth in capital assets as the Company continues to place new assets in-service, consistent with its ongoing capital investment program, and higher asset removal costs.

7 Revenues, net of purchased power, is a non-GAAP financial measure. See section "Non-GAAP Financial Measures."


			33

HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

•lower income tax expense primarily resulting from:

•higher deductible timing differences compared to the prior year; partially offset by

•higher pre-tax earnings.

Revenues

The year-over-year increase of $60 million or 14.3% in transmission revenues during the quarter was primarily due to the following:

•positive regulatory adjustments, including the recognition of CDM revenues following receipt of the JRAP Decision, partially offset by a deferred adjustment associated with the OEB-approved Earnings Sharing Mechanism; and

•higher revenues resulting from OEB-approved 2022 rates; partially offset by

•a regulatory adjustment associated with the Capitalized Overhead Tax Variance and an adjustment to transmission revenue requirement effective January 1, 2022 to cease sharing of DTA amounts pursuant to the DTA Implementation Decision, the net impact of which is offset by a decrease in income tax and therefore net income neutral.

The year-over-year increase of $23 million or 1.7% in distribution revenues during the quarter was primarily due to the following:

•higher revenues resulting from OEB-approved 2022 rates; and

•positive regulatory adjustments including a lower adjustment to the Earnings Sharing Mechanism in 2022; partially offset by

•lower purchased power costs, which are fully recovered from ratepayers and are thus net income neutral; and

•a regulatory adjustment associated with the Capitalized Overhead Tax Variance and an adjustment to base distribution rates effective January 1, 2022 to cease sharing of DTA amounts pursuant to the DTA Implementation Decision, the net impact of which is offset by a decrease in income tax and therefore net income neutral.

Distribution revenues, net of purchased power,8 increased by 9.7% during the fourth quarter of 2022 compared to the prior year, primarily due to the reasons noted above, adjusted for the recovery of purchased power costs.

OM&A Costs

The year-over-year increase of $41 million or 38.3% in transmission OM&A costs during the quarter was primarily due to the following:

•higher work program expenditures, including higher volume of maintenance work on stations, as well as higher spend on lines and facilities;

•higher corporate support costs; and

•higher property taxes; partially offset by

•lower project write-offs.

The year-over-year increase of $60 million or 36.8% in distribution OM&A costs during the quarter was primarily due to the following:

•higher work program expenditures, including higher volume of emergency restoration and environmental management as well as higher spend associated with IT initiatives and customer programs;

•higher corporate support costs;

•higher project write-offs; and

•costs related to storm restoration efforts that have been recovered from third parties and are offset in revenue, therefore net income neutral.

Depreciation, Amortization and Asset Removal Costs

The decrease of $15 million or (6.1%), in depreciation, amortization and asset removal costs in the fourth quarter of 2022 was primarily due to a gain realized on the sale of surplus property, partially offset by higher depreciation resulting from the growth in capital assets as the Company continues to place new assets in-service, consistent with its ongoing capital investment program, and higher asset removal costs.

Financing Charges

The $3 million or 2.5% increase in financing charges for the quarter ended December 31, 2022, was primarily due to higher weighted-average interest rates on short-term notes, partially offset by gains on interest rate swap agreements.

8 Revenues, net of purchased power, is a non-GAAP financial measure. See section "Non-GAAP Financial Measures."


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HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

Income Taxes

Income tax expense for the fourth quarter of 2022 decreased by $13 million compared to the same period in 2021. This resulted in a realized effective tax rate of approximately 18.4% in the fourth quarter of 2022, compared to approximately 25.1% in the fourth quarter of the prior year.

The decrease in income tax expense for the three months ended December 31, 2022 was primarily attributable to:

•higher deductible timing differences compared to the prior year; and

•net income neutral items, including incremental tax recovery relating to the Capitalized Overhead Tax Variance which was partially offset by the tax expense relating to the DTA Implementation Decision. This decrease in tax expense is offset by a corresponding decrease in revenue and therefore net income neutral; partially offset by

•higher earnings adjusted for the DTA Implementation Decision and impacts of the JRAP Decision.

Assets Placed In-Service

The increase in transmission assets placed in-service during the fourth quarter was primarily due to the following:

•substantial completion of the end-of-life air blast circuit breakers replacement at Bruce B Switching Station;

•higher investments associated with customer connections placed in-service;

•timing of investments placed in-service for information technology initiatives; and

•higher volume of transmission line refurbishments and replacements; partially offset by

•timing of investments placed in-service for major development projects.

The increase in distribution assets placed in-service during the fourth quarter was primarily due to the following:

•partial in-service of South Middle Road feeder development project;

•higher volume of storm-related asset replacements;

•timing of investments placed in-service for information technology initiatives; and

•higher volume of assets placed in-service associated with customer connections; partially offset by

•lower volume of line refurbishments and replacements.

Capital Investments

The increase in transmission capital investments during the fourth quarter was primarily due to the following:

•higher volume of refurbishment and replacement work on transmission stations and lines; and

•higher volume of work on wood poles; partially offset by

•lower volume of work on customer connections.

The increase in distribution capital investments during the fourth quarter was primarily due to the following:

•higher spend on storm-related asset replacements; and

•higher volume of work on customer connections.


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HYDRO ONE INC.

MANAGEMENT’S DISCUSSION AND ANALYSIS (continued)

For the years ended December 31, 2022 and 2021

FORWARD-LOOKING STATEMENTS AND INFORMATION

The Company’s oral and written public communications, including this document, often contain forward-looking statements that are based on current expectations, estimates, forecasts and projections about the Company’s business, the industry, regulatory and economic environments in which it operates, and includes beliefs and assumptions made by the management of the Company. Such statements include, but are not limited to, statements regarding: the Company’s and Hydro One Remotes' transmission and distribution rate applications including the JRAP and its proposed investment plan, resulting and related decisions including the DTA Implementation Decision, as well as resulting rates, recovery and expected impacts and timing; expected timing of the Company's update to its transmission and distribution revenue requirements; expected timing for a decision in respect of Hydro One Remotes’ price cap incentive rate application; expectations about the Company’s liquidity and capital resources and operational requirements; the Operating Credit Facilities; expectations regarding the Company’s financing activities; the Company’s maturing debt; the Company’s ongoing and planned projects, initiatives and expected capital investments, including expected results, costs and in-service and completion dates; contractual obligations and other commercial commitments; collective bargaining and agreements and expectations regarding the ability to negotiate renewal collective agreements; Equity Partnership Model with First Nation communities; Bill 257 and Bill 93, related regulations and the expected timing and impacts; future pension contributions; non-GAAP financial measures; internal controls over financial reporting and disclosure; recent accounting-related guidance and anticipated impacts; and the MTN Program. Words such as “expect”, “anticipate”, “intend”, “attempt”, “may”, “plan”, “will”, “would”, “believe”, “seek”, “estimate”, “goal”, “aim”, “target”, and variations of such words and similar expressions are intended to identify such forward-looking statements. These statements are not guarantees of future performance and involve assumptions and risks and uncertainties that are difficult to predict. Therefore, actual outcomes and results may differ materially from what is expressed, implied or forecasted in such forward-looking statements. Hydro One does not intend, and it disclaims any obligation, to update any forward-looking statements, except as required by law.

These forward-looking statements are based on a variety of factors and assumptions including, but not limited to, the following: the scope of the COVID-19 pandemic and duration thereof as well as the effect and severity of corporate and other mitigation measures on the Company’s operations, supply chain or employees; no unforeseen changes in the legislative and operating framework for Ontario’s electricity market or for Hydro One specifically; favourable decisions from the OEB and other regulatory bodies concerning outstanding and future rate and other applications; no unexpected delays in obtaining the required approvals; no unforeseen changes in rate orders or rate setting methodologies for the Company’s distribution and transmission businesses; no unfavourable changes in environmental regulation; continued use of US GAAP; a stable regulatory environment; no significant changes to the Company's current credit ratings; no unforeseen impacts of new accounting pronouncements; no changes to expectations regarding electricity consumption; no unforeseen changes to economic and market conditions; recoverability of costs and expenses related to the COVID-19 pandemic, including the costs of customer defaults resulting from the pandemic; completion of operating and capital projects that have been deferred; and no significant event occurring outside the ordinary course of business. These assumptions are based on information currently available to the Company, including information obtained from third-party sources. Actual results may differ materially from those predicted by such forward-looking statements. While Hydro One does not know what impact any of these differences may have, the Company’s business, results of operations, financial condition and credit stability may be materially adversely affected if any such differences occur. Factors that could cause actual results or outcomes to differ materially from the results expressed or implied by forward-looking statements include, among other things:

•the risk that the Company may be unable to comply with regulatory and legislative requirements or that the Company may incur additional costs for compliance that are not recoverable through rates;


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