Exhibit 99.1

ANNUAL INFORMATION FORM

FOR THE YEAR ENDED DECEMBER 31, 2020

February 11, 2021

ANNUAL INFORMATION FORM

For the year ended December 31, 2020

Dated February 11, 2021

TABLE OF CONTENTS
Forward-Looking Information	2	Sustainability	24
Glossary	3	Social and Environmental Policies	25
Corporate Structure	5	Sustainability Regulation and Environmental
Name and Incorporation	5	Contingencies	26
Inter-Corporate Relationships	5	Capital Structure and Dividends	26
General Development of the Business	6	Description of Capital Structure	26
Overview	6	Dividends and Distributions	26
Three-Year History	6	Debt Covenant Restrictions on Dividend
Outlook	7	Distributions	27
Description of the Business	8	Credit Ratings	28
Regulated Utilities	9	Directors and Officers	30
ITC	9	Audit Committee	32
UNS Energy	12	Members	32
Central Hudson	14	Education and Experience	32
FortisBC Energy	15	Pre-Approval Policies and Procedures	33
FortisAlberta	17	External Auditor Service Fees	33
FortisBC Electric	18	Transfer Agent and Registrar	33
Other Electric	19	Interests of Experts	34
Non-Regulated	22	Additional Information	34
Energy Infrastructure	22	Exhibit A: Summary of Terms and Conditions
Corporate and Other	22	of Authorized Securities	35
Human Resources	23	Exhibit B: Market for Securities	38
Legal Proceedings and Regulatory Actions	23	Exhibit C: Audit Committee Mandate	40
Risk Factors	24	Exhibit D: Material Contracts	48

Financial information in this AIF has been prepared in accordance with US GAAP and is presented in Canadian dollars ($) based, as applicable, on the following US-to-Canadian dollar exchange rates: (i) average of 1.34 and 1.33 for the years ended December 31, 2020 and 2019, respectively; (ii) 1.27 and 1.30 as at December 31, 2020 and 2019, respectively; and (iii) 1.32 for all forecast periods.

Except as otherwise expressly noted, the information in this AIF is given as of December 31, 2020.

ANNUAL INFORMATION FORM 1 December 31, 2020

FORWARD-LOOKING INFORMATION

Fortis includes forward-looking information in this AIF within the meaning of applicable Canadian securities laws and forward-looking statements within the meaning of the U.S. Private Securities Litigation Reform Act of 1995 (collectively referred to as "forward-looking information"). Forward-looking information reflects expectations of Fortis management regarding future growth, results of operations, performance, business prospects and opportunities. Wherever possible, words such as anticipates, believes, budgets, could, estimates, expects, forecasts, intends, may, might, plans, projects, schedule, should, target, will, would and the negative of these terms and other similar terminology or expressions have been used to identify the forward-looking information, which includes, without limitation: forecast capital expenditures for 2021-2025; the 2035 carbon emissions reduction target; forecast rate base for 2023 and 2025; additional opportunities beyond the capital plan; the expectation that long-term growth in rate base will support earnings and dividend growth; target average annual dividend growth through 2025;the expectation that future increases in energy supply costs will increase electricity rates that Newfoundland Power charges to its customers; TEP's carbon emissions reduction target and projected asset mix; and FortisBC's 2030 GHG emission target and renewable gas target.

Forward‑looking information involves significant risks, uncertainties and assumptions. Certain material factors or assumptions have been applied in drawing the conclusions contained in the forward-looking information, including, without limitation: no material adverse effects from the COVID-19 pandemic; reasonable regulatory decisions and the expectation of regulatory stability; the successful execution of the capital plan; no material capital project or financing cost overrun; sufficient human resources to deliver service and execute the capital plan; no significant variability in interest rates; the Board exercising its discretion to declare dividends, taking into account the business performance and financial conditions of the Corporation; no significant operational disruptions or environmental liability or upset; the continued ability to maintain the performance of the electricity and gas systems; no severe and prolonged economic downturn; sufficient liquidity and capital resources; the ability to hedge exposures to fluctuations in foreign exchange rates, natural gas prices and electricity prices; the continued availability of natural gas, fuel, coal and electricity supply; continuation of power supply and capacity purchase contracts; no significant changes in government energy plans, environmental laws and regulations that could have a material negative impact; maintenance of adequate insurance coverage; the ability to obtain and maintain licences and permits; retention of existing service areas; no significant changes in tax laws and the continued tax deferred treatment of earnings from the Corporation's foreign operations; continued maintenance of information technology infrastructure and no material breach of cybersecurity; continued favourable relations with Indigenous Peoples; and favourable labour relations.

Fortis cautions readers that a number of factors could cause actual results, performance or achievements to differ materially from those discussed or implied in the forward-looking information. These factors should be considered carefully and undue reliance should not be placed on the forward-looking information. Risk factors which could cause results or events to differ from current expectations are detailed in the MD&A under the heading "Business Risks" and in other continuous disclosure materials filed from time to time with Canadian securities regulatory authorities and the Securities and Exchange Commission.

All forward-looking information in this AIF is given as of the date of this AIF. Fortis disclaims any intention or obligation to update or revise any forward-looking information, whether as a result of new information, future events or otherwise.

ANNUAL INFORMATION FORM 2 December 31, 2020

GLOSSARY

Certain terms used in this 2020 Annual Information Form are defined below:

2020 Annual Information Form or AIF: this annual information form of the Corporation in respect of the year ended December 31, 2020

ACGS: Aitken Creek Gas Storage ULC

Aitken Creek: Aitken Creek natural gas storage facility

Algoma Power: Algoma Power Inc.

APS: Arizona Public Service Company

AUC: Alberta Utilities Commission

BC Hydro: BC Hydro and Power Authority

BCUC: British Columbia Utilities Commission

BECOL: Belize Electric Company Limited

Belize Electricity: Belize Electricity Limited

Board: Board of Directors of the Corporation

Canadian Niagara Power: Canadian Niagara Power Inc.

CUPE: Canadian Union of Public Employees

Caribbean Utilities: Caribbean Utilities Company, Ltd.

CBT: Columbia Basin Trust

Central Hudson: Central Hudson Gas & Electric Corporation

CMS: Consumers Energy Company

Cornwall Electric: Cornwall Street Railway, Light and Power Company, Limited

Corporation: Fortis Inc.

CPA: Canal Plant Agreement

CPC: Columbia Power Corporation

DBRS Morningstar: DBRS Limited

DTE: DTE Electric Company

EDGAR: SEC's system for Electronic Data Gathering, Analysis and Retrieval available at www.sec.gov

Eiffel Investment: Eiffel Investment Pte Ltd.

FERC: Federal Energy Regulatory Commission

FHI: FortisBC Holdings Inc.

Financial Statements: the Corporation's Audited Consolidated Financial Statements in respect of the year ended December 31, 2020

Fitch: Fitch Ratings Inc.

Fortis: Fortis Inc.

FortisAlberta: FortisAlberta Inc.

FortisBC Electric: collectively, the operations of FortisBC Inc. and its parent company, FortisBC Pacific Holdings Inc.

FortisBC Energy: FortisBC Energy Inc.

FortisOntario: FortisOntario Inc.

FortisTCI: collectively, FortisTCI Limited and Turks and Caicos Utilities Limited

FortisUS: FortisUS Inc.

FortisUS Holdings: FortisUS Holdings Nova Scotia Limited

FortisWest: FortisWest Inc.

GHG: greenhouse gas

GIC: GIC Private Limited

GSMIP: Gas Supply Mitigation Incentive Plan of FortisBC Energy

IBEW: International Brotherhood of Electrical Workers

IESO: Independent Electricity System Operator of Ontario

IPL: Interstate Power and Light Company

ITC: ITC Holdings together with all of its subsidiaries

ITC Great Plains: ITC Great Plains, LLC

ITC Holdings: ITC Holdings Corp.

ANNUAL INFORMATION FORM 3 December 31, 2020

ITC Interconnection: ITC Interconnection LLC

ITC Investment Holdings: ITC Investment Holdings Inc.

ITC Midwest: ITC Midwest LLC

ITC's MISO Regulated Operating Subsidiaries: collectively ITCTransmission, METC and ITC Midwest

ITC's Regulated Operating Subsidiaries: collectively, ITCTransmission, METC, ITC Midwest, ITC Great Plains and ITC Interconnection

ITCTransmission: International Transmission Company

LNG: liquefied natural gas

Maritime Electric: Maritime Electric Company, Limited

MD&A: the Corporation's Management Discussion and Analysis in respect of the year ended December 31, 2020

METC: Michigan Electric Transmission Company

MISO: Midcontinent Independent System Operator, Inc.

Moody's: Moody's Investors Service, Inc.

MoveUP: Movement of United Professionals

NB Power: New Brunswick Power Corporation

Newfoundland Power: Newfoundland Power Inc.

NL Hydro: Newfoundland and Labrador Hydro Corporation

NYPSC: New York Public Service Commission

NYSE: New York Stock Exchange

PEI: the province of Prince Edward Island, Canada

PNM: Public Service Company of New Mexico

PPA: power purchase agreement

PUB: Newfoundland and Labrador Board of Commissioners of Public Utilities

PWU: Power Workers' Union

ROE: return on common equity

S&P: Standard & Poor's Financial Services LLC

SEC: United States Securities and Exchange Commission

SEDAR: the System for Electronic Document Analysis and Retrieval of the Canadian Securities Administrators available at www.sedar.com

SPP: Southwest Power Pool, Inc.

SRP: Salt River Project Agricultural Improvement and Power District

T&D: transmission and distribution

TC Energy: TC Energy Corporation

TEP: Tucson Electric Power Company

TSX: Toronto Stock Exchange

UNS Electric and UNSE: UNS Electric, Inc.

UNS Energy: UNS Energy Corporation

UNS Gas: UNS Gas, Inc.

US: United States of America

US GAAP: accounting principles general accepted in the US

UUWA: United Utility Workers' Association of Canada

Waneta Expansion: 335-MW Waneta Expansion hydroelectric generating facility

Wataynikaneyap Partnership: Wataynikaneyap Power Limited Partnership

Measurements:

GW    Gigawatt(s)

GWh    Gigawatt hour(s)

km    Kilometre(s)

MW    Megawatt(s)

TJ    Terajoule(s)

PJ    Petajoule(s)

Conversions:

1 litre = 0.22 imperial gallons

1 kilometre = 0.62 miles

Conversion using the above factors on rounded numbers appearing in this AIF may produce small differences from reported amounts as a result.

ANNUAL INFORMATION FORM 4 December 31, 2020

CORPORATE STRUCTURE

Name and Incorporation

Fortis Inc. is a holding company that was incorporated as 81800 Canada Ltd. under the Canada Business Corporations Act on June 28, 1977 and continued under the Corporations Act (Newfoundland and Labrador) on August 28, 1987. The corporate head office and registered office of Fortis is located at Fortis Place, Suite 1100, 5 Springdale Street, P.O. Box 8837, St. John's, Newfoundland and Labrador, Canada, A1B 3T2.

The articles of continuance of the Corporation were amended to: (i) change its name to Fortis on October 13, 1987; (ii) set out the rights, privileges, restrictions and conditions attached to the common shares on October 15, 1987; (iii) designate 2,000,000 First Preference Shares, Series A on September 11, 1990; (iv) replace the class rights, privileges, restrictions and conditions attaching to the First Preference Shares and the Second Preference Shares on July 22, 1991; (v) designate 2,000,000 First Preference Shares, Series B on December 13, 1995; (vi) designate 5,000,000 First Preference Shares, Series C on May 27, 2003; (vii) designate 8,000,000 First Preference Shares, Series D and First Preference Shares, Series E on January 23, 2004; (viii) amend the redemption provisions attaching to the First Preference Shares, Series D on July 15, 2005; (ix) designate 5,000,000 First Preference Shares, Series F on September 22, 2006; (x) designate 9,200,000 First Preference Shares, Series G on May 20, 2008; (xi) designate 10,000,000 First Preference Shares, Series H and 10,000,000 First Preference Shares, Series I on January 20, 2010; (xii) designate 8,000,000 First Preference Shares, Series J on November 8, 2012; (xiii) designate 12,000,000 First Preference Shares, Series K and 12,000,000 First Preference Shares, Series L on July 11, 2013; and; (xiv) designate 24,000,000 First Preference Shares, Series M and 24,000,000 First Preference Shares, Series N on September 16, 2014.

Inter-Corporate Relationships

The following table lists the principal subsidiaries of the Corporation, their jurisdictions of incorporation and the percentage of votes attaching to voting securities held directly or indirectly by the Corporation as at February 11, 2021. The principal subsidiaries together comprise approximately 89% of the Corporation's consolidated assets as at December 31, 2020 and approximately 86% of the Corporation's 2020 consolidated revenue. This table excludes certain subsidiaries, the assets and revenues of which did not individually exceed 10%, or in the aggregate exceed 20%, of the total consolidated assets or total consolidated revenues of the Corporation as at December 31, 2020.

Subsidiary	Jurisdiction of Incorporation	Votes attaching to voting securities beneficially owned, controlled or directed by the Corporation (%)
ITC (1)	Michigan, United States	80.1
UNS Energy (2)	Arizona, United States	100
Central Hudson (3)	New York, United States	100
FortisBC Energy (4)	British Columbia, Canada	100
FortisAlberta (5)	Alberta, Canada	100
Newfoundland Power (6)	Newfoundland and Labrador, Canada	100

(1)ITC Holdings, a Michigan corporation, owns all of the shares of ITC Great Plains, ITC Interconnection, ITC Midwest, ITCTransmission and METC. ITC Investment Holdings, a Michigan corporation, owns all of the shares of ITC Holdings. FortisUS, a Delaware corporation, owns 80.1% of the voting securities of ITC Investment Holdings. FortisUS Holdings, a Canadian corporation, owns all of the shares of FortisUS. Fortis owns all of the shares of FortisUS Holdings. 19.9% of the voting securities of ITC Investment Holdings are owned by an affiliate of GIC.

(2)UNS Energy owns all of the shares of TEP, UNS Electric and UNS Gas. FortisUS owns all of the shares of UNS Energy.

(3)CH Energy Group, Inc., a New York corporation, owns all of the shares of Central Hudson. FortisUS owns all of the shares of CH Energy Group, Inc.

(4)FHI, a British Columbia corporation, owns all of the shares of FortisBC Energy. Fortis owns all of the shares of FHI.

(5)FortisAlberta Holdings Inc., an Alberta corporation, owns all of the shares of FortisAlberta. FortisWest, a Canadian corporation, owns all of the shares of FortisAlberta Holdings Inc. Fortis owns all of the shares of FortisWest.

(6)Fortis owns all of the shares of Newfoundland Power.

ANNUAL INFORMATION FORM 5 December 31, 2020

GENERAL DEVELOPMENT OF THE BUSINESS

Overview

Fortis is a well-diversified leader in the North American regulated electric and gas utility industry, with 2020 revenue of $8.9 billion and total assets of $55 billion as at December 31, 2020.

Regulated utilities account for 99% of the Corporation's assets with the remainder primarily attributable to non-regulated energy infrastructure. The Corporation's 9,000 employees serve 3.3 million utility customers in five Canadian provinces, nine US states and three Caribbean countries. As at December 31, 2020, 66% of the Corporation's assets were located outside Canada and 59% of 2020 revenue was derived from foreign operations.

Three-Year History

Over the past three years, Fortis has experienced significant growth in its business operations. Total assets have increased from $47.8 billion at the start of 2018 to $55.5 billion as at December 31, 2020. The Corporation's shareholders' equity has also grown from $16.7 billion at the start of 2018 to $20.3 billion as at December 31, 2020. Net earnings attributable to common equity shareholders have increased from $1,100 million in 2018 to $1,209 million in 2020.

The growth in business operations reflects the Corporation's organic growth strategy for its principal regulated utilities.

2018

In 2018 the Corporation deployed capital expenditures of $3.2 billion at its utilities and announced an ambitious utility capital plan of $17.3 billion for the period 2019 to 2023, an increase of 20% over the prior year's plan. The increase in annual earnings for 2018 was driven by growth at both the regulated and non-regulated businesses, as well as lower income tax expense primarily related to a one-time expense in 2017 associated with US tax reform, along with the positive tax impacts of electing to file a consolidated state tax return and designating assets as "held for sale" in 2018.

2019

In January 2019 Fortis announced that it entered into a definitive agreement with CBT and CPC to sell its 51% interest in the Waneta Expansion for approximately $1 billion. The transaction closed in April 2019. The sale of the Corporation's interest in the Waneta Expansion completed the asset sale portion of the Corporation's capital funding strategy.

In September 2019 Fortis announced its five-year capital plan of $18.8 billion for the period 2020 to 2024. The Corporation deployed capital expenditures of $3.8 billion at its utilities in 2019.

2020

Fortis performed well as it navigated through the global COVID-19 pandemic throughout 2020. Approximately half of the Corporation's employees transitioned to working from home while field operation employees adapted to work safely to maintain the Corporation's critical infrastructure and continue to deliver essential energy to customers.

In September 2020 the Corporation announced a five-year capital plan of $19.6 billion for the period 2021 to 2025. This plan represents an increase in $800 million from the prior year's plan. The capital plan focuses on a diverse mix of low-risk, highly executable projects needed to maintain and upgrade our existing infrastructure to expand capacity, improve reliability and support a cleaner energy future.

Also in September 2020 the Corporation announced it is building on its low emissions profile by establishing a corporate-wide target to reduce carbon emissions by 75% by 2035 from a 2019 base year. Fortis expects to achieve the target through delivering on planned carbon emissions reductions at TEP as well as clean energy initiatives across the Corporation's other utilities. For details on the Corporation's carbon emissions reduction target, refer to the "Sustainability" section of this AIF.

ANNUAL INFORMATION FORM 6 December 31, 2020

Barry V. Perry, President and Chief Executive Officer of Fortis, retired from Fortis at the end of 2020 after a nearly 35-year career, over 20 of which were with Fortis. David G. Hutchens, formerly Chief Operating Officer of Fortis and Chief Executive Officer of UNS Energy, was appointed as Mr. Perry's successor and a member of the Board effective January 1, 2021.

In addition to the efforts across the Fortis group to control costs during the pandemic, the Corporation's utilities have regulatory mechanisms that help stabilize cash flow and earnings which support the continued delivery of reliable service. Approximately 83% of the Corporation's revenues are either protected by regulatory mechanisms or are derived from residential sales which have generally increased as a result of work-from-home practices.

Excluding the impact of the delay in TEP's general rate application, the COVID-19 pandemic did not have a material impact on the Corporation's capital expenditures, revenue or earnings in 2020. The financial impact to Fortis approximated $0.05 per common share, reflecting reduced sales in the Caribbean and higher net operational expenses, including an increase in credit loss expense, largely at Central Hudson and UNS Energy.

Net earnings attributable to common equity shareholders for 2020 were $1,209 million compared to $1,655 million for 2019. The decrease included (i) a $484 million gain on the disposition of the Waneta Expansion in April 2019; and (ii) the $56 million net impact associated with the reversal of prior period liabilities as a result of the November 2019 and May 2020 FERC decisions at ITC.

The Corporation executed its largest capital plan on record in 2020, with consolidated capital expenditures of $4.2 billion. Despite adjustments to work practices and the necessary rescheduling of certain field work due to the COVID-19 pandemic, work remained on track and the Corporation delivered its strongest safety results in its history.

Over the past three years, including 2020, consolidated capital expenditures totalled $11.2 billion. Organic asset growth has been driven by capital expenditures at the Corporation's regulated utilities.

Outlook

The Corporation maintains its positive long-term outlook. Fortis continues to enhance shareholder value through the execution of its capital plan, the balance and strength of its diversified portfolio of utility businesses, and growth opportunities within and proximate to its service territories. While uncertainty exists due to the COVID-19 pandemic, the Corporation does not currently expect it to have a material financial impact in 2021.

The Corporation's $19.6 billion five-year capital plan is expected to increase rate base from $30.5 billion in 2020 to $36.4 billion by 2023 and $40.3 billion by 2025, translating into three- and five-year compound annual growth rates of approximately 6.5% and 6.0%, respectively. Beyond the five-year capital plan, Fortis continues to pursue additional energy infrastructure opportunities, including: further expansion of LNG infrastructure in British Columbia; the fully permitted, cross-border, Lake Erie Connector electric transmission project in Ontario; and the acceleration of cleaner energy infrastructure investments across our jurisdictions.

Fortis expects long-term growth in rate base will support earnings and dividend growth. Fortis is targeting average annual dividend growth of approximately 6% through 2025.

ANNUAL INFORMATION FORM 7 December 31, 2020

DESCRIPTION OF THE BUSINESS

Fortis is principally an energy delivery company, with 93% of its assets related to transmission and distribution. The business is characterized by low-risk, stable and predictable earnings and cash flows. Earnings, earnings per share and total shareholder return are the primary measures of financial performance.

The Corporation's regulated utility businesses are: ITC (electric transmission - Michigan, Iowa, Minnesota, Illinois, Missouri, Kansas and Oklahoma); UNS Energy (integrated electric and natural gas distribution - Arizona); Central Hudson (electric transmission and distribution, and natural gas distribution - New York); FortisBC Energy (natural gas transmission and distribution - British Columbia); FortisAlberta (electric distribution - Alberta); FortisBC Electric (integrated electric - British Columbia); Newfoundland Power (integrated electric - Newfoundland and Labrador); Maritime Electric (integrated electric - Prince Edward Island); FortisOntario (integrated electric - Ontario); Caribbean Utilities (integrated electric - Grand Cayman); and FortisTCI (integrated electric - Turks and Caicos Islands). Fortis also holds equity investments in the Wataynikaneyap Partnership (electric transmission - Ontario) and Belize Electricity (integrated electric - Belize).

Non-regulated energy infrastructure consists of Aitken Creek (natural gas storage facility - British Columbia), BECOL (three hydroelectric generation facilities with a combined capacity of 51 MW - Belize) and the Waneta Expansion up to its disposition in April 2019.

Fortis has a unique operating model with a small head office in St. John's, Newfoundland and Labrador and business units that operate on a substantially autonomous basis. Each utility has its own management team and most have a board of directors with a majority of independent members, which provides effective oversight within the broad parameters of Fortis policies and best practices. Subsidiary autonomy supports constructive relationships with regulators, policy makers, customers and communities. Fortis believes this model enhances accountability, opportunity and performance across the Corporation's businesses, and positions Fortis well for future investment opportunities.

Fortis strives to provide safe, reliable and cost-effective energy service to customers using sustainable practices while delivering long-term profitable growth to shareholders. Management is focused on achieving growth through the execution of its capital plan and the pursuit of investment opportunities within and proximate to its service territories.

Competition

Most of the Corporation's regulated utilities operate as the sole supplier of electricity and/or gas within their respective service territories. Competition in the regulated electric business is primarily from alternative energy sources and on-site generation by industrial customers. The Corporation faces competition in its transmission business which may restrict its ability to grow this business outside of its established service territories.

At the Corporation's regulated gas utilities, natural gas primarily competes with electricity for space and hot water heating load. In addition to other price comparisons, upfront capital cost differences between electric and natural gas equipment for hot water and space heating applications continue to present challenges for the competitiveness of natural gas on a fully costed basis. Government policy could also impact the competitiveness of natural gas in the Corporation's service territories. The British Columbia provincial government has introduced changes to energy policy, including GHG emission reduction targets and a tax on carbon-based fuels which is expected to increase in the future. As all levels of government become more active in the development of policies to address climate change, any resultant changes to energy policy may have a material impact on the competitiveness of natural gas relative to non-carbon based energy sources or other energy sources.

Seasonality

As the Corporation's subsidiaries operate in various jurisdictions throughout North America, seasonality impacts each utility differently. Most of the annual earnings of the Corporation's gas utilities are realized in the first and fourth quarters due to space heating requirements in colder weather. Earnings for electric utilities in the US are generally highest in the second and third quarters due to the use of air conditioning and other cooling equipment in the summer.

ANNUAL INFORMATION FORM 8 December 31, 2020

Summary of Operations

The following table and sections describe the Corporation's operations and reportable segments.

		Customers	Peak Demand(1)		Electric T&D Lines (circuit km)	Gas T&D Lines (km)	Generating Capacity (MW)	Revenue ($ millions)	GWh Sales	Gas Volumes(PJ)	Employees
Regulated Utilities
ITC		—	23,364	MW	25,800	—	—	1,744	—	—	699
UNS Energy		694,000	3,309	MW	22,700	5,100	3,233	2,260	16,763	15	2,057
			107	TJ
Central Hudson		380,000	1,142	MW	15,100	2,400	65	953	4,969	23	1,061
			121	TJ
FortisBC Energy		1,048,000	1,555	TJ	—	49,500	—	1,385	—	219	1,954
FortisAlberta		572,000	2,770	MW	91,000	—	—	596	16,092	—	1,085
FortisBC Electric		182,000	740	MW	7,300	—	225	424	3,291	—	560
Other Electric
	Newfoundland Power	270,000	1,356	MW	12,500	—	143	717	5,729	—	613
	Maritime Electric	84,000	287	MW	6,300	—	130	219	1,293	—	200
	FortisOntario	67,000	258	MW	3,500	—	5	225	1,289	—	213
	Caribbean Utilities	31,000	109	MW	800	—	161	243	644	—	228
	FortisTCI	15,000	40	MW	700	—	91	81	220	—	168
Non-Regulated
Energy Infrastructure		—	—		—	—	51	88	229	—	68
Corporate and Other		—	—		—	—	—	—	—	—	55
Total		3,343,000	33,375	MW	185,700	57,000	4,104	8,935	50,519	257	8,961
			1,783	TJ

(1)Electric (MW) or gas (TJ)

Regulated Utilities

ITC

ITC's business consists mainly of the electric transmission operations. ITC's Regulated Operating Subsidiaries own and operate high-voltage electric transmission systems in Michigan's Lower Peninsula and portions of Iowa, Minnesota, Illinois, Missouri, Kansas and Oklahoma that transmit electricity from generating stations to local distribution facilities connected to ITC's transmission systems. ITC's business strategy is to own, operate, maintain and invest in transmission infrastructure in order to enhance system integrity and reliability, reduce transmission constraints and support new generating resources interconnecting to ITC's transmission system.

ITC's Regulated Operating Subsidiaries earn revenues from the use of their transmission systems by customers, including investor-owned utilities, municipalities, cooperatives, power marketers and alternative energy suppliers. As independent transmission companies, ITC's Regulated Operating Subsidiaries are subject to rate regulation by FERC. The rates charged are established using cost-based formula rates.

ITC's principal transmission service customers are DTE, CMS and IPL. One or more of these customers together have consistently represented a significant percentage of ITC's operating revenue. Nearly all of ITC's revenues are from transmission customers in the US.

Market and Sales

Revenues

Revenue was $1,744 million in 2020 compared to $1,761 million in 2019.

ANNUAL INFORMATION FORM 9 December 31, 2020

ITC derives nearly all of its revenues from transmission, scheduling, control and dispatch services and other related services over ITC's Regulated Operating Subsidiaries' transmission systems to DTE, CMS, IPL and other entities, such as alternative energy suppliers, power marketers and other wholesale customers that provide electricity to end-use customers, as well as from transaction-based capacity reservations on ITC's transmission systems. MISO and SPP are responsible for billing and collecting the majority of transmission service revenues. As the billing agents for ITC's MISO Regulated Operating Subsidiaries and ITC Great Plains, MISO and SPP collect fees for the use of ITC's transmission systems, invoicing DTE, CMS, IPL and other customers on a monthly basis.

The following table compares the composition of ITC's 2020 and 2019 revenue by customer class.

	Revenue (%)
	2020	2019
Network revenues	65.6	63.0
Regional cost-sharing revenues	27.9	27.9
Point-to-point	1.0	1.0
Scheduling, control and dispatch	1.6	1.3
Recognition of ROE complaint liabilities (1)	2.4	5.2
Other	1.5	1.6
Total	100.0	100.0

(1)Adjustments have been made to the refund liability recorded related to the complaint proceedings on the MISO base rate of return on equity, which resulted in increases in operating revenues for the periods presented.

Network revenues are generated from network customers for their use of ITC's electric transmission systems and are based on the actual revenue requirements as a result of ITC's accounting under its cost-based formula rates that contain a true-up mechanism.

Network revenues from ITC Great Plains include the annual revenue requirements specific to projects that are charged exclusively within one pricing zone within SPP or are classified as direct assigned network upgrades under the SPP tariff and contain a true-up mechanism.

Regional cost-sharing revenues are generated from transmission customers for their use of ITC's MISO Regulated Operating Subsidiaries' network upgrade projects that are eligible for regional cost-sharing under provisions of the MISO tariff, including multi-value projects, which have been determined by MISO to have regional value while meeting near-term needs. Additionally, certain projects at ITC Great Plains are eligible for recovery through a region-wide charge under provisions of the SPP tariff. Regional cost sharing revenues are treated as a revenue credit to regional or network customers and is a reduction to gross revenue requirement when calculating net revenue requirement under ITC's cost-based formula rates.

Point-to-point revenues consist of revenues generated from a type of transmission service for which the customer pays for transmission capacity reserved along a specified path between two points on an hourly, daily, weekly or monthly basis. Point-to-point revenues also include other components pursuant to schedules under the MISO and SPP tariffs. Point-to-point revenues are treated as a revenue credit to network or regional customers and are a reduction to gross revenue requirement when calculating net revenue requirement under ITC's cost-based formula rates.

Scheduling, control and dispatch revenues are allocated to ITC's MISO Regulated Operating Subsidiaries by MISO as compensation for the services performed in operating the transmission system. Such services include monitoring of reliability data, current and next-day analysis, implementation of emergency procedures and outage coordination and switching.

Other revenuesconsist of rental revenues, easement revenues, revenues relating to utilization of jointly-owned assets under ITC's transmission ownership and operating agreements and amounts from providing ancillary services to customers. The majority of other revenues are treated as a revenue credit and taken as a reduction to gross revenue requirements when calculating the net revenue requirement under ITC's cost-based formula rates.

ANNUAL INFORMATION FORM 10 December 31, 2020

Contracts

ITCTransmission

DTE operates an electric distribution system that is interconnected with ITCTransmission's transmission system. A set of three operating contracts sets forth the terms and conditions related to DTE's and ITCTransmission's ongoing working relationship. These contracts include:

Master Operating Agreement - governs the primary day-to-day operational responsibilities of ITCTransmission and DTE. It identifies the control area coordination services that ITCTransmission is obligated to provide to DTE and certain generation-based support services that DTE is required to provide to ITCTransmission.

Generator Interconnection and Operation Agreement - established, re-established and maintains the direct electricity interconnection of DTE's electricity generating assets with ITCTransmission's transmission system for the purposes of transmitting electric power from and to the electricity generating facilities.

Coordination and Interconnection Agreement - governs the rights, obligations and responsibilities of ITCTransmission and DTE regarding, among other things, the operation and interconnection of DTE's distribution system and ITCTransmission's transmission system, and the construction of new facilities or modification of existing facilities. Additionally, this agreement allocates costs for operation of supervisory, communications and metering equipment.

METC

CMS operates an electric distribution system that interconnects with METC's transmission system. METC is a party to a number of operating contracts with CMS that govern the operations and maintenance of its transmission system. These contracts include:

Amended and Restated Easement Agreement - CMS provides METC with an easement to the land on which a majority of METC's transmission towers, poles, lines and other transmission facilities, used to transmit electricity for CMS and others, are located. METC pays CMS a nominal annual rent for the easement and also pays for any rentals, property taxes and other fees related to the property covered by the agreement.

Amended and Restated Operating Agreement - METC is responsible for maintaining and operating its transmission system, providing CMS with information and access to its transmission system and related books and records, administering and performing the duties of control area operator (that is, the entity exercising operational control over the transmission system) and, if requested by CMS, building connection facilities necessary to permit interaction with new distribution facilities built by CMS.

Amended and Restated Purchase and Sale Agreement for Ancillary Services - Since METC does not own any generating facilities, it must procure ancillary services from third-party suppliers, such as CMS. Currently, under this agreement, METC pays CMS for providing certain generation-based services necessary to support the reliable operation of the bulk power grid, such as voltage support and generation capability and capacity to balance loads and generation.

Amended and Restated Distribution-Transmission Interconnection Agreement - provides for the interconnection of CMS's distribution system with METC's transmission system and defines the continuing rights, responsibilities and obligations of the parties with respect to the use of certain of their own and the other parties' property, assets and facilities.

Amended and Restated Generator Interconnection Agreement - specifies the terms and conditions under which CMS and METC maintain the interconnection of CMS's generation resources and METC's transmission assets.

ANNUAL INFORMATION FORM 11 December 31, 2020

ITC Midwest

IPL operates an electric distribution system that interconnects with ITC Midwest's transmission system. ITC Midwest is a party to a number of operating contracts with IPL that govern the operations and maintenance of its transmission system. These contracts include:

Distribution-Transmission Interconnection Agreement - governs the rights, responsibilities and obligations of ITC Midwest and IPL, with respect to the use of certain of their own and the other party's property, assets and facilities and the construction of new facilities or modification of existing facilities.

Large Generator Interconnection Agreement - ITC Midwest, IPL and MISO entered into this agreement in order to establish, re-establish and maintain the direct electricity interconnection of IPL's electricity generating assets with ITC Midwest's transmission system for the purposes of transmitting electric power from and to the electricity generating facilities.

UNS Energy

UNS Energy is a vertically integrated utility services holding company, headquartered in Tucson, Arizona. It is engaged through its subsidiaries in the regulated electric generation and energy delivery business, primarily in the State of Arizona, serving approximately 694,000 electricity and gas customers. UNS Energy primarily consists of three wholly owned regulated utilities: TEP, UNS Electric and UNS Gas.

TEP, UNS Energy's largest operating subsidiary, is a vertically integrated regulated electric utility that generates, transmits and distributes electricity. TEP serves approximately 433,000 retail customers in a territory comprising approximately 2,991 square km in southeastern Arizona, including the greater Tucson metropolitan area in Pima County, as well as parts of Cochise County. TEP's service area covers a population of over one million people. TEP also sells wholesale electricity to other entities in the western US.

UNS Electric is a vertically integrated regulated electric utility that generates, transmits and distributes electricity to approximately 98,000 retail customers in Arizona's Mohave and Santa Cruz counties.

TEP and UNS Electric own generation resources with an aggregate capacity of 3,233 MW, including 54 MW of solar capacity. Several of the generating assets in which TEP and UNS Electric have an interest are jointly owned. As at December 31, 2020, approximately 33% of the generating capacity was fuelled by coal.

UNS Gas is a regulated gas distribution utility that serves approximately 163,000 retail customers in Arizona's Mohave, Yavapai, Coconino, Navajo and Santa Cruz counties.

Market and Sales

UNS Energy's electricity sales were 16,763 GWh in 2020, compared to 18,354 GWh in 2019. Gas volumes were 15 PJ in 2020 compared to 16 PJ in 2019. Revenue was $2,260 million in 2020, compared to $2,212 million in 2019.

The following table provides the composition of UNS Energy's 2020 and 2019 revenue, electricity sales, and gas volumes by customer class.

	Revenue (%)		GWh Sales (%)		PJ Volumes (%)
	2020	2019	2020	2019	2020	2019
Residential	40.9	36.5	30.9	25.0	57.3	57.9
Commercial	20.9	21.2	16.1	15.1	22.1	23.4
Industrial	13.8	13.8	18.0	16.6	1.9	2.0
Other (1)	24.4	28.5	35.0	43.3	18.7	16.7
Total	100.0	100.0	100.0	100.0	100.0	100.0

(1)Includes electricity sales and gas volumes to other entities for resale and revenue from sources other than from the sale of electricity and gas

ANNUAL INFORMATION FORM 12 December 31, 2020

Power Supply

TEP meets the electricity supply requirements of its retail and wholesale customers with its owned electrical generating capacity of 2,932 and its T&D system consisting of approximately 16,000 km of line. In 2020 TEP met a peak demand of 2,812 MW, which includes firm sales to wholesale customers. TEP is a member of a regional reserve-sharing organization and has reliability and power sharing relationships with other utilities.

TEP's generating capacity is set forth in the following table.

Generation Source	Unit No.	Location	Date in Service	Total Capacity (MW)	Operating Agent	TEP's Share (%)	TEP's Share (MW)
Coal
Springerville Station	1	Springerville, AZ	1985	387	TEP	100.0	387
Springerville Station (1)	2	Springerville, AZ	1990	406	TEP	100.0	406
San Juan Station	1	Farmington, NM	1976	340	PNM	50.0	170
Four Corners Station	4	Farmington, NM	1969	785	APS	7.0	55
Four Corners Station	5	Farmington, NM	1970	785	APS	7.0	55
Natural Gas
Gila River Power Station	2	Gila Bend, AZ	2003	550	SRP	100.0	550
Gila River Power Station (2)	3	Gila Bend, AZ	2003	550	SRP	75.0	413
Luna Generating Station	1	Deming, NM	2006	555	PNM	33.3	185
Sundt Station	3	Tucson, AZ	1962	104	TEP	100.0	104
Sundt Station	4	Tucson, AZ	1967	156	TEP	100.0	156
Sundt Internal Combustion Turbines		Tucson, AZ	1972-1973	50	TEP	100.0	50
Sundt Reciprocating Internal Combustion Engine (3)	1-10	Tucson, AZ	2019-2020	188	TEP	100.0	188
DeMoss Petrie	N/A	Tucson, AZ	2001	75	TEP	100.0	75
North Loop	N/A	Tucson, AZ	2001	96	TEP	100.0	96
Solar
Utility-Scale Renewables (4)		Various	2002-2017	42	TEP	100.0	42
Total Capacity							2,932

(1)Springerville Generating Station Unit 2 is owned by San Carlos Resources Inc., a wholly owned subsidiary of TEP.

(2)TEP owns 75% of Gila River Unit 3 and UNSE owns 25%.

(3)TEP placed in service five natural gas reciprocating internal combustion engine units in December 2019 and an additional five units in March 2020.

(4)In September 2020, Sundt Areva Solar Thermal, with a nominal capacity of 5 MW, was retired.

UNS Electric meets the electricity supply requirements of its retail customers with its owned electrical generating capacity of 302 MW and purchasing power on the wholesale market, and its T&D system consisting of approximately 7,000 km of line. In 2020 UNS Electric met a peak demand of 497 MW.

ANNUAL INFORMATION FORM 13 December 31, 2020

UNS Electric's generating capacity is set forth in the following table.

Generation Source	Unit No.	Location	Date In Service	Resource Type	Total Capacity (MW)	Operating Agent	UNSE's Share (%)	UNSE's Share (MW)
Black Mountain	1	Kingman, AZ	2011	Gas	45	UNSE	100.0	45
Black Mountain	2	Kingman, AZ	2011	Gas	45	UNSE	100.0	45
Valencia	1	Nogales, AZ	1989	Gas/Oil	14	UNSE	100.0	14
Valencia	2	Nogales, AZ	1989	Gas/Oil	14	UNSE	100.0	14
Valencia	3	Nogales, AZ	1989	Gas/Oil	14	UNSE	100.0	14
Valencia	4	Nogales, AZ	2006	Gas/Oil	21	UNSE	100.0	21
Gila River Power Station	3	Gila Bend, AZ	2003	Gas	550	SRP	25.0	137
Utility-Scale Renewables	N/A	Various	2011 -2017	Solar	12	UNSE	100.0	12
Total Capacity								302

Owned Utility-Scale Renewable Resources

TEP owns 42 MW of photovoltaic solar generation capacity and has 260 MW of renewable resources under development that are expected to be placed into service in 2021. The Oso Grande Wind Project will add approximately 250 MW of wind-powered electric generation and Raptor Ridge will add 10 MW of solar-powered electric generation. UNS Electric owns 12 MW of photovoltaic solar generation capacity.

Renewable Power Purchase Agreements

TEP has renewable PPAs of 156 MW from solar resources and 80 MW from wind resources. The solar PPAs contain options that allow TEP to purchase all or part of the related project at a future date. Wilmot Solar is under development and will add 100 MW from solar resources to TEP's capacity, accompanied by 30 MW of energy storage. Wilmot Solar is expected to be placed into service in 2021. Borderlands Wind is under development and will add 99 MW from wind resources and is expected to be placed into service in 2021. UNS Electric has renewable PPAs of 83 MW from solar resources and 10 MW from wind resources.

Gas Purchases

TEP and UNS Gas directly manage their gas supply and transportation contracts. The price for gas varies based on market conditions, which include weather, supply balance, economic growth rates and other factors. TEP and UNS Gas hedge their gas supply prices by entering into fixed-price forward contracts, collars, and financial swaps from time to time, up to three years in advance, with a view to hedging at least 70-90% of expected monthly energy volumes prior to the beginning of each month.

Central Hudson

Central Hudson is a regulated electric and gas T&D utility serving approximately 300,000 electricity customers and 80,000 natural gas customers in portions of New York State's Mid-Hudson River Valley. Central Hudson serves a territory comprising approximately 6,700 square km in the Hudson Valley. Electric service is available throughout the territory, and natural gas service is provided in and around the cities of Poughkeepsie, Beacon, Newburgh, and Kingston, New York, and in certain outlying and intervening territories.

Central Hudson's electric T&D system consists of approximately 15,100 circuit km of line and met a peak demand of 1,142 MW in 2020.

Central Hudson's natural gas system consists of approximately 2,400 km of T&D pipelines and met a peak day demand of 121 TJ in 2020.

ANNUAL INFORMATION FORM 14 December 31, 2020

Market and Sales

Central Hudson's electricity sales were 4,969 GWh in 2020, compared to 4,963 GWh in 2019. Natural gas sales volumes in 2020 were 23 PJ, compared to 22 PJ in 2019. Revenue was $953 million in 2020, compared to $917 million in 2019.

The following table compares the composition of Central Hudson's 2020 and 2019 revenue, electricity sales and gas volumes by customer class.

	Revenue (%)		GWh Sales (%)		PJ Volumes (%)
	2020	2019	2020	2019	2020	2019
Residential	63.3	62.5	44.6	41.4	25.5	28.8
Commercial	26.9	27.8	35.9	38.9	34.1	38.8
Industrial	4.3	3.9	17.9	18.1	14.2	16.9
Other (1)	5.5	5.8	1.6	1.6	26.2	15.5
Total	100.0	100.0	100.0	100.0	100.0	100.0

(1)Includes sales for resale

Power Supply

Central Hudson relies on purchased capacity and energy from third-party providers, together with its own minimal generating capacity, to meet the demands of its full-service customers.

Central Hudson is obligated to supply electricity to its retail electric customers. Central Hudson, the staff of the NYPSC and others entered into a settlement agreement in 1998 with respect to the auction of fossil fuel generation plants owned by Central Hudson. Under the settlement agreement, Central Hudson's retail customers may elect to procure electricity from third‑party suppliers or may continue to rely on Central Hudson. As part of its requirement to supply customers who continue to rely on Central Hudson for their energy supply, Central Hudson entered into a 10-year revenue sharing agreement with Constellation Energy Group, Inc. in 2011, pursuant to which Central Hudson shares in a portion of the power sales revenue attributable to Unit No. 2 of the Nine Mile Point Nuclear Generating Station.

Costs of electric and natural gas commodity purchases are recovered from customers, without earning a profit on these costs. Rates are reset monthly based on Central Hudson's actual costs to purchase the electricity and natural gas needed to serve its full-service customers.

FortisBC Energy

FortisBC Energy is the largest distributor of natural gas in British Columbia, serving approximately 1,048,000 customers in more than 135 communities. FortisBC Energy provides T&D services to customers, and obtains natural gas supplies on behalf of most of its residential, commercial and industrial customers. FortisBC Energy owns and operates approximately 49,500 km of natural gas pipelines and met a peak demand of 1,555 TJ in 2020.

Market and Sales

FortisBC Energy's natural gas sales volumes were 219 PJ in 2020, compared to 227 PJ in 2019. Revenue was $1,385 million in 2020 compared to $1,331 million in 2019.

ANNUAL INFORMATION FORM 15 December 31, 2020

The following table compares the composition of FortisBC Energy's 2020 and 2019 revenue and natural gas volumes by customer class.

	Revenue (%)		PJ Volumes (%)
	2020	2019	2020	2019
Residential	57.4	57.7	37.2	35.7
Commercial	28.7	28.6	24.6	22.9
Industrial	6.7	4.3	7.8	4.4
Other (1)	7.2	9.4	30.4	37.0
Total	100.0	100.0	100.0	100.0

(1)Includes revenue and gas volumes from transportation customers

Gas Purchase Agreements

To ensure supply of adequate resources for reliable natural gas deliveries to its customers, FortisBC Energy purchases natural gas supply from counterparties, including producers, aggregators and marketers. FortisBC Energy contracts for approximately 184 PJ of baseload and seasonal supply, of which the majority is sourced in northeast British Columbia and transported on Westcoast Energy Inc.'s T‑South pipeline system. The remainder is sourced in Alberta and transported on TC Energy's pipeline transportation system.

FortisBC Energy procures and delivers natural gas directly to core market customers. Transportation customers are responsible to procure and deliver their own natural gas to the FortisBC Energy system and FortisBC Energy then delivers the gas to the operating premises of these customers. FortisBC Energy contracts for transportation capacity on third-party pipelines, such as the T‑South pipeline and the TC Energy pipeline, to transport gas supply from various market hubs to FortisBC Energy's system. These third-party pipelines are regulated by the Canada Energy Regulator. FortisBC Energy pays both fixed and variable charges for the use of transportation capacity on these pipelines, which are recovered through rates paid by FortisBC Energy's core market customers. FortisBC Energy contracts for firm transportation capacity to ensure it is able to meet its obligation to supply customers within its broad operating region under all reasonable demand scenarios.

Gas Storage and Peak Shaving Arrangements

FortisBC Energy incorporates peak shaving and gas storage facilities into its portfolio to: (i) supplement contracted baseload and seasonal gas supply in the winter months, while injecting excess baseload supply to refill storage in the summer months; (ii) mitigate the risk of supply shortages during cooler weather and peak demand; (iii) manage the cost of gas during the winter months; and (iv) balance daily supply and demand on the distribution system during periods of peak use that occur during the winter months.

FortisBC Energy holds approximately 36 PJs of total storage capacity. FortisBC Energy owns Tilbury and Mount Hayes LNG peak shaving facilities, which provide on-system storage capacity and deliverability. FortisBC Energy also contracts for underground storage capacity and deliverability from parties in northeast British Columbia, Alberta and the Pacific Northwest of the US. On a combined basis, FortisBC Energy's Tilbury and Mount Hayes facilities, the contracted storage facilities, and other peaking arrangements can deliver up to 0.85 PJs per day of supply to FortisBC Energy on the coldest days of the heating season. The heating season typically occurs during the period from December to February.

Mitigation Activities

FortisBC Energy engages in off-system sales activities that allow for the recovery or mitigation of costs of any unutilized supply and/or pipeline and storage capacity that is available once customers' daily load requirements are met.

Under the GSMIP revenue sharing model, which is approved by the BCUC, FortisBC Energy can earn an incentive payment for mitigation activities. Historically, FortisBC Energy has earned approximately $1.8 million annually through GSMIP, while the remaining savings are credited back to customers through reduced rates. Subject to the BCUC's approval, FortisBC Energy earned an incentive payment of approximately $1.5 million for the gas contract year ending October 31, 2020.

ANNUAL INFORMATION FORM 16 December 31, 2020

The current GSMIP program was approved by the BCUC following a comprehensive review in 2011. The BCUC has approved extensions of the program through October 31, 2022.

Price-Risk Management Plan

FortisBC Energy engages in price-risk management activities to mitigate the impact on customer rates of fluctuations in natural gas prices. These activities include: (i) physical gas purchasing and storage strategies; (ii) current quarterly commodity rate-setting and a deferral account mechanism; and (iii) the use of derivative instruments, which were implemented pursuant to a price-risk management plan approved by the BCUC, as discussed below.

In May 2020 FortisBC Energy filed its Winter 2020-2021 Sumas Risk Mitigation Application with the BCUC to implement Sumas hedging strategies for the 2020-2021 winter season to mitigate the impact of price spikes and sustained elevated prices at the Sumas market hub. The BCUC approved the application in July 2020 and the hedging strategies were implemented in July and August 2020.

Unbundling

A Customer Choice program at FortisBC Energy allows eligible commercial and residential customers to buy their natural gas commodity supply from FortisBC Energy or from third-party marketers. FortisBC Energy continues to provide the delivery service of the natural gas to all its customers. For the year ended December 31, 2020, approximately 5% of eligible commercial customers and 3% of eligible residential customers purchased their commodity supply from alternate providers.

FortisAlberta

FortisAlberta is a regulated electricity distribution utility operating in Alberta. Its business is the ownership and operation of electric distribution facilities that distribute electricity, generated by other market participants, from high-voltage transmission substations to end-use customers. FortisAlberta is not involved in the generation, transmission or direct retail sale of electricity. FortisAlberta operates the electricity distribution system in a substantial portion of southern and central Alberta around and between the cities of Edmonton and Calgary, totalling approximately 91,000 circuit km of distribution lines. FortisAlberta's distribution network serves approximately 572,000 customers and met a peak demand of 2,770 MW in 2020.

Market and Sales

FortisAlberta's annual energy deliveries were 16,092 GWh in 2020 compared to 16,887 GWh in 2019. Revenue was $596 million in 2020 compared to $598 million in 2019.

The following table compares the composition of FortisAlberta's 2020 and 2019 revenue and energy deliveries by customer class.

	Revenue (%)		GWh Deliveries (%) (1)
	2020	2019	2020	2019
Residential	43.5	42.6	29.3	27.3
Commercial	24.3	24.7	13.3	13.8
Industrial	20.0	21.2	57.4	58.9
Other (2)	12.2	11.5	—	—
Total	100.0	100.0	100.0	100.0

(1)GWh percentages exclude FortisAlberta's GWh deliveries to "transmission-connected" customers. These deliveries were 6,932 GWh in 2020 and 6,940 GWh in 2019, based on an interim settlement that is expected to be finalized in May 2021, and consisted primarily of energy deliveries to large-scale industrial customers directly connected to the transmission grid.

(2)Includes rate riders, deferrals and adjustments.

ANNUAL INFORMATION FORM 17 December 31, 2020

Franchise Agreements

FortisAlberta serves customers in various municipalities throughout its service area. From time to time, municipal governments in Alberta consider creating their own electric distribution utilities by purchasing the assets of FortisAlberta located within their municipal boundaries. Upon the termination of a franchise agreement, a municipality has the right, subject to AUC approval, to purchase FortisAlberta's assets within its municipal boundaries pursuant to the Municipal Government Act (Alberta), with the price to be determined on the basis of a methodology approved by the AUC. Additionally, under the Hydro and Electric Energy Act (Alberta), if a municipality that owns an electric distribution system expands its boundaries, it can acquire FortisAlberta's assets in the annexed area. In such circumstances, the Hydro and Electric Energy Act (Alberta) provides that the AUC may determine that the municipality should compensate FortisAlberta for any facilities transferred on the basis of replacement cost less depreciation. Given the historical population and economic growth of Alberta and its municipalities, FortisAlberta is affected by transactions of this type from time to time.

FortisAlberta holds franchise agreements with 163 municipalities within its service area. The franchise agreements include 10‑year terms with an option to renew for up to two subsequent five-year terms. Over 99% of FortisAlberta's franchise agreements were entered into in 2012 and subsequent years, pursuant to which the initial terms will not expire until the end of 2022 and beyond, with notices to extend the current agreement to be provided one year in advance of expiry.

FortisBC Electric

FortisBC Electric is an integrated regulated electric utility that owns hydroelectric generating plants, high voltage transmission lines and a large network of distribution assets located in the southern interior of British Columbia. FortisBC Electric serves approximately 182,000 customers and met a peak demand of 740 MW in 2020. FortisBC Electric's T&D assets include approximately 7,300 circuit km of T&D lines.

FortisBC Electric is also responsible for operation, maintenance and management services at the 493‑MW Waneta hydroelectric generating facility owned by BC Hydro and the 335‑MW Waneta Expansion, the 149-MW Brilliant hydroelectric plant, the 120‑MW Brilliant hydroelectric expansion plant and the 185-MW Arrow Lakes generating station, all ultimately owned by CBT and CPC.

Market and Sales

Electricity sales were 3,291 GWh in 2020, compared to 3,326 GWh in 2019. Revenue was $424 million in 2020, compared to $418 million in 2019.

The following table compares the composition of FortisBC Electric's 2020 and 2019 revenue and electricity sales by customer class.

	Revenue (%)		GWh Sales (%)
	2020	2019	2020	2019
Residential	50.5	48.9	40.5	38.8
Commercial	27.1	27.1	29.4	29.4
Industrial	12.6	13.2	17.0	17.6
Other (1)	9.8	10.8	13.1	14.2
Total	100.0	100.0	100.0	100.0

(1)Includes revenue and GWh sales from wholesale customers

Generation and Power Supply

FortisBC Electric meets the electricity supply requirements of its customers through a mix of its own generation and PPAs. FortisBC Electric owns four regulated hydroelectric generating plants on the Kootenay River with an aggregate capacity of 225 MW, which provide approximately 45% of its energy needs and 30% of its peak capacity needs. FortisBC Electric meets the balance of its requirements through a portfolio of long-term and short-term PPAs.

ANNUAL INFORMATION FORM 18 December 31, 2020

FortisBC Electric's four hydroelectric generating facilities are governed by the multi‑party CPA that enables the five separate owners of nine major hydroelectric generating plants, with a combined capacity of approximately 1,900 MW and located in relatively close proximity to each other, to coordinate the operation and dispatch of their generating plants.

The following table lists the plants and their respective capacity and owner.

Plant	Capacity (MW)	Owners
Canal Plant	580	BC Hydro
Waneta Dam	493	BC Hydro
Waneta Expansion	335	Waneta Expansion Power Corporation
Kootenay River System	225	FortisBC Electric
Brilliant Dam	149	Brilliant Power Corporation
Brilliant Expansion	120	Brilliant Expansion Power Corporation
Total	1,902

Brilliant Power Corporation, Brilliant Expansion Power Corporation, Teck Metals Ltd., Waneta Expansion Power Corporation and FortisBC Electric are collectively defined in the CPA as the entitlement parties. The CPA enables BC Hydro and the entitlement parties to generate more power from their respective generating plants than they could if they operated independently through coordinated use of water flows, subject to the 1961 Columbia River Treaty between Canada and the US, and coordinated operation of storage reservoirs and generating plants. Under the CPA, BC Hydro takes into its system all power actually generated by the plants listed in the table above. In exchange for permitting BC Hydro to determine the output of these facilities, each of the entitlement parties is contractually entitled to a fixed annual entitlement of capacity and energy from BC Hydro, which is based on 50-year historical water flows and the plants' generating capabilities. The entitlement parties receive their defined entitlements irrespective of actual water flows to the entitlement parties' generating plants. BC Hydro enjoys the benefits of the additional power generated through coordinated operation and optimal use of water flows. The entitlement parties benefit by knowing years in advance the amount of power that they will receive from their generating plants and, therefore, do not face hydrology variability in generation supply planning. However, FortisBC Electric retains rights to its original water licences and flows in perpetuity. Should the CPA be terminated, the output of FortisBC Electric's Kootenay River system plants would, with the water and storage authorized under its existing licences and on a long‑term average, be approximately the same power output as FortisBC Electric receives under the CPA. The CPA does not affect FortisBC Electric's ownership of its physical generation assets. The CPA continues in force until terminated by any of the parties by giving no less than five years' notice at any time on or after December 31, 2030.

FortisBC Electric's remaining electricity supply is acquired primarily through long-term PPAs with a number of counterparties, including the Brilliant PPA, the BC Hydro PPA and the Waneta Expansion Capacity Agreement. Additionally, FortisBC Electric purchases capacity and energy from the market to meet its peak energy requirements and optimize its overall power supply portfolio. These market purchases provided approximately 10% of FortisBC Electric's energy supply requirements in 2020. FortisBC Electric's PPAs and market purchases have been accepted by the BCUC and prudently incurred costs thereunder flow through to customers through FortisBC Electric's electricity rates.

Other Electric

Other Electric consists of utilities in eastern Canada and the Caribbean as follows: Newfoundland Power; Maritime Electric; FortisOntario; a 39% equity investment in Wataynikaneyap Partnership; an approximate 60% controlling interest in Caribbean Utilities; FortisTCI; and a 33% equity investment in Belize Electricity.

Newfoundland Power is an integrated regulated electric utility and the principal distributor of electricity on the island portion of Newfoundland and Labrador. Maritime Electric is an integrated regulated electric utility and the principal distributor of electricity on PEI. FortisOntario primarily provides integrated electric utility service through its three regulated operating utilities with its customer base primarily in Fort Erie, Cornwall, Gananoque, Port Colborne and the District of Algoma in Ontario.

ANNUAL INFORMATION FORM 19 December 31, 2020

The Wataynikaneyap Partnership has a mandate of connecting 17 remote First Nations Communities in Northwestern Ontario to the electricity grid. The partnership is equally owned by 24 First Nations communities (51%), in partnership with FortisOntario (39%) and Algonquin Power & Utilities Corp. (10%). FortisOntario is responsible for construction, management and operation of the transmission line. Construction began on the project in 2019 and the first transmission tower was erected and substation ground grid installed in the third quarter of 2020. The project is on track for completion by the end of 2023.

Caribbean Utilities is an integrated regulated electric utility and the sole provider of electricity on Grand Cayman, Cayman Islands. FortisTCI is an integrated regulated electric utility on the Turks and Caicos Islands. Belize Electricity is an integrated electric utility and the principal distributor of electricity in Belize. Belize Electricity is excluded from the discussion of this segment as Fortis holds a 33% minority interest in this entity.

The following table sets out the customers, installed generating capacity, peak demand and kilometers of T&D lines for the segment.

	Customers	Peak Demand (MW)	T&D Lines (circuit km)	Generating Capacity (MW)	Resource Type(s)
Newfoundland Power	270,000	1,356	12,500	143	Hydroelectric, Gas, Diesel
Maritime Electric	84,000	287	6,300	130	Thermal, Diesel
FortisOntario (1)	67,000	258	3,500	5	Natural Gas Cogeneration
Caribbean Utilities (2)	31,000	109	800	161	Diesel
FortisTCI	15,000	40	700	91	Diesel
Total	467,000	2,050	23,800	530

(1)    FortisOntario also owns a 10% interest in certain regional electric distribution companies serving approximately 40,000 customers.

(2)    Includes 24 km of high-voltage submarine cable

Market and Sales

Electricity sales attributable to Other Electric were 9,175 GWh in 2020, compared to 9,366 GWh in 2019. Revenue was $1,485 million in 2020, compared to $1,467 million in 2019.

The following table compares the composition of revenue and electricity sales by customer class for Other Electric in 2020 and 2019.

	Revenue (%)		GWh Sales (%)
	2020	2019	2020	2019
Residential	58.7	56.0	57.3	55.4
Commercial	37.4	40.1	39.1	41.2
Industrial	1.9	1.9	2.7	2.6
Other (1)	2.0	2.0	0.9	0.8
Total	100.0	100.0	100.0	100.0

(1)    Includes revenue from sources other than from the sale of electricity

Power Supply

Newfoundland Power

Approximately 93% of Newfoundland Power's energy requirements are purchased from NL Hydro with the remaining 7% generated by Newfoundland Power generating facilities. The principal terms of the supply arrangements with NL Hydro are regulated by the PUB on a basis similar to that upon which Newfoundland Power's service to its customers is regulated.

ANNUAL INFORMATION FORM 20 December 31, 2020

NL Hydro charges Newfoundland Power for purchased power and includes charges for both demand and energy purchased. The demand charge is based on applying a rate to the peak‑billing demand for the most recent winter season. The energy charge is a two-block charge with a higher second‑block charge set to reflect NL Hydro's marginal cost of generating electricity.

The completion of Nalcor Energy's $13.1 billion Muskrat Falls hydroelectric generation development and associated transmission assets is further delayed and is now expected in September 2021. Energy from the Muskrat Falls project is expected to supply a significant portion of NL Hydro's electricity requirements, and in turn, Newfoundland Power's electricity requirements. Uncertainty remains regarding supply adequacy and reliability of the province of Newfoundland and Labrador's electrical system after commissioning. The amount and timing of any future wholesale electricity rate changes, including those associated with the Muskrat Falls project, are uncertain; however, future increases in supply costs from NL Hydro are expected to increase electricity rates that Newfoundland Power charges to its customers.

Maritime Electric

Maritime Electric is interconnected to the Province of New Brunswick via four provincially owned submarine cables with a total capacity of 560 MW. The company purchases its power supply requirements through various Energy Purchase Agreements from NB Power, a New Brunswick Crown corporation and renewable energy produced on PEI by facilities owned by the PEI Energy Corporation. Company-owned on-Island generation stations totalling 130 MW are used primarily for peaking, submarine-cable loading issues and emergency purposes.

Maritime Electric has the following contracts with NB Power: (i) an energy supply agreement covering the period March 1, 2019 to December 31, 2026; (ii) a transmission capacity contract allowing Maritime Electric to reserve 30 MW of capacity to PEI expiring November 2032; and (iii) an entitlement agreement for approximately 4.55% of the output from NB Power's Point Lepreau Nuclear Generating Station for the life of the unit. The company also has several renewable energy contracts with the PEI Energy Corporation for the purchase of energy for remaining periods ranging from two to 16 years.

As part of Maritime Electric's entitlement agreement for the Point Lepreau Nuclear Generating Station, it is required to pay its share of the capital and operating costs of the unit.

FortisOntario

The power requirements of FortisOntario's service territories are met through various sources. Canadian Niagara Power purchases its power requirements for Fort Erie and Port Colborne from IESO, purchases approximately 75% of energy requirements in the Gananoque region from Hydro One Networks Inc., and the remaining 25% from five hydroelectric generating plants owned by EO Generation LP. Algoma Power purchases its energy requirements primarily from IESO.

Under the Standard Supply Code of the Ontario Energy Board, Canadian Niagara Power and Algoma Power are obligated to provide Standard Service Supply to all its customers who do not choose to contract with an electricity retailer. This energy is provided to customers at either regulated or market prices.

Cornwall Electric purchases substantially all of its power requirements from Hydro-Québec Energy Marketing under a new contract that commenced in January 2020 and expires in December 2030. The new contract provides a minimum of 537 GWh of energy per year and up to 145 MW of capacity at any one time.

Caribbean Utilities

Caribbean Utilities relies upon in-house diesel-powered generation to produce electricity for its customers. Caribbean Utilities is party to primary and secondary fuel supply contracts with two different suppliers from whom it is committed to purchasing 60% and 40%, respectively, of its diesel fuel requirements for its diesel-powered generating plant. Caribbean Utilities executed two 24-month fuel supply contracts in June 2018 with the option to renew for two additional terms of 18 months at the end of each term. In June 2020 Caribbean Utilities exercised its option to renew for 18 months.

ANNUAL INFORMATION FORM 21 December 31, 2020

FortisTCI

FortisTCI relies upon in-house diesel-powered generation to produce electricity for its customers. FortisTCI has installed 1 MW of rooftop solar in partnership with nine commercial customers through its Utility Owned Renewable Energy Program. The company continues to engage with the Government of the Turks and Caicos Islands on the progress of the draft Electricity (Amendment) Bill, designed to enable the development of renewable energy within the country.

FortisTCI has contract with a major supplier for all of its diesel fuel requirements associated with the generation of electricity. The approximate fuel requirements under this contract are 64 million litres per annum.

Non-Regulated

Energy Infrastructure

The Corporation's Energy Infrastructure segment consists of a natural gas storage facility in British Columbia (Aitken Creek) and three hydroelectric generation facilities in Belize with a combined capacity of 51 MW held through the Corporation's subsidiary BECOL. In April 2019 Fortis sold its 51% ownership interest in long-term contracted generation assets in British Columbia, the Waneta Expansion.

Aitken Creek is the only underground natural gas storage facility in British Columbia with a total working gas capacity of 77 billion cubic feet. Fortis holds a 93.8% ownership interest in Aitken Creek through its subsidiary ACGS, acquired in 2016. ACGS contracts with third parties for both lease and park transactions and also holds its own proprietary capacity.

Generation assets in Belize consist of three hydroelectric generating facilities. All of the output of these facilities is sold to Belize Electricity under 50-year PPAs expiring in 2055 and 2060.

Market and Sales

Energy sales were 229 GWh in 2020, compared to 144 GWh in 2019. Revenue was $88 million in 2020, compared to $82 million in 2019.

Corporate and Other

The Corporate and Other segment captures expense and revenue items not specifically related to any reportable segment and those business operations that are below the required threshold for segmented reporting including net corporate expenses of Fortis.

ANNUAL INFORMATION FORM 22 December 31, 2020

HUMAN RESOURCES

Fortis and its subsidiaries have 8,961 employees, with 53% in Canada, 42% in the US and 5% in other countries. The following table provides the breakdown of employees by reportable segment.

	Employees	Participation in a Collective Agreement		Union(s)	Collective Agreement(s) Expiry Date(s)
Regulated Utilities
ITC	699	None		—	—
UNS Energy	2,057	50	%	IBEW	June 2021 – February 2025
Central Hudson	1,061	57	%	IBEW	March 2021 – April 2022
FortisBC Energy (1)	1,954	61	%	IBEW, MoveUP	March 2019 (2) – June 2023
FortisAlberta	1,085	79	%	UUWA	December 2020 (3)
FortisBC Electric	560	70	%	IBEW, MoveUP	January 2021 (4) – June 2023
Other Electric (5)	1,422	39	%	CUPE, IBEW, PWU	January 2022 – December 2023
Non-Regulated
Energy Infrastructure (6)	68	None		—	—
Corporate and Other (7)	55	None		—	—
Total	8,961	52	%

(1)Includes employees at FHI

(2)The collective agreement between FortisBC Energy and IBEW covering 565 FortisBC Energy employees expired on March 31, 2019 and is currently under renegotiation. Mediation was initiated in May 2020 and is ongoing. Operations have not been impacted to date.

(3)The collective agreement between FortisAlberta and the UUWA expired on December 31, 2020 and is currently under renegotiation.

(4)The collective agreement between FortisBC Electric and IBEW covering 192 FortisBC Electric employees expired on January 31, 2021 and is currently under renegotiation.

(5)Includes employees at Newfoundland Power, Maritime Electric, FortisOntario, Caribbean Utilities and FortisTCI. Excludes Belize Electricity.

(6)Includes employees at Aitken Creek (staffed by FortisBC Midstream Inc.), BECOL and FortisBC Alternative Energy Services Inc.

(7)Employees at Fortis Inc.

The Corporation's culture is built on safety, diversity and integrity. Fortis employees are driven to make good decisions, work hard and work safely. Fortis and its utilities respect their employees' freedom to associate and strive to maintain positive and constructive relationships with labour associations and unions.

The Corporation's subsidiaries are required to develop and retain skilled workforces for their operations. Many of the employees of the Corporation's utilities possess specialized skills and training and Fortis must compete in the marketplace for these workers. The Corporation's significant capital plan may present challenges to ensure its utilities have the qualified workforce necessary to complete the capital work initiatives.

LEGAL PROCEEDINGS AND REGULATORY ACTIONS

There are no legal proceedings that involve a claim for damages exceeding 10% of the Corporation's current assets in respect of which the Corporation is or was a party, or in respect of which any of the Corporation's property is or was the subject during the year ended December 31, 2020, nor are there any such proceedings known to the Corporation to be contemplated.

Information related to the Corporation's legal proceedings can be found in Note 28 of the Financial Statements, which are incorporated by reference in this AIF and available on SEDAR and EDGAR.

ANNUAL INFORMATION FORM 23 December 31, 2020

The Corporation's utilities operate under a cost of service regulation, in combination with performance-based rate-setting mechanisms in certain jurisdictions, and are regulated by the regulatory body in their respective operating jurisdiction. During the year ended December 31, 2020, there have not been any: (i) penalties or sanctions imposed against the Corporation by a court relating to securities legislation or by a securities regulatory authority; (ii) other penalties or sanctions imposed by a court or regulatory body against the Corporation that would likely be considered important to a reasonable investor in making an investment decision; or (iii) settlement agreements entered into by the Corporation before a court relating to securities legislation or with a securities regulatory authority.

For information with respect to the nature of regulation and material regulatory decisions and applications associated with each of the Corporation's utilities, refer to the "Regulatory Highlights" section of the MD&A and to Notes 2 and 8 of the Financial Statements, each of which are incorporated by reference in this AIF and available on SEDAR and EDGAR.

RISK FACTORS

For information with respect to the Corporation's business risks, refer to the "Business Risks" section of the MD&A, which is incorporated by reference in this AIF and available on SEDAR and EDGAR.

SUSTAINABILITY

Fortis is committed to being a strong energy partner for its communities by operating in an environmentally and socially responsible manner. The Corporation is focused on maintaining infrastructure to deliver energy more efficiently and to facilitate the delivery of cleaner energy. Fortis believes that responsible environmental and sustainability management not only creates business value, but it is also good for the planet and our customers.

To bring focus and accountability to sustainability, oversight has been integrated into each senior level of responsibility at Fortis. The Board is responsible for risk management oversight and ensuring that business is conducted to meet high standards of environmental and social responsibility. The Governance and Sustainability Committee of the Board is responsible for overseeing governance structure and sustainability practices, including reviewing programs designed to promote corporate citizenship and environmental and social responsibility. The Executive Vice President, Sustainability and Chief Human Resource Officer is responsible for enterprise-wide sustainability and stewardship. Local management teams and boards of directors at each of the Corporation's utilities are responsible for operational aspects of sustainability. Sustainability performance impacts how all Fortis executives are compensated.

Fortis is primarily an energy delivery company with 93% of its assets dedicated to this function. This focus on energy delivery presents a unique opportunity to facilitate the delivery of cleaner energy to customers and naturally limits our impact on the environment when compared with energy generation intensive businesses. Although Fortis has limited fossil-fuel generation exposure, the Corporation is committed to reducing carbon emissions and delivering more sustainable energy to our customers.

The Corporation's direct GHG emissions come primarily from its generation assets, including fossil fuel-based generation representing 5% of the Corporation's total assets. In September 2020 the Corporation announced it is building on its low emissions profile by establishing a corporate-wide target to reduce carbon emissions by 75% by 2035 from a 2019 base year. Fortis expects to achieve the target through delivering on TEP's goals to reduce carbon emissions, described below. TEP is the Corporation's primary owner of fossil fuel-based generation. Clean energy initiatives across the Corporation's other utilities will also contribute to achieving this goal.

TEP has set a target to reduce carbon emissions by 80% by 2035. Key elements of the plan include adding approximately 2,400 MW of new wind and solar power systems and 1,400 MW of energy storage systems. TEP also plans to exit coal generation by ramping down and ultimately retiring TEP's two units at the coal-fired Springerville Generating Station in 2027 and 2032. This timeline will allow TEP to reduce the plant's workforce through attrition while providing time for the company to help the local community minimize the impact of the units' retirement.

ANNUAL INFORMATION FORM 24 December 31, 2020

FortisBC Energy and FortisBC Electric have set a combined goal to reduce GHG emissions associated with customers' energy use by 30% by the year 2030. To achieve this objective, the utilities will focus on tripling investment in energy efficiency projects, increasing renewable natural gas supply and focusing on low and zero-carbon vehicles and transportation infrastructure. This overall GHG emission reduction target is supported by FortisBC Energy's aim to have 15% of its gas supply come from renewable sources by 2030.

The Corporation's environmental statement sets out its commitment to comply with all applicable laws and regulations relating to the protection of the environment, regularly conduct monitoring and audits of environmental management systems and seek feasible, cost-effective opportunities to decrease GHG emissions and increase renewable energy sources. The Fortis Sustainability Working Group, comprising key leaders from across the Fortis group of utilities, enables communication and sharing of information among the Corporation's utilities on sustainability performance, issues and opportunities. Each operating subsidiary has extensive environmental compliance programs aligned with the ISO 14001 standard, regularly reviews its environmental management systems and protocols, strives for continual performance improvement and sets and reviews its own environmental objectives, targets and programs. The Fortis Operating Group, a group of senior operational executives from all utilities, meets regularly to share best practices and identify opportunities for collaboration on a range of topics including environment, health and safety.

Social and Environmental Policies

The Corporation and its utilities each have a range of social and environmental policies, programs and practices. Fortis has a Code of Conduct which is guided by the Corporation's purpose and values and sets out standards for the ethical conduct of its business, applicable to all of its directors, officers and employees, and to the extent feasible also to its consultants, contractors and representatives. The core principles of the Fortis Code of Conduct apply universally across the organization, with each operating subsidiary adopting its own substantially similar Code. Fortis and its utilities hold regular Code of Conduct employee training; and all Fortis employees annually certify compliance.

The Code of Conduct is supported by other policies that outline the behaviour expected from management and employees, including the Anti-Corruption Policy and Respectful Workplace Policy. All Fortis operating subsidiaries have policies in place that uphold the Corporation's values as contained in these policies and demonstrate their commitment to ensuring equal opportunity and providing safe, respectful work environments.

Each Fortis operating subsidiary has a Whistleblower Policy to support the reporting of conduct that may breach the subsidiary's Code of Conduct or other workplace policies.

The Corporation's operating subsidiaries are also responsible for implementing policy frameworks that reflect their unique operations and jurisdictions, while addressing certain common priority areas, including: occupational health and safety; environmental stewardship; non-discrimination and equal opportunity in hiring and promotion; and support of local communities.

The Corporation's Board and Executive Diversity Policy describes the principles and objectives for diversity among the Board and executive leadership, including a commitment to maintaining a Board where at least one-third of its independent directors are represented by each gender. Currently, 40% of the Corporation's directors and 42% of its executive leadership team are female. 60% of Fortis utilities have either a female president or female board chair.

Advancing inclusion and diversity is a priority at Fortis. In 2019 the Corporation adopted a formal Inclusion and Diversity Commitment that applies to all employees at Fortis and its operating subsidiaries. The commitment is supported by a framework built upon three pillars - talent, culture and community. Within the framework each utility develops an action plan specific to its inclusion and diversity priorities in addition to an overarching three-year action plan that articulates enterprise initiatives focused on creating equal pathways to leadership, strengthening inclusion and diversity accountability and modelling thought leadership. An Inclusion and Diversity Council with diverse, senior level representation from across the Fortis organization guides the inclusion and diversity strategy and its implementation.

ANNUAL INFORMATION FORM 25 December 31, 2020

Sustainability Regulation and Environmental Contingencies

As part of the regulatory process, operating subsidiaries engage with stakeholders, including community groups, regulators and customers, to consult on the potential environmental impact of their operations. Fortis and its subsidiaries are subject to various federal, provincial, state and municipal laws, regulations and guidelines relating to the protection of the environment. Environmental compliance involves significant operating and capital costs. At the Corporation's regulated utilities, prudently incurred costs associated with environmental protection and compliance are generally eligible for recovery in customer rates.

The following environmental contingencies have been made as of December 31, 2020:

Mine Reclamation at Generation Facilities Not Operated by TEP. TEP pays ongoing reclamation costs related to coal mines that supply generation facilities in which TEP has an ownership interest but does not operate. TEP is permitted to fully recover these costs from customers and, accordingly, these costs are deferred as a regulatory asset.

TEP is liable for a portion of final mine reclamation costs upon closure of the mines servicing San Juan and Four Corners. TEP's estimated share of final mine reclamation costs at both mines is $61 million (US$48 million) upon expiration of the related coal supply agreements, which expire in 2022 and 2031, respectively. An aggregate liability balance related to San Juan and Four Corners final mine reclamation of $51 million (US$40 million) and $47 million (US$36 million) as at December 31, 2020 and 2019, respectively, was recognized on the balance sheet.

Former Manufactured Gas Plant Facilities. Environmental regulations require Central Hudson to investigate sites at which Central Hudson or its predecessors once owned and/or operated manufactured gas plants and, if necessary, remediate these sites. Central Hudson accrues for remediation costs based on the amounts that can be reasonably estimated. As at December 31, 2020, an obligation of $95 million (US$75 million) was recognized. Central Hudson has notified its insurers and intends to seek reimbursement where insurance coverage exists. Further, as authorized by the NYPSC, Central Hudson is currently permitted to defer, for future recovery from customers, differences between actual costs for manufactured gas plant site investigation and remediation and the associated rate allowances.

CAPITAL STRUCTURE AND DIVIDENDS

Description of Capital Structure

The authorized share capital of the Corporation consists of an unlimited number of common shares without nominal or par value, an unlimited number of first preference shares without nominal or par value, and an unlimited number of second preference shares without nominal or par value.

As at February 11, 2021, the Corporation had issued and outstanding 466.8 million common shares; 5.0 million First Preference Shares, Series F; 9.2 million First Preference Shares, Series G; 7.7 million First Preference Shares, Series H; 2.3 million First Preference Shares, Series I; 8.0 million First Preference Shares, Series J; 10.0 million First Preference Shares, Series K; and 24.0 million First Preference Shares, Series M.

For a summary of the terms and conditions of the Corporation's authorized securities, and trading information for the Corporation's publicly listed securities, refer to Exhibit "A" and Exhibit "B" of this AIF.

Dividends and Distributions

The declaration and payment of dividends on the Corporation's common shares and first preference shares are at the discretion of the Board. Dividends on the common shares are typically paid quarterly, on the first day of March, June, September and December of each year. Dividends on the Corporation's First Preference Shares, Series F, G, H, I, J, K and M are typically also paid quarterly.

ANNUAL INFORMATION FORM 26 December 31, 2020

In September 2020 Fortis increased its quarterly dividend per common share 5.8% to $0.505 per share, or $2.02 on an annualized basis. In November 2020 the Board declared a first quarter 2021 dividend on the common shares of $0.505 per share and on the First Preference Shares, Series F, G, H, I, J, K and M in accordance with the applicable prescribed rate. The first quarter dividends on the common shares and the First Preference Shares, Series F, G, H, I, J, K and M are to be paid on March 1, 2020 to holders of record as of February 16, 2021.

The following table summarizes the cash dividends declared per share for each of the Corporation's class of shares for the past three years.

	2020	2019	2018
Common Shares	1.9650	1.8550	1.7500
First Preference Shares, Series F (1)	1.2250	1.2250	1.2250
First Preference Shares, Series G (2)	1.0983	1.0983	1.0345
First Preference Shares, Series H (3)	0.5003	0.6250	0.6250
First Preference Shares, Series I (4)	0.4987	0.7771	0.7116
First Preference Shares, Series J (1)	1.1875	1.1875	1.1875
First Preference Shares, Series K (5)	0.9823	0.9823	1.0000
First Preference Shares, Series M (6)	0.9783	1.0133	1.0250

(1)The dividend rate on the First Preference Shares, Series F and First Preference Shares, Series J are fixed and do not reset.

(2)The annual dividend per share was reset to $1.0983 for the five-year period from September 1, 2018 up to but excluding September 1, 2023.

(3)The annual dividend per share was reset from $0.6250 to $0.4588 for the five-year period from June 1, 2020 up to but excluding June 1, 2025.

(4)The First Preference Shares, Series I are entitled to receive floating rate cumulative dividends, which rate will reset every quarter based on the then current three‑month Government of Canada Treasury Bill rate plus 1.45%.

(5)The Fixed Rate Reset First Preference Shares, Series K were issued in July 2013 at $25.00 per share and were entitled to receive cumulative dividends in the amount of $1.0000 per share per annum to but excluding March 1, 2019. The annual fixed dividend per share for the First Preference Shares, Series K was reset to $0.9823 for the five-year period from March 1, 2019 to but excluding March 1, 2024.

(6)The Fixed Rate Reset First Preference Shares, Series M were issued in September 2014 at $25.00 per share and were entitled to receive cumulative dividends in the amount of $1.0250 per share per annum for the first five years. The annual fixed dividend per share for the First Preference Shares, Series M was reset to $0.9783 for the five-year period from December 1, 2019 to but excluding December 1, 2024.

For purposes of the enhanced dividend tax credit rules contained in the Income Tax Act (Canada) and any corresponding provincial and territorial tax legislation, all dividends paid on common and preference shares after December 31, 2005 by Fortis to Canadian residents are designated as "eligible dividends". Unless stated otherwise, all dividends paid by Fortis hereafter are designated as "eligible dividends" for the purposes of such rules.

Debt Covenant Restrictions on Dividend Distributions

The Trust Indenture pertaining to the Corporation's $200 million Unsecured Debentures contains a covenant which provides that Fortis shall not declare or pay any dividends (other than stock dividends or cumulative preferred dividends on preferred shares not issued as stock dividends) or make any other distribution on its shares or redeem any of its shares or prepay subordinated debt if, immediately thereafter, its consolidated funded obligations would be in excess of 75% of its total consolidated capitalization.

The Corporation has $500 million and $1.3 billion of unsecured committed revolving corporate credit facilities, maturing in April 2021 and July 2024, respectively, that are available for general corporate purposes. The credit facilities contain a covenant that provides that Fortis shall not declare, pay or make any dividends or any other restricted payments if, immediately thereafter, its consolidated debt to consolidated capitalization ratio would exceed 65%.

As at December 31, 2020 and 2019, the Corporation was in compliance with its debt covenant restrictions pertaining to dividend distributions, as described above.

ANNUAL INFORMATION FORM 27 December 31, 2020

Credit Ratings

Securities issued by Fortis and its utilities, that are currently rated, are rated by one or more credit rating agencies, namely DBRS Morningstar, S&P, Moody's and/or Fitch. The ratings assigned to securities issued by Fortis and its utilities are reviewed by the agencies on an ongoing basis. Credit and stability ratings are intended to provide investors with an independent measure of credit quality of an issue of securities and are not recommendations to buy, sell or hold securities. Ratings may be subject to revision or withdrawal at any time by the rating organization. The following table summarizes the Corporation's debt credit ratings as at February 11, 2021.

Company/Security	DBRS Morningstar	S&P	Moody's
Fortis- Unsecured Debt (1)(2)	BBB (high), Positive	BBB+, Negative	Baa3, Stable
Caribbean Utilities-Unsecured Debt (3)	A (low), Stable	BBB+, Negative	—
Central Hudson-Unsecured Debt (4) (5)	—	A-, Stable	A3, Negative
FortisAlberta - Unsecured Debt	A (low), Stable	A-, Negative	Baa1, Stable
FortisBC Electric
Secured Debt	A (low), Stable	—	—
Unsecured Debt	A (low), Stable	—	Baa1, Stable
Commercial Paper	R-1 (low), Stable	—	—
FortisBC Energy
Unsecured Debt	A, Stable	—	A3, Stable
Commercial Paper	R-1 (low), Stable	—	—
ITC Holdings
Unsecured Debt (2)	—	BBB+, Negative	Baa2, Stable
Commercial Paper (2)	—	A-2, Negative	Prime-2, Stable
ITC Great Plains -First Mortgage Bonds (2)	—	A, Negative	A1, Stable
ITC Midwest - First Mortgage Bonds (2)	—	A, Negative	A1, Stable
ITCTransmission - First Mortgage Bonds (2)	—	A, Negative	A1, Stable
Maritime Electric - Secured Debt	—	A, Stable	—
METC - Secured Debt (2)	—	A, Negative	A1, Stable
Newfoundland Power - First Mortgage Bonds	A, Stable	—	A2, Stable
TEP
Unsecured Debt (2)	—	A-, Negative	A3, Stable
Unsecured Bank Credit Facility			A3, Stable
UNS Electric
Unsecured Debt	—	—	A3, Stable
Unsecured Bank Credit Facility	—	—	A3, Stable
UNS Gas - Unsecured Debt	—	—	A3, Stable
UNS Energy - Unsecured Bank Credit Facility	—	—	Baa1, Stable

(1)Between March and August 2020, all three rating agencies affirmed the Corporation's credit ratings and outlooks. In May 2020 DBRS revised its outlook to positive from stable due to: (i) significant reduction of nonconsolidated corporate debt following the sale of a 51% interest in the Waneta Expansion and the $1.2 billion common equity issuance in December 2019; (ii) solid consolidated credit metrics in 2019 and expected to continue in the near-to-medium term; and (iii) a continued strong business risk profile at regulated utilities.

(2)In March 2020 S&P reaffirmed its outlook to remain negative due to the potential impacts over the next 6 to 12 months to the consolidated financial measures should the COVID-19 pandemic or macroeconomic downturn persist.

(3)In March 2020 S&P revised its outlook to negative from stable due to the COVID-19 pandemic and its potential impacts on Cayman’s tourism industry.

(4)In October 2020 Moody's revised its outlook to negative from stable citing the company's capital program and the possible impact on financial metrics considering the current regulatory environment in New York State.

(5)Central Hudson's senior unsecured debt is also rated by Fitch at 'A-, stable'.

DBRS Morningstar rates long-term debt instruments by rating categories ranging from AAA to D, which represents the range from highest to lowest quality of such securities. DBRS Morningstar's rating scale provides an opinion on the risk of default, which is the risk that an issuer with fail to satisfy its financial obligations in accordance with the terms under which an obligation has been issued. The ratings are also based on quantitative and qualitative considerations relevant to the issuer, and the relative ranking of claims. All rating categories other than AAA and D also contain subcategories of '(high)' or '(low)'. The absence of either a '(high)' or '(low)' designation indicates the rating is in the middle of a category.

ANNUAL INFORMATION FORM 28 December 31, 2020

According to DBRS Morningstar, a rating of A is assigned to a long-term debt instrument that has good credit quality, with the issuer having substantial capacity to pay its financial obligations, but credit quality is less than AA-rated instruments and may be vulnerable to future events, but qualifying negative factors are considered reasonable. A rating of BBB is assigned to a long-term debt instrument that has adequate credit quality, with the issuer considered having acceptable capacity to pay its financial obligations but may be vulnerable to future events.

DBRS Morningstar rates short-term debt on a rating scale that ranges from R-1 to D, which represents the range from highest to lowest quality of such securities. DBRS Morningstar also uses '(high)', '(middle)', or '(low)' designations to indicate the relative standing of securities within a particular rating category. Such modifiers are not added to ratings below R-2. According to DBRS Morningstar, a rating of R-1 (low) means that the short-term debt obligation has good credit quality, the issuer has substantial ability to repay short-term debt obligations and may be vulnerable to future events, but qualifying negative factors are considered manageable.

S&P rates long-term debt on a rating scale that ranges from AAA to D, which represents the range from highest to lowest quality of such securities. S&P uses '+' or '-' designations to indicate the relative standing of securities within a particular rating category. Such modifiers are not added to ratings below CCC. S&P's long-term debt rating scale provides an opinion about the creditworthiness of an issuer with respect to the specific financial obligation and the issuer's capacity and willingness to meet its financial commitments on the obligation in accordance with its terms. According to S&P, a rating of A is assigned to long-term debt instruments that are somewhat more susceptible to the adverse effects of changes in circumstances and economic conditions than those in higher-rated categories. However, the issuer's capacity to meet its financial obligations is still strong. Debt instruments rated BBB exhibit adequate protection parameters. However, adverse economic conditions or changing circumstances are more likely to lead to a weakened capacity of the issuer to meet its financial commitments on the obligation.

S&P rates short-term obligations on a rating scale that ranges from A-1 to D, which represents the range from the highest to lowest quality of such securities. Within only the A-1 category may certain obligations be designated with a '+', indicating that the issuer's capacity to meet its financial commitments under these obligations is extremely strong. According to S&P, a short-term obligation rated A-2 is somewhat more susceptible to the adverse effects of changes in circumstances and economic conditions than obligations in higher rating categories. However, the issuer's capacity to meet its financial commitments on the short-term obligation is satisfactory.

Moody's rates long-term debt on a rating scale that ranges from Aaa to C, which represents the range from highest to lowest quality of such securities. In addition, Moody's applies numerical modifiers 1, 2 and 3 to each generic rating classification from Aa to Caa to indicate relative standing within such classification. The modifier 1 indicates that the security ranks in the higher end of its generic rating category, the modifier 2 indicates a mid-range ranking in its generic rating category and the modifier 3 indicates that the security ranks in the lower end of its generic rating category. Moody's states that its long-term debt ratings are opinions of relative risk of fixed-income obligations and reflect both the likelihood of default or impairment and any expected financial loss suffered in the event of default or impairment. According to Moody's, a rating of Baa is assigned to long-term debt instruments considered to be of medium-grade quality. Debt instruments rated Baa are subject to moderate credit risk and may possess certain speculative characteristics. Debt instruments rated A are considered upper-medium grade and are subject to low credit risk.

Moody's rates short-term debt on a rating scale that includes four designations. From highest to lowest relative repayment ability of rated issuers, such designations are Prime-1, Prime-2, Prime-3 and Not Prime. Short-term obligations with a Not Prime rating do not fall within any of the Prime rating categories. According to Moody's, a rating of Prime-2 means that an issuer has a strong ability to repay short-term debt obligations.

Fitch rates long-term debt on a rating scale that ranges from AAA to C, which represents the range from highest to lowest quality of such securities. Fitch uses '+' or '-' designations to indicate the relative status of securities within a particular rating category. Such modifiers are not added to the AAA rating or to ratings below CCC. Fitch states that its credit ratings provide an opinion on the relative ability of an entity to meet its financial commitments under long-term obligations and address relative vulnerability to default. Fitch's credit ratings do not directly address any risk other than credit risk. According to Fitch, a long-term

ANNUAL INFORMATION FORM 29 December 31, 2020

obligation rated A denotes the expectation of low credit risk, with strong capacity for payment of financial commitments. The capacity may, nevertheless, be more vulnerable to adverse business or economic conditions than is the case for higher ratings.

The Corporation and/or each of its currently rated utilities pay DBRS Morningstar, S&P, Moody's and/or Fitch an annual monitoring fee and a one-time fee in connection with each rated issuance.

DIRECTORS AND OFFICERS

The Board has governance guidelines that cover various items, including director tenure. The governance guidelines provide that Directors of the Corporation are to be elected for a term of one year and are eligible for re‑election until the annual meeting of shareholders following the date they turn 72 or until they have served on the Board for 12 years, whichever is earlier. Exceptions may be made by the Board if it is in the best interests of the Corporation and the Director has received solid annual performance evaluations, has the necessary skills and experience and meets the other Board policies and legal requirements for Board service.

The following table sets out the name, province or state, and country of residence of each of the Directors of the Corporation and their principal occupations during the five preceding years. Each Director's current term expires at the next annual meeting of shareholders.

Name, Residence, Principal Occupation Within Five Preceding Years	Director Since	Committees (1)
		AC	GS	HR
DOUGLAS J. HAUGHEY (Chair), Alberta, Canada Corporate Director.	2009	l	l	l
TRACEY C. BALL, British Columbia, Canada Corporate Director.	2014	C	l
PIERRE J. BLOUIN, Quebec, Canada Corporate Director.	2015		C	l
PAUL J. BONAVIA, Texas,USA Corporate Director.	2018		l	l
LAWRENCE T. BORGARD, Florida, USA Corporate Director. President and Chief Operating Officer of Integrys Energy Group from 2014 to 2015.	2017	l		l
MAURA J. CLARK, New York, USA Corporate Director.	2015	l	l
MARGARITA K. DILLEY, District of Columbia, USA Corporate Director.	2016	l		l
JULIE A. DOBSON, Maryland, USA Corporate Director.	2018		l	l
DAVID G. HUTCHENS, Arizona, USA President and Chief Executive Officer of the Corporation.	2021	(2)
JO MARK ZUREL, Newfoundland and Labrador, Canada Corporate Director. President of Stonebridge Capital Inc., a private investment company from 2006 to March 2019.	2016	l		C

(1)Audit Committee, Governance and Sustainability Committee and Human Resources Committee. "C" represents Chair.

(2)Mr. Hutchens does not serve on any of the committees because he is the President and Chief Executive Officer of the Corporation.

ANNUAL INFORMATION FORM 30 December 31, 2020

The following table sets out the name, province or state, and country of residence of each of the executive officers of Fortis and indicates the office held and principal occupations of the executive officers during the five preceding years.

Name, Residence, Principal Occupation During the Five Preceding Years	Office
DAVID G. HUTCHENS, Arizona, USA President and Chief Executive Officer since January 2021. Chief Operating Officer from January 2020 to December 2020 and Executive Vice President, Western Utility Operations from January 2018 to January 2020. Chief Executive Officer of UNS Energy from January 2020 to December 2020 and President and Chief Executive Officer of UNS Energy from May 2014 to January 2020.	President and Chief Executive Officer
JOCELYN H. PERRY, Newfoundland and Labrador, Canada Executive Vice President, Chief Financial Officer since June 2018. President and Chief Executive Officer of Newfoundland Power from 2017 to May 2018, Chief Financial Officer and Chief Operating Officer from 2016 to 2017 and Vice President, Finance & Chief Financial Officer from 2007 to 2016.	Executive Vice President, Chief Financial Officer
NORA M. DUKE, Newfoundland and Labrador, Canada Executive Vice President, Sustainability and Chief Human Resource Officer since December 2017 and Executive Vice President, Corporate Services and Chief Human Resource Officer from August 2015 to December 2017.	Executive Vice President, Sustainability and Chief Human Resource Officer
JAMES P. LAURITO, Florida, USA Executive Vice President, Business Development and Chief Technology Officer since May 2019 and Executive Vice President, Business Development since April 2016. President and Chief Executive Officer of Central Hudson from 2010 to April 2016.	Executive Vice President, Business Development and Chief Technology Officer
JAMES R. REID, Ontario, Canada Executive Vice President, Chief Legal Officer and Corporate Secretary since March 2018. Partner with Davies Ward Phillips & Vineberg LLP from 2003 to March 2018.	Executive Vice President, Chief Legal Officer and Corporate Secretary
GARY J. SMITH, Newfoundland and Labrador, Canada Executive Vice President, Eastern Canadian and Caribbean Operations since June 2017. President and Chief Executive Officer of Newfoundland Power from 2014 to June 2017.	Executive Vice President, Eastern Canadian and Caribbean Operations
STEPHANIE A. AMAIMO, Michigan, USA Vice President, Investor Relations since October 2017, Director, Investor Relations from 2016 to October 2017 and Director, Investor Relations of ITC Holdings from 2015 to 2016.	Vice President, Investor Relations
KAREN J. GOSSE, Newfoundland and Labrador, Canada Vice President, Treasury and Planning since April 2018. Vice President, Planning and Forecasting from November 2015 to April 2018.	Vice President, Treasury and Planning
RONALD J. HINSLEY, Michigan, USA Vice President, Chief Information Officer since May 2019.Vice President, Information Technology and Chief Information Officer of ITC Holdings since 2013.	Vice President, Chief Information Officer
KAREN M. MCCARTHY, Newfoundland and Labrador, Canada Vice President, Communications and Corporate Affairs since May 2018 and Director, Communications and Corporate Affairs from 2016 to May 2018. Director, Customer and Corporate Relations of Newfoundland Power from 2014 to 2016.	Vice President, Communications and Corporate Affairs
REGAN P. O'DEA, Newfoundland and Labrador, Canada Vice President, General Counsel since May 2017 and Associate General Counsel from 2014 to May 2017.	Vice President, General Counsel
JAMIE D. ROBERTS, Newfoundland and Labrador, Canada Vice President, Controller since March 2013.	Vice President, Controller

The directors and executive officers of Fortis, as a group, beneficially own, directly or indirectly, or exercise control or direction over 772,927 common shares, representing 0.17% of the issued and outstanding common shares of Fortis. The common shares are the only voting securities of the Corporation.

ANNUAL INFORMATION FORM 31 December 31, 2020

AUDIT COMMITTEE

Members

The members of the Corporation's Audit Committee are Tracey C. Ball (Chair), Lawrence T. Borgard, Maura J. Clark, Margarita K. Dilley, Douglas J. Haughey and Jo Mark Zurel. All members of the Audit Committee are independent and financially literate as those terms are defined by Canadian and US securities laws and TSX and NYSE requirements. In addition, the Board has determined that Tracey C. Ball, Maura J. Clark, Margarita K. Dilley and Jo Mark Zurel are financial experts and has designated each of them as "audit committee financial experts" under US securities laws.

The Corporation's Audit Committee Mandate, effective as of January 1, 2021, is attached as Exhibit "C" to this AIF.

Education and Experience

The education and experience of each Audit Committee member that is relevant to such member's responsibilities as a member of the Audit Committee are set out below.

Committee Member	Relevant Education and Experience
TRACEY C. BALL (Chair)	Ms. Ball retired in September 2014 as Executive Vice President and Chief Financial Officer of Canadian Western Bank Group. Ms. Ball has served on several private and public sector boards, including the Province of Alberta Audit Committee and the Financial Executives Institute of Canada. She graduated from Simon Fraser University with a Bachelor of Arts (Commerce). She is a member of the Chartered Professional Accountants of Alberta and the Chartered Professional Accountants of British Columbia. Ms. Ball was elected as a Fellow of the Chartered Professional Accountants of Alberta in 2007. She holds an ICD.D designation from the Institute of Corporate Directors.
LAWRENCE T. BORGARD	Mr. Borgard retired from Integrys Energy Group in 2015 where he was President and Chief Operating Officer and the Chief Executive Officer of each of Integrys' six regulated electric and natural gas utilities. Mr. Borgard graduated from Michigan State University with a Bachelor of Science (Electrical Engineering) and the University of Wisconsin-Oshkosh with an MBA. He also attended the Advanced Management Program at Harvard University Business School.
MAURA J. CLARK	Ms. Clark retired from Direct Energy, a subsidiary of Centrica plc, in March 2014 where she was President of Direct Energy Business, a leading energy retailer in Canada and the US. Previously Ms. Clark was Executive Vice President of North American Strategy and Mergers and Acquisitions for Direct Energy. Ms. Clark's prior experience includes investment banking and serving as Chief Financial Officer of an independent oil refining and marketing company. Ms. Clark graduated from Queen's University with a Bachelor of Arts in Economics. She is a member of the Association of Chartered Professional Accountants of Ontario.
MARGARITA K. DILLEY	Ms. Dilley retired from ASTROLINK International LLC in 2004, an international wireless broadband telecommunications company, where she was Vice President and Chief Financial Officer. Ms. Dilley's prior experience includes serving as Director, Strategy & Corporate Development as well as Treasurer for Intelsat. Ms. Dilley graduated from Cornell University with a Bachelor of Arts, from Columbia University with a Master of Arts and from Wharton Graduate School, University of Pennsylvania with an MBA.
DOUGLAS J. HAUGHEY	Mr. Haughey, from August 2012 through May 2013, was Chief Executive Officer of The Churchill Corporation. Prior to that, he served as President and Chief Executive Officer of Provident Energy Ltd. and held several executive roles with Spectra Energy and predecessor companies. He graduated from the University of Regina with a Bachelor of Business Administration and from the University of Calgary with an MBA. Mr. Haughey holds an ICD.D designation from the Institute of Corporate Directors.
JO MARK ZUREL	Mr. Zurel was the president of Stonebridge Capital Inc., a private investment company, from 2006 to March 2019. From 1998 to 2006, Mr. Zurel was Senior Vice-President and Chief Financial Officer of CHC Helicopter Corporation. Mr. Zurel graduated from Dalhousie University with a Bachelor of Commerce and is a Fellow of the Association of Chartered Professional Accountants of Newfoundland and Labrador. He holds an ICD.D designation from the Institute of Corporate Directors.

ANNUAL INFORMATION FORM 32 December 31, 2020

Pre-Approval Policies and Procedures

The Audit Committee has established a policy that requires pre-approval of all audit and non-audit services provided to the Corporation and its subsidiaries by the Corporation's external auditor. The Pre‑Approval Policy for Independent Auditor Services describes the services that may be contracted from the external auditor and the related limitations and authorization procedures. This policy defines prohibited services, including but not limited to bookkeeping, valuations, internal audit and management functions, which may not be contracted from the external auditor and establishes an annual limit for permissible non-audit services not greater than the total fee for audit services. Audit Committee pre-approval is required for all services provided by the external auditor.

External Auditor Service Fees

The aggregate fees billed by the Corporation's external auditors during each of the last two fiscal years are set out in the following table.

		Deloitte LLP
($ thousands)	Description of Fee Category	2020	2019
Audit Fees	Core audit services	9,362	9,745
Audit-Related Fees	Assurance and related services that are reasonably related to the audit or review of the Financial Statements and are not included under Audit Fees	1,267	1,490
Tax Fees	Services related to tax compliance, planning and advice	240	669
Other	Services which are not Audit Services, Audit-Related Fees or Tax Fees	22	—
Total		10,891	11,904

TRANSFER AGENT AND REGISTRAR

The transfer agent and registrar in Canada for the common shares and first preference shares of Fortis is Computershare Trust Company of Canada in Montréal and Toronto.

The co-transfer agent and co-registrar in the US for the common shares is Computershare Trust Company, N.A. in Canton, MA, Jersey City, NJ and Louisville, KY.

Computershare Trust Company of Canada

8th Floor, 100 University Avenue

Toronto, ON M5J 2Y1

T: 514.982.7555 or 1.866.586.7638

F: 416.263.9394 or 1.888.453.0330

W: www.investorcentre.com/fortisinc

Computershare Trust Company, N.A.

Att: Stock Transfer Department

Overnight Mail Delivery: 462 South 4th Street, Louisville, KY 40202

Regular Mail Delivery: P.O. Box 505005, Louisville, KY 40233-5005

T: 303.262.0600 or 1.800.962.4284

ANNUAL INFORMATION FORM 33 December 31, 2020

INTERESTS OF EXPERTS

Deloitte LLP is independent with respect to the Corporation within the meaning of the US Securities Act of 1933 and the applicable rules and regulations thereunder adopted by the SEC and the Public Company Accounting Oversight Board (United States) and within the meaning of the rules of professional conduct of the Chartered Professional Accountants of Newfoundland and Labrador.

ADDITIONAL INFORMATION

Additional information relating to the Corporation can be found on the Corporation's website at www.fortisinc.com, on SEDAR at www.sedar.com and on EDGAR at www.sec.gov. The information contained on, or accessible through, any of these websites is not incorporated by reference into this document unless otherwise stated.

Additional financial information is provided in the Corporation's MD&A and Financial Statements, which are incorporated by reference in this AIF and can be found on the Corporation's website at www.fortisinc.com, on SEDAR and on EDGAR.

Further additional information, including officers' and directors' remuneration and indebtedness, principal holders of the securities of Fortis, options to purchase securities and interests of insiders in material transactions, where applicable, is contained in the Management Information Circular of Fortis dated March 20, 2020 for the May 7, 2020 annual meeting of shareholders.

Requests for additional copies of the above‑mentioned documents, as well as this 2020 Annual Information Form, should be directed to the Corporate Secretary, Fortis, P.O. Box 8837, St. John's, NL, A1B 3T2 (telephone: 709.737.2800).

ANNUAL INFORMATION FORM 34 December 31, 2020

EXHIBIT A: Summary of Terms and Conditions of Authorized Securities

Common Shares

Dividends on common shares are declared at the discretion of the Board. Holders of common shares are entitled to dividends on a pro ratabasis if, as, and when declared by the Board. Subject to the rights of the holders of the first preference shares and second preference shares and any other classes of shares of the Corporation entitled to receive dividends in priority to or ratably with the holders of the common shares, the Board may declare dividends on the common shares to the exclusion of any other classes of shares of the Corporation.

On the liquidation, dissolution or winding-up of Fortis, holders of common shares are entitled to participate ratably in any distribution of assets of Fortis, subject to the rights of holders of first preference shares and second preference shares and any other classes of shares of the Corporation entitled to receive the assets of the Corporation on such a distribution in priority to or ratably with the holders of the common shares.

Holders of the common shares are entitled to receive notice of and to attend all annual and special meetings of the shareholders of Fortis, other than separate meetings of holders of any other classes or series of shares, and are entitled to one vote in respect of each Common Share held at such meetings.

Preference Shares

First Preference Shares

The following is a summary of the material rights, privileges, conditions and restrictions attached to the first preference shares as a class. The specific terms of the first preference shares, including the currency in which first preference shares may be purchased and redeemed and the currency in which any dividend is payable, if other than Canadian dollars, and the extent to which the general terms described herein apply to those first preference shares, is or will be as set forth in the applicable articles of amendment of Fortis relating to such series.

Issuance in Series

The Board may from time to time issue first preference shares in one or more series. Prior to issuing shares in a series, the Board is required to fix the number of shares in the series and determine the designation, rights, privileges, restrictions and conditions attaching to that series of first preference shares.

Priority

The shares of each series of first preference shares rank on a parity with the first preference shares of every other series and in priority to all other shares of Fortis, including the second preference shares, as to the payment of dividends, return of capital and the distribution of assets in the event of the liquidation, dissolution or winding-up of Fortis, whether voluntary or involuntary, or any other distribution of the assets of Fortis among its shareholders for the purpose of winding-up its affairs.

Each series of first preference shares participates ratably with every other series of first preference shares in respect of accumulated cumulative dividends and returns of capital, if any, cumulative dividends, whether or not declared and any amount payable on the return of capital in respect of a series of first preference shares, if not paid in full.

Voting

The holders of the first preference shares are not entitled to any voting rights as a class except to the extent that voting rights may from time to time be attached to any series of first preference shares, and except as provided by law or as described below under the heading "Modification". At any meeting of the holders of first preference shares, each holder shall have one vote in respect of each first preference share held.

ANNUAL INFORMATION FORM 35 December 31, 2020

Redemption

Subject to the provisions of the Corporations Act (Newfoundland and Labrador) and any provisions relating to any particular series, Fortis, upon giving proper notice, may redeem out of capital or otherwise at any time, or from time to time, the whole or any part of the then outstanding first preference shares of any one or more series on payment for each such first preference share at such price or prices as may be applicable to such series. Subject to the foregoing, if only a part of the then outstanding first preference shares of any particular series is at any time redeemed, the shares to be redeemed will be selected by lot in such manner as the directors or the transfer agent for the first preference shares, if any, decide, or if the directors so determine, may be redeemed pro rata, disregarding fractions.

Modification

The class provisions attached to the first preference shares may only be amended with the prior approval of the holders of the first preference shares, in addition to any other approvals required by the Corporations Act (Newfoundland and Labrador) or any other statutory provisions of like or similar effect in force from time to time.

The approval of the holders of the first preference shares with respect to any and all matters may be given by at least two-thirds of the votes cast at a meeting of the holders of the first preference shares duly called for that purpose.

First Preference Shares Authorized and Outstanding

The following table summarizes the series of first preference shares as of February 11, 2021.

	Authorized	Issued and Outstanding	Initial Yield (%)	Annual Dividend ($) (1)	Reset Dividend Yield (%)	Redemption and/or Conversion Option Date(2)	Redemption Value ($)	Right to Convert on a One for One Basis
Perpetual Fixed Rate
Series F	5,000,000	5,000,000	4.90	1.2250	—	Currently Redeemable	25.00	—
Series J (3)	8,000,000	8,000,000	4.75	1.1875	—	Currently Redeemable	25.25	—
Fixed Rate Reset (4)
Series G	9,200,000	9,200,000	5.25	1.0983	2.13	September 1, 2023	25.00	—
Series H (5)(6)	10,000,000	7,665,082	4.25	0.4588	1.45	June 1, 2025	25.00	Series I
Series K (5)	12,000,000	10,000,000	4.00	0.9823	2.05	March 1, 2024	25.00	Series L
Series M (5)	24,000,000	24,000,000	4.10	0.9783	2.48	December 1, 2024	25.00	Series N
Floating Rate Reset (5) (7)
Series I	10,000,000	2,334,918	2.10	—	1.45	June 1, 2025	25.00	Series H
Series L	12,000,000	—	—	—	—	—	—	Series K
Series N	24,000,000	—	—	—	—	—	—	Series M

(1)Holders are entitled to receive a fixed or floating cumulative quarterly cash dividend, if, as and when declared by the Board, payable in equal installments on the first day of each quarter.

(2)On or after the specified redemption dates, the Corporation has the option to redeem for cash the outstanding first preference shares, in whole or in part, at the specified per share redemption value plus all accrued and unpaid dividends up to but excluding the dates fixed for redemption, and in the case of the first preference shares that reset, on every fifth anniversary date thereafter.

(3)First Preference Shares, Series J are redeemable as of December 1, 2021 and thereafter at $25.00 per share.

(4)On the redemption and/or conversion option date, and on each five-year anniversary thereafter, the reset annual dividend per share will be determined by multiplying $25.00 per share by the annual fixed dividend rate, which is the sum of the five-year Government of Canada Bond Yield on the applicable reset date, plus the applicable reset dividend yield.

(5)On each conversion option date, the holders have the option, subject to certain conditions, to convert any or all of their shares into an equal number of Cumulative Redeemable first preference shares of a specified series.

(6)The annual dividend per share for the First Preference Shares, Series H was reset from $0.6250 to $0.4588 for the five-year period from June 1, 2020 up to but excluding June 1, 2025.

(7)The floating quarterly dividend rate will be reset every quarter based on the then current three‑month Government of Canada Treasury Bill rate plus the applicable reset dividend yield.

ANNUAL INFORMATION FORM 36 December 31, 2020

On June 1, 2020, 267,341 First Preference Shares, Series H were converted on a one-for-one basis into First Preference Shares, Series I, and 907,577 First Preference Shares, Series I were converted on a one-for-one basis into First Preference Shares Series H.

Second Preference Shares

The rights, privileges, conditions and restrictions attaching to the second preference shares are substantially identical to those attaching to the first preference shares, except that the second preference shares are junior to the first preference shares with respect to the payment of dividends, repayment of capital and the distribution of assets of Fortis in the event of a liquidation, dissolution or winding up of Fortis.

The specific terms of the second preference shares, including the currency in which second preference shares may be purchased and redeemed and the currency in which any dividend is payable, if other than Canadian dollars, and the extent to which the general terms described in herein apply to those second preference shares, will be as set forth in the applicable articles of amendment of Fortis relating to such series.

As of February 11, 2021, there were no second preference shares issued and outstanding.

ANNUAL INFORMATION FORM 37 December 31, 2020

EXHIBIT B: MARKET FOR SECURITIES

Common Shares

The common shares are traded on the TSX in Canada, and on the NYSE in the US, in each case under the symbol FTS. The following table sets forth the reported high and low trading prices and trading volumes, on a monthly basis for the year ended December 31, 2020, for the common shares on the TSX and NYSE in Canadian Dollars and US Dollars, respectively.

2020 Trading Prices and Volumes – Common Shares
	TSX			NYSE
Month	High ($)	Low ($)	Volume	High (US$)	Low (US$)	Volume
January	58.53	53.23	28,162,388	44.49	41.00	7,129,151
February	59.28	54.02	29,749,946	44.72	40.16	6,769,689
March	58.81	41.52	70,060,854	43.89	28.59	21,903,132
April	56.46	50.21	43,128,034	40.45	35.45	13,852,377
May	54.87	49.87	47,773,297	39.02	35.53	9,893,976
June	54.63	50.06	32,723,978	40.76	36.64	8,778,081
July	54.89	50.95	26,455,647	40.88	37.55	7,308,449
August	55.25	51.94	29,087,042	41.20	39.62	7,501,978
September	55.00	51.30	30,618,813	41.19	38.73	7,165,906
October	56.16	52.40	30,823,383	42.47	39.32	5,481,500
November	56.34	51.96	40,244,074	43.49	39.53	8,477,013
December	53.76	51.10	32,629,574	42.17	39.50	6,763,915

Preference Shares

The First Preference Shares, Series F; First Preference Shares, Series G; First Preference Shares, Series H; First Preference Shares, Series I; First Preference Shares, Series J; First Preference Shares, Series K; and First Preference Shares, Series M of Fortis are listed on the TSX under the symbols FTS.PR.F; FTS.PR.G; FTS.PR.H; FTS.PR.I; FTS.PR.J; FTS.PR.K and FTS.PR.M, respectively.

The following tables set forth the reported high and low trading prices and volumes for the First Preference Shares, Series F; First Preference Shares, Series G; First Preference Shares, Series H; First Preference Shares, Series I; First Preference Shares, Series J; First Preference Shares, Series K; and First Preference Shares, Series M on a monthly basis for the year ended December 31, 2020.

2020 Trading Prices and Volumes – First Preference Shares
	First Preference Shares, Series F			First Preference Shares, Series G
Month	High ($)	Low ($)	Volume	High ($)	Low ($)	Volume
January	24.19	23.62	77,489	17.74	16.78	334,760
February	24.30	23.24	42,563	17.51	16.16	113,369
March	23.95	18.96	95,026	16.31	11.11	297,277
April	23.10	20.37	38,451	15.67	13.40	158,094
May	23.33	22.05	43,997	14.61	13.58	143,485
June	23.65	22.45	55,503	14.60	13.83	119,970
July	24.50	23.58	46,797	16.62	13.95	118,575
August	24.10	23.57	83,306	15.75	14.75	191,711
September	25.19	23.69	503,275	15.89	15.02	242,547
October	26.51	24.80	268,263	16.23	15.34	129,750
November	25.70	24.80	29,800	17.00	15.96	111,071
December	25.45	25.00	32,236	16.83	16.27	125,012

ANNUAL INFORMATION FORM 38 December 31, 2020

	First Preference Shares, Series H			First Preference Shares, Series I
Month	High ($)	Low ($)	Volume	High ($)	Low ($)	Volume
January	13.88	12.88	115,276	13.65	12.80	9,123
February	13.47	11.99	108,214	13.40	11.99	24,979
March	12.01	7.48	294,824	12.11	7.71	49,701
April	10.85	9.61	173,256	10.50	9.00	55,117
May	9.99	9.34	85,007	10.01	9.10	58,793
June	9.95	9.16	66,803	9.59	8.95	91,680
July	11.18	9.55	104,299	9.95	8.91	43,239
August	10.84	10.10	119,067	10.25	9.65	20,372
September	10.74	10.20	94,257	10.30	9.99	53,357
October	10.70	10.16	140,485	10.42	10.00	18,278
November	11.10	10.10	123,715	10.60	9.99	50,935
December	12.22	10.92	120,688	11.34	10.80	49,137
	First Preference Shares, Series J			First Preference Shares, Series K
Month	High ($)	Low ($)	Volume	High ($)	Low ($)	Volume
January	22.92	22.31	349,242	16.95	16.00	166,582
February	23.45	22.35	176,650	16.83	15.55	170,052
March	22.95	17.77	191,724	15.60	10.00	188,053
April	22.22	19.32	109,252	14.16	12.75	364,109
May	22.49	21.50	119,188	14.06	12.95	160,251
June	22.65	21.80	81,518	14.15	13.19	249,878
July	23.20	22.20	107,069	15.79	13.28	149,365
August	23.10	22.61	78,263	15.09	14.03	112,132
September	24.77	22.90	82,101	15.12	14.45	120,530
October	25.00	23.76	245,504	15.45	14.62	73,351
November	24.67	23.99	133,621	15.87	15.00	88,164
December	24.61	24.16	147,781	16.40	15.72	97,530
	First Preference Shares, Series M
Month	High ($)	Low ($)	Volume
January	18.39	17.25	623,228
February	18.42	16.46	221,623
March	16.69	11.98	599,336
April	15.99	14.17	286,909
May	15.71	14.68	512,391
June	15.54	14.70	264,972
July	17.38	14.99	382,513
August	17.10	16.24	278,654
September	17.20	16.76	275,954
October	17.70	17.00	549,645
November	18.57	17.39	134,214
December	18.85	18.02	205,217

ANNUAL INFORMATION FORM 39 December 31, 2020

EXHIBIT C: AUDIT COMMITTEE MANDATE

1.0    PURPOSE AND AUTHORITY

1.1    The purpose of the Committee is to advise and assist the Board in fulfilling its oversight responsibilities relating to, among other things:

a.the integrity of the Corporation's financial statements, financial disclosures and internal controls over financial reporting and disclosure controls and procedures;

b.the Corporation's compliance with related legal and regulatory requirements;

c.the qualifications, independence and performance of the Independent Auditor and Internal Auditor, together with the compensation of the Independent Auditor;

d.the Corporation's ERM Program and the management and mitigation of significant risks identified thereunder;

e.the related policies of the Corporation set out herein; and

f.other matters set out herein or otherwise delegated to the Committee by the Board.

1.2    Consistent with this purpose, the Committee should encourage continuous improvement of, and foster adherence to, the Corporation's policies, procedures and practices at all levels. The Committee should also provide for open communication among the Independent Auditor, the Internal Auditor, Management and the Board.

1.3    To perform its duties and responsibilities, the Committee has the authority to: (i) conduct investigations into any matters within its scope of responsibility; (ii) have unrestricted access to information, management and employees and books and records of the Corporation and its affiliates; and (iii) directly access and communicate with the Independent Auditor and Internal Auditor.

2.0    DEFINITIONS

2.1    In this Mandate:

a."Board" means the board of directors of the Corporation;

b."Chair" means the Chair of the Committee;

c."Committee" means the audit committee of the Board;

d."Core Audit Services"means services necessary to: (i) audit the Corporation's annual consolidated or non-consolidated financial statements; (ii) review the Corporation's interim condensed consolidated financial statements; and (iii) audit internal controls over financial reporting in accordance with the requirements of the Sarbanes Oxley Act of 2002 and all applicable laws, regulations and professional standards;

e."Corporation" means Fortis Inc.;

f."CPAB" means the Canadian Public Accountability Board or its successor;

g."Director"means a member of the Board;

h."ERM Program" means the Corporation's Enterprise Risk Management Program that incorporates an effective risk management framework to identify, evaluate, manage, monitor and communicate key corporate risks;

i."Financial Expert"means an "audit committee financial expert" as defined in Item 407(d)(5) of SEC Regulation S-K;

ANNUAL INFORMATION FORM 40 December 31, 2020

j."Financially Literate"means having the ability to read and understand a set of financial statements that present a breadth and level of complexity of accounting issues that are generally comparable to the breath and complexity of the issues that can reasonably be expected to be present in the Corporation's financial statements;

k."Governance and Sustainability Committee"means the governance and sustainability committee of the Board;

l."Independent"means, in the context of a Member and in accordance with all applicable laws and stock exchange requirements, being free from any direct or indirect material relationship with the Corporation and its subsidiaries which, in the view of the Board, could reasonably be expected to interfere with the exercise of a Member's independent judgment;

m."Independent Auditor" means the firm of chartered professional accountants, registered with the CPAB and the PCAOB, and appointed by the shareholders to act as external auditor;

n."Internal Auditor" means the person(s) employed or engaged by the Corporation to perform the internal audit function of the Corporation;

o."Management" means the senior officers of the Corporation;

p."Mandate" means this mandate of the Committee;

q."MD&A" means the Corporation's management discussion and analysis prepared in accordance with the requirements of National Instrument 51-102F1 and the SEC in respect of the Corporation's annual consolidated and interim condensed consolidated financial statements;

r."Member" means a Director appointed to the Committee;

s."NYSE" means the New York Stock Exchange;

t."PCAOB" means the Public Company Accounting Oversight Board or its successor;

u."Related Party Transactions"means those transactions required to bedisclosed under Items 404(a) and 404(b) of SEC Regulation S-K and required to be evaluated by an appropriate group within the Corporation pursuant to Section 314.00 of the NYSE Listed Company Manual and all applicable laws and stock exchange requirements which include, without limitation, transactions between: (i) executive officers, directors, principal shareholders or their immediate family members; and (ii) the Corporation; and

v."SEC" means the United States Securities and Exchange Commission.

3.0    ESTABLISHMENT AND COMPOSITION OF COMMITTEE

3.1    The Committee shall be comprised of three (3) or more Directors, each of whom is Independent and Financially Literate. No Member may be a member of Management or an employee of the Corporation or of any affiliate of the Corporation. The Board shall appoint to the Committee at least one (1) Director who is a Financial Expert.

3.2    Members shall be appointed annually by the Board, or at other times as may be necessary, provided, however, that if the appointment of Members is not so made, each Director then serving as a Member shall continue as a Member until he or she resigns or is removed or his or her successor is appointed.

3.3    The Board may appoint a Member to fill a vacancy which occurs on the Committee between annual elections of Directors. If a vacancy exists on the Committee, the remaining Members shall exercise all of the powers of the Committee so long as at least three (3) Members remain in office.

3.4    Any Member may be removed from the Committee or replaced by a resolution of the Board.

ANNUAL INFORMATION FORM 41 December 31, 2020

3.5    No Member shall serve on more than three (3) public company audit committees (inclusive of the Corporation) without the prior approval of the Board.

3.6    The Board shall appoint a Chair on the recommendation of the Corporation's Governance and Sustainability Committee, or such other committee as the Board may authorize, provided, however, that if the appointment of the Chair is not so made, the Director who is then serving as Chair shall continue as Chair until his or her successor is appointed. The Board shall periodically rotate the Chair and shall make reasonable efforts to rotate the Chair every four (4) years.

4.0    COMMITTEE MEETINGS

4.1    The Committee shall meet at least quarterly and shall meet at such other times during the year as it deems appropriate. Meetings of the Committee shall be held at the call of: (i) the Chair; (ii) any two Members; or (iii) the Independent Auditor.

4.2    The Chief Executive Officer, the Chief Financial Officer, the Independent Auditor and the Internal Auditor shall receive notice of and, unless otherwise determined by the Chair, shall be entitled to attend all meetings of the Committee. For clarity, the Independent Auditor must attend the Committee meetings at which the Corporation's annual audited consolidated and non-consolidated financial statements and interim unaudited condensed consolidated financial statements are reviewed.

4.3    A quorum at any meeting of the Committee shall be three (3) Members.

4.4    Each Member shall have the right to vote on matters that come before the Committee.

4.5    Any matter to be determined by the Committee shall be decided by a majority of votes cast at a meeting of the Committee at which such matter is considered. Actions of the Committee may also be taken by an instrument or instruments in writing signed by all of the Members, and such actions shall be effective as though they had been decided by a majority of votes cast at a meeting of the Committee called for such purpose.

4.6    The Chair shall act as chair of all meetings of the Committee at which the Chair is present. In the absence of the Chair from any meeting of the Committee, the Members present at the meeting shall appoint one of their number to act as chair of the meeting.

4.7    Unless otherwise determined by the Chair, the Corporate Secretary of the Corporation shall act as secretary of all meetings of the Committee.

4.8    The Committee shall periodically meet separately with Management, the Internal Auditor and the Independent Auditor to discuss any matters that the Committee or any of these persons or firms believes should be discussed privately. The Committee shall conduct in camera sessions without Management present at each meeting of the Committee.

4.9    The Committee may invite any Directors, officers or employees of the Corporation or any other person to attend the meetings of the Committee to assist in the discussion and examination of the matters under consideration by the Committee.

4.10    Subject to section 5.4, the Committee may delegate authority to individual Members or subcommittees, if deemed appropriate.

ANNUAL INFORMATION FORM 42 December 31, 2020

5.0    DUTIES AND RESPONSIBILITIES OF THE COMMITTEE

A.    Independent Auditor

5.1    In consultation and coordination with the subsidiary audit committees, the Committee shall be directly responsible for the selection and appointment (through a recommendation to the Board for the appointment by the shareholders), compensation and retention of the Independent Auditor.

5.2    The Committee shall oversee the work of the Independent Auditor in connection with the Core Audit Services and any other services performed for the Corporation. The Independent Auditor shall report directly to the Committee and the Committee has the authority to communicate directly with the Independent Auditor.

5.3    The Committee shall oversee the resolution of any disagreements between Management and the Independent Auditor. The Committee shall discuss with the Independent Auditor the matters required to be discussed under PCAOB Auditing Standard No. 1301 relating to the conduct of the audit, including any problems or difficulties encountered and Management's responses thereto and any restrictions on the scope of activities or access to requested information.

5.4    The Committee shall pre-approve all services performed by the Independent Auditor in accordance with the Corporation's Pre-Approval Policy for Independent Auditor Services. For any service, other than Core Audit Services, requiring specific pre-approval in accordance with such policy, the Committee may delegate pre-approval authority to one or more of its Members. Currently, pre-approval authority in this regard has been delegated to the Chair or, in that person's absence, the Chair of the Board who is a Member. Delegates must report all pre-approval decisions to the Committee at the next scheduled meeting.

5.5    The Committee shall annually obtain and review a report from the Independent Auditor delineating all relationships between the Independent Auditor and the Corporation and its subsidiaries in accordance with Item 407(d) of SEC Regulation S-K and Section 303A.07 of the NYSE Listed Company Manual and addressing the matters set forth in PCAOB Rule 3526 and all applicable laws and stock exchange requirements and any other applicable regulations and professional standards. The Committee shall use reasonable efforts, including discussion with the Independent Auditor, to satisfy itself as to the Independent Auditor's independence in accordance with Canadian generally accepted auditing standards and PCAOB standards, the applicable requirements and interpretative guidance of SEC Regulation S-X and any other applicable regulations and professional standards. The Committee shall discuss any potential independence issues with the Board and recommend any commensurate action that the Committee deems appropriate.

5.6    The Committee shall review and evaluate the qualifications, independence and performance of the Independent Auditor and its lead engagement partner. Without limiting the foregoing, the Committee shall:

a.review and discuss with Management and separately with the Independent Auditor the results of the Corporation's annual Independent Auditor assessment process; and

b.at least annually,obtain and review a report from the Independent Auditor describing the firm's internal quality control processes and procedures, including any material issues raised by the most recent internal quality control review or peer review, or by any inquiry or investigation by governmental or professional authorities (including without limitation the PCAOB and the CPAB) within the preceding five (5) years with respect to independent audits carried out by the Independent Auditor, and any steps taken to address such issues.

The Committee shall discuss any material issues identified with the Board and recommend any commensurate action that the Committee deems appropriate.

5.7    The Committee shall ensure the rotation of the audit partner(s) as required by applicable law and consider the need for rotation of the Independent Auditor.

ANNUAL INFORMATION FORM 43 December 31, 2020

5.8    The Committee shall meet with the Independent Auditor prior to the audit to discuss the planning and staffing of the audit, including the general approach, scope, areas subject to significant risk of material misstatement, estimated fees and other terms of engagement.

B.    Financial Reporting

5.9    In consultation with Management, the Independent Auditor and the Internal Auditor, the Committee shall review and satisfy itself as to: (i) the integrity of the Corporation's internal and external financial reporting processes; (ii) the adequacy and effectiveness of the Corporation's disclosure controls and procedures (including those pertaining to the review of disclosure containing financial information extracted or derived from the Corporation's financial statements) and internal controls over financial reporting; and (iii) the competence of the Corporation's personnel responsible for accounting and financial reporting. Without limiting the generality of the foregoing, the Committee shall receive and review:

a.reports regarding: (i) critical accounting estimates, policies and practices; (ii) goodwill impairment testing; (iii) derivatives and hedges; (iv) any reserves, accruals, provisions and estimates that may have a material effect on the Corporation's financial statements; (v) any pro forma, adjusted or restated financial information, or forecasts, or projections; and (vii) the effect of regulatory and accounting initiatives, as well as off-balance sheet arrangements, on the Corporation's financial statements;

b.analyses by Management and the Independent Auditor regarding significant financial reporting issues and judgments made in connection with the preparation of the Corporation's consolidated financial statements including: (i) alternative treatments of financial information within generally accepted accounting principles related to material matters that have been discussed with Management, their ramifications and the treatment preferred by the Independent Auditor; (ii) major issues regarding auditing and accounting principles and presentations, including significant changes in the selection or application of auditing and accounting principles; and (iii) major issues regarding the adequacy of the Corporation's internal controls over financial reporting and disclosure controls and procedures and any specific audit steps adopted in light of material weaknesses or significant deficiencies in such controls; and

c.other material written communication between Management and the Independent Auditor.

5.10    The Committee shall, prior to external release, if applicable, review and discuss with Management and the Independent Auditor, and with others as it deems appropriate:

a.the Corporation's annual audited consolidated and non-consolidated financial statements and interim unaudited condensed consolidated financial statements and the Independent Auditor's related attestation reports, as well as any related MD&As;

b.Management's report and the Independent Auditor's audit report on internal controls over financial reporting;

c.significant reports or summaries thereof pertaining to the Corporation's processes for compliance with the requirements of the Sarbanes Oxley Act of 2002 with respect to internal controls over financial reporting;

d.the Independent Auditor's quarterly review reports and annual audit results report summarizing the scope, status, results and recommendations of the quarterly reviews of the Corporation's interim condensed consolidated financial statements and of the audit of the Corporation's annual consolidated financial statements and related audit of internal controls over financial reporting, and also containing at least: (i) the communications with respect thereto between the Independent Auditor and the Committee required by PCAOB Auditing Standard No. 1301 and any other applicable regulations and professional standards, including without limitation schedules of corrected and uncorrected account and disclosure misstatements and significant deficiencies and material weaknesses in internal controls; (ii) the (at least) annual independence communication required by PCAOB Rule 3526; (iii) the Management representation letter; and (iv) the documentation and communication required

ANNUAL INFORMATION FORM 44 December 31, 2020

quarterly from the Independent Auditor under the Corporation's Pre-Approval Policy for Independent Auditor Services;

e.the report to shareholders contained in the Corporation's annual report; and

f.any other document that the Committee determines should be reviewed and discussed with Management and the Independent Auditor or for which a legal or regulatory requirement in that regard exists.

5.11    The Committee shall, prior to external release, review and discuss with Management and with others as it deems appropriate, the financial information to be disclosed in the Corporation's interim and annual earnings releases or other news releases.

5.12    The Committee shall recommend the Corporation's annual audited consolidated financial statements together with the Independent Auditor's audit report thereon and on internal controls over financial reporting, Management's report on internal controls over financial reporting and disclosure controls and procedures, MD&As, earnings releases, and Reports to Shareholders for approval by the Board and subsequent external release, as well as inclusion of the noted financial statements in the Corporation's annual reports on Form 40-F. The Committee shall approve the external release of the Corporation's interim unaudited condensed consolidated financial statements and related interim MD&As and earnings releases on behalf of the Board.

5.13    The Committee shall, prior to external release, review and discuss with Management and with others as it deems appropriate, and recommend for approval by the Board:

a.any future oriented financial information, financial outlooks, and earnings or dividend guidance to be provided by the Corporation;

b.the Annual Information Form and Management Information Circular to be filed by the Corporation;

c.any prospectus or other offering documents and documents related thereto for the issuance of securities by the Corporation; and

d.other disclosure documents to be released publicly by the Corporation containing or derived from financial information.

5.14    The Committee shall review, discuss with Management and with others as it deems appropriate, the disclosures made by the Chief Executive Officer and Chief Financial Officer of the Corporation pursuant to their certification of the Corporation's annual and quarterly reports regarding significant deficiencies or material weaknesses in the design or operation of internal controls over financial reporting and any alleged fraud involving Management or other employees.

5.15    The Committee shall use reasonable efforts to satisfy itself as to the appropriateness of the Corporation's material financing, capital and tax structures.

5.16    The Committee shall review, discuss with Management and with others as it deems appropriate, financial information provided to analysts and ratings agencies. Such discussions may be in general terms (i.e. discussion of the types of information to be disclosed and the types of presentations to be made) and need not occur in advance of each release of information.

5.17    The Committee shall prepare, or cause to be prepared, any reports of the Committee required to be included in the Corporation's public disclosures or otherwise required by applicable laws.

5.18    The Committee shall review, discuss with Management and with others as it deems appropriate, and approve all Related Party Transactions and the disclosure thereof.

ANNUAL INFORMATION FORM 45 December 31, 2020

C.    Internal Audit

5.19    The Committee shall be responsible for the appointment and oversight of the Internal Auditor in accordance with the Policy on the Role of the Internal Audit Function and has the authority to communicate directly with the Internal Auditor.

5.20    The Committee shall review, discuss with the Internal Auditor and others as it deems appropriate and approve the annual internal audit plan.

5.21    The Committee shall review and discuss with Management and the Internal Auditor and others as it deems appropriate the quarterly internal audit reports prepared for the Committee (which shall incorporate all significant activities of the internal audit function for the quarter) and any Management responses thereto.

5.22    The Committee shall periodically discuss with the Internal Auditor any significant difficulties, disagreements with Management, or scope restrictions encountered in the course of carrying out the work of the internal audit function.

5.23    The Committee shall periodically discuss with the Internal Auditor the internal audit function's responsibility, budget and staffing.

5.24    The Committee shall satisfy itself as to the performance of the internal audit function and the integrity and qualifications of its staff.

D.    Risk Management and Other

5.25    The Committee shall be responsible for the oversight of and reporting to the Board in respect of the ERM Program.

5.26    The Committee shall review and discuss with Management, the Internal Auditor and others as it deems appropriate Management's report regarding identifying, assessing, managing and mitigating significant risks and related matters identified pursuant to the ERM Program.

5.27    The Committee shall review and discuss with Management and others as it deems appropriate the quarterly report prepared by Management regarding significant litigation and other material legal matters that could have a significant impact on the Corporation or its financial statements.

5.28    The Committee shall be responsible for the oversight of the Corporation's insurance programs, any renewals or replacements thereof, including in respect of directors' and officers' insurance and indemnification of Directors.

E.    Policies and Mandate

5.29    The Committee is responsible for the oversight of the following policies:

a.Policy on Reporting Allegations of Suspected Improper Conduct and Wrongdoing (Whistleblower Policy), including overseeing procedures for the receipt, retention, and treatment of complaints regarding accounting, internal controls, or auditing matters as well as procedures for confidential, anonymous submissions by employees regarding questionable accounting or auditing matters as required by applicable law;

b.Derivative Instruments and Hedging Policy;

c.Pre-Approval Policy for Independent Auditor Services;

d.Guidelines for Hiring Employees or Former Employees of the Independent Auditor;

e.Policy on the Role of the Internal Audit Function;

f.Disclosure Policy; and

ANNUAL INFORMATION FORM 46 December 31, 2020

g.other policies that may be established from time-to-time regarding accounting, financial reporting, disclosure controls and procedures, internal controls over financial reporting, oversight of the external audit of the Corporation's financial statements, and oversight of the internal audit function.

5.30    The Committee shall periodically review this Mandate and the policies in Section 5.29 and recommend any necessary amendments to the Governance and Sustainability Committee for consideration and recommendation to the Board for approval, as deemed appropriate.

6.0    REPORTING

6.1    The Chair, or another designated Member, shall report to the Board at each regular meeting on those matters that were dealt with by the Committee since the last regular meeting of the Board.

7.0    REMUNERATION OF MEMBERS

7.1    Members and the Chair shall receive such remuneration for their service on the Committee as the Board may determine from time to time, having considered the recommendation of the Governance and Sustainability Committee.

8.0    GENERAL

8.1    This Mandate shall be posted on the Corporation's corporate website at www.fortisinc.com.

8.2    The Committee shall annually review its own effectiveness and performance.

8.3    The Committee shall perform any other activities consistent with this Mandate, the Corporation's by-laws and applicable laws, that the Board or Committee determines are necessary or appropriate.

8.4    The Committee may, in its discretion and in circumstances that it considers appropriate, obtain advice and assistance from outside legal, accounting and other advisors and approve the engagement by the Committee or any Member of outside advisors or persons having special expertise, all at the expense of the Corporation. The Corporation shall provide appropriate compensation, as determined by the Committee, for the Independent Auditor, to any independent counsel or other advisors that the Committee chooses to engage, and for payment of ordinary administrative expenses of the Committee that are necessary and appropriate in carrying out its duties and responsibilities.

8.5    The Committee is not responsible for certifying the accuracy or completeness of the Corporation's financial statements or their presentation in accordance with generally accepted accounting principles, or for guaranteeing the accuracy of the attestation reports of the Independent Auditor. The fundamental responsibility for the Corporation's financial statements and reporting, internal controls over financial reporting and disclosure controls and processes rests with Management and, in accordance with its professional responsibilities, the Independent Auditor. Nothing in this Mandate is intended to modify or augment the obligations of the Corporation or the fiduciary duties of the members of the Committee or the Board under applicable laws.

ANNUAL INFORMATION FORM 47 December 31, 2020

EXHIBIT D: MATERIAL CONTRACTS

The following are the material contracts of Fortis filed on SEDAR and EDGAR during 2020 or which were entered into prior to 2020 and are still in effect. Requests for additional copies of these material contracts should be directed to the Corporate Secretary, Fortis, P.O. Box 8837, St. John's, NL, A1B 3T2 (telephone: 709.737.2800). All such contracts are also available under the Corporation's profile at www.sedar.com and www.sec.gov.

Revolving Credit Facility

Fortis is a party to a Third Amended and Restated Credit Facility dated July 31, 2017, with The Bank of Nova Scotia as underwriter, sole lead arranger and bookrunner and administrative agent and Canadian Imperial Bank of Commerce and Royal Bank of Canada as co-syndication agents, and the lenders party thereto from time to time, as amended by the First Amending Agreement dated May 11, 2018 and the Second Amending Agreement dated May 13, 2019, each between Fortis, The Bank of Nova Scotia and the lenders named therein. The Third Amended and Restated Credit Facility is a $1.3 billion unsecured committed revolving credit facility and contains the terms and conditions upon which such credit is available to Fortis during the duration of the facility. The Third Amended and Restated Credit Facility contains customary representations and warranties, affirmative and negative covenants and events of default. Customary fees are payable by Fortis in respect of the facility and amounts outstanding under the facility bear interest at market rates.

Amended and Restated Shareholders' Agreement

On January 28, 2021, ITC Investment Holdings, ITC Holdings, FortisUS and Eiffel Investment, an affiliate of GIC, entered into an Amended and Restated Shareholders' Agreement, amending the shareholders' agreement among the parties originally entered into on October 14, 2016. The Amended and Restated Shareholders' Agreement governs the rights of the parties in their respective capacities as direct or indirect shareholders of ITC Holdings.

Under the terms of the Amended and Restated Shareholders' Agreement, Eiffel Investment has certain minority approval rights relating to ITC Investment Holdings and ITC Holdings which depend on (x) whether Eiffel Investment is a holder of Class A common stock or Class B non-voting common stock at the relevant time and (y) the satisfaction by Eiffel Investment of certain ownership thresholds with respect to ITC Investment Holdings. The minority approval rights available to Eiffel Investment contingent on its ITC Investment Holdings share class and percentage ownership include rights with respect to: (i) amendments to charter documents; (ii) changes in board size; (iii) issuances of equity; (iv) business combinations that would impact Eiffel Investment differently than other shareholders; (v) insolvency; (vi) certain acquisitions of, investments in, or joint ventures relating to non-core assets, or certain material sales or dispositions of core assets; (vii) in limited circumstances, the incurrence of indebtedness by ITC Investment Holdings, ITC Holdings or its subsidiaries or the taking of certain actions that would reasonably be expected to result in the long-term unsecured indebtedness of ITC Investment Holdings, ITC Holdings and its subsidiaries being rated below investment grade; (viii) actions that would cause a ratio of ITC Holding's cash flow to debt to exceed an agreed targeted threshold; (ix) limitations on corporate overhead costs paid by ITC Holdings to Fortis; and (x) expansion of the core business outside ITC Holdings' current regulatory jurisdictions. The Amended and Restated Shareholders' Agreement also provides for a dividend policy, which can be amended only with the approval of all the independent directors of ITC Investment Holdings.

Indenture and First Supplemental Indenture

On October 4, 2016, Fortis entered into an Indenture and a First Supplement thereto with The Bank of New York Mellon, as US trustee, and BNY Trust Company of Canada, as Canadian co-trustee. The Indenture and the First Supplement set forth the terms of the Corporation's outstanding US$1.1 billion aggregate principal amount of 3.055% Unsecured Notes due 2026. The Indenture contains customary covenants, events of default and rights for the benefit of security holders and the trustees. An unlimited amount of debt securities may be issued under the Indenture, which is governed by the laws of the State of New York.

ANNUAL INFORMATION FORM 48 December 31, 2020