6-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 6-K

REPORT OF FOREIGN PRIVATE ISSUER

PURSUANT TO RULE 13a-16 OR 15d-16

OF THE SECURITIES EXCHANGE ACT OF 1934

For the month of August 2023

Commission File Number: 001-37915

Fortis Inc.

Fortis Place, Suite 1100

5 Springdale Street

St. John's, Newfoundland and Labrador

Canada, A1E 0E4

(Address of Principal Executive Office)

Indicate by check mark whether the registrant files or will file annual reports under cover of Form 20-F or Form 40F: Form 20-F o Form 40-F þ

INCORPORATION BY REFERENCE

The registrant's unaudited condensed consolidated interim financial statements as at and for the six months ended June 30, 2023, together with the notes thereto, furnished as Exhibit 99.2 to this report on Form 6-K, and the registrant's management discussion and analysis of financial condition and results of operations for the same periods furnished as Exhibit 99.3 to this report on Form 6-K, are incorporated by reference into the following Registration Statements of the Registrant, as amended or supplemented: Form S-8 (File No. 333-264838); Form S-8 (File No. 333-226663); Form S-8 (File No. 333-236213); Form F-3 (File No. 333-249039); and Form F-10 (File No. 333-268493).

EXHIBITS

Exhibit	Description
99.1	Fortis Inc. Press Release dated August 2, 2023
99.2	Unaudited Condensed Consolidated Interim Financial Statements of Fortis Inc. as at and for the six months ended June 30, 2023, together with the notes thereto
99.3	Management Discussion and Analysis of financial condition and results of operations of Fortis Inc. as at and for the six months ended June 30, 2023

SIGNATURES

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

	Fortis Inc. (Registrant)
Date: August 2, 2023	/s/ Jocelyn H. Perry
	By:	Jocelyn H. Perry
	Title:	Executive Vice President, Chief Financial Officer

EX-99.1

Exhibit 99.1

St. John's, NL - August 2, 2023

FORTIS INC. RELEASES SECOND QUARTER 2023 RESULTS

AND SUSTAINABILITY UPDATE REPORT

Fortis Inc. ("Fortis" or the "Corporation") (TSX/NYSE: FTS), a well-diversified leader in the North American regulated electric and gas utility industry, released its second quarter results1 and 2023 Sustainability Update Report.

Highlights

•Second quarter net earnings of $294 million or $0.61 per common share, up from $284 million or $0.59 per common share in 2022

•Adjusted net earnings per common share2 of $0.62, up from $0.57 in the second quarter of 2022

•Capital expenditures2 of $2.0 billion in the first half of 2023; $4.3 billion annual capital plan on track

•2023 Sustainability Update Report released highlighting the Corporation's progress on key sustainability initiatives

•Tucson Electric Power's rate application continues to progress with a decision anticipated in Q3

"We are pleased to report our second quarter results which reflect the growth of our utilities as they continue to execute the 2023 capital plan," said David Hutchens, President and Chief Executive Officer, Fortis. "Our strong financial results demonstrate the success of our regulated growth strategy, and the sale of Aitken Creek, expected to close later this year, reflects our focus on that strategy."

"From an operational perspective, our systems performed well during the quarter, even when faced with extreme weather events in Western Canada," said Mr. Hutchens. "Our 2023 Sustainability Report, released today, highlights progress on our climate, diversity and other ESG priorities. The foundation of our sustainability strategy is to deliver cleaner energy to our customers by making investments in a safe, reliable energy grid without compromising on affordability."

Net Earnings

The Corporation reported net earnings attributable to common equity shareholders ("Net Earnings") of $294 million for the second quarter, or $0.61 per common share, compared to $284 million, or $0.59 per common share for the second quarter of 2022. The increase primarily reflected rate base growth, largely at ITC and the western Canadian utilities. Also contributing to earnings growth was the timing of operating expenses at Central Hudson and FortisAlberta, an increase in the market value of certain investments that support retirement benefits, and a higher U.S.-to-Canadian dollar foreign exchange rate. Growth was tempered by lower earnings in Arizona, mainly driven by a decrease in retail electricity sales due to milder weather and the timing of wholesale sales. Lower earnings from Aitken Creek due to the mark-to-market accounting of natural gas derivatives, as well as higher corporate finance costs, also impacted earnings as compared to the second quarter of 2022. In addition, earnings per share for the quarter reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's dividend reinvestment plan.

On a year-to-date basis, Net Earnings were $731 million, or $1.51 per common share, an increase of $97 million, or $0.18 per common share compared to the same six-month period in 2022. The increase in earnings and earnings per common share reflected the same factors discussed for the quarter, except that UNS Energy and Aitken Creek contributed to earnings growth for the six-month period. Year-to-date results in Arizona reflected favourable margins on long-term wholesale sales and higher transmission revenue, and results for Aitken Creek reflected higher volumes and margins on gas sold.

____________________

1    Financial information is presented in Canadian dollars unless otherwise specified.

2    Non-U.S. GAAP Financial Measures - Fortis uses financial measures that do not have a standardized meaning under generally accepted accounting principles in the United States of America and may not be comparable to similar measures presented by other entities. Fortis presents these non-U.S. GAAP measures because management and external stakeholders use them in evaluating the Corporation's financial performance and prospects. Refer to the Non-U.S. GAAP Reconciliation provided herein.

i

Adjusted Net Earnings2

Adjusted net earnings attributable to common equity shareholders ("Adjusted Net Earnings") excludes the impact of mark-to-market accounting of natural gas derivatives at Aitken Creek. Adjusted Net Earnings of $302 million for the second quarter, or $0.62 per common share, were $30 million, or $0.05 per common share higher than the same period in 2022. On a year-to-date basis, Adjusted Net Earnings were $741 million, or $1.53 per common share, an increase of $100 million, or $0.19 per common share compared to the same six-month period in 2022. The increase for the quarter and year-to-date periods reflected the same factors discussed for Net Earnings, except that there was an increase in adjusted earnings at Aitken Creek for both the quarter and year-to-date periods due to higher margins on gas sold.

Non-U.S. GAAP Reconciliation
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Adjusted Net Earnings:
Net Earnings	294	284	10	731	634	97
Adjusting item:
Unrealized loss (gain) on mark-to-market of derivatives3	8	(12)	20	10	7	3
Adjusted Net Earnings	302	272	30	741	641	100
Adjusted net earnings per share ($)	0.62	0.57	0.05	1.53	1.34	0.19
Capital Expenditures:
Additions to property, plant and equipment	938	827	111	1,845	1,693	152
Additions to intangible assets	44	58	(14)	91	107	(16)
Adjusting item:
Wataynikaneyap Transmission Power Project4	43	45	(2)	84	94	(10)
Capital Expenditures	1,025	930	95	2,020	1,894	126

Capital Expenditures

Our $4.3 billion annual capital plan is on track with $2.0 billion invested during the first half of 2023.

The Corporation's major capital projects continue to progress. In May 2023, FortisBC Energy received approval from the British Columbia Utilities Commission ("BCUC") for its Advanced Metering Infrastructure project. The project includes replacement of residential and small commercial meters with advanced meters to support the safety, resiliency, and efficient operation of the gas distribution system. The project is expected to commence in the second half of 2023.

FortisBC Energy also received approval from the BCUC in May 2023 for amended transportation rate schedules for the Eagle Mountain Woodfibre Gas Line project. This approval brings the project one-step closer to commencement of construction. FortisBC Energy continues to receive deposit funding from Woodfibre LNG Limited for development expenditures to be incurred for the project.

The Corporation's potential growth opportunities outside of the capital plan includes Central Hudson's minority equity interest in New York Transco LLC ("Transco"), a joint venture with affiliates of other investor-owned utilities in New York State, which was created to develop, own, and operate electric transmission projects in the state. In June 2023, the New York Independent System Operator selected a proposal by Transco, in partnership with the New York Power Authority, to construct transmission infrastructure to deliver at least 3,000 MW from Long Island offshore wind facilities to the rest of the state by 2030. Transco's portion of the project is estimated to cost approximately US$2.2 billion, of which Central Hudson will contribute approximately 10%.

____________________

3    Represents timing differences related to the accounting of natural gas derivatives at Aitken Creek, net of income tax recovery of $3 million and $4 million for the three and six months ended June 30, 2023, respectively (income tax expense of $5 million and income tax recovery of $3 million for the three and six months ended June 30, 2022, respectively)

4    Represents Fortis' 39% share of capital spending for the Wataynikaneyap Transmission Power Project

ii

Sustainability

The Corporation released its 2023 Sustainability Update Report today, which summarizes recent progress and includes key performance indicators for 2022. Fortis utilities continue to add new renewable energy resources and decarbonize operations while advancing a cleaner energy transition for customers. The Corporation has reduced direct greenhouse gas ("GHG") emissions by 29% through 2022 compared to 2019 levels, marking significant progress towards our interim targets to reduce GHG emissions 50% by 2030 and 75% by 2035, as well as our 2050 net-zero direct GHG emissions target. In addition, over the last four years, the GHG intensity of delivered energy has consistently decreased, while net electricity generated by renewable sources and avoided emissions from the use of renewable natural gas has increased significantly.

The report highlights Fortis' advancements in diversity, equity and inclusion ("DEI"). The Corporation has achieved its Board of Director diversity targets, with 58% of the board comprised of women and two of twelve members identifying as visible minorities. Our commitment to advancing DEI is reflected in our leadership at Fortis Inc., where 50% of our executive team are women. In addition, to further support Fortis' sustainability reporting, limited third-party assurance was obtained on select 2022 GHG emissions data and board diversity metrics.

As we transition to a cleaner energy future, customer affordability, safety and reliability remain top priorities and are the cornerstones of our sustainability strategy. Fortis utilities continue to focus on controlling costs, identifying efficiencies and implementing innovative practices to maintain affordability.

The 2023 Sustainability Update Report can be accessed atwww.fortisinc.com/sustainability/sustainability-reporting.

Regulatory Updates

In May 2023, the Arizona Corporation Commission ("ACC") approved rate adjustments at Tucson Electric Power ("TEP") and UNS Electric, Inc. to collect the purchase power fuel adjustor clause balances over 12- and 33-month periods, respectively.

In July 2023, the administrative law judge issued a recommended opinion and order on TEP's general rate application, recommending an increase in non-fuel revenue of US$102 million, a 9.4% ROE with a 0.2% return on the fair value increment, and a 54.32% common equity component of capital structure. A decision from the ACC is expected in the third quarter of 2023.

Central Hudson filed a rate application with the New York State Public Service Commission in July 2023, requesting an increase in electric and gas delivery rates effective July 1, 2024. The application requests an allowed ROE of 9.8% and a 50% common equity component of capital structure. The timing and outcome of this proceeding is unknown.

Outlook

Fortis continues to enhance shareholder value through the execution of its capital plan, the balance and strength of its diversified portfolio of regulated utility businesses, and growth opportunities within and proximate to its service territories. While energy price volatility, global supply chain constraints, increasing interest rates and inflation represent potential concerns, the Corporation does not expect these factors to have a material impact on its operations or financial results in 2023.

Fortis is executing on the transition to a cleaner energy future and is on track to achieve its corporate-wide targets to reduce GHG emissions by 50% by 2030 and 75% by 2035. The Corporation's additional 2050 net-zero direct GHG emissions target reinforces Fortis' commitment to further decarbonize over the long-term, while preserving customer reliability and affordability.

The Corporation's $22.3 billion five-year capital plan is expected to increase midyear rate base from $34.1 billion in 2022 to $46.1 billion by 2027, translating into a five-year compound annual growth rate of 6.2%5.

Beyond the five-year capital plan, additional opportunities to expand and extend growth include: further expansion of the electric transmission grid in the U.S. to facilitate the interconnection of cleaner energy, including infrastructure investments associated with the Inflation Reduction Act of 2022 and the Midcontinent Independent System Operator, Inc. long-range transmission plan; climate adaptation and grid resiliency investments; renewable gas solutions and liquefied natural gas infrastructure in British Columbia; and the acceleration of cleaner energy infrastructure investments across our jurisdictions.

Fortis expects its long-term growth in rate base will drive earnings that support dividend growth guidance of 4-6% annually through 2027, and is premised on the assumptions and material factors listed under "Forward-Looking Information".

_______________________

5    Calculated using a constant United States dollar-to-Canadian dollar exchange rate

iii

About Fortis

Fortis is a well-diversified leader in the North American regulated electric and gas utility industry with 2022 revenue of $11 billion and total assets of $64 billion as at June 30, 2023. The Corporation's 9,200 employees serve utility customers in five Canadian provinces, ten U.S. states and three Caribbean countries.

Forward-Looking Information

Fortis includes forward-looking information in this media release 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 and 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 2023-2027; the expected timing and outcome of the sale of Aitken Creek; the 2030 GHG emissions reduction target; the 2035 GHG emissions reduction target; the 2050 net-zero direct GHG emissions target; the expected timing, outcome and impact of regulatory proceedings and decisions; the expectation that energy price volatility, global supply chain constraints, increasing interest rates and inflation will not have a material impact on operations or financial results in 2023; forecast rate base and rate base growth through 2027; the nature, timing, benefits and expected costs of certain capital projects, including FortisBC Energy's Advanced Metering Infrastructure project and the Eagle Mountain Woodfibre Gas Line Project, and additional opportunities beyond the capital plan, including Central Hudson's investment in the Propel New York Energy project through Transco, investments related to the Inflation Reduction Act of 2022, the Midcontinent Independent System Operator, Inc. long-range transmission plan, climate adaptation and grid resiliency, renewable gas solutions and liquefied natural gas infrastructure in British Columbia, and the acceleration of cleaner energy infrastructure; and the expectation that long-term growth in rate base will drive earnings that support dividend growth guidance of 4-6% annually through 2027.

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 impact from energy price volatility, global supply chain constraints and inflation; reasonable outcomes for regulatory proceedings and the expectation of regulatory stability; the successful execution of the capital plan; no material capital project and financing cost overrun; sufficient human resources to deliver service and execute the capital plan; the realization of additional opportunities beyond the capital plan; no significant variability in interest rates; no material changes in the assumed U.S. dollar to Canadian dollar exchange rate; and the Board exercising its discretion to declare dividends, taking into account the business performance and financial condition of the Corporation. Fortis cautions readers that a number of factors could cause actual results, performance or achievements to differ materially from the results discussed or implied in the forward-looking information. For additional information with respect to certain risk factors, reference should be made to the continuous disclosure materials filed from time to time by the Corporation with Canadian securities regulatory authorities and the Securities and Exchange Commission. All forward-looking information herein is given as of the date of this media release. 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.

Teleconference and Webcast to Discuss Second Quarter 2023 Results

A teleconference and webcast will be held on August 2, 2023 at 8:30 a.m. (Eastern) during which David Hutchens, President and Chief Executive Officer and Jocelyn Perry, Executive Vice President and Chief Financial Officer will discuss the Corporation's second quarter financial results.

Shareholders, analysts, members of the media and other interested parties are invited to listen to the teleconference via the live webcast on the Corporation's website, www.fortisinc.com/investor-relations/events-and-presentations.

Those members of the financial community in North America wishing to ask questions during the call are invited to participate toll free by calling 1.888.886.7786 while those outside of North America can participate by calling 1.416.764.8658. Please dial in 10 minutes prior to the start of the call. No passcode is required.

An archived audio webcast of the teleconference will be available on the Corporation's website and will be available two hours after the conclusion of the call until September 2, 2023. Please call 1.877.674.7070 or 1.416.764.8692 and enter passcode 928966#.

iv

Additional Information

This media release should be read in conjunction with the Corporation's June 30, 2023 Interim Management Discussion and Analysis and Condensed Consolidated Financial Statements. This and additional information can be accessed at www.fortisinc.com, www.sedarplus.ca, or www.sec.gov.

For more information, please contact:

Investor Enquiries	Media Enquiries
Ms. Stephanie Amaimo	Ms. Karen McCarthy
Vice President, Investor Relations	Vice President, Communications & Government Relations
Fortis Inc.	Fortis Inc.
248.946.3572	709.737.5323
investorrelations@fortisinc.com	media@fortisinc.com

v

EX-99.2

Exhibit 99.2

Interim Financial Statements

FORTIS INC.

Condensed Consolidated Interim Financial Statements

For the three and six months ended June 30, 2023 and 2022

(Unaudited)

1 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM BALANCE SHEETS (Unaudited)
FORTIS INC.
	June 30,		December 31,
As at (in millions of Canadian dollars)	2023		2022
ASSETS
Current assets
Cash and cash equivalents	$	690	$	209
Accounts receivable and other current assets (Note 5)	1,580		2,339
Prepaid expenses	162		146
Inventories	534		661
Regulatory assets (Note 6)	730		914
Assets held for sale (Note 7)	561		—
Total current assets	4,257		4,269
Other assets	1,146		1,213
Regulatory assets (Note 6)	3,226		3,095
Property, plant and equipment, net	41,777		41,663
Intangible assets, net	1,492		1,548
Goodwill	12,183		12,464
Total assets	$	64,081	$	64,252
LIABILITIES AND EQUITY
Current liabilities
Short-term borrowings (Note 8)	$	80	$	253
Accounts payable and other current liabilities	2,432		3,288
Regulatory liabilities (Note 6)	489		595
Current installments of long-term debt (Note 8)	2,284		2,481
Liabilities associated with assets held for sale (Note 7)	129		—
Total current liabilities	5,414		6,617
Regulatory liabilities (Note 6)	3,228		3,320
Deferred income taxes	4,018		4,060
Long-term debt (Note 8)	26,808		25,931
Finance leases	335		336
Other liabilities	1,101		1,146
Total liabilities	40,904		41,410
Commitments and contingencies (Note 14)
Equity
Common shares (1)	14,889		14,656
Preference shares	1,623		1,623
Additional paid-in capital	8		10
Accumulated other comprehensive income	669		1,008
Retained earnings	4,190		3,733
Shareholders' equity	21,379		21,030
Non-controlling interests	1,798		1,812
Total equity	23,177		22,842
Total liabilities and equity	$	64,081	$	64,252

(1)    No par value. Unlimited authorized shares. 486.4 million and 482.2 million issued and outstanding as at June 30, 2023 and December 31, 2022, respectively.

See accompanying Notes to Condensed Consolidated Interim Financial Statements

2 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF EARNINGS (Unaudited)
FORTIS INC.
	Quarter				Year-to-Date
For the periods ended June 30 (in millions of Canadian dollars, except per share amounts)	2023		2022		2023		2022
Revenue	$	2,594	$	2,487	$	5,913	$	5,322
Expenses
Energy supply costs	787		797		2,099		1,880
Operating expenses	713		659		1,454		1,328
Depreciation and amortization	440		417		876		824
Total expenses	1,940		1,873		4,429		4,032
Operating income	654		614		1,484		1,290
Other income, net (Note 10)	64		35		133		77
Finance charges	323		266		638		524
Earnings before income tax expense	395		383		979		843
Income tax expense	49		53		149		120
Net earnings	$	346	$	330	$	830	$	723
Net earnings attributable to:
Non-controlling interests	$	35	$	30	$	66	$	57
Preference equity shareholders	17		16		33		32
Common equity shareholders	294		284		731		634
	$	346	$	330	$	830	$	723
Earnings per common share (Note 11)
Basic	$	0.61	$	0.59	$	1.51	$	1.33
Diluted	$	0.61	$	0.59	$	1.51	$	1.33
See accompanying Notes to Condensed Consolidated Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF COMPREHENSIVE INCOME (Unaudited)
	Quarter				Year-to-Date
For the periods ended June 30 (in millions of Canadian dollars)	2023		2022		2023		2022
Net earnings	$	346	$	330	$	830	$	723
Other comprehensive (loss) income
Unrealized foreign currency translation (losses) gains (1)	(339)		448		(383)		287
Other (2)	5		4		3		24
	(334)		452		(380)		311
Comprehensive income	$	12	$	782	$	450	$	1,034
Comprehensive income attributable to:
Non-controlling interests	$	(1)	$	79	$	25	$	93
Preference equity shareholders	17		16		33		32
Common equity shareholders	(4)		687		392		909
	$	12	$	782	$	450	$	1,034

(1)Net of hedging activities and income tax expense of $6 million for the three and six months ended June 30, 2023 (three and six months ended June 30, 2022 - income tax recovery of $4 million and $3 million, respectively)

(2)Net of income tax expense of $2 million for the three and six months ended June 30, 2023 (three and six months ended June 30, 2022 - income tax expense of $2 million and $10 million, respectively)

See accompanying Notes to Condensed Consolidated Interim Financial Statements

3 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CASH FLOWS (Unaudited)
FORTIS INC.
		Quarter				Year-to-Date
For the periods ended June 30 (in millions of Canadian dollars)		2023		2022		2023		2022
Operating activities
Net earnings		$	346	$	330	$	830	$	723
Adjustments to reconcile net earnings to net cash provided by operating activities:
	Depreciation - property, plant and equipment	381		366		759		722
	Amortization - intangible assets	38		36		76		71
	Amortization - other	21		15		41		31
	Deferred income tax expense	24		32		55		55
	Equity component, allowance for funds used during construction (Note 10)	(23)		(18)		(46)		(35)
	Other	43		14		49		54
Change in long-term regulatory assets and liabilities		(103)		24		(82)		14
Change in working capital (Note 12)		217		(40)		177		(63)
Cash from operating activities		944		759		1,859		1,572
Investing activities
Additions to property, plant and equipment		(938)		(827)		(1,845)		(1,693)
Additions to intangible assets		(44)		(58)		(91)		(107)
Contributions in aid of construction		20		22		71		61
Other		(51)		(55)		(89)		(95)
Cash used in investing activities		(1,013)		(918)		(1,954)		(1,834)
Financing activities
Proceeds from long-term debt, net of issuance costs		1,247		816		1,881		1,645
Repayments of long-term debt and finance leases		(364)		(609)		(697)		(836)
Borrowings under committed credit facilities		1,972		1,562		3,875		2,986
Repayments under committed credit facilities		(2,201)		(1,552)		(3,938)		(3,152)
Net change in short-term borrowings		(273)		82		(165)		158
Issue of common shares, net of costs and dividends reinvested		14		18		28		40
Dividends
	Common shares, net of dividends reinvested	(172)		(164)		(342)		(324)
	Preference shares	(17)		(16)		(33)		(32)
	Subsidiary dividends paid to non-controlling interests	(17)		(11)		(40)		(31)
Other		20		(2)		28		7
Cash from financing activities		209		124		597		461
Effect of exchange rate changes on cash and cash equivalents		(7)		8		(2)		8
Change in cash and cash equivalents		133		(27)		500		207
Change in cash associated with assets held for sale (Note 7)		(19)		—		(19)		—
Cash and cash equivalents, beginning of period		576		365		209		131
Cash and cash equivalents, end of period		$	690	$	338	$	690	$	338
Supplementary Cash Flow Information (Note 12)
See accompanying Notes to Condensed Consolidated Interim Financial Statements

4 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CHANGES IN EQUITY (Unaudited)
FORTIS INC.
For the three months ended June 30 (in millions of Canadian dollars, except share numbers)	Common Shares (# millions)	Common Shares		Preference Shares		Additional Paid-In Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings		Non-Controlling Interests		Total Equity
As at March 31, 2023	484.4	$	14,773	$	1,623	$	8	$	967	$	3,896	$	1,816	$	23,083
Net earnings	—	—		—		—		—		311		35		346
Other comprehensive loss	—	—		—		—		(298)		—		(36)		(334)
Common shares issued	2.0	116		—		(1)		—		—		—		115
Subsidiary dividends paid to non-controlling interests	—	—		—		—		—		—		(17)		(17)
Dividends on preference shares	—	—		—		—		—		(17)		—		(17)
Other	—	—		—		1		—		—		—		1
As at June 30, 2023	486.4	$	14,889	$	1,623	$	8	$	669	$	4,190	$	1,798	$	23,177
As at March 31, 2022	476.9	$	14,354	$	1,623	$	8	$	(168)	$	3,553	$	1,624	$	20,994
Net earnings	—	—		—		—		—		300		30		330
Other comprehensive income	—	—		—		—		403		—		49		452
Common shares issued	1.8	111		—		(1)		—		—		—		110
Subsidiary dividends paid to non-controlling interests	—	—		—		—		—		—		(11)		(11)
Dividends on preference shares	—	—		—		—		—		(16)		—		(16)
Other	—	—		—		1		—		—		—		1
As at June 30, 2022	478.7	$	14,465	$	1,623	$	8	$	235	$	3,837	$	1,692	$	21,860
See accompanying Notes to Condensed Consolidated Interim Financial Statements

5 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Financial Statements

CONDENSED CONSOLIDATED INTERIM STATEMENTS OF CHANGES IN EQUITY (Unaudited)
FORTIS INC.
For the six months ended June 30 (in millions of Canadian dollars, except share numbers)	Common Shares (# millions)	Common Shares		Preference Shares		Additional Paid-In Capital		Accumulated Other Comprehensive Income (Loss)		Retained Earnings		Non-Controlling Interests		Total Equity
As at December 31, 2022	482.2	$	14,656	$	1,623	$	10	$	1,008	$	3,733	$	1,812	$	22,842
Net earnings	—	—		—		—		—		764		66		830
Other comprehensive loss	—	—		—		—		(339)		—		(41)		(380)
Common shares issued	4.2	233		—		(1)		—		—		—		232
Subsidiary dividends paid to non-controlling interests	—	—		—		—		—		—		(40)		(40)
Dividends declared on common shares ($0.565 per share)	—	—		—		—		—		(274)		—		(274)
Dividends on preference shares	—	—		—		—		—		(33)		—		(33)
Other	—	—		—		(1)		—		—		1		—
As at June 30, 2023	486.4	$	14,889	$	1,623	$	8	$	669	$	4,190	$	1,798	$	23,177
As at December 31, 2021	474.8	$	14,237	$	1,623	$	10	$	(40)	$	3,458	$	1,628	$	20,916
Net earnings	—	—		—		—		—		666		57		723
Other comprehensive income	—	—		—		—		275		—		36		311
Common shares issued	3.9	228		—		(2)		—		—		—		226
Subsidiary dividends paid to non-controlling interests	—	—		—		—		—		—		(31)		(31)
Dividends declared on common shares ($0.535 per share)	—	—		—		—		—		(255)		—		(255)
Dividends on preference shares	—	—		—		—		—		(32)		—		(32)
Other	—	—		—		—		—		—		2		2
As at June 30, 2022	478.7	$	14,465	$	1,623	$	8	$	235	$	3,837	$	1,692	$	21,860
See accompanying Notes to Condensed Consolidated Interim Financial Statements

6 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

1. DESCRIPTION OF BUSINESS

Nature of Operations

Fortis Inc. ("Fortis" or the "Corporation") is a well-diversified North American regulated electric and gas utility holding company.

Earnings for interim periods may not be indicative of annual results due to: (i) the impact of seasonal weather conditions on customer demand and market pricing; (ii) the impact of market conditions, particularly with respect to long-term wholesale sales and transmission revenue at UNS Energy, as well as margins realized on gas sold at Aitken Creek; (iii) changes in foreign exchange rates; and (iv) the timing and significance of regulatory decisions. Earnings of the gas utilities tend to be highest in the first and fourth quarters due to space-heating requirements. Earnings of the electric distribution utilities in the U.S. tend to be highest in the second and third quarters due to the use of air conditioning and other cooling equipment.

Entities within the reporting segments that follow operate with substantial autonomy.

Regulated Utilities

ITC: ITC Investment Holdings Inc., ITC Holdings Corp. and the electric transmission operations of its regulated operating subsidiaries, which include International Transmission Company, Michigan Electric Transmission Company, LLC, ITC Midwest LLC ("ITC Midwest") and ITC Great Plains, LLC. Fortis owns 80.1% of ITC and an affiliate of GIC Private Limited owns a 19.9% minority interest.

UNS Energy: UNS Energy Corporation, which primarily includes Tucson Electric Power Company ("TEP"), UNS Electric, Inc. ("UNSE") and UNS Gas, Inc.

Central Hudson: CH Energy Group, Inc., which primarily includes Central Hudson Gas & Electric Corporation.

FortisBC Energy: FortisBC Energy Inc.

FortisAlberta: FortisAlberta Inc.

FortisBC Electric: FortisBC Inc.

Other Electric: Eastern Canadian and Caribbean utilities, as follows: Newfoundland Power Inc.; Maritime Electric Company, Limited; FortisOntario Inc.; a 39% equity investment in Wataynikaneyap Power Limited Partnership; an approximate 60% controlling interest in Caribbean Utilities Company, Ltd. ("Caribbean Utilities"); FortisTCI Limited and Turks and Caicos Utilities Limited (collectively "FortisTCI"); and a 33% equity investment in Belize Electricity Limited ("Belize Electricity").

Non-Regulated

Energy Infrastructure: Long-term contracted generation assets in Belize and the Aitken Creek natural gas storage facility ("Aitken Creek") in British Columbia (Note 7).

Corporate and Other: Captures expenses and revenues 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 and non-regulated holding company expenses.

2. REGULATORY MATTERS

Regulation of the Corporation's utilities is generally consistent with that disclosed in Note 2 of the Corporation's annual audited consolidated financial statements ("2022 Annual Financial Statements"). A summary of significant outstanding regulatory matters follows.

ITC

ITC Midwest Capital Structure Complaint: In 2022, FERC issued an order denying the complaint filed by the Iowa Coalition for Affordable Transmission ("ICAT") requesting that ITC Midwest's common equity component of capital structure be reduced from 60% to 53%. In March 2023, FERC confirmed its decision following ICAT's request for rehearing.

MISO Base ROE: In 2022, the U.S. Court of Appeals for the District of Columbia Circuit issued a decision vacating certain FERC orders that had established the methodology for setting the base return on equity ("ROE") for transmission owners operating in the Midcontinent Independent System Operator, Inc. ("MISO") region, including ITC. This matter dates back to complaints filed at FERC in 2013 and 2015 challenging the MISO base ROE then in effect. The court has remanded the matter to FERC for further process, the timing and outcome of which is unknown.

Transmission Incentives: In 2021, FERC issued a supplemental notice of proposed rulemaking ("NOPR") on transmission incentives modifying the proposal in the initial NOPR released by FERC in 2020. The supplemental NOPR proposes to eliminate the 50-basis point regional transmission organization ("RTO") ROE incentive adder for RTO members that have been members for longer than three years. The timing and outcome of this proceeding is unknown.

7 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

2. REGULATORY MATTERS (cont'd)

Transmission Right of First Refusal ("ROFR"): The State of Iowa has granted incumbent electric transmission owners, including ITC, a ROFR to construct, own and maintain certain electric transmission assets in the state. A challenge against the ROFR statute by certain plaintiffs was initially dismissed by the District Court on the grounds that the plaintiffs lacked standing. In March 2023, the Iowa Supreme Court determined that the plaintiffs have standing to challenge the Iowa ROFR statute, issued a temporary injunction staying enforcement of the ROFR statute, and remanded the matter to the District Court to decide the merits of the claim. Management does not believe that this proceeding will impact projects that have already been approved and under development; however, the timing of this proceeding and any impact on future projects, is unknown.

UNS Energy

TEP General Rate Application: In July 2023, the Administrative Law Judge ("ALJ") issued a recommended opinion and order on TEP's general rate application recommending, among other things, an increase in non-fuel revenue of US$102 million, a 9.4% ROE with a 0.2% return on the fair value increment, and a 54.32% common equity component of capital structure. TEP's existing ROE and common equity component of capital structure is 9.15% and 53%, respectively. While the timing and outcome of this proceeding is unknown, the ALJ recommended that the new rates become effective on or after September 1, 2023.

PPFAC Mechanism: The Purchased Power and Fuel Adjustment Clause ("PPFAC") mechanism allows for the timely recovery or return of purchased power and fuel costs, as compared to that collected in customer rates, at TEP and UNSE. The PPFAC balance has increased in recent years, reflecting higher commodity costs. In May 2023, the ACC approved rate adjustments at TEP and UNSE to collect the PPFAC balances over 12- and 33-month periods, respectively.

Central Hudson

General Rate Application: In July 2023, Central Hudson filed a rate application with the New York Public Service Commission ("PSC") requesting an increase in electric and gas delivery rates effective July 1, 2024. The application includes a request to set Central Hudson's allowed ROE at 9.8% and a 50% common equity component of capital structure. The timing and outcome of this proceeding is unknown.

Customer Information System ("CIS") Implementation: In January 2023, Central Hudson filed a response to the PSC's Order to Commence Proceeding and Show Cause, which had directed Central Hudson to explain why the PSC should not pursue civil or administrative penalties or initiate a proceeding to review the prudence of implementation costs associated with its new CIS. In July 2023, an interim agreement was reached with the PSC, in which Central Hudson agreed to independent third-party verification of recent system improvements related to its billing system, and to accelerate the implementation of its monthly meter reading plan. The timing and outcome of this proceeding remains unknown.

FortisBC Energy and FortisBC Electric

Generic Cost of Capital ("GCOC") Proceeding: In 2021, the British Columbia Utilities Commission ("BCUC") initiated a proceeding including a review of the common equity component of capital structure and the allowed ROE. FortisBC filed a final argument with the BCUC in December 2022 and the proceeding remains ongoing, with a decision expected in the third quarter 2023. The decision could be effective retroactively to January 1, 2023.

FortisAlberta

2024 GCOC Proceeding: In 2022, the Alberta Utilities Commission ("AUC") initiated proceedings to establish the cost of capital parameters for Alberta regulated utilities, including consideration of a formula-based approach to setting the allowed ROE for 2024 and beyond. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

Third PBR Term: In 2021, the AUC issued a decision confirming that Alberta distribution utilities will be subject to a third performance-based rate setting ("PBR") term commencing in 2024. The AUC also initiated a new proceeding to consider the design of the third PBR term. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

Rural Electrification Association ("REA") Cost Recovery: In 2021, the AUC determined that costs attributable to REAs, approximating $10 million annually, can no longer be recovered from FortisAlberta's rate payers, effective January 1, 2023. In April 2023, the Alberta Court of Appeal dismissed FortisAlberta's appeal which had asserted that the AUC erred in preventing the company from recovering these costs from its own rate payers to the extent that such costs cannot be recovered directly from REAs. FortisAlberta continues to assess other means, including legislative amendments, to recover these costs.

3. ACCOUNTING POLICIES

These condensed consolidated interim financial statements ("Interim Financial Statements") have been prepared and presented in accordance with accounting principles generally accepted in the United States of America for rate-regulated entities and are in Canadian dollars unless otherwise indicated.

The Interim Financial Statements include the accounts of the Corporation and its subsidiaries and reflect the equity method of accounting for entities in which Fortis has significant influence, but not control, and proportionate consolidation for assets that are jointly owned with non-affiliated entities.

Intercompany transactions have been eliminated, except for transactions between non-regulated and regulated entities in accordance with U.S. GAAP for rate-regulated entities.

8 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

3. ACCOUNTING POLICIES (cont'd)

These Interim Financial Statements do not include all of the disclosures required in the annual financial statements and should be read in conjunction with the Corporation's 2022 Annual Financial Statements. In management's opinion, these Interim Financial Statements include all adjustments that are of a normal recurring nature, necessary for fair presentation.

The preparation of the Interim Financial Statements required management to make estimates and judgments, including those related to regulatory decisions, that affect the reported amounts of, and disclosures related to, assets, liabilities, revenues, expenses, gains, losses and contingencies. Actual results could differ materially from estimates.

The accounting policies applied herein are consistent with those outlined in the Corporation's 2022 Annual Financial Statements.

Future Accounting Pronouncements

The Corporation considers the applicability and impact of all Accounting Standards Updates ("ASUs") issued by the Financial Accounting Standards Board. Any ASUs not included in these Interim Financial Statements were assessed and determined to be either not applicable to the Corporation or are not expected to have a material impact on the Interim Financial Statements.

4. SEGMENTED INFORMATION

Fortis segments its business based on regulatory jurisdiction and service territory, as well as the information used by its President and Chief Executive Officer in deciding how to allocate resources. Segment performance is evaluated principally on net earnings attributable to common equity shareholders.

Related-Party and Inter-Company Transactions

Related-party transactions are in the normal course of operations and are measured at the amount of consideration agreed to by the related parties. There were no material related-party transactions for the three and six months ended June 30, 2023 and 2022.

The lease of gas storage capacity and gas sales from Aitken Creek to FortisBC Energy of $6 million and $15 million for the three and six months ended June 30, 2023, respectively (three and six months ended June 30, 2022 - $7 million and $20 million, respectively) are inter-company transactions between non-regulated and regulated entities, which were not eliminated on consolidation.

As at June 30, 2023, accounts receivable included $4 million due from Belize Electricity (December 31, 2022 - $7 million).

Fortis periodically provides short-term financing to subsidiaries to support capital expenditures and seasonal working capital requirements, the impacts of which are eliminated on consolidation. As at June 30, 2023 and December 31, 2022, there were no inter-segment loans outstanding. Interest charged on inter-segment loans was not material for the three and six months ended June 30, 2023 and 2022.

9 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

4. SEGMENTED INFORMATION (cont'd)

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Quarter ended June 30, 2023
Revenue	519	661	317	362	181	116	420	2,576	18	—	—	2,594
Energy supply costs	—	262	121	141	—	22	241	787	—	—	—	787
Operating expenses	125	204	144	91	44	31	56	695	10	8	—	713
Depreciation and amortization	103	88	28	78	67	24	51	439	1	—	—	440
Operating income	291	107	24	52	70	39	72	655	7	(8)	—	654
Other income, net	19	12	13	9	3	1	5	62	—	2	—	64
Finance charges	105	37	15	43	30	19	21	270	—	53	—	323
Income tax expense	49	12	5	(5)	2	3	8	74	1	(26)	—	49
Net earnings	156	70	17	23	41	18	48	373	6	(33)	—	346
Non-controlling interests	29	—	—	—	—	—	6	35	—	—	—	35
Preference share dividends	—	—	—	—	—	—	—	—	—	17	—	17
Net earnings attributable to common equity shareholders	127	70	17	23	41	18	42	338	6	(50)	—	294
Additions to property, plant and equipment and intangible assets	264	183	78	125	182	35	115	982	—	—	—	982
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Quarter ended June 30, 2022
Revenue	468	648	281	396	169	108	384	2,454	33	—	—	2,487
Energy supply costs	—	272	101	181	—	18	224	796	1	—	—	797
Operating expenses	120	167	143	88	42	33	52	645	8	6	—	659
Depreciation and amortization	94	92	26	75	61	17	47	412	4	1	—	417
Operating income	254	117	11	52	66	40	61	601	20	(7)	—	614
Other income, net	10	3	15	5	—	1	1	35	—	—	—	35
Finance charges	83	30	13	35	28	19	19	227	—	39	—	266
Income tax expense	41	13	3	5	3	3	6	74	1	(22)	—	53
Net earnings	140	77	10	17	35	19	37	335	19	(24)	—	330
Non-controlling interests	26	—	—	—	—	—	4	30	—	—	—	30
Preference share dividends	—	—	—	—	—	—	—	—	—	16	—	16
Net earnings attributable to common equity shareholders	114	77	10	17	35	19	33	305	19	(40)	—	284
Additions to property, plant and equipment and intangible assets	272	159	65	134	119	30	100	879	6	—	—	885
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

10 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

4. SEGMENTED INFORMATION (cont'd)

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Year-to-date June 30, 2023
Revenue	1,038	1,401	759	1,117	360	255	927	5,857	56	—	—	5,913
Energy supply costs	—	599	328	518	—	69	585	2,099	—	—	—	2,099
Operating expenses	260	394	306	189	86	61	116	1,412	20	22	—	1,454
Depreciation and amortization	204	175	56	155	131	48	101	870	5	1	—	876
Operating income	574	233	69	255	143	77	125	1,476	31	(23)	—	1,484
Other income, net	36	26	27	16	3	2	12	122	—	11	—	133
Finance charges	204	73	33	84	60	39	42	535	—	103	—	638
Income tax expense	96	26	14	40	5	4	14	199	7	(57)	—	149
Net earnings	310	160	49	147	81	36	81	864	24	(58)	—	830
Non-controlling interests	57	—	—	—	—	—	9	66	—	—	—	66
Preference share dividends	—	—	—	—	—	—	—	—	—	33	—	33
Net earnings attributable to common equity shareholders	253	160	49	147	81	36	72	798	24	(91)	—	731
Additions to property, plant and equipment and intangible assets	600	368	156	239	301	62	208	1,934	2	—	—	1,936
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Year-to-date June 30, 2022
Revenue	928	1,186	656	1,090	336	237	843	5,276	46	—	—	5,322
Energy supply costs	—	482	263	535	—	61	536	1,877	3	—	—	1,880
Operating expenses	243	329	292	171	84	66	105	1,290	20	18	—	1,328
Depreciation and amortization	186	181	51	150	121	34	91	814	8	2	—	824
Operating income	499	194	50	234	131	76	111	1,295	15	(20)	—	1,290
Other income, net	19	6	30	9	1	3	3	71	—	6	—	77
Finance charges	163	61	26	71	54	37	37	449	—	75	—	524
Income tax expense	82	19	12	36	7	5	11	172	2	(54)	—	120
Net earnings	273	120	42	136	71	37	66	745	13	(35)	—	723
Non-controlling interests	50	—	—	—	—	—	7	57	—	—	—	57
Preference share dividends	—	—	—	—	—	—	—	—	—	32	—	32
Net earnings attributable to common equity shareholders	223	120	42	136	71	37	59	688	13	(67)	—	634
Additions to property, plant and equipment and intangible assets	607	321	129	264	230	60	178	1,789	11	—	—	1,800
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

11 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

5. ALLOWANCE FOR CREDIT LOSSES

The allowance for credit losses balance, which is recorded in accounts receivable and other current assets, changed as follows.

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Balance, beginning of period	(59)	(53)	(58)	(53)
Credit loss expense	(3)	(5)	(11)	(10)
Credit loss deferral	(2)	—	(3)	—
Write-offs, net of recoveries	4	6	12	11
Foreign exchange	—	(1)	—	(1)
Balance, end of period	(60)	(53)	(60)	(53)

See Note 13 for disclosure on the Corporation's credit risk.

6. REGULATORY ASSETS AND LIABILITIES

Detailed information about the Corporation's regulatory assets and liabilities is provided in Note 8 to the 2022 Annual Financial Statements. A summary follows.

	As at
	June 30,	December 31,
($ millions)	2023	2022
Regulatory assets
Deferred income taxes	1,897	1,874
Deferred energy management costs	463	445
Rate stabilization and related accounts	419	557
Employee future benefits	191	207
Deferred lease costs	135	132
Derivatives	118	84
Deferred restoration costs	109	91
Manufactured gas plant site remediation deferral	87	97
Generation early retirement costs	73	78
Other regulatory assets	464	444
Total regulatory assets	3,956	4,009
Less: Current portion	(730)	(914)
Long-term regulatory assets	3,226	3,095
Regulatory liabilities
Future cost of removal	1,353	1,306
Deferred income taxes	1,271	1,364
Rate stabilization and related accounts	288	297
Employee future benefits	254	306
Renewable energy surcharge	122	126
Energy efficiency liability	89	89
Electric and gas moderator account	67	34
Alberta Electric System Operator charges deferral	58	21
Derivatives	54	224
Other regulatory liabilities	161	148
Total regulatory liabilities	3,717	3,915
Less: Current portion	(489)	(595)
Long-term regulatory liabilities	3,228	3,320

12 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

7. ASSETS HELD FOR SALE

In May 2023, the Corporation announced that FortisBC Holdings Inc. ("FHI") had entered into a definitive share purchase and sale agreement with a subsidiary of Enbridge Inc. to sell its 93.8% ownership interest in Aitken Creek for approximately $400 million, subject to customary closing conditions and adjustments. The purchase is subject to required approval, principally by the BCUC, and is expected to close by the end of the year with a March 31, 2023 effective date.

As at June 30, 2023, the related assets and liabilities, as included in the Energy Infrastructure segment, were classified as held for sale and are detailed below.

As at ($ millions)	June 30, 2023
Cash and cash equivalents	19
Accounts receivable and other current assets	30
Inventories	55
Property, plant and equipment, net	430
Goodwill	27
Total assets held for sale	561
Accounts payable and other current liabilities	20
Deferred income taxes	109
Total liabilities associated with assets held for sale	129

For the three and six months ended June 30, 2023, Aitken Creek had net earnings of $3 million and $18 million, respectively (three and six months ended June 30, 2022 - $14 million and $7 million, respectively).

8. LONG-TERM DEBT

	As at
	June 30,	December 31,
($ millions)	2023	2022
Long-term debt	27,704	26,921
Credit facility borrowings	1,562	1,657
Total long-term debt	29,266	28,578
Less: Deferred financing costs and debt discounts	(174)	(166)
Less: Current installments of long-term debt	(2,284)	(2,481)
	26,808	25,931

Significant Long-Term Debt Issuances		Interest
Year-to-Date June 30, 2023	Month	Rate					Use of
($ millions, except as noted)	Issued	(%)		Maturity	Amount		Proceeds
ITC
Unsecured senior notes	June	5.40	(1)	2033	US	500	(2) (3) (4)
Unsecured senior notes	June	4.95	(5)	2027	US	300	(2) (3) (4)
UNS Energy
Unsecured senior notes	February	5.50		2053	US	375	(2) (3)
FortisAlberta
Unsecured senior debentures	May	4.86		2053	200		(3) (4)
Central Hudson
Unsecured senior notes	March	5.68		2033	US	40	(3) (4)
Unsecured senior notes	March	5.78		2035	US	15	(3) (4)
Unsecured senior notes	March	5.88		2038	US	35	(3) (4)

(1)    ITC entered into interest rate locks which reduced the effective interest rate to 5.32%. See Note 13 to the Interim Financial Statements

(2)    Repay maturing long-term debt

(3)    General corporate purposes

(4)     Repay short-term and/or credit facility borrowings

(5)     Represents a second tranche of ITC's existing 4.95% senior notes, originally issued in 2022

13 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

8. LONG-TERM DEBT (cont'd)

In November 2022, Fortis filed a short-form base shelf prospectus with a 25-month life under which it may issue common or preference shares, subscription receipts, or debt securities in an aggregate principal amount of up to $2.0 billion. As at June 30, 2023, $2.0 billion remained available under the short-form base shelf prospectus.

			As at
Credit facilities	Regulated	Corporate	June 30,	December 31,
($ millions)	Utilities	and Other	2023	2022
Total credit facilities	3,963	2,034	5,997	5,850
Credit facilities utilized:
Short-term borrowings (1)	(80)	—	(80)	(253)
Long-term debt (including current portion) (2)	(792)	(770)	(1,562)	(1,657)
Letters of credit outstanding	(57)	(38)	(95)	(128)
Credit facilities unutilized	3,034	1,226	4,260	3,812

(1)    The weighted average interest rate was 6.7% (December 31, 2022 - 4.9%).

(2)    The weighted average interest rate was 6.0% (December 31, 2022 - 5.1%). The current portion was $1,114 million (December 31, 2022 - $1,376 million).

Credit facilities are syndicated primarily with large banks in Canada and the U.S., with no one bank holding more than approximately 20% of the Corporation's total revolving credit facilities. Approximately $5.7 billion of the total credit facilities are committed with maturities ranging from 2023 through 2028.

See Note 14 in the 2022 Annual Financial Statements for a description of the credit facilities as at December 31, 2022.

In April 2023, ITC increased its total credit facilities available from US$900 million to US$1 billion and extended the maturity to April 2028.

In May 2023, the Corporation amended its $1.3 billion revolving term committed credit facility agreement to extend the maturity to July 2028.

Also in May 2023, the Corporation extended the maturity on its unsecured US$500 million non-revolving term credit facility to May 2024. The facility is repayable at any time without penalty.

9. EMPLOYEE FUTURE BENEFITS

Fortis and each subsidiary maintain one or a combination of defined benefit pension plans and defined contribution pension plans, as well as other post-employment benefit ("OPEB") plans, including health and dental coverage and life insurance benefits, for qualifying members. The net benefit cost is detailed below.

	Defined Benefit Pension Plans		OPEB Plans
($ millions)	2023	2022	2023	2022
Quarter ended June 30
Service costs	16	26	6	8
Interest costs	40	28	7	6
Expected return on plan assets	(50)	(48)	(5)	(5)
Amortization of actuarial (gains) losses	(3)	1	(5)	(3)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	2	(3)	1	1
Net benefit cost	4	3	3	6
Year-to-date June 30
Service costs	31	52	11	17
Interest costs	80	56	15	11
Expected return on plan assets	(100)	(97)	(11)	(11)
Amortization of actuarial (gains) losses	(5)	2	(9)	(5)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	6	(5)	3	2
Net benefit cost	11	7	8	13

Defined contribution pension plan expense for the three and six months ended June 30, 2023 was $13 million and $29 million, respectively (three and six months ended June 30, 2022 - $12 million and $26 million, respectively).

14 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

10. OTHER INCOME, NET

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Equity component, allowance for funds used during construction	23	18	46	35
Interest income (1)	18	2	34	3
Non-service component of net periodic benefit cost	16	25	32	49
Gain (loss) on derivatives, net	3	(2)	12	2
Gain (loss) on retirement investments, net	—	(9)	4	(17)
Other	4	1	5	5
	64	35	133	77

(1)    Includes interest on short-term deposits, as well as interest on regulatory deferrals, including the PPFAC at TEP and UNSE

11. EARNINGS PER COMMON SHARE

Diluted earnings per share ("EPS") was calculated using the treasury stock method for stock options.

	2023			2022
	Net Earnings	Weighted		Net Earnings	Weighted
	to Common	Average		to Common	Average
	Shareholders	Shares	EPS	Shareholders	Shares	EPS
	($ millions)	(# millions)	($)	($ millions)	(# millions)	($)
Quarter ended June 30
Basic EPS	294	485.4	0.61	284	477.8	0.59
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	294	485.7	0.61	284	478.3	0.59
Year-to-date June 30
Basic EPS	731	484.3	1.51	634	476.8	1.33
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	731	484.6	1.51	634	477.3	1.33

12. SUPPLEMENTARY CASH FLOW INFORMATION

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Change in working capital
Accounts receivable and other current assets	208	49	489	(46)
Prepaid expenses	(19)	17	(19)	22
Inventories	(29)	(114)	62	(45)
Regulatory assets - current portion	164	(31)	160	(43)
Accounts payable and other current liabilities	(132)	9	(537)	17
Regulatory liabilities - current portion	25	30	22	32
	217	(40)	177	(63)
Non-cash investing and financing activities
Accrued capital expenditures	366	380	366	380
Common share dividends reinvested	102	92	205	186
Contributions in aid of construction	10	12	10	12

15 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

13. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

Derivatives

The Corporation generally limits the use of derivatives to those that qualify as accounting, economic or cash flow hedges, or those that are approved for regulatory recovery.

Derivatives are recorded at fair value with certain exceptions including those derivatives that qualify for the normal purchase and normal sale exception. Fair values reflect estimates based on current market information about the derivatives as at the balance sheet dates. The estimates cannot be determined with precision as they involve uncertainties and matters of judgment and, therefore, may not be relevant in predicting the Corporation's future consolidated earnings or cash flow.

Cash flow associated with the settlement of all derivatives is included in operating activities on the condensed consolidated interim statements of cash flows.

Energy Contracts Subject to Regulatory Deferral

UNS Energy holds electricity power purchase contracts, customer supply contracts and gas swap contracts to reduce its exposure to energy price risk. Fair values are measured primarily under the market approach using independent third-party information, where possible. When published prices are not available, adjustments are applied based on historical price curve relationships, transmission costs and line losses.

Central Hudson holds swap contracts for electricity and natural gas to minimize price volatility by fixing the effective purchase price. Fair values are measured using forward pricing provided by independent third-party information.

FortisBC Energy holds gas supply contracts to fix the effective purchase price of natural gas. Fair values reflect the present value of future cash flows based on published market prices and forward natural gas curves.

Unrealized gains or losses associated with changes in the fair value of these energy contracts are deferred as a regulatory asset or liability for recovery from, or refund to, customers in future rates, as permitted by the regulators. As at June 30, 2023, unrealized losses of $118 million (December 31, 2022 - $84 million) were recognized as regulatory assets and unrealized gains of $54 million (December 31, 2022 - $224 million) were recognized as regulatory liabilities.

Energy Contracts Not Subject to Regulatory Deferral

UNS Energy holds wholesale trading contracts to fix power prices and realize potential margin, of which 10% of any realized gains is shared with customers through rate stabilization accounts. Fair values are measured using a market approach incorporating, where possible, independent third-party information.

Aitken Creek holds gas swap contracts to manage its exposure to changes in natural gas prices, capture natural gas price spreads, and manage the financial risk posed by physical transactions. Fair values are measured using forward pricing from published market sources.

Unrealized gains or losses associated with changes in the fair value of these energy contracts are recognized in revenue. During the three months ended June 30, 2023, unrealized losses of $8 million and unrealized gains of $6 million, respectively were recognized in revenue (three and six months ended June 30, 2022 - unrealized gains of $19 million and $2 million, respectively).

Total Return Swaps

The Corporation holds total return swaps to manage the cash flow risk associated with forecast future cash settlements of certain stock-based compensation obligations. The swaps have a combined notional amount of $119 million and terms of one to three years expiring at varying dates through January 2026. Fair value is measured using an income valuation approach based on forward pricing curves. Unrealized gains and losses associated with changes in fair value are recognized in other income, net. During the three and six months ended June 30, 2023, unrealized losses of $1 million and unrealized gains of $5 million, respectively were recognized in other income, net (three and six months ended June 30, 2022 - unrealized losses of $2 million and $8 million, respectively).

Foreign Exchange Contracts

The Corporation holds U.S. dollar denominated foreign exchange contracts to help mitigate exposure to foreign exchange rate volatility. The contracts expire at varying dates through February 2025 and have a combined notional amount of $393 million. Fair value was measured using independent third-party information. Unrealized gains and losses associated with changes in fair value are recognized in other income, net. During the three and six months ended June 30, 2023, unrealized gains recognized in other income, net were $5 million and $7 million, respectively (unrealized losses of $2 million for the three and six months ended June 30, 2022, respectively).

Interest Rate Locks

In March 2023, the Corporation entered into an interest rate lock with a total notional value of $100 million to manage the interest rate risk associated with the refinancing of long-term debt maturing in the fall of 2023. The lock has a 10-year term and will be terminated no later than November 1, 2023. Fair value is measured using a discounted cash flow method based on Canadian dollar offered rates. Unrealized gains and losses associated with changes in fair value are recognized in other comprehensive income, and will be reclassified to earnings as a component of interest expense over the life of the debt. Unrealized gains of $4 million were recognized in other comprehensive income for the three and six months ended June 30, 2023.

During the second quarter of 2023, ITC entered into and settled interest rate locks with a combined notional value of US$500 million. The contracts were used to manage interest rate risk associated with the issuance of US$500 million unsecured senior notes in June 2023. Realized gains of US$4 million were recognized in other comprehensive income, which will be reclassified to earnings as a component of interest expense over 10 years.

16 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

13. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

Cross-Currency Interest Rate Swaps

In 2022, the Corporation entered into cross-currency interest rate swaps with a 7-year term to effectively convert its $500 million, 4.43% unsecured senior notes to US$391 million, 4.34% debt. The Corporation designated this notional U.S. debt as an effective hedge of its foreign net investments and unrealized gains and losses associated with exchange rate fluctuations on the notional U.S. debt are recognized in other comprehensive income, consistent with the translation adjustment related to the net investments. Other changes in the fair value of the swaps are also recognized in other comprehensive income but are excluded from the assessment of hedge effectiveness. Fair value is measured using a discounted cash flow method based on secured overnight financing rates. Unrealized gains of $9 million and $10 million were recorded in other comprehensive income for the three and six months ended June 30, 2023 (unrealized losses of $12 million for the three and six months ended June 30, 2022).

Other Investments

UNS Energy holds investments in money market accounts, and ITC and Central Hudson hold investments in trust associated with supplemental retirement benefit plans for select employees, which include mutual funds and money market accounts. These investments are recorded at fair value based on quoted market prices in active markets. Gains and losses are recognized in other income, net. During the three and six months ended June 30, 2023, gains of $1 million and $3 million, respectively was recognized in other income, net (three and six months ended June 30, 2022 - losses of $4 million and $9 million, respectively).

Recurring Fair Value Measures

The following table presents assets and liabilities that are accounted for at fair value on a recurring basis.

($ millions)	Level 1 (1)	Level 2 (1)	Level 3 (1)	Total
As at June 30, 2023
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	82	—	82
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Foreign exchange contracts, total return swaps and interest rate lock (2)	—	7	—	7
Other investments (4)	144	—	—	144
	144	138	—	282
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(146)	—	(146)
Energy contracts not subject to regulatory deferral (5)	—	(7)	—	(7)
Cross-currency interest rate swaps (5)	—	(8)	—	(8)
	—	(161)	—	(161)
As at December 31, 2022
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	304	—	304
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Other investments (4)	150	—	—	150
	150	353	—	503
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(164)	—	(164)
Energy contracts not subject to regulatory deferral (5)	—	(8)	—	(8)
Foreign exchange contracts, total return and cross-currency interest rate swaps (5)	—	(26)	—	(26)
	—	(198)	—	(198)

(1)Under the hierarchy, fair value is determined using: (i) level 1 - unadjusted quoted prices in active markets; (ii) level 2 - other pricing inputs directly or indirectly observable in the marketplace; and (iii) level 3 - unobservable inputs, used when observable inputs are not available. Classifications reflect the lowest level of input that is significant to the fair value measurement.

(2)Included in accounts receivable and other current assets or other assets

(3)Unrealized gains and losses arising from changes in fair value of these contracts are deferred as a regulatory asset or liability for recovery from, or refund to, customers in future rates as permitted by the regulators, with the exception of long-term wholesale trading contracts and certain gas swap contracts.

(4)Included in cash and cash equivalents and other assets

(5)Included in accounts payable and other current liabilities or other liabilities

17 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

13. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

Energy Contracts

The Corporation has elected gross presentation for its derivative contracts under master netting agreements and collateral positions, which apply only to its energy contracts. The following table presents the potential offset of counterparty netting.

	Gross Amount	Counterparty
	Recognized in	Netting of	Cash Collateral
($ millions)	Balance Sheet	Energy Contracts	Received/Posted	Net Amount
As at June 30, 2023
Derivative assets	131	(34)	28	125
Derivative liabilities	(153)	34	—	(119)
As at December 31, 2022
Derivative assets	353	(54)	(63)	236
Derivative liabilities	(172)	54	—	(118)

Volume of Derivative Activity

As at June 30, 2023, the Corporation had various energy contracts that will settle on various dates through 2029. The volumes related to electricity and natural gas derivatives are outlined below.

	As at
	June 30,	December 31,
	2023	2022
Energy contracts subject to regulatory deferral (1)
Electricity swap contracts (GWh)	447	586
Electricity power purchase contracts (GWh)	440	224
Gas swap contracts (PJ)	173	185
Gas supply contract premiums (PJ)	134	148
Energy contracts not subject to regulatory deferral (1)
Wholesale trading contracts (GWh)	3,960	1,886
Gas swap contracts (PJ)	26	34

(1)GWh means gigawatt hours and PJ means petajoules.

Credit Risk

For cash equivalents, accounts receivable and other current assets, and long-term other receivables, credit risk is generally limited to the carrying value on the consolidated balance sheets. The Corporation's subsidiaries generally have a large and diversified customer base, which minimizes the concentration of credit risk. Policies in place to minimize credit risk include requiring customer deposits, prepayments and/or credit checks for certain customers, performing disconnections and/or using third-party collection agencies for overdue accounts.

ITC has a concentration of credit risk as approximately 70% of its revenue is derived from three customers. The customers have investment-grade credit ratings and credit risk is further managed by MISO by requiring a letter of credit or cash deposit equal to the credit exposure, which is determined by a credit-scoring model and other factors.

FortisAlberta has a concentration of credit risk as distribution service billings are to a relatively small group of retailers. Credit risk is managed by obtaining from the retailers either a cash deposit, letter of credit, an investment-grade credit rating, or a financial guarantee from an entity with an investment-grade credit rating.

Central Hudson has seen an increase in accounts receivable due to the suspension of collection efforts in response to the COVID-19 pandemic, as well as higher commodity prices. Central Hudson continues to proactively contact customers regarding past-due balances to advise them of financial assistance available through federal and state programs, and collection efforts are expected to expand in 2023. Under its regulatory framework, Central Hudson can defer uncollectible write-offs that exceed 10 basis points above the amounts collected in customer rates for future recovery.

UNS Energy, Central Hudson, FortisBC Energy, Aitken Creek and the Corporation may be exposed to credit risk in the event of non-performance by counterparties to derivatives. Credit risk is managed by net settling payments, when possible, and dealing only with counterparties that have investment-grade credit ratings. At UNS Energy, Central Hudson and FortisBC Energy, certain contractual arrangements require counterparties to post collateral.

18 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Notes to Condensed Consolidated Interim Financial Statements (Unaudited)

For the three and six months ended June 30, 2023 and 2022

13. FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT (cont'd)

The value of derivatives in net liability positions under contracts with credit risk-related contingent features that, if triggered, could require the posting of a like amount of collateral was $52 million as at June 30, 2023 (December 31, 2022 - $178 million).

Hedge of Foreign Net Investments

The reporting currency of ITC, UNS Energy, Central Hudson, Caribbean Utilities, FortisTCI, Fortis Belize Limited and Belize Electricity is, or is pegged to, the U.S. dollar. The earnings and cash flow from, and net investments in, these entities are exposed to fluctuations in the U.S. dollar-to-Canadian dollar exchange rate. The Corporation has reduced this exposure through hedging.

As at June 30, 2023, US$2.9 billion (December 31, 2022 - US$2.9 billion) of corporately issued U.S. dollar-denominated long-term debt has been designated as an effective hedge of net investments, leaving approximately US$10.9 billion (December 31, 2022 - US$10.6 billion) unhedged. Exchange rate fluctuations associated with the net investment in foreign subsidiaries and the debt serving as the hedge are recognized in accumulated other comprehensive income.

Financial Instruments Not Carried at Fair Value

Excluding long-term debt, the consolidated carrying value of the Corporation's remaining financial instruments approximates fair value, reflecting their short-term maturity, normal trade credit terms and/or nature.

As at June 30, 2023, the carrying value of long-term debt, including current portion, was $29.3 billion (December 31, 2022 - $28.6 billion) compared to an estimated fair value of $26.9 billion (December 31, 2022 - $25.8 billion).

14. COMMITMENTS AND CONTINGENCIES

Commitments

There were no material changes in commitments from that disclosed in the Corporation's 2022 Annual Financial Statements.

Contingencies

In April 2013, FHI and Fortis were named as defendants in an action in the British Columbia Supreme Court by the Coldwater Indian Band ("Band") regarding interests in a pipeline right-of-way on reserve lands. The pipeline was transferred by FHI (then Terasen Inc.) to Kinder Morgan Inc. in 2007. The Band seeks cancellation of the right-of-way and damages for wrongful interference with the Band's use and enjoyment of reserve lands. In 2016, the Federal Court dismissed the Band's application for judicial review of the ministerial consent. In 2017, the Federal Court of Appeal set aside the minister's consent and returned the matter to the minister for redetermination. No amount has been accrued in the Interim Financial Statements as the outcome cannot yet be reasonably determined.

19 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

EX-99.3

Exhibit 99.3

Interim Management Discussion and Analysis

Contents
About Fortis	1	Liquidity and Capital Resources	11
Key Development	1	Cash Flow Requirements	11
Performance at a Glance	2	Cash Flow Summary	12
Business Unit Performance	4	Contractual Obligations	14
ITC	5	Capital Structure and Credit Ratings	14
UNS Energy	5	Capital Plan	14
Central Hudson	6	Business Risks	15
FortisBC Energy	6	Accounting Matters	15
FortisAlberta	7	Financial Instruments	16
FortisBC Electric	7	Long-Term Debt and Other	16
Other Electric	7	Derivatives	16
Energy Infrastructure	8	Summary of Quarterly Results	16
Corporate and Other	8	Related-Party and Inter-Company Transactions	17
Non-U.S. GAAP Financial Measures	8	Outlook	18
Focus on Sustainability	9	Forward-Looking Information	18
Regulatory Matters	9	Glossary	19
Financial Position	11	Condensed Consolidated Interim Financial Statements (Unaudited)	F-1

Dated August 1, 2023

This Interim MD&A has been prepared in accordance with National Instrument 51-102 - Continuous Disclosure Obligations. It should be read in conjunction with the Interim Financial Statements, the 2022 Annual Financial Statements and the 2022 Annual MD&A and is subject to the cautionary statement and disclaimer provided under "Forward-Looking Information" on page 18. Further information about Fortis, including its Annual Information Form filed on SEDAR, can be accessed at www.fortisinc.com, www.sedarplus.ca, or www.sec.gov.

Financial information herein has been prepared in accordance with U.S. GAAP (except for indicated Non-U.S. GAAP Financial Measures) and, unless otherwise specified, is presented in Canadian dollars based, as applicable, on the following U.S. dollar-to-Canadian dollar exchange rates: (i) average of 1.34 and 1.28 for the quarters ended June 30, 2023 and 2022, respectively; (ii) average of 1.35 and 1.27 year-to-date June 30, 2023 and 2022, respectively; (iii) 1.32 and 1.29 as at June 30, 2023 and 2022, respectively; (iv) 1.36 as at December 31, 2022; and (v) 1.30 for all forecast periods. Certain terms used in this Interim MD&A are defined in the "Glossary" on page 19.

ABOUT FORTIS

Fortis (TSX/NYSE: FTS) is a well-diversified leader in the North American regulated electric and gas utility industry, with 2022 revenue of $11 billion and total assets of $64 billion as at June 30, 2023. The Corporation's 9,200 employees serve 3.4 million utility customers in five Canadian provinces, ten U.S. states and three Caribbean countries.

For additional information on the Corporation's operations, reportable segments and strategy, refer to the "About Fortis" section of the 2022 Annual MD&A and Note 1 to the Interim Financial Statements.

KEY DEVELOPMENT

Pending Sale of Aitken Creek

On May 1, 2023, the Corporation announced that FortisBC Holdings Inc. had entered into a definitive share purchase and sale agreement with a subsidiary of Enbridge Inc. to sell its 93.8% ownership interest in Aitken Creek for approximately $400 million, subject to customary closing conditions and adjustments. The purchase is subject to required approval, principally by the BCUC, and is expected to close by the end of the year. Net proceeds from the transaction will further strengthen the balance sheet and support financing of the Corporation's regulated utility growth strategy.

1 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

PERFORMANCE AT A GLANCE
Key Financial Metrics
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Revenue	2,594	2,487	107	5,913	5,322	591
Common Equity Earnings
Actual	294	284	10	731	634	97
Adjusted (1)	302	272	30	741	641	100
Basic EPS($)
Actual	0.61	0.59	0.02	1.51	1.33	0.18
Adjusted (1)	0.62	0.57	0.05	1.53	1.34	0.19
Dividends paid per common share ($)	0.565	0.535	0.03	1.13	1.07	0.06
Weighted average number of common shares outstanding(# millions)	485.4	477.8	7.6	484.3	476.8	7.5
Operating Cash Flow	944	759	185	1,859	1,572	287
Capital Expenditures (1)	1,025	930	95	2,020	1,894	126

(1)See "Non-U.S. GAAP Financial Measures" on page 8

Revenue

The increase in revenue for the quarter was due primarily to: (i) Rate Base growth; (ii) higher flow-through costs in customer rates, largely at UNS Energy and Central Hudson; and, (iii) a higher U.S.-to-Canadian dollar foreign exchange rate. The increase was partially offset by lower retail electricity sales, due to unfavourable weather, and lower wholesale electricity sales at UNS Energy.

The increase in revenue for the year-to-date period was due primarily to the same factors discussed for the quarter but reflected an increase in revenue from wholesale electricity sales at UNS Energy, due to favourable pricing experienced in the first quarter of 2023.

Earnings and EPS

Common Equity Earnings increased by $10 million in comparison to the second quarter of 2022. The increase primarily reflected Rate Base growth, largely at ITC and the western Canadian utilities. Also contributing to earnings growth was the timing of operating expenses at Central Hudson and FortisAlberta, an increase in the market value of certain investments that support retirement benefits, and a higher U.S.-to-Canadian dollar foreign exchange rate. Growth in earnings was tempered by lower earnings in Arizona, driven by a decrease in retail electricity sales due to milder weather, the timing of wholesale sales, and higher operating costs, partially offset by lower depreciation expense associated with the retirement of the San Juan generating station in June 2022. Lower earnings from Aitken Creek due to the mark-to-market accounting of natural gas derivatives, as well as higher corporate finance costs, also impacted earnings as compared to the second quarter of 2022.

Common Equity Earnings for the year-to-date period increased by $97 million in comparison to the same period in 2022. The increase was due to the same factors discussed for the quarter, except that UNS Energy and Aitken Creek contributed to earnings growth for the six-month period. Year-to-date results in Arizona reflected favourable margins on long-term wholesale sales and higher transmission revenue, and results for Aitken Creek reflected higher volumes and margins on gas sold.

In addition to the above-noted items impacting earnings, the change in EPS for the quarter and year-to-date periods reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's DRIP.

2 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

For the quarter and year-to-date periods: (i) Adjusted Common Equity Earnings increased by $30 million and $100 million, respectively; and (ii) Adjusted Basic EPS increased by $0.05 and $0.19, respectively. Refer to "Non-U.S. GAAP Financial Measures" on page 8 for a reconciliation of these measures. The changes in Adjusted Basic EPS for the quarter and year-to-date periods are illustrated in the following charts.

(1)    Includes FortisBC Energy, FortisAlberta and FortisBC Electric. Primarily reflects Rate Base growth and the timing of operating expenses

(2)    Primarily reflects Rate Base growth and higher electricity sales, as well as equity income from Wataynikaneyap Power

(3)    Primarily reflects higher margins on gas sold at Aitken Creek

(4)    Reflects Rate Base growth and an increase in the market value of investments that support retirement benefits, partially offset by higher finance costs

(5)    Average foreign exchange rate of 1.34 in 2023 compared to 1.28 in 2022

(6)    Includes UNS Energy and Central Hudson. Reflects lower earnings at UNS Energy due to: (i) lower retail electricity sales, due to milder weather; (ii) the timing of long-term wholesale electricity sales; and (iii) higher operating costs due to inflationary increases, partially offset by lower depreciation expense associated with the retirement of the San Juan generating station in mid-2022 and an increase in the market value of investments that support retirement benefits. Also reflects higher earnings at Central Hudson driven by Rate Base growth and the timing of operating expenses, partially offset by finance costs in excess of amounts collected in customer rates

(7)    Primarily reflects higher finance costs

(8)    Weighted average shares of 485.4 million in 2023 compared to 477.8 million in 2022

(1)    Includes UNS Energy and Central Hudson. Reflects higher earnings at UNS Energy due to: (i) favourable margins on long-term wholesale sales and higher transmission revenue due to market conditions; (ii) lower depreciation expense associated with the retirement of the San Juan generating station in mid-2022; and (iii) an increase in the market value of investments that support retirement benefits, partially offset by higher operating costs due to inflationary increases. Also reflects higher earnings at Central Hudson driven by Rate Base growth and the timing of operating expenses, partially offset by higher finance costs in excess of amounts collected in customer rates

(2)    Includes FortisBC Energy, FortisAlberta and FortisBC Electric. Primarily reflects Rate Base growth, as well as the timing of operating expenses at FortisAlberta

(3)    Reflects Rate Base growth and an increase in the market value of investments that support retirement benefits, partially offset by higher finance costs

(4)    Includes higher volumes and margins on gas sold at Aitken Creek and higher hydroelectric production in Belize associated with rainfall levels

(5)    Primarily reflects Rate Base growth and higher electricity sales, as well as equity income from Wataynikaneyap Power

(6)    Average foreign exchange rate of 1.35 in 2023 compared to 1.27 in 2022

(7)    Primarily reflects higher finance charges

(8)    Weighted average shares of 484.3 million in 2023 compared to 476.8 million in 2022

3 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Dividends and TSR

Fortis paid a dividend of $0.565 in the second quarter of 2023, up 5.6% from the second quarter of 2022.

Fortis has increased its common share dividend for 49 consecutive years and is targeting annual dividend growth of approximately 4-6% through 2027. See "Outlook" on page 18.

Growth of dividends and the market price of the Corporation's common shares have together yielded the following TSR.

TSR (1)(%)	1-Year	5-Year	10-Year	20-Year
Fortis	(2.4)	10.3	9.9	10.9

(1)Annualized TSR per Bloomberg as at June 30, 2023

Operating Cash Flow

The $185 million and $287 million increase in Operating Cash Flow for the quarter and year-to-date periods, respectively, was due primarily to the timing of flow-through costs in customer rates, largely reflecting variances in the cost of natural gas in British Columbia. The increase was also due to higher cash earnings, reflecting Rate Base growth, and the higher U.S.-to-Canadian dollar exchange rate. The increase was partially offset by lower collateral deposits received at UNS Energy related to derivative energy contracts, and higher interest payments.

Capital Expenditures

Capital Expenditures were approximately $2.0 billion through June 2023, representing 47% of the Corporation's annual $4.3 billion Capital Plan, and up $0.1 billion compared to year-to-date 2022.

Capital Expenditures and Capital Plan reflect Non-U.S. GAAP Financial Measures. Refer to "Non-U.S. GAAP Financial Measures" on page 8 and in the "Glossary" on page 19.

BUSINESS UNIT PERFORMANCE
Common Equity Earnings	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions)	2023	2022	FX (1)	Other	2023	2022	FX (1)	Other
Regulated Utilities
ITC	127	114	6	7	253	223	14	16
UNS Energy	70	77	4	(11)	160	120	7	33
Central Hudson	17	10	1	6	49	42	3	4
FortisBC Energy	23	17	—	6	147	136	—	11
FortisAlberta	41	35	—	6	81	71	—	10
FortisBC Electric	18	19	—	(1)	36	37	—	(1)
Other Electric (2)	42	33	1	8	72	59	2	11
	338	305	12	21	798	688	26	84
Non-Regulated
Energy Infrastructure (3)	6	19	—	(13)	24	13	—	11
Corporate and Other (4)	(50)	(40)	—	(10)	(91)	(67)	(1)	(23)
Common Equity Earnings	294	284	12	(2)	731	634	25	72

(1)    The reporting currency of ITC, UNS Energy, Central Hudson, Caribbean Utilities, FortisTCI and Fortis Belize is the U.S. dollar. The reporting currency of Belize Electricity is the Belizean dollar, which is pegged to the U.S. dollar at BZ$2.00=US$1.00. The Corporate and Other segment includes certain transactions denominated in U.S. dollars

(2)    Consists of the utility operations in eastern Canada and the Caribbean: Newfoundland Power; Maritime Electric; FortisOntario; Wataynikaneyap Power; Caribbean Utilities; FortisTCI; and Belize Electricity

(3)    Consists of long-term contracted generation assets in Belize and Aitken Creek in British Columbia

(4)    Includes Fortis net corporate expenses and non-regulated holding company expenses

4 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

ITC	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions)	2023	2022	FX	Other	2023	2022	FX	Other
Revenue (1)	519	468	25	26	1,038	928	58	52
Earnings (1)	127	114	6	7	253	223	14	16

(1)Revenue represents 100% of ITC. Earnings represent the Corporation's 80.1% controlling ownership interest in ITC and reflect consolidated purchase price accounting adjustments

Revenue

The increase in revenue, net of foreign exchange, for the quarter and year-to-date periods was due primarily to Rate Base growth and higher flow-through costs in customer rates.

Earnings

The increase in earnings, net of foreign exchange, for the quarter and year-to-date periods was due primarily to Rate Base growth and an increase in the market value of certain investments that support retirement benefits, partially offset by higher finance costs.

UNS Energy	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions, except as indicated)	2023	2022	FX	Other	2023	2022	FX	Other
Retail electricity sales (GWh)	2,594	2,793	—	(199)	4,816	4,968	—	(152)
Wholesale electricity sales (GWh)(1)	1,252	1,411	—	(159)	2,631	2,804	—	(173)
Gas sales (PJ)	3	2	—	1	11	9	—	2
Revenue	661	648	33	(20)	1,401	1,186	72	143
Earnings	70	77	4	(11)	160	120	7	33

(1)    Primarily short-term wholesale sales

Sales

The decrease in retail electricity sales for the quarter and year-to-date periods was due primarily to lower air conditioning load associated with milder temperatures in the second quarter of 2023 as compared to the same period in 2022. The decrease was partially offset by customer additions.

The decrease in wholesale electricity sales for the quarter was due to lower long-term wholesale sales. On a year-to-date basis, the decrease in wholesale electricity sales was driven by lower short-term wholesale sales. Revenue from short-term wholesale sales, which relate to contracts that are less than one-year in duration, is primarily credited to customers through the PPFAC mechanism and, therefore, does not materially impact earnings.

The increase in gas sales for the quarter and year-to-date periods was due primarily to higher heating load associated with cooler temperatures in UNS Gas, Inc.'s service territory, as compared to the same periods in 2022.

Revenue

The decrease in revenue, net of foreign exchange, for the quarter was due primarily to: (i) lower retail and long-term wholesale electricity sales, discussed above; and (ii) lower revenue from short-term wholesale electricity sales due to pricing. The decrease was partially offset by the recovery of overall higher fuel and non-fuel costs through the normal operation of regulatory mechanisms.

The increase in revenue, net of foreign exchange, year to date was due primarily to: (i) the recovery of overall higher fuel and non-fuel costs through the normal operation of regulatory mechanisms; (ii) higher revenue from short-term and long-term wholesale sales due to favourable pricing; and (iii) customer additions. The increase was partially offset by lower retail electricity sales, driven by milder weather, and lower short-term wholesale sales.

Earnings

The decrease in earnings, net of foreign exchange, for the quarter was due primarily to: (i) lower retail electricity sales, due to milder weather; (ii) the timing of long-term wholesale electricity sales; and (iii) higher operating costs, primarily reflecting inflationary increases. The decrease was partially offset by lower depreciation expense associated with the retirement of the San Juan generating station in June 2022, and an increase in the market value of certain investments that support retirement benefits.

5 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

The increase in earnings, net of foreign exchange, year to date was due to: (i) favourable margins on long-term wholesale sales and higher transmission revenue due to market conditions; (ii) lower depreciation expense associated with the retirement of the San Juan generating station in June 2022; and (iii) an increase in the market value of certain investments that support retirement benefits. The increase was partially offset by higher operating costs, primarily reflecting inflationary increases. Retail electricity margin was largely flat on a year-to-date basis, as the impact of lower retail electricity sales, driven by milder weather, was offset by customer additions and an increase in lost fixed cost recovery revenue.

Central Hudson	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions, except as indicated)	2023	2022	FX	Other	2023	2022	FX	Other
Electricity sales(GWh)	1,143	1,261	—	(118)	2,410	2,517	—	(107)
Gas sales (PJ)	4	4	—	—	13	14	—	(1)
Revenue	317	281	15	21	759	656	42	61
Earnings	17	10	1	6	49	42	3	4

Sales

The decrease in electricity sales for the quarter and year-to-date periods was due primarily to milder weather.

Gas sales for the quarter and year-to-date periods were relatively consistent with the comparable periods in 2022.

Changes in electricity and gas sales at Central Hudson are subject to regulatory revenue decoupling mechanisms and, therefore, do not materially impact revenue and earnings.

Revenue

The increase in revenue, net of foreign exchange, for the quarter and year-to-date periods was due primarily to: (i) the flow-through of higher energy supply costs driven by commodity prices; and (ii) and an increase in gas and electricity delivery rates effective July 1, 2022.

Earnings

The increase in earnings, net of foreign exchange, for the quarter and year-to-date periods was due primarily to Rate Base growth and the timing of operating expenses, partially offset by finance costs in excess of amounts collected in customer rates.

FortisBC Energy
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Gas sales(PJ)	41	47	(6)	120	128	(8)
Revenue	362	396	(34)	1,117	1,090	27
Earnings	23	17	6	147	136	11

Sales

The decrease in gas sales for the quarter and year-to-date periods was due primarily to lower average consumption by residential, commercial and transportation customers, largely due to unfavourable weather, partially offset by customer additions.

Revenue

The decrease in revenue for the quarter was due primarily to a lower cost of natural gas recovered from customers and the normal operation of regulatory mechanisms, partially offset by Rate Base growth.

The increase in revenue year to date was due primarily to Rate Base growth and higher gas mitigation incentive revenue, partially offset by the normal operation of regulatory mechanisms.

Earnings

The increase in earnings for the quarter was due primarily to Rate Base growth and the timing of operating costs. The increase year to date was due primarily to Rate Base growth and higher gas mitigation incentive revenue, partially offset by higher operating costs.

FortisBC Energy earns approximately the same margin regardless of whether a customer contracts for the purchase and delivery of natural gas or only for delivery. Due to regulatory deferral mechanisms, changes in consumption levels and commodity costs do not materially impact earnings.

6 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

FortisAlberta
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Electricity deliveries(GWh)	3,899	3,794	105	8,409	8,378	31
Revenue	181	169	12	360	336	24
Earnings	41	35	6	81	71	10

Deliveries

The increase in electricity deliveries for the quarter was due to higher average consumption, largely associated with industrial customers, as well as customer additions.

The increase in electricity deliveries year to date was due primarily to customer additions as well as higher average consumption by commercial and industrial customers. This increase was partially offset by lower average consumption by residential customers due to milder weather in the first quarter of 2023.

As approximately 85% of FortisAlberta's revenue is derived from fixed or largely fixed billing determinants, changes in quantities of energy delivered are not entirely correlated with changes in revenue. Revenue is a function of numerous variables, many of which are independent of actual energy deliveries. Significant variations in weather conditions, however, can impact revenue and earnings.

Revenue and Earnings

The increase in revenue and earnings for the quarter and year-to-date periods was due primarily to Rate Base growth and the operation of the PBR efficiency carry-over mechanism, which was earned in the second term of PBR and recognized in 2023. This increase was partially offset by the lower recovery of costs attributable to REAs (see "Regulatory Matters" on page 9). The timing of operating costs also favourably impacted earnings for the quarter and year-to-date periods.

FortisBC Electric
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Electricity sales (GWh)	784	762	22	1,755	1,730	25
Revenue	116	108	8	255	237	18
Earnings	18	19	(1)	36	37	(1)

Sales

The increase in electricity sales for the quarter and year-to-date periods was due primarily to higher average consumption, largely associated with industrial customers, as well as customer additions.

Revenue

The increase in revenue for the quarter and year-to-date periods was due to the normal operation of regulatory deferrals, Rate Base growth and higher electricity sales, partially offset by a decrease in third party contract work.

Earnings

The decrease in earnings for the quarter and year-to-date periods was due to the timing of operating costs, partially offset by Rate Base growth.

Due to regulatory deferral mechanisms, changes in consumption levels do not materially impact earnings.

Other Electric	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions, except as indicated)	2023	2022	FX	Other	2023	2022	FX	Other
Electricity sales (GWh)	2,294	2,195	—	99	5,331	5,201	—	130
Revenue	420	384	6	30	927	843	12	72
Earnings	42	33	1	8	72	59	2	11

Sales

The increase in electricity sales for the quarter and year-to-date periods was due primarily to higher average consumption by residential and commercial customers, as well as customer additions.

7 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Revenue

The increase in revenue, net of foreign exchange, for the quarter and year-to-date periods was due primarily to higher electricity sales, discussed above, the flow-through of higher energy supply costs, and the normal operation of regulatory mechanisms at Newfoundland Power.

Earnings

The increase in earnings, net of foreign exchange, for the quarter and year-to-date periods was due to Rate Base growth and higher electricity sales, as well as equity income from Wataynikaneyap Power.

Energy Infrastructure
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Electricity sales(GWh)	29	37	(8)	60	54	6
Revenue	18	33	(15)	56	46	10
Earnings	6	19	(13)	24	13	11

Sales

The change in electricity sales reflected variations in hydroelectric production in Belize associated with rainfall levels.

Revenue and Earnings

Revenue and earnings for the quarter decreased due primarily to the unfavourable impact of mark-to-market accounting of natural gas derivatives at Aitken Creek, which resulted in unrealized losses of $8 million in the second quarter of 2023 compared to unrealized gains of $12 million for the same period in 2022. The decrease was partially offset by higher margins on gas sold at Aitken Creek.

Revenue and earnings year to date increased due primarily to higher volumes and margins on gas sold at Aitken Creek and higher hydroelectric production in Belize. The increase was partially offset by the unfavourable impact of mark-to-market accounting of natural gas derivatives at Aitken Creek, which resulted in unrealized losses of $10 million year-to-date 2023 compared to $7 million for the same period in 2022.

Aitken Creek is subject to commodity price risk, as it purchases and holds natural gas in storage to earn a profit margin from its ultimate sale. Aitken Creek mitigates this risk by using derivatives to materially lock in the profit margin that will be realized upon the sale of natural gas. The fair value accounting of these derivatives creates timing differences and the resultant earnings volatility can be significant.

In May 2023, the Corporation announced a definitive share purchase and sale agreement to sell its 93.8% ownership interest in Aitken Creek. See "Key Developments" on page 1 for further information.

Corporate and Other	Quarter				Year-to-Date
Periods ended June 30			Variance				Variance
($ millions)	2023	2022	FX	Other	2023	2022	FX	Other
Net expenses	(50)	(40)	—	(10)	(91)	(67)	(1)	(23)

The increase in net expenses, net of foreign exchange, for the quarter and year-to-date periods was primarily due to higher finance costs, reflecting higher interest rates and balances outstanding on the Corporation's credit facilities, as well as the refinancing of long-term debt in the second quarter of 2022.

NON-U.S. GAAP FINANCIAL MEASURES

Adjusted Common Equity Earnings, Adjusted Basic EPS and Capital Expenditures are Non-U.S. GAAP Financial Measures and may not be comparable with similar measures used by other entities. They are presented because management and external stakeholders use them in evaluating the Corporation's financial performance and prospects.

Net earnings attributable to common equity shareholders (i.e., Common Equity Earnings) and basic EPS are the most directly comparable U.S. GAAP measures to Adjusted Common Equity Earnings and Adjusted Basic EPS, respectively. These adjusted measures reflect the removal of items that management excludes in its key decision-making processes and evaluation of operating results.

Capital Expenditures include additions to property, plant and equipment and additions to intangible assets, as shown on the condensed consolidated statements of cash flows. It also includes Fortis' 39% share of capital spending for the Wataynikaneyap Transmission Power Project, consistent with Fortis' evaluation of operating results and its role as project manager during the construction of this Major Capital Project.

8 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Non-U.S. GAAP Reconciliation
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Adjusted Common Equity Earnings and Adjusted Basic EPS
Common Equity Earnings	294	284	10	731	634	97
Adjusting item:
Unrealized loss (gain) on mark-to-market of derivatives (1)	8	(12)	20	10	7	3
Adjusted Common Equity Earnings	302	272	30	741	641	100
Adjusted Basic EPS ($)	0.62	0.57	0.05	1.53	1.34	0.19
Capital Expenditures
Additions to property, plant and equipment	938	827	111	1,845	1,693	152
Additions to intangible assets	44	58	(14)	91	107	(16)
Adjusting item:
Wataynikaneyap Transmission Power Project (2)	43	45	(2)	84	94	(10)
Capital Expenditures	1,025	930	95	2,020	1,894	126

(1)    Represents timing differences related to the accounting of natural gas derivatives at Aitken Creek, net of income tax recovery of $3 million and $4 million for the three and six months ended June 30, 2023, respectively (income tax expense of $5 million and income tax recovery of $3 million for the three and six months ended June 30, 2022, respectively), included in the Energy Infrastructure segment

(2)Represents Fortis' 39% share of capital spending for the Wataynikaneyap Transmission Power Project, included in the Other Electric segment

FOCUS ON SUSTAINABILITY

Fortis' focus on sustainability is outlined in its 2022 Annual MD&A. Through 2023, the Corporation has continued to advance work on a range of sustainability initiatives. In August 2023, Fortis released its 2023 Sustainability Update Report, which summarizes recent progress and includes key performance indicators for 2022. Fortis utilities continue to add new renewable energy resources and decarbonize operations while advancing a cleaner energy transition for customers. The Corporation has reduced direct GHG emissions by 29% through 2022 compared to 2019 levels, marking significant progress towards our interim targets to reduce GHG emissions 50% by 2030 and 75% by 2035, as well as our 2050 net-zero direct GHG emissions target. In addition, over the last four years, the GHG intensity of delivered energy has consistently decreased, while net electricity generated by renewable sources and avoided emissions from the use of renewable natural gas has increased significantly.

The report highlights Fortis' advancements in DEI. The Corporation has achieved its Board diversity targets, with 58% of the Board comprised of women and two of twelve members identifying as visible minorities. Our commitment to advancing DEI is reflected in our leadership at Fortis Inc., where 50% of our executive team are women. In addition, to further support Fortis' sustainability reporting, limited third-party assurance was obtained on select 2022 GHG emissions data and Board diversity metrics.

As we transition to a cleaner energy future, customer affordability, safety and reliability remain top priorities and are the cornerstones of our sustainability strategy. Fortis utilities continue to focus on controlling costs, identifying efficiencies and implementing innovative practices to maintain affordability.

REGULATORY MATTERS

ITC

ITC Midwest Capital Structure Complaint: In 2022, FERC issued an order denying the complaint filed by ICAT requesting that ITC Midwest's common equity component of capital structure be reduced from 60% to 53%. In March 2023, FERC confirmed its decision following ICAT's request for rehearing.

MISO Base ROE: In 2022, the D.C. Circuit Court issued a decision vacating certain FERC orders that had established the methodology for setting the base ROE for transmission owners operating in the MISO region, including ITC. This matter dates back to complaints filed at FERC in 2013 and 2015 challenging the MISO base ROE then in effect. The court has remanded the matter to FERC for further process, the timing and outcome of which is unknown. Although any potential impact to Fortis is uncertain, every 10-basis point change in ROE at ITC impacts Fortis' annual EPS by approximately $0.01.

Transmission Incentives: In 2021, FERC issued a supplemental NOPR on transmission incentives modifying the proposal in the initial NOPR released by FERC in 2020. The supplemental NOPR proposes to eliminate the 50-basis point RTO ROE incentive adder for RTO members that have been members for longer than three years. The timing and outcome of this proceeding is unknown.

9 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Transmission ROFR: The State of Iowa has granted incumbent electric transmission owners, including ITC, a ROFR to construct, own and maintain certain electric transmission assets in the state. A challenge against the ROFR statute by certain plaintiffs was initially dismissed by the District Court on the grounds that the plaintiffs lacked standing. In March 2023, the Iowa Supreme Court determined that the plaintiffs have standing to challenge the Iowa ROFR statute, issued a temporary injunction staying enforcement of the ROFR statute, and remanded the matter to the District Court to decide the merits of the claim. ITC previously exercised its right to construct certain electric transmission projects approved and awarded by MISO, including projects associated with the first tranche of MISO's LRTP. Management does not believe that this proceeding will impact projects that have already been approved and under development; however, the timing of this proceeding and any impact on future projects, is unknown.

UNS Energy

TEP General Rate Application: In July 2023, the ALJ issued a recommended opinion and order on TEP's general rate application recommending, among other things, an increase in non-fuel revenue of US$102 million, a 9.4% ROE with a 0.2% return on the fair value increment, and a 54.32% common equity component of capital structure. TEP's existing ROE and common equity component of capital structure is 9.15% and 53%, respectively. While the timing and outcome of this proceeding is unknown, the ALJ recommended that the new rates become effective on or after September 1, 2023.

PPFAC Mechanism: The PPFAC mechanism allows for the timely recovery or return of purchased power and fuel costs, as compared to that collected in customer rates, at TEP and UNSE. The PPFAC balance has increased in recent years, reflecting higher commodity costs. In May 2023, the ACC approved rate adjustments at TEP and UNSE to collect the PPFAC balances over 12- and 33-month periods, respectively.

Central Hudson

General Rate Application: In July 2023, Central Hudson filed a rate application with the PSC requesting an increase in electric and gas delivery rates effective July 1, 2024. The application includes a request to set Central Hudson's allowed ROE at 9.8% and a 50% common equity component of capital structure. The timing and outcome of this proceeding is unknown.

CIS Implementation:In January 2023, Central Hudson filed a response to the PSC's Order to Commence Proceeding and Show Cause, which had directed Central Hudson to explain why the PSC should not pursue civil or administrative penalties or initiate a proceeding to review the prudence of implementation costs associated with its new CIS. In July 2023, an interim agreement was reached with the PSC, in which Central Hudson agreed to independent third-party verification of recent system improvements related to its billing system, and to accelerate the implementation of its monthly meter reading plan. The timing and outcome of this proceeding remains unknown.

FortisBC Energy and FortisBC Electric

GCOC Proceeding: In 2021, the BCUC initiated a proceeding including a review of the common equity component of capital structure and the allowed ROE. FortisBC filed a final argument with the BCUC in December 2022 and the proceeding remains ongoing, with a decision expected in the third quarter 2023. The decision could be effective retroactively to January 1, 2023.

FortisAlberta

2024 GCOC Proceeding: In2022, the AUC initiated proceedings to establish the cost of capital parameters for Alberta regulated utilities, including consideration of a formula-based approach to setting the allowed ROE for 2024 and beyond. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

Third PBR Term: In 2021, the AUC issued a decision confirming that Alberta distribution utilities will be subject to a third PBR term commencing in 2024. The AUC also initiated a new proceeding to consider the design of the third PBR term. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

REA Cost Recovery:In 2021, the AUC determined that costs attributable to REAs, approximating $10 million annually, can no longer be recovered from FortisAlberta's rate payers, effective January 1, 2023. In April 2023, the Alberta Court of Appeal dismissed FortisAlberta's appeal which had asserted that the AUC erred in preventing the company from recovering these costs from its own rate payers to the extent that such costs cannot be recovered directly from REAs. FortisAlberta continues to assess other means, including legislative amendments, to recover these costs.

10 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

FINANCIAL POSITION

Significant Changes between June 30, 2023 and December 31, 2022
Balance Sheet Account	Increase (Decrease)
($ millions)	FX	Other	Explanation
Cash and cash equivalents	(3)	484	Primarily reflects the timing of debt issuances, net of debt repayments, at ITC. Balances on hand have been largely invested in short-term deposits.
Accounts receivable and other current assets	(30)	(729)	Due to the seasonality of sales in Canada and a decrease in the fair value of energy contracts at UNS Energy and FortisBC Energy.
Assets held for sale	—	561	Reflects the pending sale of Aitken Creek. See "Key Developments" on page 1 and Note 7 of the Interim Financial Statements.
Inventories	(9)	(118)	Due to the reclassification of gas inventory at Aitken Creek to assets held for sale, as well as a lower weighted average cost and volume of natural gas in storage at FortisBC Energy.
Property, plant and equipment, net	(617)	731	Due to capital expenditures, partially offset by depreciation and the reclassification of property, plant and equipment at Aitken Creek to assets held for sale.
Goodwill	(254)	(27)	Reflects the reclassification of goodwill associated with Aitken Creek to assets held for sale.
Short-term borrowings	(6)	(167)	Reflects the repayment of commercial paper at ITC.
Accounts payable and other current liabilities	(36)	(820)	Due to the timing of the declaration of common share dividends as well as lower amounts owing for energy supply costs, primarily at UNS Energy and FortisBC Energy.
Liabilities associated with assets held for sale	—	129	Reflects the pending sale of Aitken Creek. See "Key Developments" on page 1 and Note 7 of the Interim Financial Statements.
Regulatory liabilities (current and long-term)	(57)	(141)	Reflects a decrease in unrealized gains on energy contracts at UNS Energy, which are utilized to reduce exposure to changes in energy prices.
Long-term debt (including current portion)	(429)	1,109	Reflects debt issuances, partially offset by debt repayments, as well as lower borrowings under committed credit facilities, in support of the Corporation's Capital Plan.
Shareholders' equity	(340)	689	Due primarily to: (i) Common Equity Earnings for the six months ended June 30, 2023, less dividends declared on common shares; and, (ii) the issuance of common shares, largely under the DRIP.

LIQUIDITY AND CAPITAL RESOURCES

Cash Flow Requirements

At the subsidiary level, it is expected that operating expenses and interest costs will be paid from Operating Cash Flow, with varying levels of residual cash flow available for capital expenditures and/or dividend payments to Fortis. Remaining capital expenditures are expected to be financed primarily from borrowings under credit facilities, long-term debt offerings and equity injections from Fortis. Borrowings under credit facilities may be required periodically to support seasonal working capital requirements.

Cash required of Fortis to support subsidiary growth is generally derived from borrowings under the Corporation's committed credit facility, the operation of the DRIP and issuances of common shares, preference equity and long-term debt. The subsidiaries pay dividends to Fortis and receive equity injections from Fortis when required. Both Fortis and its subsidiaries initially borrow through their committed credit facilities and periodically replace these borrowings with long-term financing. Financing needs also arise to refinance maturing debt.

11 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Credit facilities are syndicated primarily with large banks in Canada and the U.S., with no one bank holding more than approximately 20% of the Corporation's total revolving credit facilities. Approximately $5.7 billion of the total credit facilities are committed with maturities ranging from 2023 through 2028. Available credit facilities are summarized in the following table.

Credit Facilities
As at	Regulated Utilities	Corporate and Other	June 30, 2023	December 31, 2022
($ millions)
Total credit facilities (1)	3,963	2,034	5,997	5,850
Credit facilities utilized:
Short-term borrowings	(80)	—	(80)	(253)
Long-term debt (including current portion)	(792)	(770)	(1,562)	(1,657)
Letters of credit outstanding	(57)	(38)	(95)	(128)
Credit facilities unutilized	3,034	1,226	4,260	3,812

(1)    See Note 14 in the 2022 Annual Financial Statements for a description of the credit facilities as at December 31, 2022.

In April 2023, ITC increased its total credit facilities available from US$900 million to US$1 billion and extended the maturity to April 2028.

In May 2023, the Corporation amended its $1.3 billion revolving term committed credit facility agreement to extend the maturity to July 2028.

Also in May 2023, the Corporation extended the maturity on its unsecured US$500 million non-revolving term credit facility to May 2024. The facility is repayable at any time without penalty, and provides the Corporation with additional, cost effective short-term financing.

The Corporation's ability to service debt and pay dividends is dependent on the financial results of, and the related cash payments from, its subsidiaries. Certain regulated subsidiaries are subject to restrictions that limit their ability to distribute cash to Fortis, including restrictions by certain regulators limiting annual dividends and restrictions by certain lenders limiting debt to total capitalization. There are also practical limitations on using the net assets of the regulated subsidiaries to pay dividends, based on management's intent to maintain the subsidiaries' regulator-approved capital structures. Fortis does not expect that maintaining such capital structures will impact its ability to pay dividends in the foreseeable future.

As at June 30, 2023, consolidated fixed-term debt maturities/repayments are expected to average $1,472 million annually over the next five years and approximately 73% of the Corporation's consolidated long-term debt, excluding credit facility borrowings, had maturities beyond five years.

In November 2022, Fortis filed a short-form base shelf prospectus with a 25-month life under which it may issue common or preference shares, subscription receipts, or debt securities in an aggregate principal amount of up to $2.0 billion. As at June 30, 2023, $2.0 billion remained available under the short-form base shelf prospectus.

Fortis is well positioned with strong liquidity. This combination of available credit facilities and manageable annual debt maturities/repayments provides flexibility in the timing of access to capital markets. Given current credit ratings and capital structures, the Corporation and its subsidiaries currently expect to continue to have reasonable access to long-term capital in 2023.

Fortis and its subsidiaries were in compliance with debt covenants as at June 30, 2023 and are expected to remain compliant in 2023.

Cash Flow Summary
Summary of Cash Flows
Periods ended June 30	Quarter			Year-to-Date
($ millions)	2023	2022	Variance	2023	2022	Variance
Cash and cash equivalents, beginning of period	576	365	211	209	131	78
Cash from (used in):
Operating activities	944	759	185	1,859	1,572	287
Investing activities	(1,013)	(918)	(95)	(1,954)	(1,834)	(120)
Financing activities	209	124	85	597	461	136
Effect of exchange rate changes on cash and cash equivalents	(7)	8	(15)	(2)	8	(10)
Change in cash associated with assets held for sale	(19)	—	(19)	(19)	—	(19)
Cash and cash equivalents, end of period	690	338	352	690	338	352

Operating Activities

See "Performance at a Glance - Operating Cash Flow" on page 4.

12 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Investing Activities

The Corporation's Capital Plan for 2023 is estimated to be $4.3 billion, an increase of approximately 7% from $4.0 billion in 2022. The increase in cash used in investing activities for the quarter and year-to-date periods reflects higher capital investments planned for 2023, as well as the higher U.S.-to-Canadian dollar exchange rate. See "Capital Plan" on page 14.

Financing Activities

Cash flows related to financing activities will fluctuate largely as a result of changes in the subsidiaries' capital expenditures and the amount of Operating Cash Flow available to fund those capital expenditures, which together impact the amount of funding required from debt and common equity issuances. The increase in cash provided by financing activities in 2023 also reflects the advancement of certain planned debt issuances in consideration of further expected increases in interest rates. See "Cash Flow Requirements" on page 11.

Debt Financing
Significant Long-Term Debt Issuances
Year-to-date June 30, 2023	Month	Interest Rate					Use of Proceeds
($ millions, except as noted)	Issued	(%)		Maturity	Amount
ITC
Unsecured senior notes	June	5.40	(1)	2033	US	500	(2) (3) (4)
Unsecured senior notes	June	4.95	(5)	2027	US	300	(2) (3) (4)
UNS Energy
Unsecured senior notes	February	5.50		2053	US	375	(2) (3)
FortisAlberta
Unsecured senior debentures	May	4.86		2053	200		(3) (4)
Central Hudson
Unsecured senior notes	March	5.68		2033	US	40	(3) (4)
Unsecured senior notes	March	5.78		2035	US	15	(3) (4)
Unsecured senior notes	March	5.88		2038	US	35	(3) (4)

(1)    ITC entered into interest rate locks which reduced the effective interest rate to 5.32%. See Note 13 to the Interim Financial Statements

(2)    Repay maturing long-term debt

(3)    General corporate purposes

(4)     Repay short-term and/or credit facility borrowings

(5)     Represents a second tranche of ITC's existing 4.95% senior notes, originally issued in 2022

Common Equity Financing
Common Equity Issuances and Dividends Paid
Periods ended June 30	Quarter			Year-to-Date
($ millions, except as indicated)	2023	2022	Variance	2023	2022	Variance
Common shares issued:
Cash (1)	14	18	(4)	28	40	(12)
Non-cash (2)	102	93	9	205	188	17
Total common shares issued	116	111	5	233	228	5
Number of common shares issued(# millions)	2.0	1.8	0.2	4.2	3.9	0.3
Common share dividends paid:
Cash	(172)	(164)	(8)	(342)	(324)	(18)
Non-cash (3)	(102)	(92)	(10)	(205)	(186)	(19)
Total common share dividends paid	(274)	(256)	(18)	(547)	(510)	(37)
Dividends paid per common share ($)	0.565	0.535	0.03	1.13	1.07	0.06

(1)    Includes common shares issued under stock option and employee share purchase plans

(2)    Common shares issued under the DRIP and stock option plan

(3)    Common share dividends reinvested under the DRIP

On February 9, 2023, Fortis declared a dividend of $0.565 per common share which was paid on June 1, 2023, and on August 1, 2023, Fortis declared a dividend of $0.565 per common share payable on September 1, 2023. The payment of dividends is at the discretion of the Board and depends on the Corporation's financial condition and other factors.

13 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Contractual Obligations

There were no material changes to the contractual obligations disclosed in the 2022 Annual MD&A, except issuances of long-term debt and credit facility utilization (see "Cash Flow Summary" on page 12).

Off-Balance Sheet Arrangements

There were no material changes to off-balance sheet arrangements from those disclosed in the 2022 Annual MD&A.

Capital Structure and Credit Ratings

Fortis requires ongoing access to capital and, therefore, targets a consolidated long-term capital structure that will enable it to maintain investment-grade credit ratings. The regulated utilities maintain their own capital structures in line with those reflected in customer rates.

Consolidated Capital Structure	June 30, 2023		December 31, 2022
As at	($ millions)	(%)	($ millions)	(%)
Debt (1)	28,817	55.4	28,792	55.8
Preference shares	1,623	3.1	1,623	3.1
Common shareholders' equity and non-controlling interests (2)	21,554	41.5	21,219	41.1
	51,994	100.0	51,634	100.0

(1)    Includes long-term debt and finance leases, including current portion, and short-term borrowings, net of cash

(2)    Includes shareholders' equity, excluding preference shares, and non-controlling interests. Non-controlling interests represented 3.5% as at June 30, 2023 (December 31, 2022 - 3.5%)

Outstanding Share Data

As at August 1, 2023, the Corporation had issued and outstanding 486.5 million common shares and the following First Preference Shares: 5.0 million Series F; 9.2 million Series G; 7.7 million Series H; 2.3 million Series I; 8.0 million Series J; 10.0 million Series K; and 24.0 million Series M.

Only the common shares of the Corporation have voting rights. The Corporation's first preference shares do not have voting rights unless and until Fortis fails to pay eight quarterly dividends, whether or not consecutive or declared.

If all outstanding stock options were converted as at August 1, 2023, an additional 2.1 million common shares would be issued and outstanding.

Credit Ratings

The Corporation's credit ratings shown below reflect its low risk profile, diversity of operations, the stand-alone nature and financial separation of each regulated subsidiary, and the level of holding company debt.

As at June 30, 2023	Rating	Type	Outlook
S&P	A-	Issuer	Stable
	BBB+	Unsecured debt
DBRS Morningstar	A (low)	Issuer	Stable
	A (low)	Unsecured debt
Moody's	Baa3	Issuer	Stable
	Baa3	Unsecured debt

In May 2023, DBRS Morningstar confirmed the Corporation's A (low) issuer and senior unsecured debt credit ratings and stable outlook.

In July 2023, S&P confirmed the Corporation's 'A-' issuer and 'BBB+' senior unsecured debt credit ratings and stable outlook.

Capital Plan

Year-to-date Capital Expenditures of $2.0 billion are consistent with expectations and the Corporation's annual $4.3 billion Capital Plan is on track.

While global supply chain constraints and inflation represent potential concerns, the Corporation does not expect a material impact on its 2023-2027 Capital Plan, although certain planned expenditures may shift within the five years. The Corporation continues to proactively work to mitigate supply chain constraints by identifying high priority materials and consolidating buying power to improve outcomes, increasing inventory levels, and closely working with suppliers to ensure material availability.

14 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Capital Expenditures (1)
Year-to-date June 30, 2023	Regulated Utilities
		UNS Energy	Central Hudson	FortisBC Energy	Fortis Alberta	FortisBC Electric	Other Electric	Total Regulated Utilities	Non- Regulated
($ millions, except as indicated)	ITC									(2)	Total
Total	600	368	156	239	301	62	292	2,018	2		2,020

(1)    See "Non-U.S. GAAP Financial Measures" on page 8

(2)    Energy Infrastructure segment

Five-Year Capital Plan

The 2023-2027 Capital Plan is targeted at $22.3 billion, reflecting an average of $4.5 billion of Capital Expenditures annually. In total, Fortis expects to invest $5.9 billion in cleaner energy over the five-year period. The Capital Plan is low risk and highly executable, with 99% of planned expenditures to occur at the regulated utilities and only 17% relating to Major Capital Projects. Geographically, 55% of planned expenditures are expected in the U.S., including 26% at ITC, with 41% in Canada and the remaining 4% in the Caribbean.

Planned Capital Expenditures are based on detailed forecasts of energy demand as well as labour and material costs, including inflation, supply chain availability, general economic conditions, foreign exchange rates and other factors. These could change and cause actual expenditures to differ from forecast.

Major Capital Project Updates

FortisBC Energy

In May 2023, the CPCN application for the AMI project was approved by the BCUC. The project includes replacement of residential and small commercial meters with advanced meters to support the safety, resiliency, and efficient operation of the gas distribution system. The project is expected to commence in the second half of 2023.

FortisBC Energy submitted a supplemental filing with the BCUC in May 2023 for the Okanagan Capacity Upgrade project, to provide updates to key evidence in the proceeding based on recently available information. With respect to the Tilbury LNG Storage Expansion project, the regulatory process was adjourned in March 2023 in order for FortisBC Energy to prepare further information in support of the CPCN application. As a result, BCUC approval for both projects could be later than originally expected.

FortisBC Energy received approval from the BCUC in May 2023, as directed by Order of the Lieutenant Governor in Council, for amended transportation rate schedules for the Eagle Mountain Woodfibre Gas Line project. This approval brings the project one-step closer to commencement of construction. FortisBC Energy continues to receive deposit funding from Woodfibre LNG Limited for development expenditures to be incurred for the project.

Additional Investment Opportunities

Propel New York Energy Project

Central Hudson owns a minority equity interest in Transco, a joint venture with affiliates of other investor-owned utilities in New York State, which was created to develop, own, and operate electric transmission projects in the state. In June 2023, the New York Independent System Operator selected a proposal by Transco, in partnership with the New York Power Authority, to construct transmission infrastructure to deliver at least 3,000 MW from Long Island offshore wind facilities to the rest of the state by 2030. Transco's portion of the project, titled the "Propel New York Energy Project," is estimated to cost approximately US$2.2 billion, of which Central Hudson will contribute approximately 10%.

BUSINESS RISKS

The Corporation's business risks remain substantially unchanged from those disclosed in its 2022 Annual MD&A. See "Regulatory Matters" on page 9 and "Outlook" on page 18 for applicable updates.

ACCOUNTING MATTERS

Accounting Policies

The Interim Financial Statements have been prepared following the same accounting policies and methods as those used to prepare the 2022 Annual Financial Statements.

15 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Critical Accounting Estimates

The preparation of the Interim Financial Statements required management to make estimates and judgments, including those related to regulatory decisions, that affect the reported amounts of, and disclosures related to, assets, liabilities, revenues, expenses, gains, losses and contingencies. Actual results could differ materially from estimates.

There were no material changes to the nature of the Corporation's critical accounting estimates or contingencies from those disclosed in the 2022 Annual MD&A.

FINANCIAL INSTRUMENTS

Long-Term Debt and Other

As at June 30, 2023, the carrying value of long-term debt, including the current portion, was $29.3 billion (December 31, 2022 - $28.6 billion) compared to an estimated fair value of $26.9 billion (December 31, 2022 - $25.8 billion).

The consolidated carrying value of the remaining financial instruments, other than derivatives, approximates fair value, reflecting their short-term maturity, normal trade credit terms and/or nature.

Derivatives

Derivatives are recorded at fair value with certain exceptions, including those derivatives that qualify for the normal purchase and normal sale exception.

There were no material changes with respect to the nature and purpose, methodologies for fair value determination, and portfolio of the Corporation's derivatives from those disclosed in the 2022 Annual MD&A, except for interest rate locks utilized at ITC and Fortis, as disclosed in Note 13 to the Interim Financial Statements.

SUMMARY OF QUARTERLY RESULTS
		Common Equity
	Revenue	Earnings	Basic EPS	Diluted EPS
Quarter ended	($ millions)	($ millions)	($)	($)
June 30, 2023	2,594	294	0.61	0.61
March 31, 2023	3,319	437	0.90	0.90
December 31, 2022	3,168	370	0.77	0.77
September 30, 2022	2,553	326	0.68	0.68
June 30, 2022	2,487	284	0.59	0.59
March 31, 2022	2,835	350	0.74	0.74
December 31, 2021	2,583	328	0.69	0.69
September 30, 2021	2,196	295	0.63	0.62

Generally, within each calendar year, quarterly results fluctuate in accordance with seasonality. Given the diversified nature of the Corporation's subsidiaries, seasonality varies. Most of the annual earnings of the gas utilities are realized in the first and fourth quarters due to space-heating requirements. Earnings for the electric distribution utilities in the U.S. are generally highest in the second and third quarters due to the use of air conditioning and other cooling equipment.

Generally, from one calendar year to the next, quarterly results reflect: (i) continued organic growth driven by the Corporation's Capital Plan; (ii) any significant temperature fluctuations from seasonal norms; (iii) the impact of market conditions, particularly with respect to long-term wholesale sales and transmission revenue at UNS Energy, as well as margins realized on gas sold at Aitken Creek; (iv) the timing and significance of any regulatory decisions; (v) changes in the U.S.-to-Canadian dollar exchange rate; (vi) for revenue, the flow-through in customer rates of commodity costs; and (vii) for EPS, increases in the weighted average number of common shares outstanding.

June 2023/June 2022

See "Performance at a Glance" on page 2.

16 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

March 2023/March 2022

Common Equity Earnings increased by $87 million and basic EPS increased by $0.16 in comparison to the first quarter of 2022 due to Rate Base growth, mainly at ITC and the western Canadian utilities, as well as higher earnings at UNS Energy. Market conditions resulted in wholesale electricity sales with favourable margin and higher transmission revenue at UNS Energy in the first quarter of 2023 compared to later quarters in 2022. Higher retail electricity sales, including the impact of favourable weather, and lower depreciation expense associated with the retirement of the San Juan generating station in June 2022, also contributed to results in Arizona. Results for the quarter also reflected higher earnings at Aitken Creek, an increase in the market value of investments that support retirement benefits at UNS Energy and ITC, and a higher U.S.-to-Canadian dollar foreign exchange rate, partially offset by higher corporate finance costs. The change in basic EPS also reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's DRIP.

December 2022/December 2021

Common Equity Earnings increased by $42 million and basic EPS increased by $0.08 in comparison to the fourth quarter of 2021 due to: (i) Rate Base growth; (ii) higher retail electricity sales and transmission revenue at UNS Energy; (iii) higher earnings from the energy infrastructure segment driven by hydroelectric production in Belize, as well as the favourable impact of market conditions at Aitken Creek; and (iv) the timing of expenses at FortisAlberta. The translation of U.S. dollar-denominated subsidiary earnings at the higher U.S.-to-Canadian dollar foreign exchange rate and lower stock-based compensation costs also contributed to results with these impacts exceeding the related losses associated with hedging activities. The increase in earnings was partially offset by higher corporate costs, reflecting higher finance costs and a lower income tax recovery, as well as lower earnings at Central Hudson, reflecting the finalization of the company's rate application in late 2021 with retroactive application to July 1, 2021. The change in basic EPS also reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's DRIP.

September 2022/September 2021

Common Equity Earnings increased by $31 million and basic EPS increased by $0.05 in comparison to the third quarter of 2021 due to: (i) Rate Base growth, mainly at ITC; (ii) higher retail electricity sales, transmission revenue and earnings associated with the Oso Grande generating facility in Arizona; (iii) higher earnings from the energy infrastructure segment mainly due to mark-to-market accounting of natural gas derivatives and higher hydroelectric production in Belize; and (iv) the impact of new customer rates and the timing of operating costs at Central Hudson.

Growth was tempered by the timing of expenses in Alberta and a favourable adjustment recognized in 2021 related to interest rate swaps at ITC. Results for the third quarter of 2022 were also impacted by significant items at ITC, including costs associated with the suspension of the Lake Erie Connector project, and the revaluation of deferred income tax assets due to a reduction in the corporate income tax rate in the state of Iowa. The impact of mark-to-market losses associated with hedging activities was more than offset by lower stock-based compensation costs and the translation of U.S. dollar-denominated subsidiary earnings at the higher U.S.-to-Canadian dollar foreign exchange rate. The change in basic EPS also reflected an increase in the weighted average number of common shares outstanding, largely associated with the Corporation's DRIP.

RELATED-PARTY AND INTER-COMPANY TRANSACTIONS

Related-party transactions are in the normal course of operations and are measured at the amount of consideration agreed to by the related parties. There were no material related-party transactions for the three and six months ended June 30, 2023 and 2022.

The lease of gas storage capacity and gas sales from Aitken Creek to FortisBC Energy of $6 million and $15 million for the three and six months ended June 30, 2023, respectively (three and six months ended June 30, 2022 - $7 million and $20 million, respectively) are inter-company transactions between non-regulated and regulated entities, which were not eliminated on consolidation.

As at June 30, 2023, accounts receivable included $4 million due from Belize Electricity (December 31, 2022 - $7 million).

Fortis periodically provides short-term financing to subsidiaries to support capital expenditures and seasonal working capital requirements, the impacts of which are eliminated on consolidation. As at June 30, 2023 and December 31, 2022, there were no inter-segment loans outstanding. Interest charged on inter-segment loans was not material for the three and six months ended June 30, 2023 and 2022.

17 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

OUTLOOK

Fortis continues to enhance shareholder value through the execution of its Capital Plan, the balance and strength of its diversified portfolio of regulated utility businesses, and growth opportunities within and proximate to its service territories. While energy price volatility, global supply chain constraints, increasing interest rates and inflation represent potential concerns, the Corporation does not expect these factors to have a material impact on its operations or financial results in 2023.

Fortis is executing on the transition to a cleaner energy future and is on track to achieve its corporate-wide targets to reduce GHG emissions by 50% by 2030 and 75% by 2035. The Corporation's additional 2050 net-zero direct GHG emissions target reinforces Fortis' commitment to further decarbonize over the long-term, while preserving customer reliability and affordability.

The Corporation's $22.3 billion five-year Capital Plan is expected to increase midyear Rate Base from $34.1 billion in 2022 to $46.1 billion by 2027, translating into a five-year CAGR of 6.2%.

Beyond the five-year Capital Plan, additional opportunities to expand and extend growth include: further expansion of the electric transmission grid in the U.S. to facilitate the interconnection of cleaner energy, including infrastructure investments associated with the IRA and the MISO LRTP; climate adaptation and grid resiliency investments; renewable gas solutions and LNG infrastructure in British Columbia; and the acceleration of cleaner energy infrastructure investments across our jurisdictions.

Fortis expects its long-term growth in Rate Base will drive earnings that support dividend growth guidance of 4-6% annually through 2027, and is premised on the assumptions and material factors listed under "Forward-Looking Information".

FORWARD-LOOKING INFORMATION

Fortis includes forward-looking information in the MD&A 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: the expected timing and outcome of the sale of Aitken Creek; forecast capital expenditures for 2023 and 2023-2027, including cleaner energy investments; the 2030 GHG emissions reduction target; the 2035 GHG emissions reduction target; the 2050 net-zero direct GHG emissions target; the expected timing, outcome and impact of regulatory proceedings and decisions; the expected funding sources for operating expenses, interest costs and capital expenditures; the expectation that maintaining the capital structures of the regulated operating subsidiaries will not have an impact on the Corporation's ability to pay dividends in the foreseeable future; the expected consolidated fixed-term debt maturities and repayments over the next five years; the expectation that the Corporation and its subsidiaries will continue to have access to long-term capital and will remain compliant with debt covenants in 2023; the expectation that energy price volatility, global supply chain constraints, increasing interest rates and inflation will not have a material impact on operations or financial results in 2023; forecast Rate Base and Rate Base growth through 2027; the nature, timing, benefits and expected costs of certain capital projects, including FortisBC Energy's AMI project, Okanagan Capacity Upgrade project, Tilbury LNG Storage Expansion project, and Eagle Mountain Woodfibre Gas Pipeline project, and additional opportunities beyond the Capital Plan, including Central Hudson's investment in the Propel New York Energy project through Transco, investments associated with the IRA, the MISO LRTP, climate adaptation and grid resiliency, renewable gas solutions and LNG infrastructure in British Columbia, and the acceleration of cleaner energy infrastructure; and the expectation that long-term growth in Rate Base will drive earnings that support dividend growth guidance of 4-6% annually through 2027.

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 impact from energy price volatility, global supply chain constraints and inflation; 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; the realization of additional opportunities beyond the Capital Plan; no significant variability in interest rates; the Board exercising its discretion to declare dividends, taking into account the financial performance and condition 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 under the heading "Business Risks" in the 2022 Annual MD&A and in other continuous disclosure materials filed from time to time with Canadian securities regulatory authorities and the Securities and Exchange Commission. Key risk factors for 2023 include, but are not limited to: uncertainty regarding changes in utility regulation, including the outcome of regulatory proceedings at the Corporation's utilities; the physical risks associated with the provision of electric and gas service, which are exacerbated by the impacts of climate change; risks related to environmental laws and regulations; risks associated with capital projects and the impact on the Corporation's continued growth; risks associated with cybersecurity and information and operations technology; the impact of weather variability and seasonality on heating and cooling loads, gas distribution volumes and hydroelectric generation; risks associated with commodity price volatility and supply of purchased power; and risks related to general economic conditions, including inflation, interest rate and foreign exchange risks.

All forward-looking information herein is given as of August 1, 2023. 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.

18 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

GLOSSARY

2022 Annual Financial Statements: the Corporation's audited consolidated financial statements and notes thereto for the year ended December 31, 2022

2022 Annual MD&A: the Corporation's management discussion and analysis for the year ended December 31, 2022

ACC:Arizona Corporation Commission

Adjusted Basic EPS: Adjusted Common Equity Earnings divided by the basic weighted average number of common shares outstanding

Adjusted Common Equity Earnings: net earnings attributable to common equity shareholders adjusted as shown under "Non-U.S. GAAP Financial Measures" on page 8

Aitken Creek:Aitken Creek Gas Storage ULC, a direct 93.8% owned subsidiary of FortisBC Holdings Inc.

ALJ:Administrative Law Judge

AMI: Advanced Metering Infrastructure

AUC:Alberta Utilities Commission

Belize Electricity: Belize Electricity Limited, in which Fortis indirectly holds a 33% equity interest

BCUC:British Columbia Utilities Commission

Board: Board of Directors of the Corporation

CAGR(s): compound annual growth rate of a particular item. CAGR = (EV/BV)1-N-1, where: (i) EV is the ending value of the item; (ii) BV is the beginning value of the item; and (iii) N is the number of periods. Calculated on a constant U.S. dollar-to-Canadian dollar exchange rate

Capital Expenditures:cash outlay for additions to property, plant and equipment and intangible assets as shown in the Interim Financial Statements, as well as Fortis' 39% share of capital spending for the Wataynikaneyap Transmission Power Project. See "Non-U.S. GAAP Financial Measures" on page 8

Capital Plan: forecast Capital Expenditures. Represents a non-U.S. GAAP financial measure calculated in the same manner as Capital Expenditures

Caribbean Utilities: Caribbean Utilities Company, Ltd., an indirect approximately 60%-owned (as at December 31, 2022) subsidiary of Fortis, together with its subsidiary

Central Hudson: CH Energy Group Inc., an indirect wholly owned subsidiary of Fortis, together with its subsidiaries, including Central Hudson Gas & Electric Corporation

CIS: customer information system

Common Equity Earnings:net earnings attributable to common equity shareholders

Corporation: Fortis Inc.

CPCN: Certificate of Public Convenience and Necessity

DBRS Morningstar:DBRS Limited

D.C. Circuit Court:U.S. Court of Appeals for the District of Columbia Circuit

DEI:diversity, equity and inclusion

DRIP: dividend reinvestment plan

EPS: earnings per common share

FERC:Federal Energy Regulatory Commission

Fortis:Fortis Inc.

FortisAlberta: FortisAlberta Inc., an indirect wholly owned subsidiary of Fortis

FortisBC Electric: FortisBC Inc., an indirect wholly owned subsidiary of Fortis, together with its subsidiaries

FortisBC Energy:FortisBC Energy Inc., an indirect wholly owned subsidiary of Fortis, together with its subsidiaries

FortisOntario:FortisOntario Inc., a direct wholly owned subsidiary of Fortis, together with its subsidiaries

FortisTCI: FortisTCI Limited, an indirect wholly owned subsidiary of Fortis, together with its subsidiary

Fortis Belize: Fortis Belize Limited, an indirect wholly owned subsidiary of Fortis

FX:foreign exchange associated with the translation of U.S. dollar-denominated amounts. Foreign exchange is calculated by applying the change in the U.S. dollar-to-Canadian dollar FX rates to the prior period U.S. dollar balance

GCOC:generic cost of capital

GHG: greenhouse gas

GWh:gigawatt hour(s)

ICAT: Iowa Coalition for Affordable Transmission

Interim Financial Statements: the Corporation's unaudited condensed consolidated interim financial statements and notes thereto for the three and six months ended June 30, 2023

Interim MD&A: the Corporation's management discussion and analysis for the three and six months ended June 30, 2023

IRA: Inflation Reduction Act of 2022

ITC: ITC Investment Holdings Inc., an indirect 80.1%-owned subsidiary of Fortis, together with its subsidiaries, including International Transmission Company, Michigan Electric Transmission Company, LLC, ITC Midwest, and ITC Great Plains, LLC

ITC Midwest: ITC Midwest LLC

LNG:liquefied natural gas

LRTP: long-range transmission plan

Major Capital Projects:projects, other than ongoing maintenance projects, individually costing $200 million or more in the forecast/planning period

19 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

Interim Management Discussion and Analysis

Maritime Electric: Maritime Electric Company, Limited, an indirect wholly owned subsidiary of Fortis

MISO: Midcontinent Independent System Operator, Inc.

Moody's:Moody's Investor Services, Inc.

Newfoundland Power: Newfoundland Power Inc., a direct wholly owned subsidiary of Fortis

Non-U.S. GAAP Financial Measures: financial measures that do not have a standardized meaning prescribed by U.S. GAAP

NOPR: notice of proposed rulemaking

NYSE:New York Stock Exchange

Operating Cash Flow: cash from operating activities

PBR: performance-based rate setting

PJ: petajoule(s)

PPFAC: Purchased Power and Fuel Adjustment Clause

PSC:New York State Public Service Commission

Rate Base: the stated value of property on which a regulated utility is permitted to earn a specified return in accordance with its regulatory construct

REA: Rural Electrification Association

ROE: rate of returnon common equity

ROFR: right of first refusal

RTO:regional transmission organization

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

SEDAR:Canadian System for Electronic Document Analysis and Retrieval

TEP:Tucson Electric Power Company, a direct wholly owned subsidiary of UNS Energy

Transco: New York Transco LLC

TSR:total shareholder return, which is a measure of the return to common equity shareholders in the form of share price appreciation and dividends (assuming reinvestment) over a specified time period in relation to the share price at the beginning of the period

TSX: Toronto Stock Exchange

UNSE:UNS Electric, Inc.

UNS Energy:UNS Energy Corporation, an indirect wholly owned subsidiary of Fortis, together with its subsidiaries, including TEP, UNSE and UNS Gas, Inc.

U.S.:United States of America

U.S. GAAP:accounting principles generally accepted in the U.S.

Wataynikaneyap Power: Wataynikaneyap Power Limited Partnership, in which Fortis indirectly holds a 39% equity interest

20 FORTIS INC. JUNE 30, 2023 QUARTER REPORT

XML

Cover Page	6 Months Ended
	Jun. 30, 2023
Cover [Abstract]
Document Type	6-K
Entity Registrant Name	Fortis Inc.
Entity Address, Address Line Three	Fortis Place
Entity Address, Address Line Two	Suite 1100
Entity Address, Address Line One	5 Springdale Street
Entity Address, City or Town	St. John's
Entity Address, State or Province	NL
Entity Address, Country	CA
Entity Address, Postal Zip Code	A1E 0E4
Entity Central Index Key	0001666175
Current Fiscal Year End Date	--12-31
Document Period End Date	Jun. 30, 2023
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q2
Amendment Flag	false

XML

Condensed Consolidated Interim Balance Sheets (Unaudited) - CAD ($) $ in Millions		Jun. 30, 2023	Dec. 31, 2022
Current assets
Cash and cash equivalents		$ 690	$ 209
Accounts receivable and other current assets (Note 5)		1,580	2,339
Prepaid expenses		162	146
Inventories		534	661
Regulatory assets (Note 6)		730	914
Assets held for sale (Note 7)		561	0
Total current assets		4,257	4,269
Other assets		1,146	1,213
Regulatory assets (Note 6)		3,226	3,095
Property, plant and equipment, net		41,777	41,663
Intangible assets, net		1,492	1,548
Goodwill		12,183	12,464
Total assets		64,081	64,252
Current liabilities
Short-term borrowings (Note 8)		80	253
Accounts payable and other current liabilities		2,432	3,288
Regulatory liabilities (Note 6)		489	595
Current installments of long-term debt (Note 8)		2,284	2,481
Liabilities associated with assets held for sale (Note 7)		129	0
Total current liabilities		5,414	6,617
Regulatory liabilities (Note 6)		3,228	3,320
Deferred income taxes		4,018	4,060
Long-term debt (Note 8)		26,808	25,931
Finance leases		335	336
Other liabilities		1,101	1,146
Total liabilities		40,904	41,410
Commitments and contingencies (Note 14)
Equity
Common shares	[1]	14,889	14,656
Preference shares		1,623	1,623
Additional paid-in capital		8	10
Accumulated other comprehensive income		669	1,008
Retained earnings		4,190	3,733
Shareholders' equity		21,379	21,030
Non-controlling interests		1,798	1,812
Total equity		23,177	22,842
Total liabilities and equity		$ 64,081	$ 64,252

[1] No par value. Unlimited authorized shares. 486.4 million and 482.2 million issued and outstanding as at June 30, 2023 and December 31, 2022, respectively.

XML

Condensed Consolidated Interim Balance Sheets (Unaudited) (Parenthetical) - shares shares in Millions	Jun. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Common stock, shares issued (in shares)	486.4	482.2
Common stock, shares outstanding (in shares)	486.4	482.2

XML

Condensed Consolidated Interim Statements of Earnings (Unaudited) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Statement [Abstract]
Revenue	$ 2,594	$ 2,487	$ 5,913	$ 5,322
Expenses
Energy supply costs	787	797	2,099	1,880
Operating expenses	713	659	1,454	1,328
Depreciation and amortization	440	417	876	824
Total expenses	1,940	1,873	4,429	4,032
Operating income	654	614	1,484	1,290
Other income, net (Note 10)	64	35	133	77
Finance charges	323	266	638	524
Earnings before income tax expense	395	383	979	843
Income tax expense	49	53	149	120
Net earnings	346	330	830	723
Net earnings attributable to:
Non-controlling interests	35	30	66	57
Preference equity shareholders	17	16	33	32
Net earnings attributable to common equity shareholders	294	284	731	634
Net earnings	$ 346	$ 330	$ 830	$ 723
Earnings per common share (Note 11)
Basic (CAD per share)	$ 0.61	$ 0.59	$ 1.51	$ 1.33
Diluted (CAD per share)	$ 0.61	$ 0.59	$ 1.51	$ 1.33

XML

Condensed Consolidated Interim Statements of Comprehensive Income (Unaudited) - CAD ($) $ in Millions		3 Months Ended		6 Months Ended
		Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Net earnings		$ 346	$ 330	$ 830	$ 723
Other comprehensive (loss) income
Unrealized foreign currency translation (losses) gains	[1]	(339)	448	(383)	287
Other	[2]	5	4	3	24
Other comprehensive income (loss)		(334)	452	(380)	311
Comprehensive income		12	782	450	1,034
Comprehensive income attributable to:
Non-controlling interests		(1)	79	25	93
Preference equity shareholders		17	16	33	32
Common equity shareholders		(4)	687	392	909
Comprehensive income		$ 12	$ 782	$ 450	$ 1,034

[1] Net of hedging activities and income tax expense of $6 million for the three and six months ended June 30, 2023 (three and six months ended June 30, 2022 - income tax recovery of $4 million and $3 million, respectively)

[2] Net of income tax expense of $2 million for the three and six months ended June 30, 2023 (three and six months ended June 30, 2022 - income tax expense of $2 million and $10 million, respectively)

XML

Condensed Consolidated Interim Statements of Comprehensive Income (Unaudited) (Parenthetical) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Statement of Comprehensive Income [Abstract]
Unrealized foreign currency translation, tax expense (recovery)	$ 6	$ (4)	$ 6	$ (3)
Other, tax expense	$ 2	$ 2	$ 2	$ 10

XML

Condensed Consolidated Interim Statements of Cash Flows (Unaudited) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Operating activities
Net earnings	$ 346	$ 330	$ 830	$ 723
Adjustments to reconcile net earnings to net cash provided by operating activities:
Depreciation - property, plant and equipment	381	366	759	722
Amortization - intangible assets	38	36	76	71
Amortization - other	21	15	41	31
Deferred income tax expense	24	32	55	55
Equity component, allowance for funds used during construction (Note 10)	(23)	(18)	(46)	(35)
Other	43	14	49	54
Change in long-term regulatory assets and liabilities	(103)	24	(82)	14
Change in working capital (Note 12)	217	(40)	177	(63)
Cash from operating activities	944	759	1,859	1,572
Investing activities
Additions to property, plant and equipment	(938)	(827)	(1,845)	(1,693)
Additions to intangible assets	(44)	(58)	(91)	(107)
Contributions in aid of construction	20	22	71	61
Other	(51)	(55)	(89)	(95)
Cash used in investing activities	(1,013)	(918)	(1,954)	(1,834)
Financing activities
Proceeds from long-term debt, net of issuance costs	1,247	816	1,881	1,645
Repayments of long-term debt and finance leases	(364)	(609)	(697)	(836)
Borrowings under committed credit facilities	1,972	1,562	3,875	2,986
Repayments under committed credit facilities	(2,201)	(1,552)	(3,938)	(3,152)
Net change in short-term borrowings	(273)	82	(165)	158
Issue of common shares, net of costs and dividends reinvested	14	18	28	40
Dividends
Common shares, net of dividends reinvested	(172)	(164)	(342)	(324)
Preference shares	(17)	(16)	(33)	(32)
Subsidiary dividends paid to non-controlling interests	(17)	(11)	(40)	(31)
Other	20	(2)	28	7
Cash from financing activities	209	124	597	461
Effect of exchange rate changes on cash and cash equivalents	(7)	8	(2)	8
Change in cash and cash equivalents	133	(27)	500	207
Change in cash associated with assets held for sale (Note 7)	(19)	0	(19)	0
Cash and cash equivalents, beginning of period	576	365	209	131
Cash and cash equivalents, end of period	$ 690	$ 338	$ 690	$ 338

XML

Condensed Consolidated Interim Statements of Changes in Equity (Unaudited) - CAD ($) shares in Millions, $ in Millions	Total	Common Shares	Preference Shares	Additional Paid-In Capital	Accumulated Other Comprehensive Income (Loss)	Retained Earnings	Non-Controlling Interests
Balance, beginning of period (shares) at Dec. 31, 2021		474.8
Balance, beginning of period at Dec. 31, 2021	$ 20,916	$ 14,237	$ 1,623	$ 10	$ (40)	$ 3,458	$ 1,628
Increase (Decrease) in Equity [Roll Forward]
Net earnings	723					666	57
Other comprehensive income (loss)	311				275		36
Common shares issued (shares)		3.9
Common shares issued	226	$ 228		(2)
Subsidiary dividends paid to non-controlling interests	(31)						(31)
Dividends declared on common shares	(255)					(255)
Dividends on preference shares	(32)					(32)
Other	2						2
Balance, end of period (shares) at Jun. 30, 2022		478.7
Balance, end of period at Jun. 30, 2022	21,860	$ 14,465	1,623	8	235	3,837	1,692
Balance, beginning of period (shares) at Mar. 31, 2022		476.9
Balance, beginning of period at Mar. 31, 2022	20,994	$ 14,354	1,623	8	(168)	3,553	1,624
Increase (Decrease) in Equity [Roll Forward]
Net earnings	330					300	30
Other comprehensive income (loss)	452				403		49
Common shares issued (shares)		1.8
Common shares issued	110	$ 111		(1)
Subsidiary dividends paid to non-controlling interests	(11)						(11)
Dividends on preference shares	(16)					(16)
Other	1			1			0
Balance, end of period (shares) at Jun. 30, 2022		478.7
Balance, end of period at Jun. 30, 2022	21,860	$ 14,465	1,623	8	235	3,837	1,692
Balance, beginning of period (shares) at Dec. 31, 2022		482.2
Balance, beginning of period at Dec. 31, 2022	22,842	$ 14,656	1,623	10	1,008	3,733	1,812
Increase (Decrease) in Equity [Roll Forward]
Net earnings	830					764	66
Other comprehensive income (loss)	(380)				(339)		(41)
Common shares issued (shares)		4.2
Common shares issued	232	$ 233		(1)
Subsidiary dividends paid to non-controlling interests	(40)						(40)
Dividends declared on common shares	(274)					(274)
Dividends on preference shares	(33)					(33)
Other	0			(1)			1
Balance, end of period (shares) at Jun. 30, 2023		486.4
Balance, end of period at Jun. 30, 2023	23,177	$ 14,889	1,623	8	669	4,190	1,798
Balance, beginning of period (shares) at Mar. 31, 2023		484.4
Balance, beginning of period at Mar. 31, 2023	23,083	$ 14,773	1,623	8	967	3,896	1,816
Increase (Decrease) in Equity [Roll Forward]
Net earnings	346					311	35
Other comprehensive income (loss)	(334)				(298)		(36)
Common shares issued (shares)		2.0
Common shares issued	115	$ 116		(1)
Subsidiary dividends paid to non-controlling interests	(17)						(17)
Dividends on preference shares	(17)					(17)
Other	1			1
Balance, end of period (shares) at Jun. 30, 2023		486.4
Balance, end of period at Jun. 30, 2023	$ 23,177	$ 14,889	$ 1,623	$ 8	$ 669	$ 4,190	$ 1,798

XML

Condensed Consolidated Interim Statements of Changes in Equity (Unaudited) (Parenthetical) - $ / shares	6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022
Statement of Stockholders' Equity [Abstract]
Dividends declared on common shares (CAD per share)	$ 0.565	$ 0.535

XML

Description of Business

6 Months Ended

Jun. 30, 2023

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Description of Business

DESCRIPTION OF BUSINESS

Nature of Operations

Fortis Inc. ("Fortis" or the "Corporation") is a well-diversified North American regulated electric and gas utility holding company.

Earnings for interim periods may not be indicative of annual results due to: (i) the impact of seasonal weather conditions on customer demand and market pricing; (ii) the impact of market conditions, particularly with respect to long-term wholesale sales and transmission revenue at UNS Energy, as well as margins realized on gas sold at Aitken Creek; (iii) changes in foreign exchange rates; and (iv) the timing and significance of regulatory decisions. Earnings of the gas utilities tend to be highest in the first and fourth quarters due to space-heating requirements. Earnings of the electric distribution utilities in the U.S. tend to be highest in the second and third quarters due to the use of air conditioning and other cooling equipment.

Entities within the reporting segments that follow operate with substantial autonomy.

Regulated Utilities

ITC: ITC Investment Holdings Inc., ITC Holdings Corp. and the electric transmission operations of its regulated operating subsidiaries, which include International Transmission Company, Michigan Electric Transmission Company, LLC, ITC Midwest LLC ("ITC Midwest") and ITC Great Plains, LLC. Fortis owns 80.1% of ITC and an affiliate of GIC Private Limited owns a 19.9% minority interest.

UNS Energy: UNS Energy Corporation, which primarily includes Tucson Electric Power Company ("TEP"), UNS Electric, Inc. ("UNSE") and UNS Gas, Inc.

Central Hudson: CH Energy Group, Inc., which primarily includes Central Hudson Gas & Electric Corporation.

FortisBC Energy: FortisBC Energy Inc.

FortisAlberta: FortisAlberta Inc.

FortisBC Electric: FortisBC Inc.

Other Electric: Eastern Canadian and Caribbean utilities, as follows: Newfoundland Power Inc.; Maritime Electric Company, Limited; FortisOntario Inc.; a 39% equity investment in Wataynikaneyap Power Limited Partnership; an approximate 60% controlling interest in Caribbean Utilities Company, Ltd. ("Caribbean Utilities"); FortisTCI Limited and Turks and Caicos Utilities Limited (collectively "FortisTCI"); and a 33% equity investment in Belize Electricity Limited ("Belize Electricity").

Non-Regulated

Energy Infrastructure: Long-term contracted generation assets in Belize and the Aitken Creek natural gas storage facility ("Aitken Creek") in British Columbia (Note 7).

Corporate and Other: Captures expenses and revenues 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 and non-regulated holding company expenses.

XML

Regulatory Matters

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]

Regulatory Matters

REGULATORY MATTERS

Regulation of the Corporation's utilities is generally consistent with that disclosed in Note 2 of the Corporation's annual audited consolidated financial statements ("2022 Annual Financial Statements"). A summary of significant outstanding regulatory matters follows.

ITC

ITC Midwest Capital Structure Complaint: In 2022, FERC issued an order denying the complaint filed by the Iowa Coalition for Affordable Transmission ("ICAT") requesting that ITC Midwest's common equity component of capital structure be reduced from 60% to 53%. In March 2023, FERC confirmed its decision following ICAT's request for rehearing.

MISO Base ROE: In 2022, the U.S. Court of Appeals for the District of Columbia Circuit issued a decision vacating certain FERC orders that had established the methodology for setting the base return on equity ("ROE") for transmission owners operating in the Midcontinent Independent System Operator, Inc. ("MISO") region, including ITC. This matter dates back to complaints filed at FERC in 2013 and 2015 challenging the MISO base ROE then in effect. The court has remanded the matter to FERC for further process, the timing and outcome of which is unknown.

Transmission Incentives: In 2021, FERC issued a supplemental notice of proposed rulemaking ("NOPR") on transmission incentives modifying the proposal in the initial NOPR released by FERC in 2020. The supplemental NOPR proposes to eliminate the 50-basis point regional transmission organization ("RTO") ROE incentive adder for RTO members that have been members for longer than three years. The timing and outcome of this proceeding is unknown.

Transmission Right of First Refusal ("ROFR"): The State of Iowa has granted incumbent electric transmission owners, including ITC, a ROFR to construct, own and maintain certain electric transmission assets in the state. A challenge against the ROFR statute by certain plaintiffs was initially dismissed by the District Court on the grounds that the plaintiffs lacked standing. In March 2023, the Iowa Supreme Court determined that the plaintiffs have standing to challenge the Iowa ROFR statute, issued a temporary injunction staying enforcement of the ROFR statute, and remanded the matter to the District Court to decide the merits of the claim. Management does not believe that this proceeding will impact projects that have already been approved and under development; however, the timing of this proceeding and any impact on future projects, is unknown.

UNS Energy

TEP General Rate Application: In July 2023, the Administrative Law Judge ("ALJ") issued a recommended opinion and order on TEP's general rate application recommending, among other things, an increase in non-fuel revenue of US$102 million, a 9.4% ROE with a 0.2% return on the fair value increment, and a 54.32% common equity component of capital structure. TEP's existing ROE and common equity component of capital structure is 9.15% and 53%, respectively. While the timing and outcome of this proceeding is unknown, the ALJ recommended that the new rates become effective on or after September 1, 2023.

PPFAC Mechanism: The Purchased Power and Fuel Adjustment Clause ("PPFAC") mechanism allows for the timely recovery or return of purchased power and fuel costs, as compared to that collected in customer rates, at TEP and UNSE. The PPFAC balance has increased in recent years, reflecting higher commodity costs. In May 2023, the ACC approved rate adjustments at TEP and UNSE to collect the PPFAC balances over 12- and 33-month periods, respectively.

Central Hudson

General Rate Application: In July 2023, Central Hudson filed a rate application with the New York Public Service Commission ("PSC") requesting an increase in electric and gas delivery rates effective July 1, 2024. The application includes a request to set Central Hudson's allowed ROE at 9.8% and a 50% common equity component of capital structure. The timing and outcome of this proceeding is unknown.

Customer Information System ("CIS") Implementation: In January 2023, Central Hudson filed a response to the PSC's Order to Commence Proceeding and Show Cause, which had directed Central Hudson to explain why the PSC should not pursue civil or administrative penalties or initiate a proceeding to review the prudence of implementation costs associated with its new CIS. In July 2023, an interim agreement was reached with the PSC, in which Central Hudson agreed to independent third-party verification of recent system improvements related to its billing system, and to accelerate the implementation of its monthly meter reading plan. The timing and outcome of this proceeding remains unknown.

FortisBC Energy and FortisBC Electric

Generic Cost of Capital ("GCOC") Proceeding: In 2021, the British Columbia Utilities Commission ("BCUC") initiated a proceeding including a review of the common equity component of capital structure and the allowed ROE. FortisBC filed a final argument with the BCUC in December 2022 and the proceeding remains ongoing, with a decision expected in the third quarter 2023. The decision could be effective retroactively to January 1, 2023.

FortisAlberta

2024 GCOC Proceeding: In 2022, the Alberta Utilities Commission ("AUC") initiated proceedings to establish the cost of capital parameters for Alberta regulated utilities, including consideration of a formula-based approach to setting the allowed ROE for 2024 and beyond. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

Third PBR Term: In 2021, the AUC issued a decision confirming that Alberta distribution utilities will be subject to a third performance-based rate setting ("PBR") term commencing in 2024. The AUC also initiated a new proceeding to consider the design of the third PBR term. The proceeding remains ongoing, and a decision from the AUC is expected in the second half of 2023.

Rural Electrification Association ("REA") Cost Recovery: In 2021, the AUC determined that costs attributable to REAs, approximating $10 million annually, can no longer be recovered from FortisAlberta's rate payers, effective January 1, 2023. In April 2023, the Alberta Court of Appeal dismissed FortisAlberta's appeal which had asserted that the AUC erred in preventing the company from recovering these costs from its own rate payers to the extent that such costs cannot be recovered directly from REAs. FortisAlberta continues to assess other means, including legislative amendments, to recover these costs.

XML

Accounting Policies

6 Months Ended

Jun. 30, 2023

Accounting Policies [Abstract]

Accounting Policies

ACCOUNTING POLICIES

These condensed consolidated interim financial statements ("Interim Financial Statements") have been prepared and presented in accordance with accounting principles generally accepted in the United States of America for rate-regulated entities and are in Canadian dollars unless otherwise indicated.

The Interim Financial Statements include the accounts of the Corporation and its subsidiaries and reflect the equity method of accounting for entities in which Fortis has significant influence, but not control, and proportionate consolidation for assets that are jointly owned with non-affiliated entities.

Intercompany transactions have been eliminated, except for transactions between non-regulated and regulated entities in accordance with U.S. GAAP for rate-regulated entities.

These Interim Financial Statements do not include all of the disclosures required in the annual financial statements and should be read in conjunction with the Corporation's 2022 Annual Financial Statements. In management's opinion, these Interim Financial Statements include all adjustments that are of a normal recurring nature, necessary for fair presentation.

The preparation of the Interim Financial Statements required management to make estimates and judgments, including those related to regulatory decisions, that affect the reported amounts of, and disclosures related to, assets, liabilities, revenues, expenses, gains, losses and contingencies. Actual results could differ materially from estimates.

The accounting policies applied herein are consistent with those outlined in the Corporation's 2022 Annual Financial Statements.

Future Accounting Pronouncements

The Corporation considers the applicability and impact of all Accounting Standards Updates ("ASUs") issued by the Financial Accounting Standards Board. Any ASUs not included in these Interim Financial Statements were assessed and determined to be either not applicable to the Corporation or are not expected to have a material impact on the Interim Financial Statements.

XML

Segmented Information

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Segmented Information

SEGMENTED INFORMATION

Fortis segments its business based on regulatory jurisdiction and service territory, as well as the information used by its President and Chief Executive Officer in deciding how to allocate resources. Segment performance is evaluated principally on net earnings attributable to common equity shareholders.

Related-Party and Inter-Company Transactions

Related-party transactions are in the normal course of operations and are measured at the amount of consideration agreed to by the related parties. There were no material related-party transactions for the three and six months ended June 30, 2023 and 2022.

The lease of gas storage capacity and gas sales from Aitken Creek to FortisBC Energy of $6 million and $15 million for the three and six months ended June 30, 2023, respectively (three and six months ended June 30, 2022 - $7 million and $20 million, respectively) are inter-company transactions between non-regulated and regulated entities, which were not eliminated on consolidation.

As at June 30, 2023, accounts receivable included $4 million due from Belize Electricity (December 31, 2022 - $7 million).

Fortis periodically provides short-term financing to subsidiaries to support capital expenditures and seasonal working capital requirements, the impacts of which are eliminated on consolidation. As at June 30, 2023 and December 31, 2022, there were no inter-segment loans outstanding. Interest charged on inter-segment loans was not material for the three and six months ended June 30, 2023 and 2022.

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Quarter ended June 30, 2023
Revenue	519	661	317	362	181	116	420	2,576	18	—	—	2,594
Energy supply costs	—	262	121	141	—	22	241	787	—	—	—	787
Operating expenses	125	204	144	91	44	31	56	695	10	8	—	713
Depreciation and amortization	103	88	28	78	67	24	51	439	1	—	—	440
Operating income	291	107	24	52	70	39	72	655	7	(8)	—	654
Other income, net	19	12	13	9	3	1	5	62	—	2	—	64
Finance charges	105	37	15	43	30	19	21	270	—	53	—	323
Income tax expense	49	12	5	(5)	2	3	8	74	1	(26)	—	49
Net earnings	156	70	17	23	41	18	48	373	6	(33)	—	346
Non-controlling interests	29	—	—	—	—	—	6	35	—	—	—	35
Preference share dividends	—	—	—	—	—	—	—	—	—	17	—	17
Net earnings attributable to common equity shareholders	127	70	17	23	41	18	42	338	6	(50)	—	294
Additions to property, plant and equipment and intangible assets	264	183	78	125	182	35	115	982	—	—	—	982
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Quarter ended June 30, 2022
Revenue	468	648	281	396	169	108	384	2,454	33	—	—	2,487
Energy supply costs	—	272	101	181	—	18	224	796	1	—	—	797
Operating expenses	120	167	143	88	42	33	52	645	8	6	—	659
Depreciation and amortization	94	92	26	75	61	17	47	412	4	1	—	417
Operating income	254	117	11	52	66	40	61	601	20	(7)	—	614
Other income, net	10	3	15	5	—	1	1	35	—	—	—	35
Finance charges	83	30	13	35	28	19	19	227	—	39	—	266
Income tax expense	41	13	3	5	3	3	6	74	1	(22)	—	53
Net earnings	140	77	10	17	35	19	37	335	19	(24)	—	330
Non-controlling interests	26	—	—	—	—	—	4	30	—	—	—	30
Preference share dividends	—	—	—	—	—	—	—	—	—	16	—	16
Net earnings attributable to common equity shareholders	114	77	10	17	35	19	33	305	19	(40)	—	284
Additions to property, plant and equipment and intangible assets	272	159	65	134	119	30	100	879	6	—	—	885
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Year-to-date June 30, 2023
Revenue	1,038	1,401	759	1,117	360	255	927	5,857	56	—	—	5,913
Energy supply costs	—	599	328	518	—	69	585	2,099	—	—	—	2,099
Operating expenses	260	394	306	189	86	61	116	1,412	20	22	—	1,454
Depreciation and amortization	204	175	56	155	131	48	101	870	5	1	—	876
Operating income	574	233	69	255	143	77	125	1,476	31	(23)	—	1,484
Other income, net	36	26	27	16	3	2	12	122	—	11	—	133
Finance charges	204	73	33	84	60	39	42	535	—	103	—	638
Income tax expense	96	26	14	40	5	4	14	199	7	(57)	—	149
Net earnings	310	160	49	147	81	36	81	864	24	(58)	—	830
Non-controlling interests	57	—	—	—	—	—	9	66	—	—	—	66
Preference share dividends	—	—	—	—	—	—	—	—	—	33	—	33
Net earnings attributable to common equity shareholders	253	160	49	147	81	36	72	798	24	(91)	—	731
Additions to property, plant and equipment and intangible assets	600	368	156	239	301	62	208	1,934	2	—	—	1,936
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Year-to-date June 30, 2022
Revenue	928	1,186	656	1,090	336	237	843	5,276	46	—	—	5,322
Energy supply costs	—	482	263	535	—	61	536	1,877	3	—	—	1,880
Operating expenses	243	329	292	171	84	66	105	1,290	20	18	—	1,328
Depreciation and amortization	186	181	51	150	121	34	91	814	8	2	—	824
Operating income	499	194	50	234	131	76	111	1,295	15	(20)	—	1,290
Other income, net	19	6	30	9	1	3	3	71	—	6	—	77
Finance charges	163	61	26	71	54	37	37	449	—	75	—	524
Income tax expense	82	19	12	36	7	5	11	172	2	(54)	—	120
Net earnings	273	120	42	136	71	37	66	745	13	(35)	—	723
Non-controlling interests	50	—	—	—	—	—	7	57	—	—	—	57
Preference share dividends	—	—	—	—	—	—	—	—	—	32	—	32
Net earnings attributable to common equity shareholders	223	120	42	136	71	37	59	688	13	(67)	—	634
Additions to property, plant and equipment and intangible assets	607	321	129	264	230	60	178	1,789	11	—	—	1,800
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

XML

Allowance for Credit Losses

6 Months Ended

Jun. 30, 2023

Receivables [Abstract]

Allowance for Credit Losses

ALLOWANCE FOR CREDIT LOSSES

The allowance for credit losses balance, which is recorded in accounts receivable and other current assets, changed as follows.

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Balance, beginning of period	(59)	(53)	(58)	(53)
Credit loss expense	(3)	(5)	(11)	(10)
Credit loss deferral	(2)	—	(3)	—
Write-offs, net of recoveries	4	6	12	11
Foreign exchange	—	(1)	—	(1)
Balance, end of period	(60)	(53)	(60)	(53)

See Note 13 for disclosure on the Corporation's credit risk.

XML

Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]

Regulatory Assets and Liabilities

REGULATORY ASSETS AND LIABILITIES

Detailed information about the Corporation's regulatory assets and liabilities is provided in Note 8 to the 2022 Annual Financial Statements. A summary follows.

	As at
	June 30,	December 31,
($ millions)	2023	2022
Regulatory assets
Deferred income taxes	1,897	1,874
Deferred energy management costs	463	445
Rate stabilization and related accounts	419	557
Employee future benefits	191	207
Deferred lease costs	135	132
Derivatives	118	84
Deferred restoration costs	109	91
Manufactured gas plant site remediation deferral	87	97
Generation early retirement costs	73	78
Other regulatory assets	464	444
Total regulatory assets	3,956	4,009
Less: Current portion	(730)	(914)
Long-term regulatory assets	3,226	3,095
Regulatory liabilities
Future cost of removal	1,353	1,306
Deferred income taxes	1,271	1,364
Rate stabilization and related accounts	288	297
Employee future benefits	254	306
Renewable energy surcharge	122	126
Energy efficiency liability	89	89
Electric and gas moderator account	67	34
Alberta Electric System Operator charges deferral	58	21
Derivatives	54	224
Other regulatory liabilities	161	148
Total regulatory liabilities	3,717	3,915
Less: Current portion	(489)	(595)
Long-term regulatory liabilities	3,228	3,320

XML

Assets Held for Sale

6 Months Ended

Jun. 30, 2023

Discontinued Operations and Disposal Groups [Abstract]

Assets Held for Sale

ASSETS HELD FOR SALE

In May 2023, the Corporation announced that FortisBC Holdings Inc. ("FHI") had entered into a definitive share purchase and sale agreement with a subsidiary of Enbridge Inc. to sell its 93.8% ownership interest in Aitken Creek for approximately $400 million, subject to customary closing conditions and adjustments. The purchase is subject to required approval, principally by the BCUC, and is expected to close by the end of the year with a March 31, 2023 effective date.

As at June 30, 2023, the related assets and liabilities, as included in the Energy Infrastructure segment, were classified as held for sale and are detailed below.

As at ($ millions)	June 30, 2023
Cash and cash equivalents	19
Accounts receivable and other current assets	30
Inventories	55
Property, plant and equipment, net	430
Goodwill	27
Total assets held for sale	561
Accounts payable and other current liabilities	20
Deferred income taxes	109
Total liabilities associated with assets held for sale	129

For the three and six months ended June 30, 2023, Aitken Creek had net earnings of $3 million and $18 million, respectively (three and six months ended June 30, 2022 - $14 million and $7 million, respectively).

XML

Long-Term Debt

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Long-Term Debt

LONG-TERM DEBT

	As at
	June 30,	December 31,
($ millions)	2023	2022
Long-term debt	27,704	26,921
Credit facility borrowings	1,562	1,657
Total long-term debt	29,266	28,578
Less: Deferred financing costs and debt discounts	(174)	(166)
Less: Current installments of long-term debt	(2,284)	(2,481)
	26,808	25,931

Significant Long-Term Debt Issuances		Interest
Year-to-Date June 30, 2023	Month	Rate					Use of
($ millions, except as noted)	Issued	(%)		Maturity	Amount		Proceeds
ITC
Unsecured senior notes	June	5.40	(1)	2033	US	500	(2) (3) (4)
Unsecured senior notes	June	4.95	(5)	2027	US	300	(2) (3) (4)
UNS Energy
Unsecured senior notes	February	5.50		2053	US	375	(2) (3)
FortisAlberta
Unsecured senior debentures	May	4.86		2053	200		(3) (4)
Central Hudson
Unsecured senior notes	March	5.68		2033	US	40	(3) (4)
Unsecured senior notes	March	5.78		2035	US	15	(3) (4)
Unsecured senior notes	March	5.88		2038	US	35	(3) (4)

(1)    ITC entered into interest rate locks which reduced the effective interest rate to 5.32%. See Note 13 to the Interim Financial Statements

(2)    Repay maturing long-term debt

(3)    General corporate purposes

(4)     Repay short-term and/or credit facility borrowings

(5)     Represents a second tranche of ITC's existing 4.95% senior notes, originally issued in 2022

In November 2022, Fortis filed a short-form base shelf prospectus with a 25-month life under which it may issue common or preference shares, subscription receipts, or debt securities in an aggregate principal amount of up to $2.0 billion. As at June 30, 2023, $2.0 billion remained available under the short-form base shelf prospectus.

			As at
Credit facilities	Regulated	Corporate	June 30,	December 31,
($ millions)	Utilities	and Other	2023	2022
Total credit facilities	3,963	2,034	5,997	5,850
Credit facilities utilized:
Short-term borrowings (1)	(80)	—	(80)	(253)
Long-term debt (including current portion) (2)	(792)	(770)	(1,562)	(1,657)
Letters of credit outstanding	(57)	(38)	(95)	(128)
Credit facilities unutilized	3,034	1,226	4,260	3,812

(1)    The weighted average interest rate was 6.7% (December 31, 2022 - 4.9%).

(2)    The weighted average interest rate was 6.0% (December 31, 2022 - 5.1%). The current portion was $1,114 million (December 31, 2022 - $1,376 million).

Credit facilities are syndicated primarily with large banks in Canada and the U.S., with no one bank holding more than approximately 20% of the Corporation's total revolving credit facilities. Approximately $5.7 billion of the total credit facilities are committed with maturities ranging from 2023 through 2028.

See Note 14 in the 2022 Annual Financial Statements for a description of the credit facilities as at December 31, 2022.

In April 2023, ITC increased its total credit facilities available from US$900 million to US$1 billion and extended the maturity to April 2028.

In May 2023, the Corporation amended its $1.3 billion revolving term committed credit facility agreement to extend the maturity to July 2028.

Also in May 2023, the Corporation extended the maturity on its unsecured US$500 million non-revolving term credit facility to May 2024. The facility is repayable at any time without penalty.

XML

Employee Future Benefits

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Employee Future Benefits

EMPLOYEE FUTURE BENEFITS

Fortis and each subsidiary maintain one or a combination of defined benefit pension plans and defined contribution pension plans, as well as other post-employment benefit ("OPEB") plans, including health and dental coverage and life insurance benefits, for qualifying members. The net benefit cost is detailed below.

	Defined Benefit Pension Plans		OPEB Plans
($ millions)	2023	2022	2023	2022
Quarter ended June 30
Service costs	16	26	6	8
Interest costs	40	28	7	6
Expected return on plan assets	(50)	(48)	(5)	(5)
Amortization of actuarial (gains) losses	(3)	1	(5)	(3)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	2	(3)	1	1
Net benefit cost	4	3	3	6
Year-to-date June 30
Service costs	31	52	11	17
Interest costs	80	56	15	11
Expected return on plan assets	(100)	(97)	(11)	(11)
Amortization of actuarial (gains) losses	(5)	2	(9)	(5)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	6	(5)	3	2
Net benefit cost	11	7	8	13

Defined contribution pension plan expense for the three and six months ended June 30, 2023 was $13 million and $29 million, respectively (three and six months ended June 30, 2022 - $12 million and $26 million, respectively).

XML

Other Income, Net

6 Months Ended

Jun. 30, 2023

Other Income and Expenses [Abstract]

Other Income, Net

OTHER INCOME, NET

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Equity component, allowance for funds used during construction	23	18	46	35
Interest income (1)	18	2	34	3
Non-service component of net periodic benefit cost	16	25	32	49
Gain (loss) on derivatives, net	3	(2)	12	2
Gain (loss) on retirement investments, net	—	(9)	4	(17)
Other	4	1	5	5
	64	35	133	77

(1)    Includes interest on short-term deposits, as well as interest on regulatory deferrals, including the PPFAC at TEP and UNSE

XML

Earnings Per Common Share

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Earnings Per Common Share

EARNINGS PER COMMON SHARE

Diluted earnings per share ("EPS") was calculated using the treasury stock method for stock options.

	2023			2022
	Net Earnings	Weighted		Net Earnings	Weighted
	to Common	Average		to Common	Average
	Shareholders	Shares	EPS	Shareholders	Shares	EPS
	($ millions)	(# millions)	($)	($ millions)	(# millions)	($)
Quarter ended June 30
Basic EPS	294	485.4	0.61	284	477.8	0.59
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	294	485.7	0.61	284	478.3	0.59
Year-to-date June 30
Basic EPS	731	484.3	1.51	634	476.8	1.33
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	731	484.6	1.51	634	477.3	1.33

XML

Supplementary Cash Flow Information

6 Months Ended

Jun. 30, 2023

Supplemental Cash Flow Elements [Abstract]

Supplementary Cash Flow Information

SUPPLEMENTARY CASH FLOW INFORMATION

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Change in working capital
Accounts receivable and other current assets	208	49	489	(46)
Prepaid expenses	(19)	17	(19)	22
Inventories	(29)	(114)	62	(45)
Regulatory assets - current portion	164	(31)	160	(43)
Accounts payable and other current liabilities	(132)	9	(537)	17
Regulatory liabilities - current portion	25	30	22	32
	217	(40)	177	(63)
Non-cash investing and financing activities
Accrued capital expenditures	366	380	366	380
Common share dividends reinvested	102	92	205	186
Contributions in aid of construction	10	12	10	12

XML

Fair Value of Financial Instruments and Risk Management

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments and Risk Management

FAIR VALUE OF FINANCIAL INSTRUMENTS AND RISK MANAGEMENT

Derivatives

The Corporation generally limits the use of derivatives to those that qualify as accounting, economic or cash flow hedges, or those that are approved for regulatory recovery.

Derivatives are recorded at fair value with certain exceptions including those derivatives that qualify for the normal purchase and normal sale exception. Fair values reflect estimates based on current market information about the derivatives as at the balance sheet dates. The estimates cannot be determined with precision as they involve uncertainties and matters of judgment and, therefore, may not be relevant in predicting the Corporation's future consolidated earnings or cash flow.

Cash flow associated with the settlement of all derivatives is included in operating activities on the condensed consolidated interim statements of cash flows.

Energy Contracts Subject to Regulatory Deferral

UNS Energy holds electricity power purchase contracts, customer supply contracts and gas swap contracts to reduce its exposure to energy price risk. Fair values are measured primarily under the market approach using independent third-party information, where possible. When published prices are not available, adjustments are applied based on historical price curve relationships, transmission costs and line losses.

Central Hudson holds swap contracts for electricity and natural gas to minimize price volatility by fixing the effective purchase price. Fair values are measured using forward pricing provided by independent third-party information.

FortisBC Energy holds gas supply contracts to fix the effective purchase price of natural gas. Fair values reflect the present value of future cash flows based on published market prices and forward natural gas curves.

Unrealized gains or losses associated with changes in the fair value of these energy contracts are deferred as a regulatory asset or liability for recovery from, or refund to, customers in future rates, as permitted by the regulators. As at June 30, 2023, unrealized losses of $118 million (December 31, 2022 - $84 million) were recognized as regulatory assets and unrealized gains of $54 million (December 31, 2022 - $224 million) were recognized as regulatory liabilities.

Energy Contracts Not Subject to Regulatory Deferral

UNS Energy holds wholesale trading contracts to fix power prices and realize potential margin, of which 10% of any realized gains is shared with customers through rate stabilization accounts. Fair values are measured using a market approach incorporating, where possible, independent third-party information.

Aitken Creek holds gas swap contracts to manage its exposure to changes in natural gas prices, capture natural gas price spreads, and manage the financial risk posed by physical transactions. Fair values are measured using forward pricing from published market sources.

Unrealized gains or losses associated with changes in the fair value of these energy contracts are recognized in revenue. During the three months ended June 30, 2023, unrealized losses of $8 million and unrealized gains of $6 million, respectively were recognized in revenue (three and six months ended June 30, 2022 - unrealized gains of $19 million and $2 million, respectively).

Total Return Swaps

The Corporation holds total return swaps to manage the cash flow risk associated with forecast future cash settlements of certain stock-based compensation obligations. The swaps have a combined notional amount of $119 million and terms of one to three years expiring at varying dates through January 2026. Fair value is measured using an income valuation approach based on forward pricing curves. Unrealized gains and losses associated with changes in fair value are recognized in other income, net. During the three and six months ended June 30, 2023, unrealized losses of $1 million and unrealized gains of $5 million, respectively were recognized in other income, net (three and six months ended June 30, 2022 - unrealized losses of $2 million and $8 million, respectively).

Foreign Exchange Contracts

The Corporation holds U.S. dollar denominated foreign exchange contracts to help mitigate exposure to foreign exchange rate volatility. The contracts expire at varying dates through February 2025 and have a combined notional amount of $393 million. Fair value was measured using independent third-party information. Unrealized gains and losses associated with changes in fair value are recognized in other income, net. During the three and six months ended June 30, 2023, unrealized gains recognized in other income, net were $5 million and $7 million, respectively (unrealized losses of $2 million for the three and six months ended June 30, 2022, respectively).

Interest Rate Locks

In March 2023, the Corporation entered into an interest rate lock with a total notional value of $100 million to manage the interest rate risk associated with the refinancing of long-term debt maturing in the fall of 2023. The lock has a 10-year term and will be terminated no later than November 1, 2023. Fair value is measured using a discounted cash flow method based on Canadian dollar offered rates. Unrealized gains and losses associated with changes in fair value are recognized in other comprehensive income, and will be reclassified to earnings as a component of interest expense over the life of the debt. Unrealized gains of $4 million were recognized in other comprehensive income for the three and six months ended June 30, 2023.

During the second quarter of 2023, ITC entered into and settled interest rate locks with a combined notional value of US$500 million. The contracts were used to manage interest rate risk associated with the issuance of US$500 million unsecured senior notes in June 2023. Realized gains of US$4 million were recognized in other comprehensive income, which will be reclassified to earnings as a component of interest expense over 10 years.

Cross-Currency Interest Rate Swaps

In 2022, the Corporation entered into cross-currency interest rate swaps with a 7-year term to effectively convert its $500 million, 4.43% unsecured senior notes to US$391 million, 4.34% debt. The Corporation designated this notional U.S. debt as an effective hedge of its foreign net investments and unrealized gains and losses associated with exchange rate fluctuations on the notional U.S. debt are recognized in other comprehensive income, consistent with the translation adjustment related to the net investments. Other changes in the fair value of the swaps are also recognized in other comprehensive income but are excluded from the assessment of hedge effectiveness. Fair value is measured using a discounted cash flow method based on secured overnight financing rates. Unrealized gains of $9 million and $10 million were recorded in other comprehensive income for the three and six months ended June 30, 2023 (unrealized losses of $12 million for the three and six months ended June 30, 2022).

Other Investments

UNS Energy holds investments in money market accounts, and ITC and Central Hudson hold investments in trust associated with supplemental retirement benefit plans for select employees, which include mutual funds and money market accounts. These investments are recorded at fair value based on quoted market prices in active markets. Gains and losses are recognized in other income, net. During the three and six months ended June 30, 2023, gains of $1 million and $3 million, respectively was recognized in other income, net (three and six months ended June 30, 2022 - losses of $4 million and $9 million, respectively).

Recurring Fair Value Measures

The following table presents assets and liabilities that are accounted for at fair value on a recurring basis.

($ millions)	Level 1 (1)	Level 2 (1)	Level 3 (1)	Total
As at June 30, 2023
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	82	—	82
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Foreign exchange contracts, total return swaps and interest rate lock (2)	—	7	—	7
Other investments (4)	144	—	—	144
	144	138	—	282
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(146)	—	(146)
Energy contracts not subject to regulatory deferral (5)	—	(7)	—	(7)
Cross-currency interest rate swaps (5)	—	(8)	—	(8)
	—	(161)	—	(161)
As at December 31, 2022
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	304	—	304
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Other investments (4)	150	—	—	150
	150	353	—	503
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(164)	—	(164)
Energy contracts not subject to regulatory deferral (5)	—	(8)	—	(8)
Foreign exchange contracts, total return and cross-currency interest rate swaps (5)	—	(26)	—	(26)
	—	(198)	—	(198)

(1)Under the hierarchy, fair value is determined using: (i) level 1 - unadjusted quoted prices in active markets; (ii) level 2 - other pricing inputs directly or indirectly observable in the marketplace; and (iii) level 3 - unobservable inputs, used when observable inputs are not available. Classifications reflect the lowest level of input that is significant to the fair value measurement.

(2)Included in accounts receivable and other current assets or other assets

(3)Unrealized gains and losses arising from changes in fair value of these contracts are deferred as a regulatory asset or liability for recovery from, or refund to, customers in future rates as permitted by the regulators, with the exception of long-term wholesale trading contracts and certain gas swap contracts.

(4)Included in cash and cash equivalents and other assets

(5)Included in accounts payable and other current liabilities or other liabilities

Energy Contracts

The Corporation has elected gross presentation for its derivative contracts under master netting agreements and collateral positions, which apply only to its energy contracts. The following table presents the potential offset of counterparty netting.

	Gross Amount	Counterparty
	Recognized in	Netting of	Cash Collateral
($ millions)	Balance Sheet	Energy Contracts	Received/Posted	Net Amount
As at June 30, 2023
Derivative assets	131	(34)	28	125
Derivative liabilities	(153)	34	—	(119)
As at December 31, 2022
Derivative assets	353	(54)	(63)	236
Derivative liabilities	(172)	54	—	(118)

Volume of Derivative Activity

As at June 30, 2023, the Corporation had various energy contracts that will settle on various dates through 2029. The volumes related to electricity and natural gas derivatives are outlined below.

	As at
	June 30,	December 31,
	2023	2022
Energy contracts subject to regulatory deferral (1)
Electricity swap contracts (GWh)	447	586
Electricity power purchase contracts (GWh)	440	224
Gas swap contracts (PJ)	173	185
Gas supply contract premiums (PJ)	134	148
Energy contracts not subject to regulatory deferral (1)
Wholesale trading contracts (GWh)	3,960	1,886
Gas swap contracts (PJ)	26	34

(1)GWh means gigawatt hours and PJ means petajoules.

Credit Risk

For cash equivalents, accounts receivable and other current assets, and long-term other receivables, credit risk is generally limited to the carrying value on the consolidated balance sheets. The Corporation's subsidiaries generally have a large and diversified customer base, which minimizes the concentration of credit risk. Policies in place to minimize credit risk include requiring customer deposits, prepayments and/or credit checks for certain customers, performing disconnections and/or using third-party collection agencies for overdue accounts.

ITC has a concentration of credit risk as approximately 70% of its revenue is derived from three customers. The customers have investment-grade credit ratings and credit risk is further managed by MISO by requiring a letter of credit or cash deposit equal to the credit exposure, which is determined by a credit-scoring model and other factors.

FortisAlberta has a concentration of credit risk as distribution service billings are to a relatively small group of retailers. Credit risk is managed by obtaining from the retailers either a cash deposit, letter of credit, an investment-grade credit rating, or a financial guarantee from an entity with an investment-grade credit rating.

Central Hudson has seen an increase in accounts receivable due to the suspension of collection efforts in response to the COVID-19 pandemic, as well as higher commodity prices. Central Hudson continues to proactively contact customers regarding past-due balances to advise them of financial assistance available through federal and state programs, and collection efforts are expected to expand in 2023. Under its regulatory framework, Central Hudson can defer uncollectible write-offs that exceed 10 basis points above the amounts collected in customer rates for future recovery.

UNS Energy, Central Hudson, FortisBC Energy, Aitken Creek and the Corporation may be exposed to credit risk in the event of non-performance by counterparties to derivatives. Credit risk is managed by net settling payments, when possible, and dealing only with counterparties that have investment-grade credit ratings. At UNS Energy, Central Hudson and FortisBC Energy, certain contractual arrangements require counterparties to post collateral.

The value of derivatives in net liability positions under contracts with credit risk-related contingent features that, if triggered, could require the posting of a like amount of collateral was $52 million as at June 30, 2023 (December 31, 2022 - $178 million).

Hedge of Foreign Net Investments

The reporting currency of ITC, UNS Energy, Central Hudson, Caribbean Utilities, FortisTCI, Fortis Belize Limited and Belize Electricity is, or is pegged to, the U.S. dollar. The earnings and cash flow from, and net investments in, these entities are exposed to fluctuations in the U.S. dollar-to-Canadian dollar exchange rate. The Corporation has reduced this exposure through hedging.

As at June 30, 2023, US$2.9 billion (December 31, 2022 - US$2.9 billion) of corporately issued U.S. dollar-denominated long-term debt has been designated as an effective hedge of net investments, leaving approximately US$10.9 billion (December 31, 2022 - US$10.6 billion) unhedged. Exchange rate fluctuations associated with the net investment in foreign subsidiaries and the debt serving as the hedge are recognized in accumulated other comprehensive income.

Financial Instruments Not Carried at Fair Value

Excluding long-term debt, the consolidated carrying value of the Corporation's remaining financial instruments approximates fair value, reflecting their short-term maturity, normal trade credit terms and/or nature.

As at June 30, 2023, the carrying value of long-term debt, including current portion, was $29.3 billion (December 31, 2022 - $28.6 billion) compared to an estimated fair value of $26.9 billion (December 31, 2022 - $25.8 billion).

XML

Commitments and Contingencies

6 Months Ended

Jun. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

COMMITMENTS AND CONTINGENCIES

Commitments

There were no material changes in commitments from that disclosed in the Corporation's 2022 Annual Financial Statements.

Contingencies

In April 2013, FHI and Fortis were named as defendants in an action in the British Columbia Supreme Court by the Coldwater Indian Band ("Band") regarding interests in a pipeline right-of-way on reserve lands. The pipeline was transferred by FHI (then Terasen Inc.) to Kinder Morgan Inc. in 2007. The Band seeks cancellation of the right-of-way and damages for wrongful interference with the Band's use and enjoyment of reserve lands. In 2016, the Federal Court dismissed the Band's application for judicial review of the ministerial consent. In 2017, the Federal Court of Appeal set aside the minister's consent and returned the matter to the minister for redetermination. No amount has been accrued in the Interim Financial Statements as the outcome cannot yet be reasonably determined.

XML

Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2023

Accounting Policies [Abstract]

Basis of Accounting

These condensed consolidated interim financial statements ("Interim Financial Statements") have been prepared and presented in accordance with accounting principles generally accepted in the United States of America for rate-regulated entities and are in Canadian dollars unless otherwise indicated.

Consolidation

The Interim Financial Statements include the accounts of the Corporation and its subsidiaries and reflect the equity method of accounting for entities in which Fortis has significant influence, but not control, and proportionate consolidation for assets that are jointly owned with non-affiliated entities.

Intercompany transactions have been eliminated, except for transactions between non-regulated and regulated entities in accordance with U.S. GAAP for rate-regulated entities.

These Interim Financial Statements do not include all of the disclosures required in the annual financial statements and should be read in conjunction with the Corporation's 2022 Annual Financial Statements. In management's opinion, these Interim Financial Statements include all adjustments that are of a normal recurring nature, necessary for fair presentation.

Use of Accounting Estimates

The preparation of the Interim Financial Statements required management to make estimates and judgments, including those related to regulatory decisions, that affect the reported amounts of, and disclosures related to, assets, liabilities, revenues, expenses, gains, losses and contingencies. Actual results could differ materially from estimates.

Future Accounting Pronouncements

The Corporation considers the applicability and impact of all Accounting Standards Updates ("ASUs") issued by the Financial Accounting Standards Board. Any ASUs not included in these Interim Financial Statements were assessed and determined to be either not applicable to the Corporation or are not expected to have a material impact on the Interim Financial Statements.

XML

Segmented Information (Tables)

6 Months Ended

Jun. 30, 2023

Segment Reporting [Abstract]

Schedule of Information by Reportable Segment

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Quarter ended June 30, 2023
Revenue	519	661	317	362	181	116	420	2,576	18	—	—	2,594
Energy supply costs	—	262	121	141	—	22	241	787	—	—	—	787
Operating expenses	125	204	144	91	44	31	56	695	10	8	—	713
Depreciation and amortization	103	88	28	78	67	24	51	439	1	—	—	440
Operating income	291	107	24	52	70	39	72	655	7	(8)	—	654
Other income, net	19	12	13	9	3	1	5	62	—	2	—	64
Finance charges	105	37	15	43	30	19	21	270	—	53	—	323
Income tax expense	49	12	5	(5)	2	3	8	74	1	(26)	—	49
Net earnings	156	70	17	23	41	18	48	373	6	(33)	—	346
Non-controlling interests	29	—	—	—	—	—	6	35	—	—	—	35
Preference share dividends	—	—	—	—	—	—	—	—	—	17	—	17
Net earnings attributable to common equity shareholders	127	70	17	23	41	18	42	338	6	(50)	—	294
Additions to property, plant and equipment and intangible assets	264	183	78	125	182	35	115	982	—	—	—	982
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Quarter ended June 30, 2022
Revenue	468	648	281	396	169	108	384	2,454	33	—	—	2,487
Energy supply costs	—	272	101	181	—	18	224	796	1	—	—	797
Operating expenses	120	167	143	88	42	33	52	645	8	6	—	659
Depreciation and amortization	94	92	26	75	61	17	47	412	4	1	—	417
Operating income	254	117	11	52	66	40	61	601	20	(7)	—	614
Other income, net	10	3	15	5	—	1	1	35	—	—	—	35
Finance charges	83	30	13	35	28	19	19	227	—	39	—	266
Income tax expense	41	13	3	5	3	3	6	74	1	(22)	—	53
Net earnings	140	77	10	17	35	19	37	335	19	(24)	—	330
Non-controlling interests	26	—	—	—	—	—	4	30	—	—	—	30
Preference share dividends	—	—	—	—	—	—	—	—	—	16	—	16
Net earnings attributable to common equity shareholders	114	77	10	17	35	19	33	305	19	(40)	—	284
Additions to property, plant and equipment and intangible assets	272	159	65	134	119	30	100	879	6	—	—	885
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

	Regulated								Non-Regulated
									Energy		Inter-
		UNS	Central	FortisBC	Fortis	FortisBC	Other	Sub	Infra-	Corporate	segment
($ millions)	ITC	Energy	Hudson	Energy	Alberta	Electric	Electric	Total	structure	and Other	eliminations	Total
Year-to-date June 30, 2023
Revenue	1,038	1,401	759	1,117	360	255	927	5,857	56	—	—	5,913
Energy supply costs	—	599	328	518	—	69	585	2,099	—	—	—	2,099
Operating expenses	260	394	306	189	86	61	116	1,412	20	22	—	1,454
Depreciation and amortization	204	175	56	155	131	48	101	870	5	1	—	876
Operating income	574	233	69	255	143	77	125	1,476	31	(23)	—	1,484
Other income, net	36	26	27	16	3	2	12	122	—	11	—	133
Finance charges	204	73	33	84	60	39	42	535	—	103	—	638
Income tax expense	96	26	14	40	5	4	14	199	7	(57)	—	149
Net earnings	310	160	49	147	81	36	81	864	24	(58)	—	830
Non-controlling interests	57	—	—	—	—	—	9	66	—	—	—	66
Preference share dividends	—	—	—	—	—	—	—	—	—	33	—	33
Net earnings attributable to common equity shareholders	253	160	49	147	81	36	72	798	24	(91)	—	731
Additions to property, plant and equipment and intangible assets	600	368	156	239	301	62	208	1,934	2	—	—	1,936
As at June 30, 2023
Goodwill	8,127	1,829	597	913	228	235	254	12,183	—	—	—	12,183
Total assets	23,838	12,303	5,105	8,587	5,718	2,625	4,993	63,169	685	256	(29)	64,081
Year-to-date June 30, 2022
Revenue	928	1,186	656	1,090	336	237	843	5,276	46	—	—	5,322
Energy supply costs	—	482	263	535	—	61	536	1,877	3	—	—	1,880
Operating expenses	243	329	292	171	84	66	105	1,290	20	18	—	1,328
Depreciation and amortization	186	181	51	150	121	34	91	814	8	2	—	824
Operating income	499	194	50	234	131	76	111	1,295	15	(20)	—	1,290
Other income, net	19	6	30	9	1	3	3	71	—	6	—	77
Finance charges	163	61	26	71	54	37	37	449	—	75	—	524
Income tax expense	82	19	12	36	7	5	11	172	2	(54)	—	120
Net earnings	273	120	42	136	71	37	66	745	13	(35)	—	723
Non-controlling interests	50	—	—	—	—	—	7	57	—	—	—	57
Preference share dividends	—	—	—	—	—	—	—	—	—	32	—	32
Net earnings attributable to common equity shareholders	223	120	42	136	71	37	59	688	13	(67)	—	634
Additions to property, plant and equipment and intangible assets	607	321	129	264	230	60	178	1,789	11	—	—	1,800
As at June 30, 2022
Goodwill	7,900	1,779	581	913	228	235	248	11,884	27	—	—	11,911
Total assets	21,993	11,796	4,587	8,272	5,328	2,565	4,487	59,028	776	300	(150)	59,954

XML

Allowance for Credit Losses (Tables)

6 Months Ended

Jun. 30, 2023

Receivables [Abstract]

Schedule of Allowance for Credit Losses

The allowance for credit losses balance, which is recorded in accounts receivable and other current assets, changed as follows.

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Balance, beginning of period	(59)	(53)	(58)	(53)
Credit loss expense	(3)	(5)	(11)	(10)
Credit loss deferral	(2)	—	(3)	—
Write-offs, net of recoveries	4	6	12	11
Foreign exchange	—	(1)	—	(1)
Balance, end of period	(60)	(53)	(60)	(53)

XML

Regulatory Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2023

Regulated Operations [Abstract]

Schedule of Regulatory Assets

Detailed information about the Corporation's regulatory assets and liabilities is provided in Note 8 to the 2022 Annual Financial Statements. A summary follows.

	As at
	June 30,	December 31,
($ millions)	2023	2022
Regulatory assets
Deferred income taxes	1,897	1,874
Deferred energy management costs	463	445
Rate stabilization and related accounts	419	557
Employee future benefits	191	207
Deferred lease costs	135	132
Derivatives	118	84
Deferred restoration costs	109	91
Manufactured gas plant site remediation deferral	87	97
Generation early retirement costs	73	78
Other regulatory assets	464	444
Total regulatory assets	3,956	4,009
Less: Current portion	(730)	(914)
Long-term regulatory assets	3,226	3,095
Regulatory liabilities
Future cost of removal	1,353	1,306
Deferred income taxes	1,271	1,364
Rate stabilization and related accounts	288	297
Employee future benefits	254	306
Renewable energy surcharge	122	126
Energy efficiency liability	89	89
Electric and gas moderator account	67	34
Alberta Electric System Operator charges deferral	58	21
Derivatives	54	224
Other regulatory liabilities	161	148
Total regulatory liabilities	3,717	3,915
Less: Current portion	(489)	(595)
Long-term regulatory liabilities	3,228	3,320

Schedule of Regulatory Liabilities

Detailed information about the Corporation's regulatory assets and liabilities is provided in Note 8 to the 2022 Annual Financial Statements. A summary follows.

	As at
	June 30,	December 31,
($ millions)	2023	2022
Regulatory assets
Deferred income taxes	1,897	1,874
Deferred energy management costs	463	445
Rate stabilization and related accounts	419	557
Employee future benefits	191	207
Deferred lease costs	135	132
Derivatives	118	84
Deferred restoration costs	109	91
Manufactured gas plant site remediation deferral	87	97
Generation early retirement costs	73	78
Other regulatory assets	464	444
Total regulatory assets	3,956	4,009
Less: Current portion	(730)	(914)
Long-term regulatory assets	3,226	3,095
Regulatory liabilities
Future cost of removal	1,353	1,306
Deferred income taxes	1,271	1,364
Rate stabilization and related accounts	288	297
Employee future benefits	254	306
Renewable energy surcharge	122	126
Energy efficiency liability	89	89
Electric and gas moderator account	67	34
Alberta Electric System Operator charges deferral	58	21
Derivatives	54	224
Other regulatory liabilities	161	148
Total regulatory liabilities	3,717	3,915
Less: Current portion	(489)	(595)
Long-term regulatory liabilities	3,228	3,320

XML

Assets Held for Sale (Tables)

6 Months Ended

Jun. 30, 2023

Discontinued Operations and Disposal Groups [Abstract]

Schedule of Assets and Liabilities Held for Sale

As at June 30, 2023, the related assets and liabilities, as included in the Energy Infrastructure segment, were classified as held for sale and are detailed below.

As at ($ millions)	June 30, 2023
Cash and cash equivalents	19
Accounts receivable and other current assets	30
Inventories	55
Property, plant and equipment, net	430
Goodwill	27
Total assets held for sale	561
Accounts payable and other current liabilities	20
Deferred income taxes	109
Total liabilities associated with assets held for sale	129

XML

Long-Term Debt (Tables)

6 Months Ended

Jun. 30, 2023

Debt Disclosure [Abstract]

Schedule of Long-Term Debt

	As at
	June 30,	December 31,
($ millions)	2023	2022
Long-term debt	27,704	26,921
Credit facility borrowings	1,562	1,657
Total long-term debt	29,266	28,578
Less: Deferred financing costs and debt discounts	(174)	(166)
Less: Current installments of long-term debt	(2,284)	(2,481)
	26,808	25,931

Significant Long-Term Debt Issuances		Interest
Year-to-Date June 30, 2023	Month	Rate					Use of
($ millions, except as noted)	Issued	(%)		Maturity	Amount		Proceeds
ITC
Unsecured senior notes	June	5.40	(1)	2033	US	500	(2) (3) (4)
Unsecured senior notes	June	4.95	(5)	2027	US	300	(2) (3) (4)
UNS Energy
Unsecured senior notes	February	5.50		2053	US	375	(2) (3)
FortisAlberta
Unsecured senior debentures	May	4.86		2053	200		(3) (4)
Central Hudson
Unsecured senior notes	March	5.68		2033	US	40	(3) (4)
Unsecured senior notes	March	5.78		2035	US	15	(3) (4)
Unsecured senior notes	March	5.88		2038	US	35	(3) (4)

(1)    ITC entered into interest rate locks which reduced the effective interest rate to 5.32%. See Note 13 to the Interim Financial Statements

(2)    Repay maturing long-term debt

(3)    General corporate purposes

(4)     Repay short-term and/or credit facility borrowings

(5)     Represents a second tranche of ITC's existing 4.95% senior notes, originally issued in 2022

Schedule of Credit Facilities

			As at
Credit facilities	Regulated	Corporate	June 30,	December 31,
($ millions)	Utilities	and Other	2023	2022
Total credit facilities	3,963	2,034	5,997	5,850
Credit facilities utilized:
Short-term borrowings (1)	(80)	—	(80)	(253)
Long-term debt (including current portion) (2)	(792)	(770)	(1,562)	(1,657)
Letters of credit outstanding	(57)	(38)	(95)	(128)
Credit facilities unutilized	3,034	1,226	4,260	3,812

(1)    The weighted average interest rate was 6.7% (December 31, 2022 - 4.9%).

(2)    The weighted average interest rate was 6.0% (December 31, 2022 - 5.1%). The current portion was $1,114 million (December 31, 2022 - $1,376 million).

XML

Employee Future Benefits (Tables)

6 Months Ended

Jun. 30, 2023

Retirement Benefits [Abstract]

Schedule of Net Benefit Costs

The net benefit cost is detailed below.

	Defined Benefit Pension Plans		OPEB Plans
($ millions)	2023	2022	2023	2022
Quarter ended June 30
Service costs	16	26	6	8
Interest costs	40	28	7	6
Expected return on plan assets	(50)	(48)	(5)	(5)
Amortization of actuarial (gains) losses	(3)	1	(5)	(3)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	2	(3)	1	1
Net benefit cost	4	3	3	6
Year-to-date June 30
Service costs	31	52	11	17
Interest costs	80	56	15	11
Expected return on plan assets	(100)	(97)	(11)	(11)
Amortization of actuarial (gains) losses	(5)	2	(9)	(5)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	6	(5)	3	2
Net benefit cost	11	7	8	13

XML

Other Income, Net (Tables)

6 Months Ended

Jun. 30, 2023

Other Income and Expenses [Abstract]

Schedule of Other Income, Net

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Equity component, allowance for funds used during construction	23	18	46	35
Interest income (1)	18	2	34	3
Non-service component of net periodic benefit cost	16	25	32	49
Gain (loss) on derivatives, net	3	(2)	12	2
Gain (loss) on retirement investments, net	—	(9)	4	(17)
Other	4	1	5	5
	64	35	133	77

(1)    Includes interest on short-term deposits, as well as interest on regulatory deferrals, including the PPFAC at TEP and UNSE

XML

Earnings Per Common Share (Tables)

6 Months Ended

Jun. 30, 2023

Earnings Per Share [Abstract]

Schedule of Net Earnings to Common Shareholders

Diluted earnings per share ("EPS") was calculated using the treasury stock method for stock options.

	2023			2022
	Net Earnings	Weighted		Net Earnings	Weighted
	to Common	Average		to Common	Average
	Shareholders	Shares	EPS	Shareholders	Shares	EPS
	($ millions)	(# millions)	($)	($ millions)	(# millions)	($)
Quarter ended June 30
Basic EPS	294	485.4	0.61	284	477.8	0.59
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	294	485.7	0.61	284	478.3	0.59
Year-to-date June 30
Basic EPS	731	484.3	1.51	634	476.8	1.33
Potential dilutive effect of stock options	—	0.3		—	0.5
Diluted EPS	731	484.6	1.51	634	477.3	1.33

XML

Supplementary Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2023

Supplemental Cash Flow Elements [Abstract]

Schedule of Supplementary Cash Flow Information

	Quarter		Year-to-Date
($ millions)	2023	2022	2023	2022
Periods ended June 30
Change in working capital
Accounts receivable and other current assets	208	49	489	(46)
Prepaid expenses	(19)	17	(19)	22
Inventories	(29)	(114)	62	(45)
Regulatory assets - current portion	164	(31)	160	(43)
Accounts payable and other current liabilities	(132)	9	(537)	17
Regulatory liabilities - current portion	25	30	22	32
	217	(40)	177	(63)
Non-cash investing and financing activities
Accrued capital expenditures	366	380	366	380
Common share dividends reinvested	102	92	205	186
Contributions in aid of construction	10	12	10	12

XML

Fair Value of Financial Instruments and Risk Management (Tables)

6 Months Ended

Jun. 30, 2023

Fair Value Disclosures [Abstract]

Fair Value Hierarchy

The following table presents assets and liabilities that are accounted for at fair value on a recurring basis.

($ millions)	Level 1 (1)	Level 2 (1)	Level 3 (1)	Total
As at June 30, 2023
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	82	—	82
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Foreign exchange contracts, total return swaps and interest rate lock (2)	—	7	—	7
Other investments (4)	144	—	—	144
	144	138	—	282
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(146)	—	(146)
Energy contracts not subject to regulatory deferral (5)	—	(7)	—	(7)
Cross-currency interest rate swaps (5)	—	(8)	—	(8)
	—	(161)	—	(161)
As at December 31, 2022
Assets
Energy contracts subject to regulatory deferral (2) (3)	—	304	—	304
Energy contracts not subject to regulatory deferral (2)	—	49	—	49
Other investments (4)	150	—	—	150
	150	353	—	503
Liabilities
Energy contracts subject to regulatory deferral (3) (5)	—	(164)	—	(164)
Energy contracts not subject to regulatory deferral (5)	—	(8)	—	(8)
Foreign exchange contracts, total return and cross-currency interest rate swaps (5)	—	(26)	—	(26)
	—	(198)	—	(198)

(1)Under the hierarchy, fair value is determined using: (i) level 1 - unadjusted quoted prices in active markets; (ii) level 2 - other pricing inputs directly or indirectly observable in the marketplace; and (iii) level 3 - unobservable inputs, used when observable inputs are not available. Classifications reflect the lowest level of input that is significant to the fair value measurement.

(2)Included in accounts receivable and other current assets or other assets

(3)Unrealized gains and losses arising from changes in fair value of these contracts are deferred as a regulatory asset or liability for recovery from, or refund to, customers in future rates as permitted by the regulators, with the exception of long-term wholesale trading contracts and certain gas swap contracts.

(4)Included in cash and cash equivalents and other assets

(5)Included in accounts payable and other current liabilities or other liabilities

Derivative Asset Contracts Under Master Netting Agreements and Collateral Positions

The Corporation has elected gross presentation for its derivative contracts under master netting agreements and collateral positions, which apply only to its energy contracts. The following table presents the potential offset of counterparty netting.

	Gross Amount	Counterparty
	Recognized in	Netting of	Cash Collateral
($ millions)	Balance Sheet	Energy Contracts	Received/Posted	Net Amount
As at June 30, 2023
Derivative assets	131	(34)	28	125
Derivative liabilities	(153)	34	—	(119)
As at December 31, 2022
Derivative assets	353	(54)	(63)	236
Derivative liabilities	(172)	54	—	(118)

Derivative Liability Contracts Under Master Netting Agreements and Collateral Positions

The Corporation has elected gross presentation for its derivative contracts under master netting agreements and collateral positions, which apply only to its energy contracts. The following table presents the potential offset of counterparty netting.

	Gross Amount	Counterparty
	Recognized in	Netting of	Cash Collateral
($ millions)	Balance Sheet	Energy Contracts	Received/Posted	Net Amount
As at June 30, 2023
Derivative assets	131	(34)	28	125
Derivative liabilities	(153)	34	—	(119)
As at December 31, 2022
Derivative assets	353	(54)	(63)	236
Derivative liabilities	(172)	54	—	(118)

Schedule of Volume of Derivative Activity

As at June 30, 2023, the Corporation had various energy contracts that will settle on various dates through 2029. The volumes related to electricity and natural gas derivatives are outlined below.

	As at
	June 30,	December 31,
	2023	2022
Energy contracts subject to regulatory deferral (1)
Electricity swap contracts (GWh)	447	586
Electricity power purchase contracts (GWh)	440	224
Gas swap contracts (PJ)	173	185
Gas supply contract premiums (PJ)	134	148
Energy contracts not subject to regulatory deferral (1)
Wholesale trading contracts (GWh)	3,960	1,886
Gas swap contracts (PJ)	26	34

(1)GWh means gigawatt hours and PJ means petajoules.

XML

Description of Business - Regulated Utilities (Details)	Jun. 30, 2023
Wataynikaneyap Power Limited Partnership
Public Utilities, General Disclosures [Line Items]
Equity investment ownership (percent)	39.00%
Belize Electricity
Public Utilities, General Disclosures [Line Items]
Equity investment ownership (percent)	33.00%
ITC
Public Utilities, General Disclosures [Line Items]
Controlling ownership interest (percent)	80.10%
Noncontrolling ownership (percent)	19.90%
Caribbean Utilities
Public Utilities, General Disclosures [Line Items]
Controlling ownership interest (percent)	60.00%

XML

Regulatory Matters (Details) $ in Millions, $ in Millions	1 Months Ended		6 Months Ended	12 Months Ended
	Jul. 31, 2023 USD ($)	May 31, 2023	Jun. 30, 2023	Dec. 31, 2022	Dec. 31, 2021 CAD ($)
AUC | REA Cost Recovery
Public Utilities, General Disclosures [Line Items]
Disallowed cost recovery, annual amount					$ 10
ITC Midwest | FERC | ITC Midwest Capital Structure Complaint
Public Utilities, General Disclosures [Line Items]
Equity component of capital structure (percent)				60.00%
Complaint, proposed reduction of equity component of capital structure				53.00%
TEP | General Rate Application
Public Utilities, General Disclosures [Line Items]
Equity component of capital structure (percent)			53.00%
Approved ROE			9.15%
TEP | Arizona Corporation Commission | PPFAC Mechanism
Public Utilities, General Disclosures [Line Items]
Approved rate, period		12 months
TEP | Administrative Law Judge | General Rate Application | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested increase in revenue	$ 102
Requested ROE	9.40%
Requested return on fair value increment	0.20%
Requested equity component of capital structure	54.32%
UNS Electric Inc. | Arizona Corporation Commission | PPFAC Mechanism
Public Utilities, General Disclosures [Line Items]
Approved rate, period		33 months
Central Hudson | New York Public Service Commission | General Rate Application | Subsequent Event
Public Utilities, General Disclosures [Line Items]
Requested ROE	9.80%
Requested equity component of capital structure	50.00%

XML

Segmented Information - Related-party and Inter-company Transactions (Details) - CAD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Related Party Transaction [Line Items]
Related party transactions	$ 0	$ 0	$ 0	$ 0
Revenue	2,594,000,000	2,487,000,000	5,913,000,000	5,322,000,000
Inter-segment loans	0		0		$ 0
Related Party
Related Party Transaction [Line Items]
Revenue	6,000,000	$ 7,000,000	15,000,000	$ 20,000,000
Accounts receivable	$ 4,000,000		$ 4,000,000		$ 7,000,000

XML

Segmented Information - Information by Reportable Segment (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Dec. 31, 2022
Segment Reporting Information [Line Items]
Revenue	$ 2,594	$ 2,487	$ 5,913	$ 5,322
Energy supply costs	787	797	2,099	1,880
Operating expenses	713	659	1,454	1,328
Depreciation and amortization	440	417	876	824
Operating income	654	614	1,484	1,290
Other income, net	64	35	133	77
Finance charges	323	266	638	524
Income tax expense	49	53	149	120
Net earnings	346	330	830	723
Non-controlling interests	35	30	66	57
Preference share dividends	17	16	33	32
Net earnings attributable to common equity shareholders	294	284	731	634
Additions to property, plant and equipment and intangible assets	982	885	1,936	1,800
Goodwill	12,183	11,911	12,183	11,911	$ 12,464
Total assets	64,081	59,954	64,081	59,954	$ 64,252
Inter-segment eliminations
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
Energy supply costs	0	0	0	0
Operating expenses	0	0	0	0
Depreciation and amortization	0	0	0	0
Operating income	0	0	0	0
Other income, net	0	0	0	0
Finance charges	0	0	0	0
Income tax expense	0	0	0	0
Net earnings	0	0	0	0
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	0	0	0	0
Additions to property, plant and equipment and intangible assets	0	0	0	0
Goodwill	0	0	0	0
Total assets	(29)	(150)	(29)	(150)
Regulated | Operating segments
Segment Reporting Information [Line Items]
Revenue	2,576	2,454	5,857	5,276
Energy supply costs	787	796	2,099	1,877
Operating expenses	695	645	1,412	1,290
Depreciation and amortization	439	412	870	814
Operating income	655	601	1,476	1,295
Other income, net	62	35	122	71
Finance charges	270	227	535	449
Income tax expense	74	74	199	172
Net earnings	373	335	864	745
Non-controlling interests	35	30	66	57
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	338	305	798	688
Additions to property, plant and equipment and intangible assets	982	879	1,934	1,789
Goodwill	12,183	11,884	12,183	11,884
Total assets	63,169	59,028	63,169	59,028
Regulated | Operating segments | ITC
Segment Reporting Information [Line Items]
Revenue	519	468	1,038	928
Energy supply costs	0	0	0	0
Operating expenses	125	120	260	243
Depreciation and amortization	103	94	204	186
Operating income	291	254	574	499
Other income, net	19	10	36	19
Finance charges	105	83	204	163
Income tax expense	49	41	96	82
Net earnings	156	140	310	273
Non-controlling interests	29	26	57	50
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	127	114	253	223
Additions to property, plant and equipment and intangible assets	264	272	600	607
Goodwill	8,127	7,900	8,127	7,900
Total assets	23,838	21,993	23,838	21,993
Regulated | Operating segments | UNS Energy
Segment Reporting Information [Line Items]
Revenue	661	648	1,401	1,186
Energy supply costs	262	272	599	482
Operating expenses	204	167	394	329
Depreciation and amortization	88	92	175	181
Operating income	107	117	233	194
Other income, net	12	3	26	6
Finance charges	37	30	73	61
Income tax expense	12	13	26	19
Net earnings	70	77	160	120
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	70	77	160	120
Additions to property, plant and equipment and intangible assets	183	159	368	321
Goodwill	1,829	1,779	1,829	1,779
Total assets	12,303	11,796	12,303	11,796
Regulated | Operating segments | Central Hudson
Segment Reporting Information [Line Items]
Revenue	317	281	759	656
Energy supply costs	121	101	328	263
Operating expenses	144	143	306	292
Depreciation and amortization	28	26	56	51
Operating income	24	11	69	50
Other income, net	13	15	27	30
Finance charges	15	13	33	26
Income tax expense	5	3	14	12
Net earnings	17	10	49	42
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	17	10	49	42
Additions to property, plant and equipment and intangible assets	78	65	156	129
Goodwill	597	581	597	581
Total assets	5,105	4,587	5,105	4,587
Regulated | Operating segments | FortisBC Energy
Segment Reporting Information [Line Items]
Revenue	362	396	1,117	1,090
Energy supply costs	141	181	518	535
Operating expenses	91	88	189	171
Depreciation and amortization	78	75	155	150
Operating income	52	52	255	234
Other income, net	9	5	16	9
Finance charges	43	35	84	71
Income tax expense	(5)	5	40	36
Net earnings	23	17	147	136
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	23	17	147	136
Additions to property, plant and equipment and intangible assets	125	134	239	264
Goodwill	913	913	913	913
Total assets	8,587	8,272	8,587	8,272
Regulated | Operating segments | FortisAlberta
Segment Reporting Information [Line Items]
Revenue	181	169	360	336
Energy supply costs	0	0	0	0
Operating expenses	44	42	86	84
Depreciation and amortization	67	61	131	121
Operating income	70	66	143	131
Other income, net	3	0	3	1
Finance charges	30	28	60	54
Income tax expense	2	3	5	7
Net earnings	41	35	81	71
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	41	35	81	71
Additions to property, plant and equipment and intangible assets	182	119	301	230
Goodwill	228	228	228	228
Total assets	5,718	5,328	5,718	5,328
Regulated | Operating segments | FortisBC Electric
Segment Reporting Information [Line Items]
Revenue	116	108	255	237
Energy supply costs	22	18	69	61
Operating expenses	31	33	61	66
Depreciation and amortization	24	17	48	34
Operating income	39	40	77	76
Other income, net	1	1	2	3
Finance charges	19	19	39	37
Income tax expense	3	3	4	5
Net earnings	18	19	36	37
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	18	19	36	37
Additions to property, plant and equipment and intangible assets	35	30	62	60
Goodwill	235	235	235	235
Total assets	2,625	2,565	2,625	2,565
Regulated | Operating segments | Other Electric
Segment Reporting Information [Line Items]
Revenue	420	384	927	843
Energy supply costs	241	224	585	536
Operating expenses	56	52	116	105
Depreciation and amortization	51	47	101	91
Operating income	72	61	125	111
Other income, net	5	1	12	3
Finance charges	21	19	42	37
Income tax expense	8	6	14	11
Net earnings	48	37	81	66
Non-controlling interests	6	4	9	7
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	42	33	72	59
Additions to property, plant and equipment and intangible assets	115	100	208	178
Goodwill	254	248	254	248
Total assets	4,993	4,487	4,993	4,487
Non-Regulated | Operating segments | Energy Infrastructure
Segment Reporting Information [Line Items]
Revenue	18	33	56	46
Energy supply costs	0	1	0	3
Operating expenses	10	8	20	20
Depreciation and amortization	1	4	5	8
Operating income	7	20	31	15
Other income, net	0	0	0	0
Finance charges	0	0	0	0
Income tax expense	1	1	7	2
Net earnings	6	19	24	13
Non-controlling interests	0	0	0	0
Preference share dividends	0	0	0	0
Net earnings attributable to common equity shareholders	6	19	24	13
Additions to property, plant and equipment and intangible assets	0	6	2	11
Goodwill	0	27	0	27
Total assets	685	776	685	776
Non-Regulated | Operating segments | Corporate and Other
Segment Reporting Information [Line Items]
Revenue	0	0	0	0
Energy supply costs	0	0	0	0
Operating expenses	8	6	22	18
Depreciation and amortization	0	1	1	2
Operating income	(8)	(7)	(23)	(20)
Other income, net	2	0	11	6
Finance charges	53	39	103	75
Income tax expense	(26)	(22)	(57)	(54)
Net earnings	(33)	(24)	(58)	(35)
Non-controlling interests	0	0	0	0
Preference share dividends	17	16	33	32
Net earnings attributable to common equity shareholders	(50)	(40)	(91)	(67)
Additions to property, plant and equipment and intangible assets	0	0	0	0
Goodwill	0	0	0	0
Total assets	$ 256	$ 300	$ 256	$ 300

XML

Allowance for Credit Losses (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Allowance for Credit Losses [Roll Forward]
Beginning of period	$ (59)	$ (53)	$ (58)	$ (53)
Credit loss expense	(3)	(5)	(11)	(10)
Credit loss deferral	(2)	0	(3)	0
Write-offs, net of recoveries	4	6	12	11
Foreign exchange	0	(1)	0	(1)
End of period	$ (60)	$ (53)	$ (60)	$ (53)

XML

Regulatory Assets and Liabilities - Schedule of Regulatory Assets and Liabilities (Details) - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Regulatory Assets [Line Items]
Total regulatory assets	$ 3,956	$ 4,009
Less: Current portion	(730)	(914)
Long-term regulatory assets	3,226	3,095
Regulatory Liabilities [Line Items]
Total regulatory liabilities	3,717	3,915
Less: Current portion	(489)	(595)
Long-term regulatory liabilities	3,228	3,320
Future cost of removal
Regulatory Liabilities [Line Items]
Total regulatory liabilities	1,353	1,306
Deferred income taxes
Regulatory Liabilities [Line Items]
Total regulatory liabilities	1,271	1,364
Rate stabilization and related accounts
Regulatory Liabilities [Line Items]
Total regulatory liabilities	288	297
Employee future benefits
Regulatory Liabilities [Line Items]
Total regulatory liabilities	254	306
Renewable energy surcharge
Regulatory Liabilities [Line Items]
Total regulatory liabilities	122	126
Energy efficiency liability
Regulatory Liabilities [Line Items]
Total regulatory liabilities	89	89
Electric and gas moderator account
Regulatory Liabilities [Line Items]
Total regulatory liabilities	67	34
Alberta Electric System Operator charges deferral
Regulatory Liabilities [Line Items]
Total regulatory liabilities	58	21
Derivatives | Energy contracts subject to regulatory deferral
Regulatory Liabilities [Line Items]
Total regulatory liabilities	54	224
Other
Regulatory Liabilities [Line Items]
Total regulatory liabilities	161	148
Deferred income taxes
Regulatory Assets [Line Items]
Total regulatory assets	1,897	1,874
Deferred energy management costs
Regulatory Assets [Line Items]
Total regulatory assets	463	445
Rate stabilization and related accounts
Regulatory Assets [Line Items]
Total regulatory assets	419	557
Employee future benefits
Regulatory Assets [Line Items]
Total regulatory assets	191	207
Deferred lease costs
Regulatory Assets [Line Items]
Total regulatory assets	135	132
Derivatives | Energy contracts subject to regulatory deferral
Regulatory Assets [Line Items]
Total regulatory assets	118	84
Regulatory Liabilities [Line Items]
Total regulatory liabilities	54	224
Deferred restoration costs
Regulatory Assets [Line Items]
Total regulatory assets	109	91
Manufactured gas plant site remediation deferral
Regulatory Assets [Line Items]
Total regulatory assets	87	97
Generation early retirement costs
Regulatory Assets [Line Items]
Total regulatory assets	73	78
Other
Regulatory Assets [Line Items]
Total regulatory assets	$ 464	$ 444

XML

Assets Held for Sale - Narrative (Details) - Held-for-Sale - Aitken Creek - CAD ($) $ in Millions	1 Months Ended	3 Months Ended		6 Months Ended
	May 31, 2023	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Ownership percentage sold	93.80%
Proceeds on disposition	$ 400
Earnings before tax, excluding the gain on disposition		$ 3	$ 14	$ 18	$ 7

XML

Assets Held for Sale - Schedule of Assets and Liabilities Held for Sale (Details) - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total assets held for sale	$ 561	$ 0
Total liabilities associated with assets held for sale	129	$ 0
Held-for-Sale | Aitken Creek
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash and cash equivalents	19
Accounts receivable and other current assets	30
Inventories	55
Property, plant and equipment, net	430
Goodwill	27
Total assets held for sale	561
Accounts payable and other current liabilities	20
Deferred income taxes	109
Total liabilities associated with assets held for sale	$ 129

XML

Long-Term Debt - Schedule of Long-Term Debt (Details) - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Debt Instrument [Line Items]
Long-term debt, excluding credit facility borrowings	$ 27,704	$ 26,921
Long-term debt	29,266	28,578
Less: Deferred financing costs and debt discounts	(174)	(166)
Less: Current installments of long-term debt	(2,284)	(2,481)
Long-term debt less current portion and deferred financing costs and debt discounts	26,808	25,931
Credit facility
Debt Instrument [Line Items]
Less: Current installments of long-term debt	(1,114)	(1,376)
Credit facility | Long-term credit facility borrowings
Debt Instrument [Line Items]
Long-term debt	$ 1,562	$ 1,657

XML

Long-Term Debt - Long-term Debt Issuances (Details) - Unsecured $ in Millions, $ in Millions	Jun. 30, 2023 USD ($)	May 31, 2023 CAD ($)	Mar. 31, 2023 USD ($)	Feb. 28, 2023 USD ($)	Dec. 31, 2022
ITC | Unsecured senior notes, 2033 maturity
Debt Instrument [Line Items]
Interest rate	5.40%
Debt instrument, face amount	$ 500
Effective interest rate	5.32%
ITC | Unsecured senior notes, 2027 maturity
Debt Instrument [Line Items]
Interest rate	4.95%
Debt instrument, face amount	$ 300
ITC | Unsecured senior notes, 2022 issuance, 2027 maturity
Debt Instrument [Line Items]
Interest rate					4.95%
UNS Energy | Unsecured senior notes, 2053 maturity
Debt Instrument [Line Items]
Interest rate				5.50%
Debt instrument, face amount				$ 375
FortisAlberta | Unsecured senior debentures, 2053 maturity
Debt Instrument [Line Items]
Interest rate		4.86%
Debt instrument, face amount		$ 200
Central Hudson | Unsecured senior notes, 2033 maturity
Debt Instrument [Line Items]
Interest rate			5.68%
Debt instrument, face amount			$ 40
Central Hudson | Unsecured senior notes, 2035 maturity
Debt Instrument [Line Items]
Interest rate			5.78%
Debt instrument, face amount			$ 15
Central Hudson | Unsecured senior notes, 2038 maturity
Debt Instrument [Line Items]
Interest rate			5.88%
Debt instrument, face amount			$ 35

XML

Long-Term Debt - Narrative (Details) $ in Millions, $ in Millions	1 Months Ended	6 Months Ended
	Nov. 30, 2022 CAD ($)	Jun. 30, 2023 CAD ($)	May 31, 2023 CAD ($)	May 31, 2023 USD ($)	Apr. 30, 2023 USD ($)	Dec. 31, 2022 CAD ($)	Dec. 31, 2022 USD ($)
Debt Instrument [Line Items]
Short-form base shelf prospectus, life	25 months
Short-form base shelf prospectus, principal amount, up to	$ 2,000
Short-form base shelf prospectus, remaining amount available		$ 2,000
Maximum borrowing capacity		$ 5,997				$ 5,850
ITC | Unsecured Committed Revolving Credit Facilities
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 1,000		$ 900
Corporate And Other - Credit Facilities | Unsecured Committed Revolving Credit Facilities
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 1,300
Corporate And Other - Credit Facilities | Unsecured Non-revolving Facility, 2024 Maturity
Debt Instrument [Line Items]
Maximum borrowing capacity				$ 500
No one bank | Bank concentration risk | Credit facility
Debt Instrument [Line Items]
Concentration risk percentage		20.00%
Committed facilities with maturities ranging from 2023 through 2028
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 5,700

XML

Long-Term Debt - Schedule of Credit Facilities (Details) - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Line of Credit Facility [Line Items]
Total credit facilities	$ 5,997	$ 5,850
Credit facilities utilized:
Short-term borrowings	(80)	(253)
Long-term debt (including current portion)	(29,266)	(28,578)
Letters of credit outstanding	(95)	(128)
Credit facilities unutilized	4,260	3,812
Current installments of long-term debt	$ 2,284	$ 2,481
Credit facility
Credit facilities utilized:
Long-term debt (including current portion), weighted average interest rate (percent)	6.00%	5.10%
Current installments of long-term debt	$ 1,114	$ 1,376
Credit facility
Credit facilities utilized:
Short-term borrowings	$ (80)	$ (253)
Short-term borrowings, weighted average interest rate (percent)	6.70%	4.90%
Credit facility
Credit facilities utilized:
Long-term debt (including current portion)	$ (1,562)	$ (1,657)
Regulated Utilities
Line of Credit Facility [Line Items]
Total credit facilities	3,963
Credit facilities utilized:
Letters of credit outstanding	(57)
Credit facilities unutilized	3,034
Regulated Utilities | Credit facility
Credit facilities utilized:
Short-term borrowings	(80)
Regulated Utilities | Credit facility
Credit facilities utilized:
Long-term debt (including current portion)	(792)
Corporate and Other
Line of Credit Facility [Line Items]
Total credit facilities	2,034
Credit facilities utilized:
Letters of credit outstanding	(38)
Credit facilities unutilized	1,226
Corporate and Other | Credit facility
Credit facilities utilized:
Short-term borrowings	0
Corporate and Other | Credit facility
Credit facilities utilized:
Long-term debt (including current portion)	$ (770)

XML

Employee Future Benefits - Schedule of Net Benefit Costs (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Defined Benefit Pension Plans
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service costs	$ 16	$ 26	$ 31	$ 52
Interest costs	40	28	80	56
Expected return on plan assets	(50)	(48)	(100)	(97)
Amortization of actuarial (gains) losses	(3)	1	(5)	2
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	2	(3)	6	(5)
Net benefit cost	4	3	11	7
OPEB Plans
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service costs	6	8	11	17
Interest costs	7	6	15	11
Expected return on plan assets	(5)	(5)	(11)	(11)
Amortization of actuarial (gains) losses	(5)	(3)	(9)	(5)
Amortization of past service credits/plan amendments	(1)	(1)	(1)	(1)
Regulatory adjustments	1	1	3	2
Net benefit cost	$ 3	$ 6	$ 8	$ 13

XML

Employee Future Benefits - Narrative (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Retirement Benefits [Abstract]
Defined contribution plan cost recognized	$ 13	$ 12	$ 29	$ 26

XML

Other Income, Net (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Other Income and Expenses [Abstract]
Equity component, allowance for funds used during construction	$ 23	$ 18	$ 46	$ 35
Interest income	18	2	34	3
Non-service component of net periodic benefit cost	16	25	32	49
Gain (loss) on derivatives, net	3	(2)	12	2
Gain (loss) on retirement investments, net	0	(9)	4	(17)
Other	4	1	5	5
Other income, net	$ 64	$ 35	$ 133	$ 77

XML

Earnings Per Common Share - Schedule of Earnings Per Share (EPS) (Details) - CAD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Net Earnings to Common Shareholders
Basic EPS	$ 294	$ 284	$ 731	$ 634
Potential dilutive effect of stock options	0	0	0	0
Diluted EPS	$ 294	$ 284	$ 731	$ 634
Weighted Average Shares
Basic EPS (shares)	485.4	477.8	484.3	476.8
Potential dilutive effect of stock options (shares)	0.3	0.5	0.3	0.5
Diluted EPS (shares)	485.7	478.3	484.6	477.3
EPS
Basic (CAD per share)	$ 0.61	$ 0.59	$ 1.51	$ 1.33
Diluted (CAD per share)	$ 0.61	$ 0.59	$ 1.51	$ 1.33

XML

Supplementary Cash Flow Information (Details) - CAD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Jun. 30, 2023	Jun. 30, 2022
Change in working capital
Accounts receivable and other current assets	$ 208	$ 49	$ 489	$ (46)
Prepaid expenses	(19)	17	(19)	22
Inventories	(29)	(114)	62	(45)
Regulatory assets - current portion	164	(31)	160	(43)
Accounts payable and other current liabilities	(132)	9	(537)	17
Regulatory liabilities - current portion	25	30	22	32
Changes in working capital	217	(40)	177	(63)
Non-cash investing and financing activities
Accrued capital expenditures	366	380	366	380
Common share dividends reinvested	102	92	205	186
Contributions in aid of construction	$ 10	$ 12	$ 10	$ 12

XML

Fair Value of Financial Instruments and Risk Management - Derivative Narrative (Details) $ in Millions, $ in Millions	1 Months Ended	3 Months Ended			6 Months Ended		12 Months Ended
	Mar. 31, 2023 CAD ($)	Jun. 30, 2023 CAD ($)	Jun. 30, 2023 USD ($)	Jun. 30, 2022 CAD ($)	Jun. 30, 2023 CAD ($)	Jun. 30, 2022 CAD ($)	Dec. 31, 2022 CAD ($)	Jun. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized losses recognized in regulatory assets		$ 3,956			$ 3,956		$ 4,009
Unrealized gains recognized as regulatory liabilities		3,717			3,717		3,915
Other investments
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains (losses) on investments		$ 1		$ (4)	$ 3	$ (9)
UNS Energy
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Realized gains, portion shared with customers (percent)					10.00%
Corporate | Unsecured senior notes, 2029 maturity | Unsecured
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, face amount							$ 500
Interest rate							4.43%		4.43%
ITC | Unsecured senior notes, 2033 maturity | Unsecured
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt instrument, face amount								$ 500
Interest rate		5.40%			5.40%			5.40%
Energy contracts
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized gains (losses) on energy contracts		$ (8)		19	$ 6	2
Total return swaps | Corporate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Notional amount		119			119
Unrealized gains (losses) on derivatives		(1)		(2)	$ 5	(8)
Total return swaps | Corporate | Minimum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative terms					1 year
Total return swaps | Corporate | Maximum
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative terms					3 years
Foreign exchange contracts | Corporate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Notional amount		393			$ 393
Unrealized gains (losses) on derivatives		5		2	7	2
Interest rate lock | Corporate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Notional amount	$ 100
Derivative terms	10 years
Unrealized gain recognized in other comprehensive income		$ 4			4
Interest rate lock | ITC
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Notional amount executed and settled			$ 500
Realized gain recognized in other comprehensive income			$ 4
Gain on derivative, reclassification adjustment period		10 years	10 years
Cross-currency interest rate swap | Corporate
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Notional amount									$ 391
Derivative terms							7 years
Unrealized gains (losses) on derivatives		$ 9		$ 12	10	$ 12
Derivative interest rate							4.34%		4.34%
Derivative instruments | Energy contracts subject to regulatory deferral
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Unrealized losses recognized in regulatory assets		118			118		$ 84
Unrealized gains recognized as regulatory liabilities		$ 54			$ 54		$ 224

XML

Fair Value of Financial Instruments and Risk Management - Fair Value Hierarchy (Details) - Recurring - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Assets
Other investments	$ 144	$ 150
Total Assets	282	503
Liabilities
Total Liabilities	(161)	(198)
Energy contracts subject to regulatory deferral
Assets
Derivative asset	82	304
Liabilities
Derivative liability	(146)	(164)
Energy contracts not subject to regulatory deferral
Assets
Derivative asset	49	49
Liabilities
Derivative liability	(7)	(8)
Foreign exchange contracts, total return, and interest rate swaps
Assets
Derivative asset	7
Cross-currency interest rate swap
Liabilities
Derivative liability	(8)
Foreign exchange contracts, total return and cross-currency interest rate swaps
Liabilities
Derivative liability		(26)
Level 1
Assets
Other investments	144	150
Total Assets	144	150
Liabilities
Total Liabilities	0	0
Level 1 | Energy contracts subject to regulatory deferral
Assets
Derivative asset	0	0
Liabilities
Derivative liability	0	0
Level 1 | Energy contracts not subject to regulatory deferral
Assets
Derivative asset	0	0
Liabilities
Derivative liability	0	0
Level 1 | Foreign exchange contracts, total return, and interest rate swaps
Assets
Derivative asset	0
Level 1 | Cross-currency interest rate swap
Liabilities
Derivative liability	0
Level 1 | Foreign exchange contracts, total return and cross-currency interest rate swaps
Liabilities
Derivative liability		0
Level 2
Assets
Other investments	0	0
Total Assets	138	353
Liabilities
Total Liabilities	(161)	(198)
Level 2 | Energy contracts subject to regulatory deferral
Assets
Derivative asset	82	304
Liabilities
Derivative liability	(146)	(164)
Level 2 | Energy contracts not subject to regulatory deferral
Assets
Derivative asset	49	49
Liabilities
Derivative liability	(7)	(8)
Level 2 | Foreign exchange contracts, total return, and interest rate swaps
Assets
Derivative asset	7
Level 2 | Cross-currency interest rate swap
Liabilities
Derivative liability	(8)
Level 2 | Foreign exchange contracts, total return and cross-currency interest rate swaps
Liabilities
Derivative liability		(26)
Level 3
Assets
Other investments	0	0
Total Assets	0	0
Liabilities
Total Liabilities	0	0
Level 3 | Energy contracts subject to regulatory deferral
Assets
Derivative asset	0	0
Liabilities
Derivative liability	0	0
Level 3 | Energy contracts not subject to regulatory deferral
Assets
Derivative asset	0	0
Liabilities
Derivative liability	0	0
Level 3 | Foreign exchange contracts, total return, and interest rate swaps
Assets
Derivative asset	0
Level 3 | Cross-currency interest rate swap
Liabilities
Derivative liability	$ 0
Level 3 | Foreign exchange contracts, total return and cross-currency interest rate swaps
Liabilities
Derivative liability		$ 0

XML

Fair Value of Financial Instruments and Risk Management - Derivative Contracts Under Master Netting Agreements and Collateral Positions (Details) (Details) - Energy contracts - CAD ($) $ in Millions	Jun. 30, 2023	Dec. 31, 2022
Derivative assets
Gross Amount Recognized in Balance Sheet	$ 131	$ 353
Counterparty Netting of Energy Contracts	(34)	(54)
Cash Collateral Received/Posted	28	(63)
Net Amount	125	236
Derivative liabilities
Gross Amount Recognized in Balance Sheet	(153)	(172)
Counterparty Netting of Energy Contracts	34	54
Cash Collateral Received/Posted	0	0
Net Amount	$ (119)	$ (118)

XML

Fair Value of Financial Instruments and Risk Management - Volume of Derivative Activity (Details) GJ in Millions	6 Months Ended	12 Months Ended
	Jun. 30, 2023 GJ GWh	Dec. 31, 2022 GJ GWh
Electricity swap contracts, Energy contracts subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GWh	447	586
Electricity power purchase contracts, Energy contracts subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GWh	440	224
Gas swap contracts, Energy contracts subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GJ	173	185
Gas supply contract premiums, Energy contracts subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GJ	134	148
Wholesale trading contracts, Energy contracts not subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GWh	3,960	1,886
Gas swap contracts, Energy Contracts not subject to regulatory deferral
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Volume (gwh / gj) | GJ	26	34

XML

Fair Value of Financial Instruments and Risk Management - Credit Risk Narrative (Details) - CAD ($) $ in Millions	6 Months Ended
	Jun. 30, 2023	Dec. 31, 2022
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Uncollectible write-off deferral, exceed customer rate collected threshold	0.0010
Value of derivative instruments in net liability positions	$ 52	$ 178
Revenue | Three customers | Customer concentration risk | ITC
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Concentration risk percentage	70.00%

XML

Fair Value of Financial Instruments and Risk Management - Foreign Exchange Hedge Narrative (Details) - Foreign net investments - USD ($) $ in Billions	Jun. 30, 2023	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Unhedged foreign net investments	$ 10.9	$ 10.6
Designated as hedging instrument
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Long-term debt designated as an effective hedge	$ 2.9	$ 2.9

XML

Fair Value of Financial Instruments and Risk Management - Financial Instruments Not Carried At Fair Value Narrative (Details) - CAD ($) $ in Billions	Jun. 30, 2023	Dec. 31, 2022
Carrying value
Debt Instrument [Line Items]
Long-term debt, including current portion	$ 29.3	$ 28.6
Estimated fair value
Debt Instrument [Line Items]
Long-term debt, including current portion	$ 26.9	$ 25.8

XML

Commitments and Contingencies - Narrative (Details)	Jun. 30, 2023 CAD ($)
FortisBC Holdings and Fortis | Claim related to pipeline rights
Site Contingency [Line Items]
Contingency accrual	$ 0